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204-061
1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: 23. BOTTOM 16" H40 108 9-5/8" L80 2613 7" L80 4861 3-1/2" L80 6050 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, N/A 422 sx Class G6.125" TUBING RECORD 184 sx LiteCrete8.5" 103863-1/2" SIZE DEPTH SET (MD) 10327 / 4788 PACKER SET (MD/TVD) 7301' MD / 3663' TVD 42" BOTTOM 12.25" 81 sx ArcticCrete Surface 525 sx AS III Lite, 415 sx LiteCrete 9.3# Surface 10327 10521 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG CONOCOPHILLIPS ALASKA WAG Gas 11/25/2021 204-061 / 321-528 50-103-20456-01-00 KRU 3S-24A2565' FNL, 1266' FEL, Sec.18, T12N, R8E, UM 268' FNL, 2471' FEL, Sec. 25, T12N, R7E, UM ALK 2616, ALK 4624 4/30/2004 12518' MD / 6054" TVD 7301' MD / 3663' TVD 24' P.O. BOX 100360, ANCHORAGE, ALASKA 99510-0360 475994 5993852 106' FNL, 2457' FEL, Sec. 25, T12N, R7E, UM 62.5# CASING WT. PER FT.GRADE 5/2/2004 CEMENTING RECORD 5985773 1740' MD / 1524' TVD SETTING DEPTH TVD 5985611 TOP HOLE SIZE AMOUNT PULLED 469967 469953 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. 108 4527 ADL380107, ADL025544, ADL0025551 Kuparuk Field / Kuparuk River Oil Pool 8 bbls 15.8 ppg Class G IA @ 9470-10303' 22 bbls 15.8 ppg Class G Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: T @9292-10350' T @10350-12412' Plugged and Abandoned Perforations Cemented: 12295-12318' MD and 5897-5913' TVD Gas-Oil Ratio: Surface Surface Per 20 AAC 25.283 (i)(2) attach electronic information 26# 12513 Surface 4784 Surface 40# Choke Size: Under retainer: 15 bbls 15.8 ppg class G Top of retainer: 14.4 bbls 15.8 ppg Class G Sr Res EngSr Pet GeoSr Pet Eng 505' MD / 503" TVD Oil-Bbl: Water-Bbl:Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 1:31 pm, Oct 30, 2023 Abandoned 11/25/2021 JSB RBDMS JSB 110723 DSR-11/16/23 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1740' 1524' Top of Productive Interval N/A 31. List of Attachments: Summary of Operations, Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Mike Callahan Digital Signature with Date:Contact Email: mike.callahan@conocophillips.com Contact Phone:(907) 231-2176 Staff Drilling Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Plugged and Abandoned TPI (Top of Producing Interval). Authorized Name and Formation Name at TD:Plugged and Abandoned Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange 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. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. 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. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Mike Callahan DN: CN=Mike Callahan, E=mike.callahan@conocophillips.com Reason: I am the author of this documentLocation: Date: 2023.10.30 12:13:59-08'00' Foxit PDF Editor Version: 12.1.2 Mike Callahan Component Description MD (ft)TVD (ft)Length (ft) 1 4-1/2" x 1" KBG-4-5 - SV 2,696' 1,939' 10' 2 4-1/2" x 1" KBG-4-5 - DV 6,968' 3,536' 10' 3 4-1/2" 3.813" X Profil e 6,994' 3,546' 5' 4 4-1/2" 3.813" X Profil e 7,092' 3,583' 5' 5 SLB Metris Evolve 10k Gauge 7,109' 3,589' 5' 6 5" OD Bullet Seal Assembly 7,128' 3,597' 15' 3-½” 9.2# L-80 SLHT Liner @ 12,513' MD / 6,050' TVD 16" 62.5 ppf H-40 Insulated Conductor @ 108' MD/TVD 7" 26# L-80 BTCM Intermediate casing @ 11,255' MD / 5,203' TVD Top Coyote 7,880' MD / 4,093' TVD 3S-24B Sidetrack Schematic X GLGL GLGL Liner Top Packer @ 10,327'' MD 9-5/8" 40# L-80 BTC Surface Casing set @ 4,527' MD / 2,613' TVD 4-1/2" 12.6# L-80 H563 Liner set @ 8,714' MD / 4,927' TVD CIBP / Whipstock @ 7,301' MD / 3,663' TVD Tubing cut pre- rig @ ~7500' MD Perfs @ 7,944' MD / 4,157' TVD to 7,953' MD / 4,166' TVD 7,957' MD / 4,170' TVD to 7,963' MD / 4,176' TVD Component Description MD (ft) TVD (ft) Length (ft) 7 5" x 15' Sealbore Extension 7,124' 3,595'15' 8 4-1/2" x 7" Liner Top Packer / Hanger 7,140' 3,601'10' 9 4-1/2" 3.813" XN Profil e 7,170' 3,613'4' 10 4-1/2" Float Collar + Landing Collar 8,829' 4,697'4' 11 4-1/2" Float Sho e 8,712' 4,737'3' Lower Completion Component Details 1 4 10-11 5 2 3 67 X N 8 4-1/2" 12.6# L-80 H563 Tubing seals @ 7,136' MD / 3,600' TVD Cement plug @ 9,292' MD (10/2/21) Upper Completion Component Details Lower Completion Component Details 9 X Confining Layer Top 6,500' MD / 3,358' TVD Page 1/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/21/2021 02:00 11/21/2021 14:00 12.00 MIRU, MOVE MOB P Move pits away from sub, move sub off 3S-611, remove tree from sub and hang 3S-24 tree in sub. Stage wellhead equipment behind well. Spot sub. Back pits into position. Identified damaged flow line. 0.0 0.0 11/21/2021 14:00 11/21/2021 18:00 4.00 MIRU, MOVE DMOB T Pull pits ahead. Remove damaged flexible flow line hose. Remove nipples from hose. Shorten and reinstall nipples, back pits in and install flowline 0.0 0.0 11/21/2021 18:00 11/21/2021 21:30 3.50 MIRU, MOVE MOB P Spot pits, berm, hook up service interconnects, steam, air, water, mud lines, etc. Work on post move checklist "RIG ACCEPTED AT 2130 Hrs" 0.0 0.0 11/21/2021 21:30 11/22/2021 00:00 2.50 MIRU, MOVE RURD P Take on 10.0 ppg NaCl/NaBr brine, RU circ equipment to tree, manifold and tiger tank. Load, strap and tally 4" 15.7# XT-39 DP in shed 0.0 0.0 11/22/2021 00:00 11/22/2021 00:30 0.50 MIRU, MOVE RURD P Take on 10.0 ppg NaCl/NaBr brine, RU circ equipment to tree, manifold and tiger tank. Load, strap and tally 4" 15.7# XT-39 DP in shed 0.0 0.0 11/22/2021 00:30 11/22/2021 02:30 2.00 MIRU, WELCTL MPSP P Pull H-BPV T= 0 psi, IA= 0 psi, OA= 0 psi 0.0 0.0 11/22/2021 02:30 11/22/2021 09:30 7.00 MIRU, WELCTL KLWL P Continue dilute brine, test lines to 3500 psi, circulate and displace out diesel and seawater with 10.1 ppg NaCl/NaBr brine @ 5 BPM, 1200 PSI down tubing out IA through choke house to tiger tank. Stopped to empty tiger tank twice. Take on additional load10.1 PPG NaCl/NaBr into pits. Pumped total of 584 Bbls before clean 10.1 PPG KWF was seen at surface. 0.0 0.0 11/22/2021 09:30 11/22/2021 10:00 0.50 MIRU, WELCTL OWFF P Observed well for flow - no flow 30 Min. 0.0 0.0 11/22/2021 10:00 11/22/2021 10:30 0.50 MIRU, WELCTL MPSP P Dry rod in BPV. 0.0 0.0 11/22/2021 10:30 11/22/2021 11:00 0.50 MIRU, WELCTL PRTS P Pressure test BPV from below T/ 1000 PSI for 10 Min - good test. 0.0 0.0 11/22/2021 11:00 11/22/2021 11:30 0.50 MIRU, WHDBOP RURD P R/D B/D circulating equipment. 0.0 0.0 11/22/2021 11:30 11/22/2021 15:30 4.00 MIRU, WHDBOP NUND P N/D tree, adapter. Function LDS. Dress hanger @ install blanking plug, screwed in 10 3/4 turns. 9 LH turns T/ M/U Acme. Top of blanking plug 1.15' 0.0 0.0 11/22/2021 15:30 11/22/2021 22:30 7.00 MIRU, WHDBOP NUND P N/U DSA, Stack. Change out flow block on kill side to block with rotating flange. Get RKB measurements. Change-out TD saver sub to 4" XT-39, Install riser. 0.0 0.0 11/22/2021 22:30 11/23/2021 00:00 1.50 MIRU, WHDBOP RURD P RU to test BOPE, MU 3.5" Test Joint 0.0 0.0 11/23/2021 00:00 11/23/2021 02:30 2.50 MIRU, WHDBOP BOPE P Initial BOPE test at 250/3500 PSI for 5 Min each, Tested annular, Upper 2-7/8 x 5 VBR w/ 3 1/2" test joint. Choke manifold valves 1-11, 16, 2” Demco, HCR Kill, Man Kill, Super choke and manual choke. "AOGCC Rep. Jeff Jones waived witness Test. 11/21/21 7:15 AM 0.0 0.0 11/23/2021 02:30 11/23/2021 04:30 2.00 MIRU, WHDBOP BOPE P Lock down screw dripping, Continue testing choke manifold, valves 12 and 13 and dart valve while FMC service LDS 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 Page 2/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/23/2021 04:30 11/23/2021 09:00 4.50 MIRU, WHDBOP BOPE P Continue Test BOPE with 3.5" test Jt. Lower 3.5" x 5.5" VBR, Koomy drawdown test, test blind rams, Manifold valves 14 and 15 , Upper and lower IBOPs, With 4.5" test joint, test upper and lower VBR's, Man and HCR choke, TIW, gas alarms, PVT and flow show. 0.0 0.0 11/23/2021 09:00 11/23/2021 10:00 1.00 SLOT, WELLPR RURD P Retrieve blanking plug, RD test JT, blow down lines 0.0 0.0 11/23/2021 10:00 11/23/2021 10:45 0.75 SLOT, WELLPR MPSP P Pull BPV with dry rod, OWFF 0.0 0.0 11/23/2021 10:45 11/23/2021 12:30 1.75 SLOT, WELLPR RURD P Rig up equipment to L/D 3 1/2 tubing. 7,478.0 7,445.0 11/23/2021 12:30 11/23/2021 13:00 0.50 SLOT, WELLPR THGR P MU landing Jt, BOLDS, Pull Hgr to floor with 120K initial, dropped to 70K, LD Hgr and Lndg Jt 7,478.0 7,445.0 11/23/2021 13:00 11/23/2021 14:00 1.00 SLOT, WELLPR CIRC P Circ. B/U @ 256gpm. 750 psi. 7,445.0 7,445.0 11/23/2021 14:00 11/23/2021 15:00 1.00 SLOT, WELLPR RURD P Back ups on the tongs were frozen and not dressed out with the correct size. 7,445.0 7,445.0 11/23/2021 15:00 11/24/2021 00:00 9.00 SLOT, WELLPR PULD P LD 3-1/2" Tubing 7,445.0 2,800.0 11/24/2021 00:00 11/24/2021 02:30 2.50 SLOT, WELLPR PULD P LD 3-1/2" Tubing. Complete recovery. 237 Jts, 16.17' cut-off ,2 GLM's, 2 pups and hanger w/ pup. Began seeing pitting on collars last 800' LD, 3rd jt below lower GLM had some pitting on tube 2,800.0 0.0 11/24/2021 02:30 11/24/2021 03:30 1.00 SLOT, WELLPR RURD P RD Tbg equip 0.0 0.0 11/24/2021 03:30 11/24/2021 04:30 1.00 SLOT, WELLPR OTHR P Install wear bushing 0.0 0.0 11/24/2021 04:30 11/24/2021 10:00 5.50 SLOT, WELLPR BHAH P PU and MU Baker scraper assy 0.0 751.0 11/24/2021 10:00 11/24/2021 18:00 8.00 SLOT, WELLPR PULD P Single in the hole with scraper assy. on 4" DP, tag 3.5" tubing stump at 7475' drill pipe measure. 751.0 7,475.0 11/24/2021 18:00 11/24/2021 20:00 2.00 SLOT, WELLPR CIRC P Std back one std to 7376' , circulate at 7 bpm, 1780 psi, rotate 60 rpm at 5K tq and reciprocate scraper from 7364' to 7268' 7,475.0 7,280.0 11/24/2021 20:00 11/24/2021 23:30 3.50 SLOT, WELLPR TRIP P POOH on trip tank to 751'. 10 min flow check 7,280.0 751.0 11/24/2021 23:30 11/25/2021 00:00 0.50 SLOT, WELLPR BHAH P LD BHA 751.0 78.0 11/25/2021 00:00 11/25/2021 01:30 1.50 SLOT, WELLPR BHAH P LD BHA, clear/clean floor 78.0 0.0 11/25/2021 01:30 11/25/2021 02:00 0.50 SLOT, WELLPR SVRG P Service rig 0.0 0.0 11/25/2021 02:00 11/25/2021 06:00 4.00 SLOT, WELLPR RURD P Spot Eline unit, RU Eline 0.0 0.0 11/25/2021 06:00 11/25/2021 13:00 7.00 SLOT, WELLPR ELOG P Perform USIT/CCL log run in casing evaluation mode 0.0 0.0 11/25/2021 13:00 11/25/2021 15:00 2.00 SLOT, WELLPR ELOG P Evaluate logs with town. CIBP set depth @ ˜7320’ 0.0 0.0 11/25/2021 15:00 11/25/2021 16:30 1.50 SLOT, WELLPR ELOG P M/U CIBP on E-line 0.0 0.0 11/25/2021 16:30 11/25/2021 20:00 3.50 SLOT, WELLPR ELOG P RIH and set CIBP @ 7,320' Center of element (Run speed 80' min), POOH w/ Eline/setting tool to surface 0.0 0.0 11/25/2021 20:00 11/25/2021 20:30 0.50 SLOT, WELLPR PRTS P RU and pressure test casing to 2030 psi for 10 min, RD 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 Page 3/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/25/2021 20:30 11/25/2021 21:30 1.00 SLOT, WELLPR ELOG P RD E-Line 0.0 0.0 11/25/2021 21:30 11/26/2021 00:00 2.50 PROD1, WHPST BHAH P MU whipstock BHA, orient MWD to WS face 0.0 113.0 11/26/2021 00:00 11/26/2021 01:30 1.50 PROD1, WHPST BHAH P MU whipstock BHA. 113.0 853.0 11/26/2021 01:30 11/26/2021 02:30 1.00 PROD1, WHPST DHEQ P RIH, Shallow hole test MWD (Good Test) 853.0 2,230.0 11/26/2021 02:30 11/26/2021 11:00 8.50 PROD1, WHPST WPST P Continue RIH w/ whipstock on 4" DP to 7,229 2,230.0 7,229.0 11/26/2021 11:00 11/26/2021 11:30 0.50 PROD1, WHPST CIRC P Break circulation @ 278 gpm 1280 psi. P/U= 105k S/O= 73k. Orient tool Face to 125. 7,229.0 7,229.0 11/26/2021 11:30 11/26/2021 12:00 0.50 PROD1, WHPST OTHR P Slack off to 7,319, recheck orientain. S/O and set the K anchor with 18K down wt. and shear out with 40k. Top of the wipstock 7,301' 7,229.0 7,319.0 11/26/2021 12:00 11/26/2021 14:00 2.00 PROD1, WHPST DISP P Displace well over from 10.1 ppg. NaCl to 10.0 ppg. LSND @ 280 gpm 1209 psi. 7,319.0 7,319.0 11/26/2021 14:00 11/26/2021 15:30 1.50 PROD1, WHPST WPST P Milling window f/ 7301' to 7303': @ 191 gpm, 975 psi. 80 rpm. 4.2k Tq. P/U= 105k S/O= 73 ROT= 83k O/A PSI= 0 7,301.0 7,303.0 11/26/2021 15:30 11/26/2021 20:00 4.50 PROD1, WHPST WPST P Milling window f/ 7303' to 7337': @ 191 gpm, 975 psi. 100 rpm. 4.7k Tq. P/U= 105k S/O= 73 ROT= 83k. Pumped high vis super sweep at 7314' Window 7301'-7314' O/A PSI= 0 7,303.0 7,314.0 11/26/2021 20:00 11/26/2021 21:00 1.00 PROD1, WHPST WPST P Milled 23' of rathole to 7337', Gives 3' gauge hole below BOW. 220 gpm, 1290 psi, 100 rpm, 4.6k tq, P/U= 110k S/O= 75 ROT= 80k 7,314.0 7,337.0 11/26/2021 21:00 11/26/2021 22:00 1.00 PROD1, WHPST CIRC P Circulated high vis super sweep around while dress window 4x. 220 gpm, 1290 psi, 100 rpm, 4.6k tq, P/U= 110k S/O= 75 ROT= 80k. Drift window no pump, no rotary, good. 7,337.0 7,268.0 11/26/2021 22:00 11/27/2021 00:00 2.00 PROD1, WHPST TRIP P Flow check, POOH on trip tank 7,268.0 4,153.0 11/27/2021 00:00 11/27/2021 03:00 3.00 PROD1, WHPST TRIP P POOH on trip tank, flow check 4,153.0 853.0 11/27/2021 03:00 11/27/2021 06:00 3.00 PROD1, WHPST BHAH P LD window milling assy, 853.0 0.0 11/27/2021 06:00 11/27/2021 07:30 1.50 PROD1, WHPST RURD P Clear and clean floor, stage BHA on floor, Jet BOPE stack, Flush Kill and Choke lines. 0.0 0.0 11/27/2021 07:30 11/27/2021 08:00 0.50 PROD1, WHPST SVRG P Service Top Drive, Reposition Rotary hose. 0.0 0.0 11/27/2021 08:00 11/27/2021 13:00 5.00 PROD1, WHPST BHAH P BHA: Make up motor to bit, make up and mwd, load source, run in HWDP 0.0 913.0 11/27/2021 13:00 11/27/2021 15:00 2.00 PROD1, WHPST PULD P RIH, Pick up 18 jnt of DP 913.0 1,489.0 11/27/2021 15:00 11/27/2021 16:30 1.50 PROD1, WHPST DHEQ T Shallow hole test directional tools. 1,489.0 1,489.0 11/27/2021 16:30 11/27/2021 18:00 1.50 PROD1, WHPST TRIP T MWD Failed POOH, rack HWDP/Jars 1,489.0 186.0 11/27/2021 18:00 11/27/2021 20:00 2.00 PROD1, WHPST BHAH T Pull source, Change out Digiscope, orient to motor 186.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 Page 4/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/27/2021 20:00 11/27/2021 21:30 1.50 PROD1, WHPST BHAH T MU LWD, load source 0.0 141.0 11/27/2021 21:30 11/27/2021 22:30 1.00 PROD1, WHPST TRIP T RIH HWDP/Jars and DP stds from derrick to 1489' 141.0 1,489.0 11/27/2021 22:30 11/27/2021 22:45 0.25 PROD1, WHPST DHEQ P Shallow hole test MWD ok 1,489.0 1,489.0 11/27/2021 22:45 11/28/2021 00:00 1.25 PROD1, WHPST PULD P RIH picking up 24 more Jts DP to 1943' 1,489.0 1,943.0 11/28/2021 00:00 11/28/2021 02:30 2.50 PROD1, WHPST TRIP P RIH with drilling assy 7251' 1,943.0 7,251.0 11/28/2021 02:30 11/28/2021 03:30 1.00 PROD1, WHPST TRIP P Orient TF, RIH through window to 7320', smooth, wash to bottom at 7337' 7,251.0 7,337.0 11/28/2021 03:30 11/28/2021 03:45 0.25 PROD1 , DRILL DDRL P Drill from 7337' MD to 7341' MD, 213 gpm, 1640 psi. AST=.17, ART= 0, ADFT=.17 hrs 7,337.0 7,341.0 11/28/2021 03:45 11/28/2021 04:45 1.00 PROD1 , DRILL RGRP T Pull std, rack back, repair TD brake, RIH to btm 7,341.0 7,341.0 11/28/2021 04:45 11/28/2021 12:00 7.25 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,341'- 7400' MD, 3713' TVD, 200 gpm, 1630 psi, FO 32%, WOB K, off bottom 1800 psi, PU 95, SO 65K, AST=8.03 , ADT 8.03, BIT=8.03, JARS=8.03 7,341.0 7,400.0 11/28/2021 12:00 11/28/2021 16:00 4.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,400'- 7416' MD, 3723' TVD, 200 gpm, 2100 psi, FO 32%, WOB 16K, off bottom 1900 psi, PU 95, SO 65K, AST=3.05 , ADT 11.08, BIT=11.08, JARS=11.08 7,400.0 7,416.0 11/28/2021 16:00 11/28/2021 19:30 3.50 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,416'- 7442' MD, 3739' TVD, 200 gpm, 2170 psi on/ 2010 psi off, FO 32%, 30RPM, 5.5K tq on, 5.0K tq off, WOB 16K, PU 95, SO 65K, ROT 80K, AST=0, ART= 3.62 , ADT 18.32, BIT=18.32, JARS=18.32 7,416.0 7,442.0 11/28/2021 19:30 11/29/2021 00:00 4.50 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,442'- 7608' MD, 3739' TVD, 200 gpm, 2170 psi on/ 2010 psi off, FO 32%, 13.73 ECD, 40RPM, 5.5K tq on, 5.0K tq off, WOB 18K, PU 95, SO 65K, ROT 80K, AST=2.92, ART= 1.17 , ADT= 4.09TADT 18.32, BIT=18.7, JARS=18.7 7,442.0 7,608.0 11/29/2021 00:00 11/29/2021 06:00 6.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,608'- 7695' MD, 3,852' TVD, 240 gpm, 2580 psi on/ 2450 psi off, FO 32%, 12.91 ECD, 40RPM, 5.5K tq on, 5.0K tq off, WOB 18K, PU 105, SO 80K, ROT 85K, 7,608.0 7,695.0 11/29/2021 06:00 11/29/2021 12:00 6.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,695'- 7,754' MD, 3,968' TVD, 240 gpm, 2820 psi on/ 2450 psi off, FO 32%, 12.91 ECD, 40RPM, 5.5K tq on, 5.0K tq off, WOB 20K, PU 100, SO 80K, ROT 85K, 7,695.0 7,754.0 11/29/2021 12:00 11/29/2021 14:30 2.50 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,754'- 7,784' MD, 3,993 TVD, 240 gpm, 2750 psi on/ 2520 psi off, FO 32%, 12.91 ECD, WOB 18-23K, PU 100, SO 65K 7,754.0 7,784.0 11/29/2021 14:30 11/29/2021 19:30 5.00 PROD1 , DRILL SIPB T Flow observed with pumps off, shut in well. SIDPP 260 psi, SICP 340 psi, CBU through choke adjusting choke to maintain min losses, no light fluid or hydrocarbons observed. 7,784.0 7,784.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 Page 5/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/29/2021 19:30 11/29/2021 23:00 3.50 PROD1 , DRILL SIPB T Bleed off ~2 bbls twice minimal pressure decrease, circ and warm up lines, bleed off 10 bbls twice, decreasing shut in pressures observed, CBU, no light fluids or hydrocarbons observed, bleed off 20 bbls, then attempt another 20 bbls, observing decreasing flow back trend, stop at 12 bbl gain due to time/cold, Decreasing trends observed indiicative of wellbore breathing. 7,784.0 7,784.0 11/29/2021 23:00 11/30/2021 00:00 1.00 PROD1 , DRILL SIPB T Circ and warm up lines, take on fluid, once fluid on and volumes stabilized, open choke 100% while circ at 2 bpm, gained 3 bbls then stabilized 7,784.0 7,784.0 11/30/2021 00:00 11/30/2021 00:30 0.50 PROD1 , DRILL SIPB T Pump off with choke open 100%, observed decreasing flow back trend. 2 bpm initial to .25 bpm final, open annular, slight flow observed 7,784.0 7,784.0 11/30/2021 00:30 11/30/2021 01:00 0.50 PROD1 , DRILL SIPB T Circulate at 2bpm to warrm lines, take on remainder of mud, blow down choke line, 7,784.0 7,784.0 11/30/2021 01:00 11/30/2021 02:15 1.25 PROD1 , DRILL SIPB T Stage up pump rate to drilling rate,240 gpm, 12.45 ECD minimal losses, shakers running wet, simulate connection 2X to obtain flow back signature 7,784.0 7,784.0 11/30/2021 02:15 11/30/2021 06:00 3.75 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,784'- t/7,842' MD, 4000 TVD, 240 gpm, 2300psi. 2200 psi. off 7,784.0 7,842.0 11/30/2021 06:00 11/30/2021 12:00 6.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/' 7,784’ – 8,119' MD, 4320' TVD, 240 gpm, 2820 psi on/ 2450 psi off, FO 32%, 12.67 ECD, 40RPM, 5.5K tq on, 5.0K tq off, WOB 20K, PU 100, SO 80K, ROT 85K, 7,842.0 8,119.0 11/30/2021 12:00 11/30/2021 18:00 6.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 8,119'-8425' MD, 4645' TVD, 240 gpm, 2150 psi on/ 2050 psi off, FO 32%, 12.64 ECD, 40RPM, 7.3K tq on, 6.5K tq off, WOB 2-4K, PU 130, SO 75K, ROT 98K, 8,119.0 8,425.0 11/30/2021 18:00 12/1/2021 00:00 6.00 PROD1 , DRILL DDRL P TD 6 1/8" production section f/ 8425' - 8724' MD, 4944'TVD, 220 gpm, 2050 psi on/ 1930 psi off, FO 32%, 12.58 ECD, 40RPM, 7.3K tq on, 6.5K tq off, WOB 4-7K, PU 146 SO 88K, ROT 105K, 8,425.0 8,724.0 12/1/2021 00:00 12/1/2021 01:30 1.50 PROD1 , DRILL CIRC P Circulate and condition well, work DP, Survey, SPR #1 30 SPM=610 PSI 40 SPM=725 SPR #2 30 SPM=590 40 SPM=690. Empty cuttings tank. Load pits with fresh 10 PPG LSND Rack back stand 82, Pu single 31.14' 8,724.0 8,627.0 12/1/2021 01:30 12/1/2021 03:00 1.50 PROD1 , DRILL CIRC P Displace well over to clean 10ppg mud. 8,627.0 8,627.0 12/1/2021 03:00 12/1/2021 04:00 1.00 PROD1 , DRILL OWFF P Flow check for 30 minutes no flow. Load pits with 290 BBL's 10 PPG LSND for TOOH. 8,627.0 8,627.0 12/1/2021 04:00 12/1/2021 06:00 2.00 PROD1 , DRILL TRIP P TOOH from 8627' T/ 7382' Survey PUW= 105K 8,627.0 7,347.0 12/1/2021 06:00 12/1/2021 06:30 0.50 PROD1 , DRILL DLOG P Two Missed survey @ 7,347 & 7,382' 7,347.0 7,382.0 12/1/2021 06:30 12/1/2021 07:30 1.00 PROD1 , DRILL TRIP P TIH F/ 7,382' - T/7,740' 7,382.0 7,740.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 Page 6/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/1/2021 07:30 12/1/2021 11:00 3.50 PROD1 , DRILL DLOG P MAD pass log from 7,740' - T/ 7,459' 30 rpm 240 gpm 3.3 fpm pulling speed. 7,740.0 7,459.0 12/1/2021 11:00 12/1/2021 14:00 3.00 PROD1 , DRILL SLPC P Pull up throug the window to 7,243' . Slip and cut off drilling line 7,459.0 7,243.0 12/1/2021 14:00 12/1/2021 18:00 4.00 PROD1 , DRILL TRIP P TOOH F/7,243' - T/911.95' 7,243.0 913.1 12/1/2021 18:00 12/1/2021 18:15 0.25 PROD1 , DRILL OWFF P Observe well for flow. 913.1 913.1 12/1/2021 18:15 12/1/2021 18:45 0.50 PROD1 , DRILL BHAH P LD 2 singles and jars. 913.0 823.9 12/1/2021 18:45 12/1/2021 20:00 1.25 PROD1 , DRILL BHAH P Stand back HWDP. 823.9 186.3 12/1/2021 20:00 12/1/2021 23:00 3.00 PROD1 , DRILL BHAH P LD BHA Filter sub, collar, stabilizer, stage equipment and remove source. Bit gauged 6.125" 186.3 0.0 12/1/2021 23:00 12/1/2021 23:30 0.50 PROD1 , DRILL CLEN P Clean and clear rig floor 0.0 0.0 12/1/2021 23:30 12/2/2021 00:00 0.50 PROD1 , DRILL BOPE P Drain stack, pull bowl protector. 0.0 0.0 12/2/2021 00:00 12/2/2021 04:00 4.00 PROD1 , DRILL BOPE P Set test plug and 4" test joint, Tested annular preventer, HCR choke, HCR kill, and choke valve 7 to 250/3500 PSI for 5 minutes per AOGCC regulation. State witness waived by Lou Laubenstein. Re- set bowl protector. 0.0 0.0 12/2/2021 04:00 12/2/2021 05:00 1.00 PROD1 , DRILL RURD P Rig up to run 4.5 Liner. 0.0 0.0 12/2/2021 05:00 12/2/2021 10:30 5.50 COMPZ1, CASING PUTB P Pick up shoe track and test floats (good test) TIH with 4 ½ 12.6# L-80 Hyd. 563 Liner 0.0 1,191.0 12/2/2021 10:30 12/2/2021 13:30 3.00 COMPZ1, CASING OTHR P Pick up Packer3 1,191.0 1,191.0 12/2/2021 13:30 12/2/2021 16:00 2.50 COMPZ1, CASING OTHR P Drift HWDP out ofthe derrick (Drift froze in third stand off HWDP) 1,191.0 1,515.0 12/2/2021 16:00 12/3/2021 00:00 8.00 COMPZ1, CASING RUNL P TIH with 4 ½ 12.6# L-80 Hyd. 563 Liner on 4" DP. F/1515 T/8700' filling every 20 stands. PU 1 single and 4 5' pups. Spot in cementers and support trucks. Clean pill pit. 1,515.0 8,700.0 12/3/2021 00:00 12/3/2021 01:00 1.00 COMPZ1, CASING RUNL P RIH with liner from 8700 to 8714' MU Cement head to DP. PUW-=125K SOW=80K 8,700.0 8,714.0 12/3/2021 01:00 12/3/2021 04:30 3.50 COMPZ1, CASING CIRC P Condition well PR=37 SPM DP=640 PSI. Circulate SxS 0.0 0.0 12/3/2021 04:30 12/3/2021 08:00 3.50 COMPZ1, CASING CMNT P 15 bbl. of H2O, test surface lines to 2000 psi. (good test) pump 25bbl. Tuned Spacer with red die @ 4BPM, 900 PSI, 32% F/, Start batching . Pump 37.8 bbls of 15.8 ppg G blend. cement at 4 bpm, psi, F/O 32%. Drop top plug swap over & kick out with 25 bbls 10.1 duo-vis pill. displace w/ 10.1 ppg LSND @ 3 bpm, 635 psi, F/O 32%. Reduced rate to 2 bpm 435 psi. Bump plug with 1.3 over calculated . final circ. psi. 1848 Pressure up to 2000 hold for 5 minutes. Bleed off pressure, Check floats good. CIP 05:52 hrs 12/03/21. No losses, 0.0 0.0 12/3/2021 08:00 12/3/2021 09:00 1.00 COMPZ1, CASING HOSO P Set ZXP Top Liner packer, 0.0 0.0 12/3/2021 09:00 12/3/2021 10:00 1.00 COMPZ1, CASING CIRC P Circ. B/U. 5bbl. of cement was observed at surface 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 Page 7/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/3/2021 10:00 12/3/2021 11:00 1.00 COMPZ1, CASING RURD P Rig down cement head 0.0 0.0 12/3/2021 11:00 12/3/2021 11:30 0.50 COMPZ1, CASING PRTS P Rig up and test packer to 2000 psi. hold for 10 min. 0.0 0.0 12/3/2021 11:30 12/3/2021 16:00 4.50 COMPZ1, CEMENT TRIP P POOH racking back D/P & HWDP and L/D Runnning Tool 0.0 0.0 12/3/2021 16:00 12/3/2021 17:00 1.00 COMPZ1, CEMENT BHAH P P/U M/U Polishing Mill BHA. 0.0 0.0 12/3/2021 17:00 12/3/2021 21:00 4.00 COMPZ1, CEMENT MILL P TIH to the Top of the PBR @ 7,125' 0.0 7,125.0 12/3/2021 21:00 12/3/2021 21:45 0.75 COMPZ1, CEMENT MILL P Tag No-Go at liner top at 7126' PU=125 top of liner at 7130' Establish milling parameters. PUW= 120 SOW=60 Rot Tq=6.3 at 40 RPM Rot Tq = 6.7K at 60 RPM 200 GPM=1400 PSI 300 GPM=1400 PSI Dressed PBR 3 times at 40 RPM 300 GPM Rot Tq=5K SOW=74K, 1200 PSI 7,125.0 12/3/2021 21:45 12/3/2021 22:30 0.75 COMPZ1, CEMENT CIRC P Stopped rotating, picked mill up off top of PBR. Reciprocate DP roll well over to 9.4PPG corrosion inhibited NaCl brine. 12/3/2021 22:30 12/4/2021 00:00 1.50 COMPZ1, CEMENT SVRG T Replace service loop on Top-drive. 12/4/2021 00:00 12/4/2021 13:00 13.00 COMPZ1, CEMENT SVRG T Replace service loop on Top-drive. steam out trip tank and clean pits. Clean and clear rig floor for L/D DP. 7,105.0 7,105.0 12/4/2021 13:00 12/4/2021 21:30 8.50 COMPZ1, CEMENT PULD P L/D 4" DP & HWDP 7,105.0 25.0 12/4/2021 21:30 12/4/2021 22:00 0.50 COMPZ1, CEMENT BHAH P L/D BHA 25.0 0.0 12/4/2021 22:00 12/4/2021 22:30 0.50 COMPZ1, CEMENT CLEN P Clean and clear floor, Pull bowl protector, Jet BOP stack 0.0 0.0 12/4/2021 22:30 12/4/2021 23:00 0.50 COMPZ1, CEMENT SVRG P Service top drive 0.0 0.0 12/4/2021 23:00 12/5/2021 00:00 1.00 COMPZ1, CEMENT RURD P Move 3rd party equip. to floor, SLB spooler unit, I wire clamps, ETC. 0.0 0.0 12/5/2021 00:00 12/5/2021 02:00 2.00 COMPZ1, CEMENT RURD P Continue to set up floor to run completion. Clean Pits. 0.0 0.0 12/5/2021 02:00 12/5/2021 19:00 17.00 COMPZ1, RPCOMP RCST P RIH W/4-1/2" 12.6# L-80 Hyd 563 completion. F surface T/7127' Tagged on No-Go, Bottom of seals at 7143' PUW=95K SOW=50K 0.0 7,143.0 12/5/2021 19:00 12/6/2021 00:00 5.00 COMPZ1, RPCOMP HOSO P Spaced out completion .83' off tag, bottom of seals at 7143.61'. MU Pup joints 7.87', 7.87', 7.88', 5.79'. OAL= 29.41' Space out pups. PU Hanger and landing joint terminate I-wire. Test termination at hanger to 5000 psi for 10 minutes. Verify continuity on gauge. 7,143.0 7,143.6 12/6/2021 00:00 12/6/2021 01:00 1.00 COMPZ1, RPCOMP HOSO P Land tubing hanger RILDS torque to 450 Ft/Lbs. 7,143.6 7,143.6 12/6/2021 01:00 12/6/2021 03:30 2.50 COMPZ1, RPCOMP PRTS P Pressure test tubing to 3500 PSI for 30 Minutes. Bled pressure back to 1500 PSI on tubing pressured 7" casing up to 2150 PSI tested for 30 minutes. 7,143.6 7,143.6 12/6/2021 03:30 12/6/2021 04:30 1.00 COMPZ1, RPCOMP RURD P Rig down test equipment set BPV test from below to 1000 psi for 10 minutes good. 7,143.6 7,143.6 12/6/2021 04:30 12/6/2021 12:00 7.50 COMPZ1, RPCOMP OTHR P Perform between well maintenance on BOPE 7,143.6 7,143.6 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 Page 8/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/6/2021 12:00 12/6/2021 15:00 3.00 COMPZ1, WHDBOP NUND P N/D BOPE 7,143.6 7,143.6 12/6/2021 15:00 12/7/2021 00:00 9.00 COMPZ1, WHDBOP NUND P NU adpater and tree test, adapter to 5000 PSI. Terminate and test I-wire. 7,143.6 7,143.6 12/7/2021 00:00 12/7/2021 01:00 1.00 COMPZ1, WHDBOP NUND P NU tree and tested to 5000 PSI for 10 minutes. 7,143.6 7,143.6 12/7/2021 01:00 12/7/2021 02:00 1.00 COMPZ1, WHDBOP NUND P Pulled HP-BPV. 12/7/2021 02:00 12/7/2021 03:30 1.50 COMPZ1, WHDBOP FRZP P Pumped 68 BBLS freeze protect down annulus. U-Tube well till 0 psi on tubing and IA. Blow down and disconnect hardline from tree and wellhead. 12/7/2021 03:30 12/7/2021 04:30 1.00 COMPZ1, WHDBOP MPSP P Set 4" H-BPV in tubing hanger. Rig released Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϬϰϬϲϭϬ Ͳ^Ğƚ͗ϯϲϭϰϴJRBy Abby Bell at 1:43 pm, Dec 21, 2021 3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21 ! 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Jill Simek Digitally signed by Jill Simek Date: 2021.10.19 17:20:55 -08'00' Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM post cement plug 9,292.0 10/2/2021 3S-24A fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag TOC 10/2/2021 3S-24A fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.0 Set Depth (ftKB) 4,527.3 Set Depth (TVD)… 2,613.2 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 26.5 Set Depth (ftKB) 11,255.0 Set Depth (TVD)… 5,203.2 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description WINDOW OD (in) 7 ID (in) 6.00 Top (ftKB) 10,509.0 Set Depth (ftKB) 10,522.0 Set Depth (TVD)… 4,861.6 Wt/Len (l… 26.00 Grade L-80 Top Thread Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 10,326.7 Set Depth (ftKB) 12,513.0 Set Depth (TVD)… 6,050.0 Wt/Len (l… 9.20 Grade L-80 Top Thread SLHT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 10,326.7 4,784.2 67.20 PACKER BAKER 5" X 7" ZXP HR LINER TOP ISOLATION PACKER 5.000 10,345.6 4,791.6 67.08 NIPPLE RS PACKOFF SEAL NIPPLE 5.50" X 4.25" 4.250 10,348.4 4,792.6 67.06 HANGER BAKER 5" X 7" FLEXLOCK LINER HANGER 5.000 10,357.7 4,796.3 67.00 SBE BAKER 80-40 SEAL BORE EXTENSION 5.00" X 4.00" 4.000 10,376.9 4,803.8 66.88 XO BUSHING XO Bushing, 5" TKC X 3-1/2" SLHT 5.57" X 3.00" 3.000 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.4 Set Depth (ft… 10,386.5 Set Depth (TVD) (… 4,807.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rdEUE Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 23.4 23.4 0.12 HANGER FMC 5M GEN V TUBING HANGER 2.992 504.9503.2 10.17 NIPPLE CAMCO 'DS' LANDING NIPPLE 2.875 10,302.9 4,775.067.31 SLEEVE-O BAKER CMU SLIDING SLEEVE w/ DS PROFILE - OPEN 2/18/12 2.813 10,349.3 4,793.0 67.06 LOCATOR BAKER G-22 LOCATOR SUB 3.000 10,350.1 4,793.367.05 SEAL ASSY SEAL ASSEMBLY with 1/2 MULE SHOE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 10,313. 0 4,778.9 67.26 LEAK TUBING LEAK, LDL, 1.3 BPM, 2900 PSI 7/4/2016 2.990 10,343. 0 4,790.5 67.10 LEAK TUBING LEAK, LDL, 1.3 BPM, 2900 PSI E/L CONFIRMED LEAK @ 10,313 IN PUP JT BELOW CMU, 1/20/2012 7/4/2016 2.990 12,000. 0 5,692.2 46.72CEMENT RETAINER 2.75" FH1 CEMENT RETAINER (2.75" X 1.45') 9/27/2021 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 12,295.0 12,318.0 5,896.7 5,912.7 C-4, 3S-24A 5/18/2004 6.0 IPERF 2.5" HSD, 60 deg phase, PJ 2506 HMX Charges, 1' Blank 12297-12298' due to TCP Connection between guns Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 10,350.0 12,412.0 4,793.3 5,978.7 Plug – Plug Back / Abandonment Plug 15 BBLS 15.8 PPG CLASS G CEMENT UNDER RETAINER SET AT 12000', 14.4 BBLS LAID IN ON TOP OF RETAINER. CMT TOP @10350 9/26/2021 9,470.010,303.0 4,462.7 4,775.0 Plug – Plug Back / Abandonment Plug 22 BBLS 15.8 PPG CLASS G CEMENT PUMPED INTO IA. CMT TOP @9470' 9/27/2021 9,292.0 10,350.0 4,395.6 4,793.3 Plug – Plug Back / Abandonment Plug 8 BBLS CLASS G LAID INTO TUBING TO 9292ft SLM 9/27/2021 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 4,248.1 2,507.5 67.00 Camco KBUG- M 1 GAS LIFT DMY BK-50.000 0.05/5/2004 2 7,355.7 3,683.2 67.72 Camco KBUG- M 1 GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 3 9,240.9 4,376.4 67.96 Camco KBUG- M 1 GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 4 10,252.9 4,755.8 67.53 Camco KBUG- M 1GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 Notes: General & Safety End Date Annotation 5/5/2004NOTE: SIDETRACKED WELL; OLD PERFS CEMENT SQUEEZED 3S-24A, 10/19/2021 3:13:43 PM Vertical schematic (actual) LINER; 10,326.7-12,513.0 IPERF; 12,295.0-12,318.0 CEMENT RETAINER; 12,000.0 INTERMEDIATE; 26.5-11,255.0 WINDOW; 10,509.0-10,522.0 SEAL ASSY; 10,350.1 Plug – Plug Back / Abandonment Plug; 10,350.0 ftKB LOCATOR; 10,349.3 LEAK; 10,343.0 LEAK; 10,313.0 SLEEVE-O; 10,302.9 GAS LIFT; 10,252.9 Plug – Plug Back / Abandonment Plug; 9,470.0 ftKB Plug – Plug Back / Abandonment Plug; 9,292.0 ftKB GAS LIFT; 9,240.9 GAS LIFT; 7,355.7 SURFACE; 29.0-4,527.3 GAS LIFT; 4,248.1 NIPPLE; 504.9 CONDUCTOR; 28.0-108.0 HANGER; 23.4 Other String 1; 0.000 KUP PROD KB-Grd (ft) 33.67 Rig Release Date 6/12/2003 3S-24A ... TD Act Btm (ftKB) 12,518.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045601 Wellbore Status PROD Max Angle & MD Incl (°) 69.84 MD (ftKB) 3,853.08 WELLNAME WELLBORE Annotation Last WO: End Date 5/6/2004 H2S (ppm) 75 Date 11/16/2015 Comment SSSV: NIPPLE SUNDRY NOTICE 10-407 KRU 3S-24A Suspend October 19, 2021 ConocoPhillips Alaska, Inc. performed suspend operations on 3S-24A, commencing operations on September 10, 2021 and completing the suspension on October 2, 2021. A cement retainer was set at 12,000ft KB and 15 bbls of Class “G” cement was pumped through the retainer to the perforations. Coiled tubing then unstung from the cement retainer and placed 14.4 bbls of Class “G” cement to 10,350ft KB in the tubing. The next day, 30 additional bbls of cement was pumped, with coiled tubing, to place cement in tubing and IA. A State Witnessed tag found top of cement at 9,292ft SLM. The field Well Service Report Summary is attached. 15 bbls of Class “G” cement was pumped through the retainer to the perforations. placed g g 14.4 bbls of Class “G” cement to 10,350ft KB p p 30 additional bbls of p gy cement was pumped, with coiled tubing, to place cement in tubing and IA. , Planned TOC in tubing was to be ~10,000'. Tag was at 9292'. -WCB A cement retainer was set at 12,000ft KB As per 25.112 (c)(1)(D), the retainer was set between 50' and 500' above the perforated interval, as it was set at 12,000', and the uppermost perfs are at 12295'. The lowermost perfs are at 12318', and as per the same reg, cement must be pumped from the retainer to a minimum of 100' below the lowermost perfs, translating to a depth of 12418' (12000+318+100). TD is 12513, so there is sufficient depth for the cement. The 3-1/2" 9.2 lb/ft tubing has a capacity of .00870 bbl/ft. Thus, 418' of cement translates to 3.64 bbls (418 ft)(.00870 bbl/ft)=3.64 bbls. 15 bbls were pumped, so this requirement was easily met (roughly 11 bbls cement were probably squeezed into the perfs). -WCB g in the tubing. g 14.4 bbls of cement atop the retainer, inside the 3-1/2" tubing. This translates to 1655' ((14.4 bbls)/(.00870 bbl/ft)=1655')). The retainer depth is 12,000', and 12000'-1655'=10345', so the cement laid in up to 10350' makes sense. 8 bbls were laid in above that, "up to 9470" which also makes close sense (8bbls/.00870 bbl/ft = 920'...10352'-920'=9432). -WCB 22 bbls were then pumped through the sliding sleeve. The 3-1/2" x 7" capacity is .0264 bbl/ft, yielding 833' of annular cement [(22bbls)/(.0264 bbl/ft)=833']. The reported annular cement top of 9470' also makes sense, given the sliding sleeve depth of 10303' (10303-833=9470'). -WCB tag found top of cement at 9,292ft SLM pp, ! ! "# $ % &$ ' ( ( ) ) " $ ) ) " ) " ) * ! + ' & "! + ! ! # ! # $ & ) ( ) $ ' , % ' !, )! ! ' ) % ) ) ! ! ) ) ! ! ) ! )! % $ )) )) - ) !)! , % , ' % $ $ ) . ) %$ $ ) /) . # )' & 11 2 & !) ) + ! !' !) 3 " & ' ) $ ) ) " )! % $ )) )) - ) !)! , ' ( ( ) ) " ) ( ! ! # ! # $ & $ ' , % ' !, )! ! ' ) % . # )' & % 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: ___________________ 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A 3S-24A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 12,518 1674 psi 9,292' - Cement N/A Casing Collapse Structural Conductor 630 Surface 3,090 Intermediate 5,410 Production Liner 10,540 Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Baker ZXP HR Liner Top Isolation Packer 10,327' MD, 4,784' TVD 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:Mike Callahan Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6,052 12,513' 6,050' mike.callahan@conocophillips.com (907) 231-2176 12,295 - 12,318' 3-1/2" 5,897' - 5,913' 10/17/2021 12,513'2,186' 3-1/2" 6,050' 11,229' 4,498' Perforation Depth MD (ft): 11,255' 16" 9-5/8" 80' 5,203' 108' 4,527' 7" Length Size L-80 TVD Burst 4808' MD 7,240 3,280 5,750 108' 2,613' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL380107, ADL025544 204-061 P.O. Box 100360 Anchorage, AK 99510-0360 103-20456-01 ConocoPhillips Kuparuk Field / Kuparuk River Oil Pool 10,160 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 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 Senior Drilling Engineer Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:15 am, Oct 05, 2021 321-528 KRU Digitally signed by Mike Callahan DN: C=US, CN=Mike Callahan, E=mike.callahan@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021-10-05 10:00:33 Foxit PhantomPDF Version: 9.7.0 Mike Callahan VTL 10/6/21 BOP test to 3500 psig Annular preventer test to 2500 psig X DLB 10/05/2021 10-407 ; ADL0025551 DLB X DSR-10/5/21 50-103-20456-01-00 DLB X dts 10/6/2021 JLC 10/6/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.06 11:23:26 -08'00' RBDMS HEW 10/7/2021 Application for Plug to Redrill 3S-24A Saved: 5-Oct-21 3S—24A 10-403 Page 1 of 2 Printed: 5-Oct-21 3S-24A Application for Plug to Redrill 3S-24A Plug for Redrill Procedure Permit to Drill # 204-061 3S-24A is being plugged to drill the 3S-24B rotary sidetrack. The Kuparuk interval has been abandoned per the previously approved form 10-403 (sundry # 321-405). The 3-1/2” tubing is cemented, and cement was tagged on 10/2 at 9,292’ MD. This procedure is for the rig work to occur prior to milling the window for the 3S-24B sidetrack. Proposed Procedure: 1. MIRU Nabors 7ES on 3S-24A. 2. Install and test BOPE to 250 psi low / 3500 psi high (2500 psi annular) 3. Pull and lay down existing tubing (pre-rig cut at ~7500’). 4. Run casing scraper down to 7400’. 5. Set CIBP and whipstock at 7300’, oriented 180° for low-side exit. 6. Perform pressure test on 7” casing to 2000 psi. Subsequent work to mill window and drill the 3S-24B sidetrack is covered in the Permit to Drill previously submitted. Application for Plug to Redrill 3S-24A Saved: 5-Oct-21 3S—24A 10-403 Page 2 of 2 Printed: 5-Oct-21 Proposed Completion Schematic MEMORANDUM TO: Jim Regg-7 %0(Z%( ?ut P.I. Supervisor I FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 2, 2021 SUBJECT: Well Bore Plug & Abandonment KRU 3S -24A CPAI PTD 2040610; Sundry 321-405 Section: 18 - Township: 12N Range: 8E Meridian: Umiat 12,000 ft MD Drilling Rig: NA Rig -Elevation: NA Total Depth: 12518 ft MD Lease No.: ADL380107 Operator Rep: Sid Ferguson Suspend: X P&A: Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 4527 Feet Csg Cut@ Feet Intermediate: 7" O.D. Shoe@ 11255 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 3 1/2" O.D. Shoe@ 12513 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 4808 Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To Mw Above Veritied Tubing Retainer 12,000 ft MD 9292 ft MD Wireline tag OA 10 10 10 Initial 15 min 30 min 45 min Result Tubing 325 375 375 IA 2600 - 2550 - 2550 - P OA 10 10 10 Initial 15 min 30 min 45 min Result Tubing 1550 1525 1525 - IA 0 0 0 P OA 10 10 10 Remarks: Reservior abandonment plug to suspend well for future redrill. Returns from the slick line bailer looked like contaminated cement with the thickness of clay. Attachments: none rev. 11-28-18 2021-1002_Plug_Verification _KRU_3S-24A_bn ! " # $! % " &&&&&&&&&&&&&&&&&&& ' $ (" " ) *$ +,*# - #./$ 0/ 1 $ $ " # # ! 2 ,2 3 $ 4* 56 $ 7895 7 * :*5 7 * ;*5 7 + #* :* + #* ;* : 5 7 5:*7< =5:*7 ')1>$9 " / 6 = ;= ;:*5 7;*5 7 ' - " != * ? = +, *# # (+ * ) != " /6 /$< * 6 .;#*@ @ @ 6A@ " #@/$< ! 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"# ')1> + 6 I 6 I /6$*@ " $ + ;/ $" ::/ / $ ##$% %"& "& ' ##" $ '8"')'18 $()(*(+, $((---*, $((-- .8)(> ((.* ?,88-.8J J =44)8 -(*((-.(*( " =J/ * ;*5 7 G .8)(> $9 #//& 0/$$"& % %"& ' $ 1 2 81> '.-> "%%"&/"&$' G$ :*5 7 )140%)4->;* 8%(8- # -9'8'8 3 4*51451 4 6 By Samantha Carlisle at 12:10 pm, Aug 17, 2021 321-405 Jill Simek Digitally signed by Jill Simek Date: 2021.08.17 10:34:31 -08'00' X 10-407 X SFD 8/17/2021 SFD 8/17/2021 VTL 8/31/21 X DSR-8/17/21 SFD 8/17/2021 dts 8/31/2021 JLC 8/31/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.02 10:07:14 -08'00' RBDMS HEW 9/2/2021 !"# $ % &#' (")" ! *##+" ") ' *## !)#*,-"$ # )) '.(/ ,-#" 0' (/'" $1023- ! $.-* * * 0 1(/' # ! 10' 3' (/' ) " ") ) *##) ! )"!)$0# 0'3))$ %#45- ! "$ !)) 6!# (/ )# $.' # ) "#$3# 7 "$ )#& '1(/'$)"*## !)# ) %!"$7 8 (/' # #29#:& ! " # ! $! ! % ! ' 7) )* ;<'% !)# = >$':? # #"")) +")!' #" " #+"' ' :7;* !"!! /; " &'' ' ?$9: ) !)@ & *# ! '0A/ > , / > ! ") >6 " ) "+" !$ ) ': :"#' ' : >B' #"!$% # "$2%!$ ! ! %! 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y Samantha Carlisle at 9:42 am, Mar 01, 2021 321-100 Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2021.02.26 13:27:33 -09'00' DSR-3/1/21VTL 3/2/21 DLB 03/01/2021 X X 10-404 " 3/3/21 dts 3/3/2021 JLC 3/3/2021 RBDMS HEW 3/3/2021 ! """ # $%& '( (( ## ) # " * + , - ## . - /& # && &0-1. ( 2& * -& '" *2" &* "23 &# 4 2'&" *2 *&2' - * 201 ( 567( 8 9 *'& - '/& 2 # # (8 8 ( 0 2 :' **&- 0 -4 # ; &2' &## '* . # Lynn Aleshire Digitally signed by Lynn Aleshire Date: 2021.02.26 13:26:25 -09'00' !"#$#%& '() Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: RKB 10,438.0 9/3/2020 3S-24A condijw Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET RBP 9/3/2020 3S-24A condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 29.0 Set Depth (ftKB) 4,527.3 Set Depth (TVD)… 2,613.2 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 26.5 Set Depth (ftKB) 11,255.0 Set Depth (TVD)… 5,203.2 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description WINDOW OD (in) 7 ID (in) 6.00 Top (ftKB) 10,509.0 Set Depth (ftKB) 10,522.0 Set Depth (TVD)… 4,861.6 Wt/Len (l… 26.00 Grade L-80 Top Thread Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 10,326.7 Set Depth (ftKB) 12,513.0 Set Depth (TVD)… 6,050.0 Wt/Len (l… 9.20 Grade L-80 Top Thread SLHT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 10,326.7 4,784.2 67.20 PACKER BAKER 5" X 7" ZXP HR LINER TOP ISOLATION PACKER 5.000 10,345.6 4,791.6 67.08 NIPPLE RS PACKOFF SEAL NIPPLE 5.50" X 4.25" 4.250 10,348.4 4,792.6 67.06 HANGER BAKER 5" X 7" FLEXLOCK LINER HANGER 5.000 10,357.7 4,796.3 67.00 SBE BAKER 80-40 SEAL BORE EXTENSION 5.00" X 4.00" 4.000 10,376.9 4,803.8 66.88 XO BUSHING XO Bushing, 5" TKC X 3-1/2" SLHT 5.57" X 3.00" 3.000 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.4 Set Depth (ft… 10,386.5 Set Depth (TVD) (… 4,807.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection 8rdEUE Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 23.4 23.4 0.12 HANGER FMC 5M GEN V TUBING HANGER 2.992 504.9 503.2 10.17 NIPPLE CAMCO 'DS' LANDING NIPPLE 2.875 10,302.9 4,775.067.31 SLEEVE-O BAKER CMU SLIDING SLEEVE w/ DS PROFILE - OPEN 2/18/12 2.813 10,349.3 4,793.0 67.06 LOCATOR BAKER G-22 LOCATOR SUB 3.000 10,350.1 4,793.367.05 SEAL ASSY SEAL ASSEMBLY with 1/2 MULE SHOE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 10,313. 0 4,778.9 67.26 LEAK TUBING LEAK, LDL, 1.3 BPM, 2900 PSI 7/4/2016 2.990 10,343. 0 4,790.5 67.10 LEAK TUBING LEAK, LDL, 1.3 BPM, 2900 PSI E/L CONFIRMED LEAK @ 10,313 IN PUP JT BELOW CMU, 1/20/2012 7/4/2016 2.990 10,400. 0 4,812.966.72 PLUG2.72" P2P RBP W/ EQ VALVE, SN:CPEQ35034, FILL EXT, 8.02' OAL 9/3/2020 0.000 CPP35297 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 12,295.012,318.0 5,896.7 5,912.7 C-4, 3S-24A 5/18/2004 6.0 IPERF 2.5" HSD, 60 deg phase, PJ 2506 HMX Charges, 1' Blank 12297-12298' due to TCP Connection between guns Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 4,248.1 2,507.5 Camco KBUG- M 1 GAS LIFT DMY BK-50.000 0.05/5/2004 2 7,355.7 3,683.2 Camco KBUG- M 1 GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 3 9,240.9 4,376.4 Camco KBUG- M 1GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 4 10,252.9 4,755.8 Camco KBUG- M 1GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 Notes: General & Safety End Date Annotation 5/5/2004 NOTE: SIDETRACKED WELL; OLD PERFS CEMENT SQUEEZED 3S-24A, 9/3/2020 7:35:00 PM Vertical schematic (actual) LINER; 10,326.7-12,513.0 IPERF; 12,295.0-12,318.0 INTERMEDIATE; 26.5-11,255.0 WINDOW; 10,509.0-10,522.0 PLUG; 10,400.0 LEAK; 10,343.0 LEAK; 10,313.0 GAS LIFT; 10,252.9 GAS LIFT; 9,240.9 GAS LIFT; 7,355.7 SURFACE; 29.0-4,527.3 GAS LIFT; 4,248.1 NIPPLE; 504.9 CONDUCTOR; 28.0-108.0 KUP PROD KB-Grd (ft) 33.67 Rig Release Date 6/12/2003 3S-24A ... TD Act Btm (ftKB) 12,518.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045601 Wellbore Status PROD Max Angle & MD Incl (°) 69.84 MD (ftKB) 3,853.08 WELLNAME WELLBORE Annotation Last WO: End Date 5/6/2004 H2S (ppm) 75 Date 11/16/2015 Comment SSSV: NIPPLE Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 3S-24A 50-103-20456-01 n/a Kuparuk River Plug Setting Record Field- Final 2-Sep-20 0 1 2 3S-24A 50-103-20456-01 n/a Kuparuk River Plug Setting Record Field- Final 3-Sep-20 0 1 3 CPF-1A 50-029-21243-00 9067722868 Shallow Sands Water Flow Log Field & Processed 22-Sep-20 0 1 4 CPF-1A 50-029-21243-00 9067722868 Shallow Sands Water Flow Log Field & Processed 23-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 2040610 E-Set: 34352 12/08/2020 Abby Bell Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 3S-24A 50-103-20456-01 n/a Kuparuk River Plug Setting Record Field- Final 2-Sep-20 0 1 2 3S-24A 50-103-20456-01 n/a Kuparuk River Plug Setting Record Field- Final 3-Sep-20 0 1 3 CPF-1A 50-029-21243-00 9067722868 Shallow Sands Water Flow Log Field & Processed 22-Sep-20 0 1 4 CPF-1A 50-029-21243-00 9067722868 Shallow Sands Water Flow Log Field & Processed 23-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 2040610 E-Set: 34351 12/08/2020 Abby Bell • • RECEIVED STATE OF ALASKA JUL 19 ZOIb ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OGCC 1.Opens Abandon )"y" Rug Perforations F' Fracture Stimulate r Pull Tubing r kJperations shutdow n Performed: Suspend r Perforate r Other Stimulate Alter Casing 9 Change Approved Program Rug for Redrill fl Perforate New Pool r Repair Well Re-enter Susp Well r Other:Extend SPJP patch lw 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory I— 204-061 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 50-103-20456-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025544/ADL0025551/ADL0380107 KRU 3S-24A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12518 feet Plugs(measured) 2877 true vertical 6054 feet Junk(measured) N/A Effective Depth measured 12513 feet Packer(measured) 10286, 10347, 10350 true vertical 6050 feet (true vertical) 4768,4782,4793 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108 108' SURFACE 4498 9.625 4527 2613' WINDOW 13 7 10522 4862' INTERMEDIATE 11229 7 11255 5203' 4-..x•71- .....,,...,,,.,,,,..,,,� LINER 2186 3.5 12513 6050' Perforation depth: Measured depth: 12295-12318 True Vertical Depth: 5897-5913 SCANNED JAN 3 12017 Tubing(size,grade,MD,and TVD) 3.5, L-80, 10349 MD,4793 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO'DS'LANDING NIPPLE @ 505 MD and 503 TVD PACKER-UPPER WEATHERFORD ER PACKER @ 10286 MD and 4768 TVD PUMP-JET PUMP(PH-1013)#11 NOZZLE,#12 THROAT @ 10302 MD and 4775 TVD SLEEVE-0-BAKER CMU SLIDING SLEEVE W/DS PROFILE 10303 MD and 4775 TVD PACKER-LOWER WEATHERFORD ER PACKER @ 10347 MD and 4782 TVD SEAL ASSY-SEAL ASSEMBLY WITH 1/2 MULE SHOE @ 10350 MD and 4793 TVD 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 Casing Pressure Tubing Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a _ n/a n/a n/a 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development Pa Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas fl WDSPL r Printed and Bectronic Fracture Stimulation Data n GSTOR r WINJ r WAG 1""" GINJ r SUSP r SPLUG E 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 Dusty Freeborn/Jan Byrne 659-7126 Email: N1617@conocophillips.com Printed Name DuF eb n Title: Well Integrity Supervisor Signature Date:7/16/16 Form 10-404 Revised 5/2015 4 r1-4" r,I) l Submit Original Only RBDMS l)-I►!'I. 2 2 2016 • • • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUL 19 20th AOGCC 16th day of July 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Ms. Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3S-24A PTD 204-061 for a tubing patch set. The patch containing the surface powered jet pump was pulled, extended and reset to cover two tubing leaks that were identified at 10,313' and 10,343'. Please call Jan Byrne or myself if you have any questions. Regards, /671& Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 • • 3S-24A • DESCRIPTION OF WORK COMPLETED SUMMARY A B 1 2 Date Event Summary 3 02/19/16 Pulled upper ER packer of patch and upper spacer pipe containing existing SPJP from 4 10,289'. 5 6 02/21/16 Attempted CMIT-TxIA against lower section of spacer pipe. Failed. 7 02/22/16 Pulled lower section of spacer pipe from 10,271' and attempt CMIT-TxIA against lower ER 8 packer at 10,323. Failed. 9 10 07/01/16 Pulled lower ER packer from 10,323'. Reset ER packer at 10,321' 11 12 07/02/16 CMIT-TxIA failed against lower ER packer at 10,321'. Pulled packer. 13 14 07/03/16 Set WRP at 10,400'. CMIT-TxIA passed. 15 16 07/04/16 Ran LDL from 10,400'to surface. Leak found at 10,313' and 10,343'. Pulled WRP 17 18 07/05/16 Set Lower WP packer at 10,347. CMIT-TxIA passed. 19 07/06/16 Set lower section of patch, SPJP, upper section of patch, and upper WP packer at 10,286'. 20 MIT-T passed. 21 22 23 24 25 26 27 28 4. KUP PROD • 3S-24A ConocoPhillips lIv 8. Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/DWI Field Name Wellbore Statue nel)) MD(ftKB) Act BM,(9610) a Oyp 501032045601 KUPARUK RIVER UNIT PROD 69.84 3,853.08 12,518,0 ••• �• Comment 625(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 7S-24A,7/15201611'3100 AM SSSV:NIPPLE 75 11/16/2015 Last WO: 33.67 6/12/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,287.0 2/21/2016 Rev Reason:PULL JET PUMP/PACKERS,SET pproven 7/15/2016 PATCH,TAG,H2S GANGER;23.4 r u It Casing Strings Casing Description OD(In) ID(In) Top(WB) Set Depth MKS) Sat Depth(TVD)...Wt/Len(L..Grade Top Thread CONDUCTOR 16 15.062 28.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...WVLen)1...Grade Top Thread SURFACE 95/8 8.835 29B) (888)4,527.3 2,M... 40(00 Grad BTC Caning Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen p...Grade Top Thread 'a1°'INTERMEDIATE 7 6.276 26.5 11,255.0 5,203.2 26.00 L-80 BTCM '"Casing Description 00(10) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len It...Grade Top Thread WINDOW 7 6.000 10.509.0 10,522.0 4,861.6 26.00 1-80 Casing Description OD(In) ID(In) Top(ftKB) Set Depth(MKS) Set Depth(TVD)...Wt/Len(...Grade Top Thread CONDUCTOR:2a.0-108.0 . 4. LINER 3 1(2 2.992 10,326.7 12,513.0 6,050.0 9.20 L-BO SLHT Liner Details NIPPLE;504.9ES Nominal ID Top(ftKB) Top(TVD)IRKS) Top Incl(°) ttem Des Com (In) 10,326.7 4,784.2' 67.20'PACKER BAKER 5"X 7"ZXP HR LINER TOP ISOLATION 5.000 PACKER 14 GAS LIFT:4.294.110,345.6 4,791.6 67.08 NIPPLE RS PACKOFF SEAL NIPPLE 5.50"X4.25" 4.250 g: 10,348.4 4,792.6 67.06'HANGER BAKER 5"X 7"FLEXLOCK LINER HANGER 6.000 ?-1 10,357.7 4,796.3 67.(X)•,SBE BAKER 80-40 SEAL BORE EXTENSION 5.00"X 4.000 r p. 4.00' (t 1 10,376.9 4.803.8 66.88 XO BUSHING X0 Bushing,5"TKG X 3-72"SLHT 5.57"X 3.00" 3.000 Tubing Strings Tubing Description String Ma...I ID(In) I Top(ftKB) I Set Depth(ft...I Set Depth(TVD)(...I WI(1b/ft) `Grade I Top Connection TUBING 31/2 2.992 234 10,386.5 4,807.6 9.301 L-80 8r4EUE Mod SURFAC E;29.0-4,527.7- Completion Details Nominal 10 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) ltem Des Com (In) l' 23.4 23.4 0.12 HANGER FMC 5M GEN V TUBING HANGER 2.992 GAS LIFT;7,355.7 504.9 503.2 10.17 NIPPLE CAMCO'DS'LANDING NIPPLE 2.875 10,302.9 4,775.0' 67.31 SLEEVE-O BAKER CMU SLIDING SLEEVE ed DS PROFILE-OPEN 2.813 2/18/12 10,349.3 4,793.0 67.06 LOCATOR BAKER G-22 LOCATOR SUB 3.000' GAS LIFT;9,240.9 ri 10,350.1 4,793.3 67.05 SEAL ASSY SEAL ASSEMBLY with 1/2 MULE SHOE 3.000 Other In Hole(reline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (610B) (°) Des Corn Run Date ID(in) 10,285.5 4,768.3 67.39 SPACER 2.70"JJ TIE BACK W/30'SPACER PIPE 8 SNAP 7/5/2016 1.680 PIPE LATCH INTO LOWER PACKER GAS LIFT;10.252.0 [ 3; 10.309.6 4,777.6 67.28 PATCH 2.72"WFT UPPER WP PACKER(serd cp350144) 7/6/2016 1.680 W/7'SPACER PIPE,JET PUMP(ser#ph-1125, -- 811 nozzle/#12 throat), 9'SPACER PIPE 8 TIE BACK STINGER INTO • STRADDLE EXTENSION(oat=27.55) SPACER PIPE;10,205.5 10,347.0 4,792.1 67.07 PATCH 2.72 WP LOWER PACKER(oal=5.2) 7/5/2016 1.680 SLEEVE-0 10,302.0 L Perforations 8 Slots I Dena Top(TVD) Btm(TVD) (shots# Top(ftKB) etm(ftKB) (ftKB) (ftKB) Shot KB) Zone Date 1) Type Corn 12,295.0 12,318.0' 5,896.7' 5,912.7 0-4,3S-24A 5/18/2004 6.0 IPERF 2.5"HSD,60 deg phase, PATCH,10,309 s PJ 2506 HMX Charges, i'Blank 12297-12298' I-' - due to TCP Connection between guns g Mandrel Inserts St Ion N Top(TVD) Valve Latch Port Sl:e TRO Run Top(ftKB) (RKBJ Make Model OD(In) Sera Type Type (In) (psi) Run Date Com PATCH;10,347.0N i 1 4,248.1 2,507.5 Cameo KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 M LOCATOR:10.349.3 'i I '2 7,355.7 3,683.2 Camco 'KBUG- ' 1 GAS LIFT DMY BK-5 0.000 0.0 5/6/2004 I' M 3 9,240.9 4,376.4 Camco -MUG- 1 GAS LIFT DMY BK-5 0.000' 0.0 5/5/2004 a SEAL ASSY;10,350.1 4 10,252.9 4,755.8 Camp 'KBUG- ' 1'GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 �- M V Notes:General&Safety End Dale Annotation 5/5/2004 NOTE:SIDETRACKED WELL;OLD PERFS CEMENT SQUEEZED 11/30/2009 'NOTE:View Schematic w/Alaska Schematic9.0 WINDOW,10506.0-10 522 o 120/2012 NOTE:E/L CONFIRMED LEAK @ 10,313IN PUP JT BELOW CMU I INTERMEDIATE;26.5-11,255.0- l IPERF:12,395.0-12.318.0 LINER;10,326.7-12,513.0 .1 11c s � D ICTa2 3 20 • • 15 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 sC,ANNED MAY 1 1 2016 October 20, 2015 Commissioner Cathy Foerster d 4. ` 0 6.i Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 3 a.`7 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, c_xy (Tr j MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/20/2015 3H,3J,3Q&3S Pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3H-26 501032020800 1940290 9" NA 9" NA 4.3 10/9/2015 3J-18 500292270100 1961470 12" NA 12" NA 8 10/3/2015 3J-19 500292270200 1961480 11" NA 11" NA 4.25 10/5/2015 3Q-21 500292263000 1951930 12" NA 12" NA 5.5 10/9/2015 3S-6A 501032045401 2030880 11" NA 11" NA 9.1 10/3/2015 3S-23A 501032045301 2060430 16" NA 16" NA 6.2 10/3/2015 3S-24A 501032045601 2040610 18" NA 18" NA 6.3 10/3/2015 3S-26 501032036101 2010400 9" NA 9" NA 3.8 10/3/2015 y., F y. STATE OF ALASKA l n, ' 8 2015 - A.A OIL AND GAS CONSERVATION COASION REPORT OF SUNDRY WELL OPERATIONS AOCIICC 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter CasingChangeApprovedProgramr Rug for Redrill r Perforate New Pool Repair Well Re enter Susp Well Other:Cond Extension 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-061 3.Address: 6.API Number: Stratigraphic r Service r- P. O. Box 100360,Anchorage,Alaska 99510 50-103-20456-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380107,ADL0025551,ADL0025544 KRU 3S-24A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12518 feet Plugs(measured) None true vertical 6054 feet Junk(measured) None Effective Depth measured 12328 feet Packer(measured) 10350 true vertical 5912 feet (true vertical) 4793 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81'6" 16 108 108 1640 630 SURFACE 4498 9-5/8 4527 2613 5750 3090 INTERMEDIATE 11229 7 11255 5203 7240 5410 LINER 2186 3-1/2 12513 6050 10160 10540 Perforation depth: Measured depth: 12295-12318 h111 True Vertical Depth: 5897'-5913' SO*NEP N 0f :t3 Tubing(size,grade,MD,and TVD) 3.5, L-80, 10349 MD,4793 TVD Packers&SSSV(type,MD,and TVD) PACKER=SEAL ASSEMBLY WITH 1/2 MULE SHOE @ 10350 MD and 4793 TVD SSSV=CAMCO'DS' LANDING NIPPLE @ 505 MD and 503 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-432 Contact Martin Walters/MJ Loveland Email n1878conocophillips.com Printed Name Martin Walter/s,, Title Well Integrity Supervisor Signature �/���U, � �✓ L� Phone:659-7043 Date: 10/4/2015 VT-/o/iz/i5 4 69,4x- RBDMS-)OCT 12 2015 Form 10-404 Revised 5/2015 Submit Original Only 3S-24A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/20/15 Welder welded 18"x 16" .375 62#extension onto conductor. 10/03/15 Injected 6.3 gallons of RG2401 into the conductor. ti of 7,4, //j,-c' THE STATE Alaska Oil and Gas of t Conservation Commission z_ 333 West Seventh Avenue \Tti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 04t, 41LASVJ' Fax 907.276 7542 www.aogcc.alaska.gov scoNED I Martin Walters Well Integrity Supervisor ConocoPhillips Alaska, Inc. O�O� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-24A Sundry Number: 315-432 Dear Mr. Walters: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jai Cathy P Foerster Chair DATED this 20day of July, 2015 Encl. STATE OF ALASKA 'RECEIVED i-,—,SKA OIL AND GAS CONSERVATION COMMISSION 11L 15 ?O1 APPLICATION FOR SUNDRY APPROVALS ,o a-s Z I-2.4/S 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing V Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well F,Re-enter Susp Well r Other:Cond Extension 2.Operator Name 4 Current Well Class 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory r Development r 204-061 • 3.Address: Stratigraphic r Service 1"-- 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20456-01 7. If perforating, What 8 Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F/ rg� 3S-24A 9.Property Designation(Lease Number): 10.Field/Pool(s) ADL0380107, ADL0025551,ADL0025544 - Kuparuk River Field/Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft):O/ Plugs(measured): Junk(measured): 12518 6054 )X 41 13 5c/ 'o Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108' 108' 1640 630 SURFACE 4498 9-5/8 4527' 2613' 5750 3090 INTERMEDIATE 11229 7 11255' 5203' 7240 5410 LINER 2186 3.5 12513' 6050' 10160 10540 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size Tubing Grade: Tubing MD(ft): 12295-12318 5897'-5913' 3 5 L-80 10349 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER=SEAL ASSEMBLY WITH 1/2 MULE SHOE MD=10350 TVD=4793 SSSV=CAMCO'DS'LANDING NIPPLE MD=505 TVD=503 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations: 15 Well Status after proposed work 9/15/2015 OIL WINJ r WDSPL r Suspended r 16.Verbal Approval Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Martin Walters/MJ Loveland Email n1878@cop.com Printed Name , j' Martin Walters Title: Well Integrity Supervisor Signature hYir _ /1 hi�1- _t Phone:659-7043 Date:07/12/15 ��, ��/ ccc Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 3/6- LIS/ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0— 4-(' 4- g TAHPFPROVME�pD BY N —7LOp `/ �_ Approved by: lCpcft a R ori 1Omonths from triC Z13�t�Oil30�rOval. Date:/'submit Form and Form 10-403 Revi�d 5/2015 � �� Attachmen in Duplicate ZP4y' RBDMSAUG - 2 2015 RECEIVED ConocoPhillips Alaska ��'f- 15 20b P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AG 11 C July 13, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3S-24A, PTD 204-061 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, 17tie( 74(1416°— Martin Walters ConocoPhillips Well Integrity Projects Supervisor y/ . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 3S-24A (PTD 204-061) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 13, 2015 This application for Sundry approval for Kuparuk well 3S-24A is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 18". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor • k, KUP PROD 3S-24A ConocoPhiflips - Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(1) MD(ftKB) Act Btu,(ftKB) ,f-4,7 mpc 501032045501 KUPARUK RIVER UNIT PROD 69.84 3,853.08 12,518.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3S-24A.9/20201310.54:21 AM SSSV:NIPPLE 100 5/29/2012 Last WO: 33.67 6/12/2003 Vertical schematic(actual) Annotation Depth(ORB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,300.0 6/5/2013 Rev Reason:SET JET PUMP/PACKERS osborl 9/18/2013 HANGER;23.4 ( ll Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(fIKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 29.0 4,527.3 2,6132 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread P . INTERMEDIATE 7 6276 26.5 11,255.0 5,203.2 26.00 L-80 BTCM ./*,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) -Set Depth(TVD)... Wt/Len(I...Grade Top Thread WINDOW 7 6.000 10,509.0 10,522.0 4,861.6 26.00 L-80 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR,28.D-10a.0-4. . LINER 31/2 2.992 10,326.7 12,513.0 6,050.0 920 L-80 SLHT Liner Details NIPPLE;5049 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Corn (in) 10,326.7 4,7842 67.20 PACKER BAKER 5"X 7"ZXP HR LINER TOP ISOLATION 5.000 PACKER GAS LIFT;4,248.1 10,345.6 4,791.6 67.08 NIPPLE RS PACKOFF SEAL NIPPLE 5.50"X 4.25" 4.250 10,348.4 4,792.6 67.06 HANGER BAKER 5"X 7"FLEXLOCK LINER HANGER 5.000 10,357.7 4,796.3 67.00 SBE BAKER 80-40 SEAL BORE EXTENSION 5.00"X 4.000 4.00" t 10,376.9 4,803.8 66.88 XO BUSHING XO Bushing,5"TKC X 3-1/2"SLHT 5.57"X 3.00" I 3.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING I 31/21 2.9921 23.4 10,386.51 4,807.61 9.301 L-80 I8rdEUE Mod SURFACE;29.0-4,527.3- Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 23.4 23.4 0.12 HANGER FMC 5M GEN V TUBING HANGER - 2.992 504.9 503.2 10.17 NIPPLE CAMCO'DS'LANDING NIPPLE 2.875 GAS LIFT;7,355.7 10,302.9 4,775.0 67.31 SLEEVE-0 BAKER CMU SLIDING SLEEVE w/DS PROFILE-OPEN 2.813 I 2/18/12 1 10,349.3 4,793.0 67.06 LOCATOR BAKER G-22 LOCATOR SUB 3.000 10,350.1 4,793.3 67.05 SEAL ASSY SEAL ASSEMBLY with 1/2 MULE SHOE 3.000 GAS LIFT;9,240.9 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I: Top(ND) Top Incl a Top(ftKB) (ftKB) Des Com Run Date ID(in) 10,289.0 4,769.7 67.37 PACKER UPPER WEATHERFORD ER PACKER 9/5/2013 1.810 1 10,291.9 4,770.8 67.36 PATCH PATCH/SPACER PIPE 9/5/2013 1.630 GAS LIFT;10,252.9al 10,302.2 4,774.7 67.31 PUMP JET PUMP(PH-1013)#11 NOZZLE,#12 THROAT 9/5/2013 10,304.8 4,775.7 67.30 PATCH PATCH/SPACER PIPE/SNAP LATCH SEAL ASSY 9/5/2013 1.630 + 10,323.2 4,782.9 6721 PACKER LOWER WEATHERFORD ER PACKER 2/26/2012 1.750 PACKER;10,289.0 Perforations&Slots PATCH;10,291 9 DDeensns 4 b Top(TVD) Btm(ND) (shots# Iiit. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn PUMP;10,302.2 !' ^! 12,295.0 12,318.0 5,896.7 5,912.7 C-4,3S-24A 5/18/2004 6.0 IPERF 2.5"HSD,60 deg phase, PJ 2506 HMX Charges, SLEEVE-0;10,302.9 1'Blank 12297-12298' due to TCP Connection between guns PATCH;10,304.8 A 1 PACKER;10,323.2 T' Mandrel Details St ati C a on Top(TVD) Valve Latch Port Size TRO Run o I. No Top(ftKB) (ftKB) Make Madel OD(in) Sery Type Type (in) (psi) Run Date m 1 4,248.1 2,507.5 Cameo KBUG- 1 GAS LIFT DMY BK 5 0.000 0.0 5/52004 M m 2 7,355.7 3,683.2 Cameo KBUG- 1 GAS LIFT DMY 'BK-5 0.000 0.0 5/5/2004 M i 3 9,240.9 4,376.4 Cameo KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 M LOCATOR;10,349.3 Id 4 10,252.9 4,755.8 Camco KBUG- 1 GAS LIFT DMY BK-5 0.000 0.0 5/5/2004 ' ,' M Notes:General&Safety SEAL ASSY;10,350.1 .err IC_ End Date _ Annotation 7 ;.[ 5/5/2004 NOTE:SIDETRACKED WELL;OLD PERFS CEMENT SQUEEZED 11/30/2009 NOTE:View Schematic w/Alaska Schematic9.0 1/20/2012 NOTE:EJL CONFIRMED LEAK @ 10,313 IN PUP JT BELOW CMU WINDOW,10,509.0-10,522.0 • ill L INTERMEDIATE;26.5-11,255.0 J IL IPERF;12,295.0-12,318.0 LINER;10,326.7-12,513.0 ' Bettis, Patricia K (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Thursday, July 23, 2015 6:06 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3S-24A: Sundry Application Patricia, The following four email have the requested data. We apologize for the error. Total Depth 12518', 6054'TVD Effective Depth 12413', 5980' TVD MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday,July 16, 2015 9:54 AM To: NSK Well Integrity Proj Subject: [EXTERNAL]KRU 3S-24A: Sundry Application Good morning Martin, Please advise what the current plug back depth is for the KRU 3S-24A well, both MD and TVD. This information was missing from the sundry application. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday,July 16, 2015 9:54 AM To: NSK Well Integrity Proj (N1878@conocophillips.com) Subject: KRU 3S-24A: Sundry Application Good morning Martin, Please advise what the current plug back depth is for the KRU 3S-24A well, both MD and TVD. This information was missing from the sundry application. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 'd- - 0 ~ L Well History File Identifier Organizing (done) Äo-sided 111111111 1111111111 o Rescan Needed 111111111111111I111 RES CAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Diskettes, No. D Other, NofType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: D Other:: BY: ~ Date to/19/0?; Date bile¡ /ot:- I X 30 = 30 Date: (p //1/ tJb /5/ mP "' 111111111111111I Project Proofing BY: r..- Maria) /5/ rwP Scanning Preparation BY: ~ + Jv1 = TOTAL PAGES S7 (Count does not include cover sheet) 1/\11 P /5/ f r ~ Produc6onScanning /1111111111I1111111 Stage 1 Page Count from Scanned File: III () (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date:{p/ /q/06 If NO in stage 1, page(s) discrepancies were found: YES NO /5/ V\1 r BY: Stage 1 NO BY: Maria Date: /5/ 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned III II 111111 III ,,1/1 BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc r max. STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COMMISSION OCT 0 8 2013 REPORT OF SUNDRY WELL OPERATIONS R 1.Operations Performed: Abandon r Repair w ell J7 Rug Perforations r Perforate (° Oth Alter Casing r Pull Tubing r Stimulate- Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-061 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic (® Service 50-103-20456-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 3801071- &1,ALI<2616/4C24 i M Loot 11 ADLoo2.' 54-I4• 3S-24A • 1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 12518 feet Plugs(measured) None true vertical 6054 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 10289, 10305, 10323, 10350 true vertical 0 feet (true vertical) 4770,4776,4783,4793 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108 108' SURFACE 4498 9 5/8 4527 2614' INTERMEDIATE 11229 7 11255 5204' Perforation depth: Measured depth: 12,295-12,318 True Vertical Depth: 5897-5913 SCANNEV NOV 1 4 Z013 Tubing(size,grade,MD,and ND) 3.5, L-80, 10349 MD,4793 TVD Packers&SSSV(type,MD,and ND) PACKER-UPPER WEATHERFORD ER PACKER @ 10289 MD and 4770 TVD PATCH-PATCH/SPACER PIPE/JET PUMP/SNAP LATCH SEAL ASSY @ 10305 MD and 4776 TVD PACKER-LOWER WEATHERFORD ER PACKER @ 10323 MD and 4783 TVD SEAL ASSY-SEAL ASSEMBLY WITH 1/2 MULE SHOE @ 10350 MD and 4793 TVD 12.Stimulation or cement squeeze summary: N/A 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 Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r • Service r Stratigraphic 16.Well Status after work: Oil I;✓' • Gas r WDSPL r Daily Report of Well Operations x GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bre t Roters/K:.,. ons Email n1617(c/7cop.com Printed Name -II Lyon ' Title Problem Wells Supervisor Signature Phone:659-7224 Date 10/04/13 ' /111010 Form 10-404 Revised 10/2012 �� /d94`� Submit Original Only r /0//5-7/3 RBDMS OCT 11 - . • • co-E71 2013 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 04, 2013 Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. for Kuparuk producer 3S-24A (PTD 204-061) for a tubing patch with a surface powered jet pump included within the patch assembly. Please call Brent Rogers or myself at 659-7224 if you have any questions. Sincerely elly Lyons ConocoPhillips Problem Wells Supervisor Enclosures • • 3S-24A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/04/13 BRUSH'N FLUSH W/ HOT DIESEL& DRIFT TBG WITH 2.83" GAUGE RING TO TOP OF PUMP ASSEMBLY @ 10,292' RKB. PULLED PATCH /JET PUMP (S/N: AR-1013, NO EROSION) @ 10,292' RKB. LOST ELEMENT OFF UPPER ER PKR. IN PROGRESS 06/05/13 PULLED LOWER ER PKR @ 10,320' RKB; TAGGED @ 12,300' SLM (7' OF RAT HOLE/ SAMPLE OBTAINED) BRUSH'n FLUSH TBG @ STRADDLE JET PUMP INTERVAL. READY FOR E-LINE OR DIGITAL SLICKLINE TO SET LOWER ER PKR. IN PROGRESS. 07/12/13 SET 2.74" ER PACKER @ 10325' RKB, SETTING TOOL DID NOT RELEASE, UNABLE TO JAR FREE, DROPPED CUTTER BAR (1-3/4" FN, 196" OAL)TOOLSTRING IN HOLE-40' OAL, 2.74" OD, 1-3/8" FN. RIG OFF WELL TO ALLOW FOR COIL JOB, IN PROGRESS. 07/15/13 PULLED 1-7/8" CUTTER BAR FROM 10230' SLM, ATTEMPTED TO FISH TOOLSTRING @ 10254' SLM, JARRED FOR A TOTAL OF 3hrs, PLANTED 3-1/2" BAIT SUB &2"JDC WITHOUT PAULS ON TOOLSTRING @ 10254' SLM 09/04/13 PULLED DSL TOOLSTRING FROM TOP OF WFD ER PACKER @ 10325' RKB. SET WFD ER. TEST TOOL& LRS CMIT-TxIA TO 2500# ...JOB IN PROGRESS **CMIT pass (2 bbls): preTIO=1550/1550/155, initial=2550/2550/155, 15min=2460/2460/155, 30 m i n=2420/2420/155** 09/05/13 SET UPPER PACKER&JET PUMP ASSEMBLY @ 10291' RKB (MID ELEMENT), RAN ER TEST TOOL TO TOP OF PATCH @ 10290' RKB, LRS PERFORM PASSING MIT-T, PULLED ER TEST TOOL FROM 10290' RKB **MITT pass(0.5 bbls): preTIO=1450/450/155, initial=2550/450/155, 15min=2450/450/155, 30 m i n=2400/450/155** Summary Pulled existing and reset retrievable patch with SPJP in tubing. • • 3S-24A DESCRIPTION OF WORK COMPLETED SUMMARY • • • ✓ ConocoPhillips RECEIVED Alaska APR 10 2012 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 AOGCC April 08, 2012 Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr.Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3S-24A (PTD 204 -061) for a tubing patch with a SPJP included within the patch assembly. - j- Please call Brent Rogers or Kelly Lyons at 659 -7224 if you have any questions. Sincerely, Brent Rogers ConocoPhillips Problem Well Supervisor 56 1.4144ff.E) APR 2012 Enclosures STATE OF ALASKA AI OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J' Exploratory r - 204 -061 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 - 50- 103- 20456 -01 7. Property Desigpation (Lease Number): V" 8. Well Name and Number: ADL 380107 & 25551, ALK 2616 & 4624 f tDL J J t k f t to M 3S - 24A 9. Logs (List Togs and submit electronic and printed data per 20AAC25.07 : 10. Field /Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 12518 feet Plugs (measured) None true vertical 6054 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 10290, 10292, 10320, 10350 true vertical 0 feet (true vertucal) 4770, 4771, 4782, 4793 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108 108' 0 0 SURFACE 4498 9 5/8 4527 2614' 0 0 INTERMEDIATE 11229 7 11255 5204' 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 12,295 - 12,318 RECEIVED True Vertical Depth: 5897 - 5913 APR 2012 Tubing (size, grade, MD, and TVD) 3.5, L -80, 10349 MD, 4793 TVD AOGCC Packers & SSSV (type, MD, and TVD) PATCH PACKER - WEATHERFORD PACKER @ 10290 MD and 4770 TVD PATCH - SPACER PIPE, JET PUMP - #11 NOZZLE, #12 THROAT, SLICK STICK, SNAP LATCH SEAL ASSEMBLY @ 10292 MD and 4771 TVD PATCH PACKER - WEATHERFORD ER PACKER @ 10320 MD and 4782 TVD SEAL ASSY - SEAL ASSEMBLY WITH 1/2 MULE SHOE @ 10350 MD and 4793 TVD 12. Stimulation or cement squeeze summary: N/A 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 Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16. Well Status after work: - Oil 17 Gas r WDSPL r Dairy Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 1 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 Brent Rogers / Kelly Lyons Printed Name Brent Rogers Title Problem Well Supervisor Signature / 6 j� Phone: 659 -7224 Date 04/08/12 Form 10-404 Revised 11/201 RBDMS APR 1. 0 20 4-(.-(O' Submit Original Only 3S -24A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/20/12 SET 2.74" WEATHERFORD LOWER ER PACKER AT A MID ELEMENT DEPTH OF 10323'. RIGGED DOWN AND TURNED WELL OVER TO DSO. 03/18/12 RAN 3 1/2" ER TEST TOOL TO ER PKR @ 10323' RKB.2000# CMIT PASSED.VERIFIED CMU @ 10302' RKB IS OPEN. READY FOR PATCH JET PUMP ASSY. INITIAL T /I /0= 300/475/0 BOL ASRC PUMP FOR 3 BBL T /I /0= 1800/2000/0 AFTER 15 MIN T /I /0= 1775/1925/0 AFTER 30 MIN T /I /0= 1700/1900/0 NOTIFY CWG REP BEAT DOWN MORE AND RETEST BUMP UP T X IA WITH 1/2 BBL T /I /0= 2050/2200/0 AFTER 15 MIN T /I /0= 2025/2175/0 AFTER 30 MIN T /I /0= 2025/2175/0 03/19/12 RAN 2.5" HES DPU TO SET UPPER 2.74" ER PKR SPACEPIPE JETPUMP (SN PH- 1013,#11 NOZZLE, #12 THROAT) SPACEPIPE SLICKSTICK (SAFETY RELEASE) SPACEPIPE AND STINGER ASSY (OAL= 31.6',MIN ID 1.63 ") SET IN LOWER ER PKR @ 10323' RKB.MIT TBG 2500# GOOD.READY TO BOL INITIAL T /I /0= 300/500/0 PRESSURE TBG UP WITH 1 BBL T /I /0= 2500/500/0 AFTER 15 MIN T /I /0= 2425/500/0 AFTER 30 MIN T /I /0= 2400/500/0. MIT PASS. 1 1 Summary Set 30' Weatherford retrievable patch with SPJP in tubing. 1 1 1 2_1516 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 21, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3S -24A Run Date: 2/20/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3S -24A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103- 20456 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907- 273 -3535 klinton.wood @halliburton.com Date: 119 ill— Signed: imort WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 23, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ` .r,_ MAY ; 6 231 RE: Leak Detect Log: 3S-24A Run Date: 1/20/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3S -24A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103- 20456 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 4 4/4)— Signed: NAL *-) • 2 06 1 1 4999 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 16, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MAY 2131 RE: Multifinger Imaging Tool (MIT) : 3S-24A Run Date: 1/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3S -24A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50 -103- 20456 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: t 1.1 Signed: 41 11)_tige • • Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139 @conocophillips.com] Sent: Thursday, January 27, 2011 9:09 AM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); Colombie, Jody J (DOA); NSK Prod Engr & Optimization Supv; NSK Fieldwide Operations Supt; Bradley, Stephen D Subject: FW: RE: Request for Approval Attachments: Kuparuk Gas Injector Flow back Volumes.xls Tom, Attached you will find the Kuparuk Gas Injector Flowback information per your request:_ - Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. all Kuparuk Office: 907.659.7535 �" L FE'B28 a Kuparuk Pager: 659.7000; #924 CPAI Internal Mail: NSK -69 This email may contain confidential information. If you receive this e-mail in error .lease notify the sender and delete this email immediately. L.l From: Maunder, Thomas E (DOA) [mailto tom.maunder ©alaska.gov] Sent: Tuesday, January 25, 2011 9 :09 AM To: NSK Prod Engr & Optimization Supv Subject: RE: Request for Approval Gary/Denise, Following up on my brief conversation with Gary the other day, could one of you provide some information with regard to the flowback of these WAG injectors while TAPS was unavailable. Please copy everyoned as before with your response. Thanks in advance, Tom Maunder, PE AOGCC LI From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. 1/27/2011 • Page 2 of 3 Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mailto :n2046 ©conocophillips.com] Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [ailto tom.maunder©a alaska.govj Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mai iito ;n2046(aconocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D 1/27/2011 • • Page 3 of 3 Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ■lowback PTD# Adjacent PTD# Estimated Prod as Injector SI Producer (Mscfd) ?P -420 201 -182 2P -422A 202 -067 4,500 a:P -447 203 -154 2P -448A 202 -005 2,000 aU -03 185 -006 2U -02 185 -005 3,500 - 5S -09 202 -205 3S -08C 207 -163 7,500 3S -26 201 -040 473S-24A 204 -061) 6,500 ��— 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/27/2011 • oft_ • Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to colleagues so they may make necessary assessments. P my 9 Y Y Y I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D Subject: Request for Approval Importance: High SLAMAIEP 7011° Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ilowback Adjacent Estimated Prod as Injector PTD# SI Producer PTD# (Mscfd) P -420 201 -182 2P -422A 202 -067 4,500 P -447 203 -154 2P -448A 202 -005 2,000 ;U -03 185 -006 2U -02 185 -005 3,500 IS -09 202 -205 3S -08 07 -163 7,500 1S -26 201 -040 (3S -24A 204 -061 6 50 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/11/2011 Page 1 of • • )— Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval 1/11/2011 • • -~~ ~ - , _r ~,-: .~ ~, __ ~ o MICROFILMED 03/01 /2008 DO NOT PLACE ANY. NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 it ,:z. _~_~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ("-"~I",H,ìt-rj t, ¡.;^ ~"I ""\..I-/,··'ì·~ t y......,,;-- ,~,~1 ,-- Q() yo ... 0 to J 3~- ~y.A Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on November 18, 2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~f C--/ ConocoPhillips W ell Integrity Supervisor Attachment T . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Au ust 7,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 I~ J~ ^-~~ DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040610 Well Name/No. KUPARUK RIV UNIT 3S-24A Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20456-01-00 MD 12518 Completion Date 5/18/2004 Completion Status 1-01L TVD 6054 REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: Res/GR/NeutlDens Well Log Information: Log/ Data Type Rpt J.dg Electr Digital Dataset Med/Frmt Number Name Directional Survey Induction/Resistivity Log Log Run Scale Media No 25 Blu 2 25 Blu 2 25 Blu 2 25 Blu 2 2 .L~ , tt(g' 11.-' I "'""::I " í~ y/ C Lis ~g Induction/Resistivity Density Density LIS Verification 12567 Induction/Resistivity Perforation Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? e:, Daily History Received? Chips Received? ~ y " r4 -- Formation Tops Analysis Received? ~ Comments: Current Status 1-01L UIC N Directional S~Yes ....::) (data taken from Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received Comments 6/17/2004 10521 12518 Open 7/15/2004 GR,RWD,ORD,CCN, DSN 12567 1 0521 12518 Open 7/15/2004 GR,RWD,ORD,CCN,DSN 12567 10521 12518 Open 7/15/2004 MPR DSN 12567 10521 12518 Open 7/15/2004 MPR, DSN 12567 10521 12518 7/15/2004 DSN 12567 10521 12518 Open 7/15/2004 GR,MPR,CCN,ORD + GRAPHICS 10200 12375 Case 5/27/2004 PERFORATING RECORD W/SBHPS & JEWELRY LOG Sample Set Number Comments ~N é)N . . Permit to Drill 2040610 MD 12518 TVD 6054 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Well Name/No. KUPARUK RIV UNIT 3S-24A Operator CONOCOPHILLlPS ALASKA INC Completion Date 5/18/2004 Completion Status 1-01L Current Status 1-01L ~ Date: API No. 50-103-20456-01-00 UIC N {e( J~~~ þ . . e Conoc;Phillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 2, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 3S-24A. The Sundry regards converting the artificial lift method from gas lift to surface powered jet pump. A producer MIT form is also included in the Sundry packet. Please call Marie McConnell or Jerry Dethlefs at 659-7224 if you have any questions. Problem Well Supervisor RECE\VED AUG - 4 2004 c mmission Alaska Oil & Gas Cons. 0 Anchorage Attachments OR\G\NAL Total Depth measured 12518' feet true vertical 6054' feet Effective Depth measured 12518 feet true vertical 6276' feet Casing Length Size MD Structural CONDUCTOR 108' 30" 108 SURFACE 4499' 9-5/8" 4527' PRODUCTION 10495' 7" 1 0521 ' LINER 2186' 3-1/2" 12513' WINDOW l' 3-1/2" 10522' Perforation depth: Measured depth: 12295-12318' true vertical depth: 5897-5913' . #' 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 56' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: e STATE OF ALASKA e ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell 0 Pull Tubing 0 Opera!. ShutdownD Other D o o Stimulate D Waiver D Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development _ [;2] Stratigraphic 0 Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 204-061 / 6. API Number: 50-103-20456-01 Exploratory Service D D 9. Well Name and Number: 3S-24A 10. FieldlPool(s): Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2613' 4862' 6050' RECEIVED AUG - 4 2004 Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10387' MD. Packers & SSSV (type & measured depth) no packer SSE 10358' SSSV= NIP SSSV NIP= 505' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: N/A ~['ì'flÞ SEP 1 0 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 26 243 106 549 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16, Well Status after proposed work: Oil0 Gas 0 WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/ft Exempt: Contact Maire McConnell/ Jerry Dethlefs 659-7224 Prioted N.me MJ ~o~nd /' / T;', SI,,,,,Me ~/ ~ ~ Phon. Form 10-404 Revised 04/2004 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations_X Oil-Sbl 51 216 Casinq Pressure Tubinq Pressure 280 220 200 2337 WDSPLD Problem well Supervisor / 659-7224 Date 'Z5' 1/ {:7 Y Preoared bv MJ Loveland qlGINAL Submit Original Only e ~ . 3S-24A DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 7/1612004 PULLED OV @ 10253' RKB AND SET DGLV. MITIA TO 3000 PSI FOR 30 MINUTES; PASSED. SHIFTED OPEN SLIDING SLEEVE @ 12303' RKB. 7/1712004 SET 2.81 CS LOCK W/3" A.C. JET PUMP (SEA. PH-1110) HAS A 9-B RATIO: #9 NOZZLE AND # 10 THROAT @ 10303' RKB IN CMU SLIDING SLEEVE. 30 BBLS DIESEL PUMPED OWN IA TO ENSURE INJECTIVITY. }f f ! g e 1"", . A Lf- OC::/ Transmittal Form '&ill BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 3S-24A Contains the following: 1 LDWG Compact Disc í 25" 7 (Includes Graphic Image files) 1 LDWG lister summary 1 blue line - MPR Measured Depth Log 1 blueline - MPR TVD Log 1 blueline - CCN/ORD Measured Depth Log 1 blueline - CCN/ORD TVD Log LAC Job#: 670282 Sent B~~~~le,~/!!~~el V /í Received JÍy: lye it."^- í/' /r&äA/0:'¿í'i/'- I i V PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Date: July 6, 2004 Date: ;;01 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 f' I'i 1Rt!,¡g-lIIHIIIl&tAfta/,l L", !~:.~.:. ...... -.' L......."'" _ u., _~, ....;. ~~" .. , ,- ~~-;~;_.'._~:.,._.~:-~ . - ,- ~ e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test . Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3S-24A 07116/04 Craig Ramm - LRS Packer Depth Pretest we1l13S-24A I Type Inj N I T.V.D. I 4784 I Tubing I 12101 P.T.D.2040610 Type Test P Test psi 1500 Casing 1150 Notes: Pre Surface Powered Jet Pump conversion MIT weill I Type Inj I I T.V.D. I Tub~ng I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I T.V.D. I Tub~ng I P.T.D. Type Test Test psi 1500 Casing Notes: well I Type Inj I I T.V.D·I I Tub~ng I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I T.V.D. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: Test Details: Producer MIT - before swapping from GL to Jet Pump TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form Revised: 05/19/02 MITP KRU 3S-24A 7 -16-04,x1s Initial 15 Min. 30 Min. 12101 12301 123011nterval 0 3000 2900 2900 P/F P Intervall P/F Ilnterval P/F Ilnterval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) 7/31/2004 TUBING (23-10387, 00:3,500, 10:2,992) ROOUCTION (26-10521, 00:7.000, Wt:26,OO) SLEEVE-O 0303-10304, 00:4,490) PACKER 0327-10328, 00:7.000) NIP 0346-10347, 00:5,500) HANGER 0348-10349, 00:7.000) LOCATOR 0349-10350, 00:5.000) LINER 0327-12513, 00:3,500. Wt:9.30) Perf 2295-12318) e ~ .. e . KRU 3S-24A Well Type: PROD Angle @ TS: deg @ Orig Completion: 5/6/2004 Angle @ TO: 45 deg @ 12518 Last W/O: Rev Reason: Set DMY, Open sleeve, set Pump Ref Log Date: Last Update: 7/31/2004 TO: 12518 ftKB Max Hole Angle: 70 3853 Size Top Bottom TVD Wt Grade Thread 7,000 26 10521 4862 26,00 L-80 BTCM 9,625 28 4527 2613 40,00 L-80 BTCM 62,500 28 108 108 62,50 H-40 WELDED 3,500 10327 12513 6050 9,30 L-80 SLHT 3,500 10521 10522 4862 0,00 ConocoPhillips Alaska, Inc. 35'24A API: 501032045601 SSSV Type: NIPPLE Annular Fluid: 24,3' RKB 12431 5/17/2004 Description PRODUCTION SURFACE CONDUCTOR LINER WINDOW Thread EUE8rd Size 3,500 Top 23 Bottom 10387 Interval TVD 12295 - 12318 5897 - 5913 Zone Status Ft SPF Date Type Comment 23 6 5/18/2004 IPERF 2,5" HSD, 60 deg phase, PJ 2506 HMX Charles, l' Blank 12297-12298' due to TCP Connection between St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 4248 2507 CAMeO KBUG-M DMY 1,0 BK-5 0,000 0 5/5/2004 2 7355 3683 CAMCO KBUG-M DMY 1,0 BK-5 0.000 0 5/5/2004 3 9241 4376 CAMeo KBUG-M DMY 1,0 BK-5 0,000 0 5/5/2004 4 10253 4756 CAMCO KBUG-M DMY 1,0 BK 0.000 0 7/16/2004 Depth TVD Type Description 23 23 HANGER FMC 5M GEN V TUBING HANGER 505 503 NIP CAMCO 'DS' LANDING NIPPLE set 5/512004 10303 4775 SLEEVE-O BAKER CMU SLIDING SLEEVE WfDS' PROFILE set 5/5/04, OPENED 7/16/04 10303 4775 PUMP 3" R.C, JET PUMP (SN: PH-1110) 9-B RATIO: #9 NOZZLE, #10 THROAT, w/2,81" CS LOCK set 7/17/04 10349 4793 LOCATOR BAKER G-22 LOCATOR SUB 10350 4793 SEAL 10387 4808 SHOE ID 3,500 2,875 2,813 0,000 3,000 3,000 3,000 Depth TVD 10327 4784 10346 4792 10348 4793 10358 4796 ·'·Gêtìöršl:ílfôtes' Date Note 5/5/2004 SIDETRACKED WELL; OLD PERFS CEMENT SQUEEZED 5/9/2004 TREE: FMC / GEN 5/5M TREE CAP CONNECTION: TOP 5,75" ACME W/3,5" EUE 8rd THREAD Type PACKER NIP HANGER SBE Description BAKER ZXP HR LINER TOP ISOLATION PACKER RS PACKOFF SEAL NIPPLE BAKER FLEXLOCK LINER HANGER ID 5,000 4,500 5,000 4,000 'JII l . . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocóPhillips P. o. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 14, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-24A (APD # 204-061) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3S-24A. If you have any questions regarding this matter, please contact me at 265-6830 or Kelly McLure at 265-6059. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad r t: JUN 1 tJ 2004 _ STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAGD 1a, Well Status: Oil 0 Gas U GINJ D 2, Operator Name: D WDSPL D WINJ Plugged D Abandoned D 20AAC 25,105 No, of Completions _ ConocoPhillips Alaska, Inc. 3. Address: p, O. Box 100360, Anchorage, AK 99510-0360 4a, Location of Well (Govemmental Section): Surface: 2565' FNL, 1266' FEL, See, 18, T12N, R8E, UM At Top Productive Horizon: 106' FNL, 2457' FEL, Sec. 25, T12N, R7E, UM Total Depth: 268' FNL, 2471' FEL, Sec, 25, T12N, R7E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 475994 .' y- TPI: x- 469967 y- Total Depth: x- 469953 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: Res/GR/ NeutlDens 22, CASING SIZE 16" 9,625" WT, PER FT, 62.5# 40# 26# 9,3# GRADE B L-80 L-80 L-80 7" window 3,5" 5993852 5985773 5985611 Zone-4 Zone-4 Zone- 4 Suspended D 20AAC 25,110 Other 5. Date Comp" Susp" Iß or Aband,: May,K'2004 6, Date Spudded: April 30, 2004 7, Date TD Reached: May 2, 2004 8, KB Elevation (It): 24' RKB 9, Plug Back Depth (MD + TVD): 12413' MD / 5980' TVD 10, Total Depth (MD + TVD): . 12518' MD /6054' TVD 11, Depth where SSSV set: Landing Nipple @ 505' 19. Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM Surface 108' Surface 108' Surface 4527' Surface 2613' Surface 10521' Surface 4861' 10327' 12513' 4784' 6050' 23, Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 12295' - 12318' MD 5897' - 5913' TVD 6spf 26. Date First Production May 21, 2004 Date of Test Hours Tested 24, SIZE 3,5" ß;ç,o~ (p ;I feet MSL HOLE SIZE 12,25" 8,5" 6,125" 1b, Well Class: Development 0 Service D 12, Permit to Drill Number: D Exploratory Stratigraphic Test D 204-061 13, API Number: 50-103-20456-01 14, Well Name and Number: 3S-24A 15, Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16, Property Designation: ADL 380107 & 25551 17, Land Use Permit: ALK 2616 & 4624 20. Thickness of Permafrost: 1740' MD I~ ;;;6f /h.L) ,12: '/; fS-" 7Y /) , .:p.¡ ~ttJ.~.· CEMENTING RECORD AMOUNT PULLED 42" 81 sx ArcticCrete 525 sx AS III Lite, 415 sx LiteCrete 184 sx LiteCrete 422 sx Class G TUBING RECORD DEPTH SET (MD) 10349' PACKER SET 10327' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc,) Shut-In Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL Flow Tubing Casing Pressure press. 27, psi Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary), Submit core chips; if none, state "none", Form 10-407 Revised 12/2003 24-Hour Rate -> NONE WATER-BBL GAS-MCF W A TER-BBL CORE DATA CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY - API (corr) E [) rëm\.~;;:_~JÕÑ\ i ¡ S1-8-.:41 'N 1 .''' ') 004 ! ,'......... I ¡ .., U' I j .' \""{S.'; ¡ ,'.. ,. [;(pn¡r.'1i!:t\;c~-::~ .:,'='::::J CONTINUED ON REVERSE RBDMS BFl JlJM 1 6 100' L,f G GEOLOGIC MARKERS It 29, e 28. FORMATION TESTS NAME MD TVD Include and briefly summarize test results, List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None", 3S-24A Top Kuparuk 12295' 5897' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31, I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact: Kelly McLure @ 265-6059 Printed Name~ Thoma~ Signature l _.\ \ ~ . Title: Phone Kuparuk DrillinQ Team Leader 4.> 6-e5ê> Date 61tyfDy Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information, If none, state "None", Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 38-24 38-24 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 4/26/2004 Rig Release: 5/6/2004 Rig Number: Spud Date: 5/18/2003 End: 5/6/2004 Group: 4/26/2004 00:00 - 04:00 4.00 MOVE DMOB DEMOB Blow down rig and prep for rig move 04:00 - 12:00 8.00 MOVE MOVE MOVE Hook up complexes and sub to trucks and move rig from 2L to 3S pad 12:00 - 14:00 2.00 MOVE OTHR MOVE Clean up diesel spill wI ACS, Peak and rig crew 14:00 - 15:15 1.25 MOVE POSN RIGUP Lay herculite and mats and spot sub on 3S-24A 15:15 - 17:00 1.75 MOVE POSN RIG UP Lay mats for pits, pumps, motors and boilers and spot modules 17:00 - 18:30 1.50 MOVE POSN RIGUP Lay herculite and spot rockwasher, Lay mats and spot pipeshed 18:30 - 20:30 2.00 MOVE POSN RIGUP Trim berms around rig and spot tioga on pipeshed. 20:30 - 22:00 1.50 MOVE OTHR RIGUP Make interconnects between modules and work on rig acceptance check list. Rig on highline power at 21 :00 hrs, Rig Accepted @ 2100 hrs 04/26/2004. 22:00 - 00:00 2.00 DRILL OTHR DECOMP Load pipeshed wI 4' d,p. 4/27/2004 00:00 - 02:00 2.00 DRILL OTHR DECOMP Fin loading pipe shed with 4' XT 39 DP and strapped same 02:00 - 02:15 0.25 DRILL SFTY DECOMP Held PJSM on PU & standing back 4" DP 02:15 - 14:30 12.25 DRILL PULD DECOMP PU & stood back in derrick 333 jts (111 stds) of 4" XT 39 DP, PU & stood back 27 jts (9 stds) of 4" HT 38 HWDP 14:30 - 15:45 1.25 WELCTL OTHR DECOMP Checked well pressure on tree -0- psi, pulled VR plugs on 7" x 31/2' annulus, -0- psi on lA, pulled BPV and installed TWC 15:45 - 16:45 1.00 WELCTL NUND DECOMP ND tree and 11' 5M adapter flange 16:45 - 19:00 2.25 WELCTL NUND DECOMP NU 135/8' 5M BOP stack and lines, changed out lower pipe rams from 4" to 31/2" 19:00 - 00:00 5.00 WELCTL BOPE DECOMP RU and began testing BOPE, valves, manifold and rams to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi NOTE: John Spaulding with AOGCC waived witnessing of BOP test 4/28/2004 00:00 - 01 :00 1.00 WELCTL BOPE DECOMP Fin testing BOPE and performed Koomey test, RD test equipment and pulled TWC 01 :00 - 02:30 1.50 DRILL RIRD DECOMP RU safety valves on 3 1/2' landing jt and back out lockdown screws 02:30 - 02:45 0.25 DRILL PULD DECOMP PU 100K st wt and pulled hanger to rig floor, no problems releasing hanger or pulling out of seal assembly 02:45 - 03:45 1,00 DRILL PULD DECOMP RU 3 1/2' tbg tongs and LD landing jt and hanger 03:45 - 05:30 1.75 DRILL CIRC DECOMP Circ hole with clean seawater, displaced out approx 66 bbls diesel used for freeze protection, staged pump rate up to 6 bpm at 900 psi, st wt 90K 05:30 - 05:45 0.25 DRILL OBSV DECOMP Monitored well-static 05:45 - 06:00 0.25 DRILL SFTY DECOMP Held PJSM on LD 3 1/2" completion 06:00 - 16:00 10.00 DRILL PULD DECOMP POOH LD 3 1/2' completion assembly, LD 352 jts of 3 1/2" 9.3# L-80 EUE-Mod, tbg, GLM's with pup jts, DS nipple and seal assembly (11,127') All completion assembly accounted for 16:00 - 17:30 1.50 WELCTL EQRP DECOMP Installed test plug and changed out lower pipe rams from 3 1/2" to 4" 17:30 - 18:00 0.50 WELCTL BOPE DECOMP Tested lower pipe rams to 250 psi then to 5,000 psi, pulled test plug and installed wear bushing 18:00 - 18:15 0.25 LOG SFTY DECOMP Held PJSM with rig crew and Schlumberger wireline on running gauge ring and junk basket 18:15 - 21 :45 3.50 LOG ELOG DECOMP RU SWS E-line, MU 6.125" gauge ring/junk basket and RIH, began setting down at 8,500', worked tool down to 9,000' making slow progress, began POOH, gauge ringf¡unk basket hung up at 3,535', 21 :45 - 22:30 0.75 LOG OTHR DECOMP Worked Gauge ring junk basket at 3,535' for 40 min and worked free, 22:30 - 23:30 1.00 LOG ELOG DECOMP Fin POOH with Gauge ring/junk basket, recovered 3 gals of cuttings in junk basket, RD SWS Decision was made to make clean out/gauge run with whipstock mills 23:30 - 00:00 0.50 DRILL PULD DECOMP Brought whipstock mills and cross overs to rig floor, preparing to MU BHA for clean out/gauge run 4/29/2004 00:00 - 00:30 0.50 DRILL PULD DECOMP Held PJSM and MU cleanout/gauge run BHA #1 00:30 - 01 :00 0.50 RIGMNT RSRV DECOMP Serviced rig & top drive Printed: 5/24/2004 2:50:23 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-24 3S-24 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 4/26/2004 Rig Release: 5/6/2004 Rig Number: Spud Date: 5/18/2003 End: 5/6/2004 Group: 4/29/2004 01:00-04:15 3.25 DRILL TRIP DECOMP RIH with BHA #1 to 10,821' with no problems, PU 2 stds to 10,634' 04: 15 - 06:30 2.25 DRILL CIRC DECOMP Pumped 100 bbl hi vis sweep (150 vis), circ out with clean seawater, recovered 5-10 gals of cuttings from sweep, circ hole clean at 70 rpm's, 9K ft-Ibs torque, staged pump rate up to 8 bpm at 1,500 psi, rot wt 106K, up wt 112K, dn wt 105K 06:30 - 08:00 1.50 RIGMNT RGRP DECOMP Repaired hyd by-pass on iron roughneck 08:00 - 12:00 4.00 DRILL TRIP DECOMP POOH with BHA #1 to 55', no problems 12:00 - 12:15 0.25 DRILL PULD DECOMP LD cleanout/gauge run BHA #1 12:15 - 14:00 1.75 LOG ELOG DECOMP RU Schlumberger E-line and RIH with 6.125" gauge ring/junk basket to 10,638' with no problems 14:00 - 15:30 1,50 LOG ELOG DECOMP POOH with gauge ring/junk basket with no problems and LD same, no recovery in junk basket 15:30 - 17:30 2.00 LOG ELOG DECOMP RIH with Baker 7" CIBPand set same at 10,538' 17:30 - 19:15 1.75 LOG ELOG DECOMP POOH and LD setting tool, RD SWS 19:15 - 21:30 2.25 WINDOWPULD DECOMP MU & RIH with BHA #2, Bakßr 7' btm trip whipstock and milling assembly with MWD and oriented same, 4-43/4' dc's, RIH with 9 stds 4" HWDP and 1 std 4' DP to 1,146' 21 :30 - 22:00 0.50 WINDOWCIRC DECOMP Shallow tested MWD at 175 gpm, 450 psi & ck ok, blow down top drive 22:00 - 00:00 2.00 WINDOWTRIP DECOMP RI H slow with whipstock on 4" XT 39 DP from 1,146' to 3,860' 4/30/2004 00:00-01:15 1.25 WINDOWTRIP DECOMP Cont RIH slow with Baker 7" btm trip whipstock on 4" DP from 3,860' to 6,009' 01:15 - 02:15 1.00 RIGMNT RSRV DECOMP Slip & cut 75' of drilling line 02:15 - 02:30 0.25 DRILL DEQT DECOMP Tested 7" csg and CIBP to 1,000 psi for 15 min & ck ok 02:30 - 05:15 2.75 WINDOWTRIP DECOMP Cont RIH slow with Baker 7" btm trip whipstock on 4' DP from 6,009' to 10,401 ' 05:15 - 06:30 1.25 WINDOWSETW DECOMP Est circ at 290 gpm, 1,500 psi and worked DP down orienting whipstock to 15 deg left of high side from 10,401', tagged CIBP at 10,527' DP (10,538' WL), set whipstock and sheared off same, st up wt 155K, dn 75K with seawater in hole 06:30 - 08:00 1.50 WINDOWCIRC DECOMP Displaced out seawater in well over to new 10.2 ppg LSND mud with 3% lubricants, st wt with mud in hole, rot wt 90K, up wt 130K, dn wt 85K 08:00 - 12:00 4.00 WINDOWSTWP DECOMP Milled window in 7' csg from 10,509' to 10,540' MDI 4,869' TVD, top of ./ window at 10,509 MD'I 4,856' TVD, btm of window 10,521' (12' window, 19' of open hole), 2-3K wt, initial rpm's 65, final rpm's 120, torque ave 6K ft-Ibs, max torque 8K ft-Ibs, circ rate 295 gpm at 1,550 psi 12:00 - 13:00 1.00 WINDOWCIRC DECOMP Pumped hi vis fiber sweep and circ hole clean, worked mills thru window while circ, circ at 295 gpm at 1,550 psi, after circ clean, worked mills thru window with no pump or rotation several times with no problems, had good recovery from sweep and magnets while milling window 13:00 - 14:00 1.00 DRILL FIT DECOMP RU & performed FITto 13.1 ppg EMW with 10.2 ppg MW, 725 psi at 4,856' TVD 14:00 - 19:00 5.00 WINDOWTRIP DECOMP POOH with milling assembly BHA #2 to 228', stood back HWDP 19:00 - 20:00 1.00 WINDOWPULD DECOMP LD Milling assembly BHA #2, upper mill came out full gauge 20:00 - 21 :00 1.00 WINDOWOTHR DECOMP Pulled wear bushing and flushed out BOP stack, re-installed wear bushing 21:00-23:15 2.25 DRILL PULD PROD PU & Began MU 6 1/8" directional BHA #3, oriented and uploaded MWD 23:15 - 23:30 0.25 DRILL SFTY PROD Held PJSM with crew on loading radioactive sources 23:30 - 00:00 0.50 DRILL PULD PROD Cont MU BHA #3, loaded radioactive sources and RIH with 3 stds HWDP to 275' 5/1/2004 00:00 - 01:15 1.25 DRILL PULD PROD Fin MU BHA #3 and RIH with HWDP to 1,103', shallow tested MWD and ck ok Printed: 5/24/2004 2:50:23 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 35-24 35-24 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 4/26/2004 Rig Release: 5/6/2004 Rig Number: Spud Date: 5/18/2003 End: 5/6/2004 Group: 5/1/2004 01:15 - 06:00 4.75 DRILL TRIP PROD RIH with BHA #3, PU 39 jts 4" XT 39 DP from pipe shed then RIH with stds to 1 0,450' 06:00 - 06:30 0.50 DRILL TRIP PROD Est Circ, oriented BHA then RIH thru window at 10,509' to btm at 10,540' with no problems 06:30 - 08:00 1.50 DRILL DRLG PROD Drilled 6 1/8" hole from 10,540' to 10,627', (87') ART .4 hrs, AST .4 hrs 08:00 - 09:00 1.00 DRILL CIRC PROD Circ btms up at 310 gpm at 2,500 psi and performed PWD baseline test with 10.2 ppg mud, clean hole ECD was 12.99 ppg, 09:00 - 10:45 1.75 DRILL CIRC PROD Circ and conditioned mud, lowered YP from 29 to 24 due to high ECD, circ at 310 gpm at 2,500 psi 10:45 - 14:30 3,75 DRILL DRLG PROD Drill, slide & survey 6 1/8" hole per directional plan from 10,627' to 10,870' MDI 5,010' TVD (243') ART 1.8 hrs, AST 1.5 hrs, 5-7K wOb, 90 rpm's, 73 spm, 310 gpm, off btm pressure 2,450 psi, on btm 2,620 psi, off btm torque 5K ft-Ibs, on btm 6K ft-Ibs, rot wt 105K, up wt 134K, dn wt 85K, 10.2 ppg MW, ave ECD 12.85 ppg 14:30 - 15:30 1.00 DRILL CIRC PROD Circ hole working on MWD signal, troubleshoot surface equip to improve MWD signal and found no problems on surface, slowed tool transmittion rate and improved MWD signal 15:30 - 00:00 8,50 DRILL DRLG PROD Drill, slide & survey 6 1/8" hole per directional plan from 10,870' to 11,340 MDI 5,258' TVD (470') ART 2.9 hrs, AST 1.6 hrs, 3-7K wob, 90 rpm's, 73 spm, 310 gpm, off btm pressure 2,500 psi, on btm 2,600 psi, off btm torque 5K ft-Ibs, on btm 6K ft-Ibs, rot wt 108K, up wt 135K, dn wt 90K, 10.3 ppg MW, ave ECD 12.85 ppg, ave BGG 30 units, max gas 100 units, pumped 1-hi vis sweep and had 10% increase in cuttings back 5/2/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill, slide & survey 61/8" hole per directional plan from 11,340' to 11,937' MDI 5,647' TVD (597') ART 6.7 hrs, AST 1.4 hrs, 3-5K wob, 90 rpm's, 73 spm, 310 gpm, off btm pressure 2,600 psi, on btm 2,800 psi, off btm torque 6K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 116K, up wt 140K, dn wt 95K, raised MW to 10.5 ppg at 11,500' per wt up schedule, ave ECD with 10.5 ppg MW was 13.0 ppg, ave BGG 120 units, max gas 320 units from Morraine sand 12:00 - 23:45 11.75 DRILL DRLG PROD Drill, 61/8" hole from 11,937' to 12,518' MDI 6,054' TVD (581') (T.D.) " ART 9,2 hrs, AST -0- hrs, 3-7K wob, 90 rpm's, 68 spm, 275 gpm, off btm pressure 2,600 psi, on btm 2,800 psi, off btm torque 8K ft-Ibs, on btm 9K ft-Ibs, rot wt 120K, up wt 155K, dn wt 98K, raised MW to 10.9 ppg per wt up schedule and ECD with 10.9 ppg MW ave 13.2 ppg, with no mud losses, ave BGG 120 units, max gas 460 units from KUP sand, Est top of KUP "C" sand at 12,294' MDI 5,896' TVD, top of Muluveach at 12,318' MDI 5,913' TVD 23:45 - 00:00 0.25 DRILL OBSV PROD Monitored Well 15 min-static 5/3/2004 00:00 - 01 :30 1.50 DRILL CIRC PROD Pumped hi vis sweep and circ out, had no increase in cuttings from sweep, max gas after monitoring well 176 units, circ a total of 2x btms up at 275 gpm at 2,550 psi, 90 rpms with 8K ft-Ibs off btm torque, rot wt 120K, up wt 155K, dn wt 98K, BGG ave 70 units 01 :30 - 03:30 2,00 DRILL TRIP PROD Pumped out of hole at drlg rate to 12,438', POOH on elevators to 10,660' (20 stds total) with no problems ( Btm of window @ 10,521 ') 03:30 - 03:45 0.25 DRILL OBSV PROD Monitored well-static 03:45 - 05:00 1.25 DRILL TRIP PROD RIH to 12,438' and washed 80' to btm with no problems 05:00 - 08:15 3.25 DRILL CIRC PROD Circ hole clean and cond hole for liner, pumped 30 bbl hi vis sweep and circ out, had a max gas of 4,927 units and no increase in cuttings from sweep, gas dropped out in 10 min, circ a total of 4X btms up and clean at shakers, staged pump rate up to 288 gpm at 2,700 psi, 90 rpm's, 10.9 ppg mw ECD ave 12.9 ppg, ave BGG 80 units Printed: 5/24/2004 2:50:23 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 35-24 35-24 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 4/26/2004 Rig Release: 5/6/2004 Rig Number: Spud Date: 5/18/2003 End: 5/6/2004 Group: 5/3/2004 08:15 - 08:30 0.25 DRILL OBSV PROD Monitored well-static 08:30-11:15 2.75 DRILL TRIP PROD Precautionary pumped out of hole 15 stds from 12,518' to 11,192' to above top of Morraine sand with no problems, pumped out at 288 gpm at 2,700 psi 11 :15 - 12:00 0.75 DRILL CIRC PROD Circ btms up and had no increase in gas, dropped 2.25" rabbit on wire 12:00 - 12:30 0.50 DRILL TRIP PROD POOH from 11,192' to 10,450', pulled thru window at 10,521' with no problems 12:30 - 12:45 0.25 DRILL OBSV PROD Monitored well inside csg shoe, well static 12:45 - 20:00 7.25 DRILL TRIP PROD Pumped dry job and POOH to BHA at 1,100', monitored well-static, cont POOH to 183' standing back HWDP 20:00 - 23:00 3.00 DRILL PULD PROD Began LD BHA #3, downloaded MWD and finished LD BHA, cleared rig floor 23:00 - 23:45 0.75 CASE RURD PROD RU Doyon's 3 1/2" liner running equipment 23:45 - 00:00 0.25 CASE SFTY PROD Held PJSM with rig crew, tong operator and Baker rep on MU and running of liner 5/4/2004 00:00 - 02:45 2.75 CASE PULR PROD MU 67 jts of 31/2" 9.2# L-80 SLHT Liner and RIH to 2,130' 02:45 - 04:00 1,25 CASE PULR PROD MU Baker 5" x 7" SBE, Flexlock hanger and ZXP liner top packer assembly 04:00 - 04:15 0.25 CASE CIRC PROD RIH with Liner assembly on 1 std of 4" DP, circ 2X liner cap, circ at 5 bpm at 575 psi, up wt 50K, dn wt 45K 04:15 - 10:00 5.75 CASE RUNL PROD RIH with liner to 10,413' (top of window @ 10,509') 10:00 - 12:00 2,00 CASE CIRC PROD Circ and cond mud prior to entering open hole, staged pump rate up to 4.5 bpm at 1,050 psi, circ 1 complete hole volume, no gas at btms up, st up wt 115K dn wt 80K, rotated string at 15 rpms with 3K ft-Ibs torque 12:00 - 14:30 2.50 CASE PULR PROD RIH thru window wIno problem, cont in open hole to 12,483', no problems 14:30 - 15:00 0,50 CASE RURD PROD Mu Baker cement head with single, est circ and washed down tagging btm at 12,518', PU to 12,513' 15:00 - 17:00 2.00 CEMENTCIRC PROD Circ & cond mud for cmtg liner, staged pump rate up to 5 bpm at 1,450 psi, lowered YP from 24 to 15 with 10.9 ppg 43 vis mud in & out, no mud loss or gas on btms up, ave BGG 10 units, Held PJSM with Cmtrs, vac truck drivers and rig crew, batch mixed cement while circ hole With pumps on rotated liner at 15 rpms and 5.5K ft-Ibs torque, reciprocated liner also, rot wt 98K, up wt 115K, dn wt 93K, With Pumps off, st wt up wt 137K, dn wt 82K 17:00 - 17:45 0.75 CEMENT PUMP PROD Turned over to Dowell and pumped 10 bbls of CW 100, tested lines to 4,500 psi, then pumped 10 add. bbls of CW 100 (20 total) then pumped 20 bbls of 12.5 ppg MUDPUSH XL at an ave of 2.5 bpm at 650 psi, followed with 88 bbls bbls, 422 sxs of class "G" cmt with additives at 15.8 ppg and 1.17 yield, ave 4 bpm at 450 psi, reciprocated and rotated liner, shut down and washed up to rig floor 17:45 - 18:30 0.75 CEMENTDISP PROD Dropped wiper plug and followed with 20 bbls of 8.6 ppg hi vis seawater perf. pill and 10.9 ppg mud, ave rate 4 bpm, at 1,200 psi bumped plug on calc displacement to 1,600 psi, (saw LWP plug shear) reciprocated and rotated pipe throughout job, had full retums during cmt job, checked floats and held, CIP at 18:25 hrs 18:30 - 18:45 0.25 CEMENTOTHR PROD Pressure up using rig pumps and set hanger, then set Liner top packer per Baker procedure with no problems, Released from liner. Top of Liner @ 10,327' MD/4,784' TVD, Landing collar @ 12,413' MDI 5,980' TVD and Float Shoe @ 12,513' MDI 6,050'TVD 18:45 - 19:30 0.75 CASE CIRC PROD Circ hole clean above TOI at 10,327', circ at 8 bpm at 2,400 psi at btms up had 12 bbls of 15.8 ppg cmt back 19:30 - 20:00 0.50 CASE RURD PROD RD cement head and LD 2 jts 4" DP Printed: 5/24/2004 2:50:23 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-24 3S-24 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 4/26/2004 Rig Release: 5/6/2004 Rig Number: Spud Date: 5/18/2003 End: 5/6/2004 Group: 5/4/2004 20:00 - 21 :30 1.50 CASE CIRC PROD Rev circ hole at 8 bpm at 1,750 psi, circ 1 complete hole volume 21 :30 - 22:30 1.00 CASE CIRC PROD Pumped 25 bbl hi vis spacer and displaced out 10.9 ppg mud with 8.6 ppg seawater, staged pump rate up to 8 bpm at 1,700 psi 22:30 - 22:45 0.25 DRILL OBSV PROD Monitored well-static 22:45 - 00:00 1.25 DRILL PULD PROD Began POOH with setting tool and LD 45 its of 31/2" XT-39 DP 5/5/2004 00:00 - 05:15 5.25 DRILL PULD PROD POOH with liner setting tool LD 285 its of 4" XT-39 DP 05:15 - 05:45 0.50 DRILL PULD PROD LD Baker liner setting tool 05:45 - 08:30 2.75 DRILL PULD PROD RIH with 10 stds 4" HWDP, iars and 14 stds of 4" DP, POOH LD same, pulled wear bushing and cleared rig floor 08:30 - 08:45 0.25 CMPL TN RURD CMPL TN RU to run 3 1/2" completion 08:45 - 09:00 0.25 CMPL TN SFTY CMPL TN Held PJSM with rig crew, Baker Rep and tong operator on running of 3 1/2" completion 09:00 - 16:30 7.50 CMPL TN RUNT CMPL TN Ran 3 1/2" completion per well plan to top of 31/2" liner at 10,327', MU ,/ seal assembly w/space out pups and No-Go, 1 jt 3 1/2" tbg, CMU Sliding sleeve with "DS" profile with pup its, 1 it of 31/2" tbg, 4-3 1/2" x 1" KBUG-M GLM's with pups above & below and "DS" nipple, Ran a total of 328 its of 3 1/2" 9.3# L-80 EUE 8rd Mod Tbg, st up wt 87K, dn wt 58K 16:30 - 18:00 1.50 CMPL TN SOHO CMPL TN Est circ at TOL and located SBE, spaced out 3 1/2" completion, MU hanger, verified space out and pu hanger 18:00 - 21 :30 3.50 CMPL TN CIRC CMPL TN Clrc hole with clean seawater, pumped 100 bbls fresh water, 180 bbls seawater, 80 bbls of seawater with corrosion inhibitor and followed with 80 bbls seawater, pumped at 3 bpm at 300 psi 21 :30 - 22:30 1.00 CMPL TN SOHO CMPL TN Landed 3 1/2" tbg hanger and RILDS, St WT when landed 87K with 35K block wt. Landed 31/2" tbg 2' above No-Go at 10,349", CMU sliding sleeve at 10,303', Camco KBUG GLM with DKC-2 shear valve at 10,253' and "DS" nipple at 505' Totallenght of Completion assembly including hanger, 10,363' 22:30 - 00:00 1.50 CMPL TN DEQT CMPL TN Tested 3 1/2" tbg to 3,500 psi for 30 min, bled down tbg to 1,900 psi, pressure tested 3 1/2" x 7" annulus to 3,500 psi for 30 min, good test, bled down annulus to 1,900 psi and DKC-2 valve sheared at 2,500 psi 5/6/2004 00:00 - 00:30 0.50 CMPL TN RURD CMPL TN LD 3 1/2" landing it and installed TWC 00:30 - 00:45 0.25 WELCTL SFTY CMPL TN Held PJSM on flushing out, ND BOP's & NU tree 00:45 - 03:30 2.75 WELCTL EORP CMPL TN Opend up BOP's and flushed out ram cavities, flushed out small amount of cement and metal shavings 03:30 - 04:00 0.50 WELCTL NUND CMPL TN ND BOP's 04:00 - 06:00 2.00 WELCTL NUND CMPL TN NU WKM 31/8" 5M tree, tested void and tree to 5,000 psi and checked ok, pulled TWC 06:00 - 07:30 1.50 CMPL TN FRZP CMPL TN Freeze protected well with 80 bbls of diesel and allowed to u-tube 07:30 - 08:30 1.00 WELCTL OTHR CMPL TN Installed 3" type "H" BPV and secured well RELEASED RIG @ 08:30 Hrs 5/6/04 Printed: 5/24/2004 2:50:23 PM e 3S-24A Well Events Summary e Date Summary 05/09/04 DRIFT TO 12374' RKB WITH 2.68" CENT. FELL SLOWLY TO A STOP. WOULD NOT FALL DEEPER. 05/10104 PULL DCR & SET 5/16" OV@10,253'RKB,DRIFT WI 23'-2.5" DUMMY GUN TO 11,940'WLM NOT DEEP ENOUGH FOR PERF. TARGET DEPTH. PTTBG WI TRIPLEX TO 3500, GOOD TEST.O [GLV] 05/16/04 FCO GEL FROM LINER FROM 10350'-12411' CTM WITH 340 BBLS SLICK SW AND 150 BBLS SLICK DIESEL, TAGGED 12411' CTM - LEFT WELLBORE WITH FILLED WITH SW AND A 3500' DIESEL CAPO [FCO] 05/17104 GAUGED TBG WI 2.74" SWAGE. TAGGED @ 12431' RKB, EST. 113' BELOW TARGET PERFS. DRIFTED TBG WI 23' X 2.5" DUMMY GUN TO 12370'.0 [Tag] 05/18/04 PERFORATED INTERVAL 12295'-12318' USING 2.5" HSD GUN LOADED 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION WITH POWERJET HMX CHARGES - PJ 2506. TOTAL OF 134 HOLES. API PENETRATION 25.2", ENTRANCE HOLE 0.32". Conoc~illips ConocoPhillips Alas!nc.,Slot #24 Pad 3S, Palm, North Slope, Alaska wellbl24A Well path: MWD w/Sag&Mag <10741-12518'> Date Printed: 25-May-2004 "~i. BAKER ....HIS INTEQ NRrne 24 ID 11 43.1639 .Field Name Palm I EastinQ 4;7258,3400 I Northi :96412.0100 I Coord SVstem Name NOrttfAlianment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 56.1ft above Mean Sea Level) Vertical Section is from O,OON O.OOE on azimuth 219.67 degrees Bottom hole distance is 10217,08 Feet on azimuth 216.09 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~t{ -Ofll ¥ ConocoPhillips ConocoPhillips Alas!nc.,5Iot #24 Pad 35, Palm, North Slope, Alaska wellb' 24A Well path: MWD w/5ag&Mag <10741-12518'> Date Printed: 25-May-2004 "~i. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing PositionCY) Position(X) Sectionrftl 10741.12 65,60 215,56 4951.30 6923.118 5729.96W 0,00 8986.76 470241.92 5986947.61 10927.82 62.13 203,99 5033.76 7068.10S 5813,20W 5,86 9151.50 470158,22 5986802.90 11020,10 60.32 201,50 5078,18 7142,68S 5844.49W 3,07 9228,88 470126,70 5986728.43 11114.81 58.96 199.47 5126.05 7219,22S 5873,09W 2.34 9306,06 470097.85 5986651,99 11209.21 55.44 194.39 5177.20 7295,06S 5896.25W 5,86 9379,21 470074.45 5986576.23 11301,36 53,59 190.71 5230.71 7368.27S 5912,58W 3,82 9445,99 470057.89 5986503.08 11395.45 51,80 189.47 5287.73 7441.958 5925.70W 2,17 9511.08 470044,54 5986429.45 11488.51 48,56 186,30 5347.32 7512.728 5935.54W 4.35 9571,84 470034.46 5986358.72 11582.30 48.12 189,08 5409.67 7582.14S 5944,91W 2.26 9631.26 470024,87 5986289.33 11675.89 47.74 188,29 5472,38 7650.82S 5955.40W 0.75 9690.82 470014,16 5986220.70 11769.50 47.36 186.60 5535,57 7719.30S 5964,36W 1.39 9749,25 470004.99 5986152.25 11863,12 47.17 185,84 5599.10 7787,66S 5971,81W 0,63 9806,62 469997.32 5986083.92 11956,12 46.97 185.16 5662.44 7855.44S 5978.34W 0,58 9862.96 469990.58 5986016.17 12049.13 46,44 184.48 5726.22 7922.908 5984.02W 0.78 9918.52 469984.67 5985948.74 12142,88 46,10 185,60 5791.03 7990,388 5989,97W 0,94 9974,26 469978,51 5985881.29 12?35.94 45,85 185,28 5855,70 8056.99S 5996,32W 0.37 10029.58 469971,95 5985814.70 12330.33 45,59 186,94 5921,61 8124.18S 6003,51W 1.29 10085.89 469964,54 5985747.55 12422.86 45.11 186,05 5986.64 8189,58S 6010,96W 0.86 10140,99 469956,89 5985682,17 12518.00 45,11 186,05 6053.78 8256.61S 6018,06W 0.00 10197.12 469949.57 5985615.18 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #2 56.1ft above Mean 8ea Level) Vertical Section is from O.OON O,OOE on azimuth 219.67 degrees Bottom hole distance is 10217.08 Feet on azimuth 216,09 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc;p.,illips ConocoPhillips Ala'lnc.,Slot #24 Pad 3S, Palm, North Slope, Alaska wellb.24A Wellpath: MWD w/Sag&Mag <10741-12518'> Date Printed: 25-May-2004 r&l. BAKER HUGHES INTEQ Comments MDfftl TVDrftl I North£ftl 12518,00 6053,78 8256,61S Eastrftl I Comment 6018,06W Proiected Dat a - NO SURVEY HoteSections Diameter Start "nl MDrftl 61/8 10509.00 I Start Start Stårt 'I End I End End I Start, I Wêllbore TVDrftl Northrftl ,Eastrftl MDlftl ,TVDlftl Northrftl Eastrftl · '4856.466756,828 5598,81W 12518,00 6053,78 8256.61S 6018,06W 24A Casinas Nàme Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDrftl TVDlftl Northrftl Eastrftl MDlftl TVDrftl Northrftl Eastfftl 0.00 0,00 O,OON O,OOE 10509,00 4856,46 6756.82S 5598.81W 24A 10509,00 4856.46 6756,82S 5598.81W 12513,00 605025 8253.08S 6017.69W 24A 7" CasinA 3 1/2" Liner All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 56,1 ft above Mean 8ea Level) Vertical Section is from O.OON O,OOE on azimuth 219,67 degrees Bottom hole distance is 10217,08 Feet on azimuth 216.09 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Re: 3S-24A (PTD 204-061) plan to convert to jet pump e e Subject: Re: 3S-24A (PTD 204-061) plan to convert to jet pump From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 01 Jun 200413:42:31 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> Marie, I pulled the file for 3S-15 and the 404 is in there. Thanks to you and Sharon. Submitting the same paperwork will work just fine. Tom NSK Problem Well Supv wrote: Tom, Yes, one well, 3S-15 was converted to jet pump a few months ago. We had some emails about it on 3/30/04, but a lot has happened since then. Please let me know if you did not get the 10-404 Sundry. I helped Sharon generate it in mid April, so I think it was sent as required. Marie -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, June 01, 2004 11:23 -:AM'-' To: NSK Problem Well Supv Subject: Re: 3S-24A (PTD 204-061) plan to convert to jet pump Marie, Are there any other wells using jet pumps on 3S?? I was not aware of any. Thanks for the notice. Submitting the 404 so Bob can capture the lift method change helps keep the records straight. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, 3S-24A will be converted from gas lift to surface powered jet pump due to freezing problems. The following wellwork will be completed: 1. The replace OV with DV 2. MITIA 3. Opening the sliding sleeve 4. Set jet pump in sliding sleeve. A 10-404 will be completed after the conversion and will include the MITIA data. Marie McConnell Problem Well Supervisor 659-7224 lof2 6/1/20041:42 PM RE: 3S-24A Possible P&A and sidetrack 3S-24B Plan- Follow Up . . Subject: RE: 3S-24A Possible P&A and sidetrack 3S-24B Plan- Follow Up From: "McLure, Kelly" <Kelly.A.McLure@conocophillips.com> Date: Tue, 04 May 200413:53:24 -0500 To: Thomas Maunder <tom_maunder@admin.state.ak.us> ~aL\__ 0 ~ \ Tom, We received the results last night at midnight from the MWD download and the reservoir quality improved significantly once we had the recorded data from the real time data due to more readings recorded and stored in the MWD tool and the intermittent data points taken for real time. The conclusion is there will be no need for a sidetrack for 3S-24A. We will continue on with the current 3-1/2" monobore completion. Regards, Kelly McLure Kelly McLure Kuparuk Drilling Engineer Drilling & Wells Anchorage, AK 907-265-6059 (direct) 907-265-1535 (fax) -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, May 03, 2004 4:43 PM To: McLure, Kelly Cc: Thomas, Randy L Subject: Re: 3S-24A Possible P&A and sidetrack 3S-24B Plan Ke 11 Y , If I understand correctly, the bottom plug will extend from 12518 to about 12100. With an excess allowance this should give an adequate bottomhole plug. Based on no other hydrocarbon zones in the OH, moving up to your window/kickoff plug is acceptable. For your window plug, my only observation is not to cut yourself on that plug length. In order to assure that you get a plug, it appropriate to set a similar length plug there as at the bottom. call, only my observation. We will waive requiring the bottomhole plug to be tagged, provided it goes into place with no indication of lost circulation. Based on what you report regarding the drilling, losses are not expected placing the plug. You have approval to proceed with the plugging as planned. Please plan on submitting the sundry tomorrow. You are correct about the name of the new sidetrack. That will take a new 401 since your BHL is likely to be changing by more than 500'. Keep us informed at that plan comes together. In cases such as the sidetrack to 3S-24B, a verbal approval is possible. That approval can be dealt with in the next day or so as plans are formalized. Please call with any questions. Tom Maunder, PE AOGCC short may be Your McLure, Kelly wrote: Tom, As per our conversation I am currently waiting on the directional plan for a possible sidetrack for the 3S-24A. The new well would be the 3S-24B well. lof2 7/2/200410:22 AM RE: 3S-24A Possible P&A and sidetrack 3S-24B Plan- Follow Up Reason for possible si~rack: the current well reserv~ quality is not what we were looking for. A first pass result from the real time data has been looked at. Reservoir and Geology are currently wanting the MWD data to make a final decision for running a completion in the well or to plug back and sidetrack to another bottom hole location. possibly logging to wait for existing The new location would be approx 500-600' north of where our current location is. P&A plan for the 3S-24A would be as follows: the well was drilled to 12518' MD/6054' TVD with a 10.9 ppg MW. The TD is approx 225' below the Miluveach Zone. A cement plug would be set from TD of 12518' MD up to 200' above the top of the Kuparuk C sand at approximately 12294' MD/5896' TVD. Then we would spot a viscous pill 50' below the window and place 100' cement on top of that pill up inside the casing to cement the current window milled in the 7.0" casing with the window exit from 10530' MD - 10560' MD. Based on the directional plan we would attempt to utilize the current window milled and exit the casing again from the same point and drIll to the new bottom hole location. A detailed plan will follow on Tuesday morning based on the outcome of the data analysis when the MWD tools are downloaded at surface on Monday May 3, 2004. Please let me know if you need more information for a preliminary or verbal as this decision will be made in the middle of the night on Monday night/ Tuesday Morning. Any questions please call me on my cell 240-5905 for anymore information needed as I will run downstairs for a meeting with my geologist. Regards, Kelly McLure 20f2 7/2/2004 10:22 AM Ke: 3S-24 answers . ~)~l~ ~á~-Q~ Subject: Re: 38-24 answers From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 16 Apr 200412:49:34 -0800 To: "McLure, Kelly" <Kelly.A.McLure@conocophillips.com> Thanks Kelly. I agree on the 7", there doesn't appear anything else one could do and given the breathing it is not surprising that differential sticking became a problem. The way the reports read, breathing occurred at lower EMWs than would have been expected. That sort of ties in to the LOTs. With regard to the LOTs, I do appreciate the need to squeeze given the planned mud weights. It appears that the break point on the 2nd graph was improved, however the 440 psi or so it dropped to essentially repeats the latter part of the initial LOT so I am not sure if the squeeze really achieved any greater ultimate shoe integrity. My main point on these issues is that when there is a major departure from what was planned and permitted, it seems that at least a courtesy notice should be provided. The operations ultimately performed amount to changes in approved plans. Such notice keeps us informed and aware. Again, thanks for the information. If you or your colleagues have any questions, please call. Torn Maunder, PE AOGCC McLure, Kelly wrote: Torn, I am attaching the Surface LOT Test sheet the post squeeze LOT, adn the 7' injectivity test for you to review. Please see below the answers in red and the attachments. All, I am sending this to several of you, since I am not sure who will provided the answers/requests. In doing the review of the planned 3S-24A, I have pulled the file of 3S-24 and in looking at that Summary I have a couple of questions. In reading the well summary, I note there were two events that led to changes in the planned operations. These include: 1. "Low initial LOT" at the surface shoe and a subsequent squeeze. The first LOT was performed and it leaked off at 432 psi which equates to 11.98 ppg EMW. I know the surface LOT was planned (shown in the wellplan to be for 11.8 ppg EMW based on a 20 bbl kick tolerance from 11.1 ppg MW, the equivalent pressure expected at the K-1 interval. Therefore, right at the LOT equivalent, so a squeeze was done for the shoe and then a second LOT performed. The second LOT showed a pressure of 13.96 ppg EMW. This was sufficient enought to continue drilling the next hole section. See attachments for LOT data sheets. 2. Stuck 7" casing with it cemented 2400' off bottom. The 7" casing run was very uneventful and went as planned until the point we were stuck. It happened on a connection when we were sitting with the casing in the slips. Doglegs through that area were 1-2 degrees so that should not have been a contributor. We have checked in detail the logs as well as the rig 2 second data from digital readouts for pressure, WOB, Block weights, pump strokes, output, etc. There is no information in the detail breakdown of the event showing what could have led to stuck pipe. It is our analysis that we were differentially stuck at that depth. I plan to drill with a lower mud weight for the sidetrack and instill all the proper drilling practices. It is my intention the lower mud weight will help decrease or eliminate the chance of stuck pipe on the sidetrack due to our differentially stuck pipe conclusion. Should this not completely answer all your questions please give me a call. I will be out for lunch, but back by 1pm today and in the office all afternoon. THANKS! I would appreciate receiving further information on item 1. The lot test sheets would be a good start. lof2 7/2/200410:16 AM Ke: :; S-:¿4 answers On item 2, your actions4lltre appropriate however I feel ~ some contact should have been made regarding the changes to the well design. I look forward to receiving the LOT documents. Please call with any questions. Tom Maunder, PE AOGCC «3S-24 Surf LOT 1st attempt.xls» «Post SQZ Surf LOT.xls» 2 of2 7/2/200410:16 AM PRESSURE INTEGRITY TEST CONOCOPHILLlPS Alaska, inC. ïE'.':: Date· I r::¡L~'1IL~nl1':; . .....' . VI .h.-' .............. #2 Mud Pump (do~-aG ~CJ)-CJ ì ~ :}::,:::::::::::::::::::::~:~mp Rate: ... JI:I¡.¡'¡i~!¡I::¡I:II~lj Strk/min Pressure Integrity Test Volume Input VolumelStroke I ... lil~II~I~1 Bbls/Strk I Casing Test Rig: BurleyìH 38-21; Well Name: ... Strokes ... Pump used ng Supervisor Dri Shut-in :':~tË o. 5 J¡¡¡¡¡;¡¡¡¡¡¡¡¡¡ª~Q¡ 1 ........·385.· 1, 5 ¡:':':¡¡'¡:::~.:i':~¡:~:':i:;)):;:': 2 :\\:: ~ 2, 5 :¡:¡:j:¡:¡:¡:j\::, .:; ::~$.: 3. ~ ,'¡'¡!I¡I'I'I'¡'i'¡~~i.' 4 ~¡ffff~3ï5¡ . ................. .........':!i;;;: ;!;. 4, 5 ~~:~~:~~~~~~~~~~~~~;:¡,,\:¡,,\:I~ 5 ¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡j~¡ä~~¡ 5. 5 ¡¡¡¡¡¡¡¡~¡~¡¡¡¡¡¡¡¡ãiô¡ .................. ........ ..$.$.'0' :::;:::::::::::;:::,,' .: ...................... " 6 ~.i.i'¡.i.i.j.i.i.i.II.II(II:. 6, 5 ~))~:¡:¡:);¡¡ß.P.¡ 7 \)))maßø.~ ,::1]11111111111111 7 ,5 j~))))¡a$.~~ 8, ~ 1:':\!::¡:!:¡¡¡::¡I~I~· 9. ~ ),!,¡,:,',:¡·,":Ii~, 1 0 ::::j::m::j:. Volume Bled Back .......... Bbls .:.:.:.:.:.:.:.:.:. Shut-in Pumping Min,'p'~i... ..~~r,~~" .....p.~,i.."" o ::¡:g$þþ ¡:¡:¡:¡:¡:¡:¡:¡:¡:¡:¡:¡:ij: ::¡:~¡¡:¡:¡:¡:¡~¡:¡::~it~ ~ ,1,11111: :i¡'ii¡iii!:ii¡ii:¡:!lil: 'l:i!:jjii,':~"II~: ~ 1,I'illl i,i:.,i,i,i,I,I,¡,i,i,il, :'i'i'i'·'·'·:III' 1!1 ii ~~ '!'!II~ ,I,I,I,I,!,!,!,!,!II,!I!,I,I,I,I,!,I,I,!,I,I,I,I,I,I,I ~~ .:i:~11 i'i!.ii:i~i¡l:i'i¡I~' i:i:·'i~:¡ii.:i:i¡·iii·:'ii¡·'i!' ~:¡:!.ii:i¡!:i¡i:i:i:i!j"·'i '1¡::i¡:i'!ii:!:lli'·!:!.¡'iI:i:1 ..........,,,.. ",,,........,,,, .............., ,..........,...., ............... ........""..... .............., ,..............., I. ............... .........,,,..... ~¡~¡~¡~¡~¡~¡~¡~¡~¡~j~¡~¡~¡~¡r¡~¡~¡~¡~¡¡¡¡¡i¡~jiji¡;#¡j¡;¡¡¡ ~~: ~ ~ ~; 1: 1:~:~: ~: ~:~~~:~:~~::~ ~ ~:~ :~;\: ~:~ ~ ~: ~: ~~~~! ::~~~ ~ ~~::~~ ¡;¡:¡i¡i¡i:i¡i¡i¡i¡i¡i::¡:¡::~ ::¡:::¡i:i¡i¡i¡i¡i¡i::¡i¡i¡i:i:i¡: ...........".. ,,,....,,....,,.. ,............., ................, :¡::!¡:¡:¡:::i:i:¡;¡i¡:¡:¡:¡i¡;j:¡:¡:¡:i:::¡:¡:¡:¡:¡:¡:¡¡¡:i:¡:¡ Itll Volume ........Voiüii-ïë"·"'" Bled Back Pumped r:mm:mm:] Bbls 1.1 Bbls Pumping Strks psi o 0 5 1 (30 ¡¡¡¡¡¡¡¡~r¡@;if ¡¡;~\~~~$.ø.i ....·"·1·5· ....·50.0.· ......... ....... ::::::;:;:;:::::;:;:.,:;:;:::::::;,',::,:,: 1f¡¡¡f¡¡¡¡ii: ¡¡¡¡¡¡¡¡¡¡iiij¡ ......">:'îtt· .....<!i:':!' ;!;. ~~~~~¡~¡mt~~~¡ ¡¡¡¡mt~~~¡ trr¡~¡~ßQ ¡~¡1¡~1¡Ö~Q¡ ........""$. ... 1'1 ß5. "......;ø .... .. . ~j~j~¡~j~¡~¡~¡~¡:;:!:!:!.¡~¡ ~r¡:j,!~hj:!:¡:¡:!.!~¡ :¡1¡1:r1(¡~~ 1:1¡1~~~~~¡ [/¡r)4.$. )450.0. ]~!:1~j:j~r¡~ml- j:j:¡~~j~m~~ :':':'I'i'i'I'i'~i i'¡'¡ij~~' '['I'['I'I¡I'·::~~·':¡'i~I~~ ""....."", ,,,,,......,,. ·i,I'i'i¡:'¡:·¡i'I¡~ii·ill~I~: ..".."...... .............. t~¡~t¡:¡:¡~¡~¡~¡~rj~ ¡~¡~¡~¡~¡~¡~¡~¡r~rj~¡~ ~ttt~~~~tt~~~ ~~~ttt~~tt~~~ ~ttttt;;~~;(~~~~ttttt~~~ ¡¡¡¡¡¡¡~¡¡fff¡¡;¡¡¡j¡¡¡¡¡i¡¡¡¡¡¡¡¡¡¡¡¡¡j¡¡¡¡¡ ; ~~ ¡ ~ ¡ ~ ¡ j ¡ ¡ ¡ ¡ ¡ ¡ ¡~¡ ~¡ ¡ r¡j¡~ J~¡ ¡¡1¡ ~ ¡~¡1¡1¡1 ¡1 ¡1¡ j¡~¡~ ~~~~~~:~:~:~:~;!;~¡~j~~~:~~~ :~:~:~~~:~~~~~~~~~~~~~~~~~~~ :i:;:i:i:i:i:i:;:;:;:i:i:i:iji:i:i:i:;:i:i:i:i:i:i:¡:¡ ;~;~~~~~tt¡¡;t;;;;; t~~;~;;~;t;~~t~t .;.;.;.:.:.:.:.:.:.;.;.;,;.:,:.;.:.:.:.:.:.:.:.:.;.;.:.: ¡:¡:¡;¡;¡:¡:::¡:¡:¡:¡¡¡:¡¡¡¡¡:¡:¡:¡i¡¡¡i¡¡¡¡¡¡j¡¡¡¡¡¡¡¡: ::;::::;;::;;:;:;:;:::::::::':::::::::::::::::::::::::::: :!:!:!:!:!:!:!:\:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:!:! 1;~;~;;;;:;:~:~:~:~;~:~:~:~:J:~:~:j:j:j:j:~:~:j:~:;:;: /1rrr¡ttttttMt¡jjijjjj Volume Pumped 3.1 Bbls ... Hole Depth 537IFt-MD I 2,6'17 Ft-TVD I '" I annulus and DP. Pumping down 4 ... casin~ Shoe De~th 4 ;:'''~ I Ft MD '1 '.": ':; Ft TVD ......Lf - ~ tJ !.....' - 19-5/8" 4O#/Ft L-80 BTC Casing Shoe Test LOT/FIT Hole Size: 18-1/2" '" RKB-CHF:I 23,31Ft Casinq Size and Description Type of Test: ppg Lb/100 Ft2 Lbs Lbs ppg psi Pressure Inte~ritvTest Mud Weight: .s 8 Mud 10 min Gel: 100 Rotating Weight: Blocks/Top Drive Weight: Desired PIT EMW: Estimates for Test: Casinq Test Mud Weight: Mud 10 min Gel: e~) 000 29,000 18.0 1250 ppg Lb/100 Ft2 psi Lbs Lbs bbls 96 42.0 2 ~)CO 85,000 2.9. DOO 3 Test Pressure: Rotating Weight: BlockslTop Drive Weight: Estimates for Test: r::::::~:::::::::::r::::::':::':::::::::: o 5 10 Shut-In o 1.5 bbls I '" I PIT 15 Second Shut-in Pressure, psi 395 ppg E Lost 15 psi during test, held 99,4% of l I test pressure, .. ..1 " 1 I 1 ,I ·~:~:d~:~::'":'!':=~~~~::~;~~~~~.<:. Go to PIT Plot. 8 8 0.052 X 2613 + . = 96 11 ./ "'L (2613 Ft-TVD) = = Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 4527 Ft-MD 000 500 3000 2500 2000 500 EMW W 0::: ::> en en w 0::: a.. 30 . 20 25 Minutes . 15 time, PIT Point . 2 3 Barrels ~CASING TEST -- LEAK-OFF TEST Comments: Pump Rate '..................¡ ...........,....., .........,........ ... JIIIIIIIIIIIIIIIIIIII~~~I Strk/min Pressure Integrity Test ... Volume Input Volume/Stroke I "'11~1~1~lil Bbls/Strk I Casing Test PRESSURE INTEGRITY TEST CONOCOPHILLlPS Alaska, Inc. ïE" I D t I "'~'0(~'nL~~' , "::;:1 a e: ,..,!¿,<:-;.;;:.... :..) #2 Mud Pump J 00-00 I ¡ ?O ~.--O LS Rig 3S-2,~ Well Name: ... used Pt¡mp Burley!H Drilling Supervisor Strokes Shut-in Min ......p~.i..... ¡:¡:¡:¡:¡:¡:¡:¡:¡:4.~~ !!:¡,¡·,!:J'·'·!.,III :!:¡!¡:¡!¡i¡:¡(àai !'!':'!'!.'!'!'!'!'!".I.I.I'!'Q""! .................... , .............. '.. ............ " .......... ',,', :.:.:.;.: .; ..... .. ,,,.. , '(¡'(fl'! " !f¡!ff!!!::,./.::i. ffffJ.%7P ¡¡¡¡¡11¡~¡¡¡1¡¡¡f:!:~;:';;!:;:!: .........$.10 ~¡f~¡¡¡~r¡¡¡~5~ .................. !ffff'Sa$. ",',',',',',',',',111 ~¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡¡~~ !!!!'!!!!!'!!''!!''96.0: '1,:,!,·,.,:,j'i,,:IÎ ;'·¡!¡!I!!::i¡:!:¡,i~1. ,.................... ··'·1J'·¡¡!¡!·'¡':'I.I~ .::::.....:X,'l('..:.: ......... . :::::::::;:::. ":. ,'....,..... " .I"" o 0,25 0,5 1 1,5 2 2,5 3 3,5 4 4.5 5 5,5 6 6,5 7 7,5 8 8,5 9 9,5 10 VOlume Bled Back ·······,···..······~Bbls ;:;:;:;:;:;:;:;:;:;:1 Pumping 1¡:::;~~:~¡~ ¡:!:!¡::::::]]i:::::ø.: II 1.1.¡i'i¡i¡/i;::'/!~il i:¡,!"':ii:'ill~/ ttttn1!4. ttt!\54.$.! !!I!III!JJII]IIIIIII!! !]!]I!I!! ¡'i'i¡i¡i'i'i¡i:i,i~,~ !':'!'!'!'¡'i¡!'~IJ.' !II ¡¡~rr¡;¡j¡~¡~¡~¡¡¡~¡¡¡¡¡' 1¡1¡1¡1¡1¡1¡1¡1¡;¡1¡¡¡i¡i¡i¡)¡1¡1¡ II II lilt Shut-in Min ...p'~.i.... o ¡¡¡¡ªIOQ: 1 \;4.9à :1)~)ï!J':UA; 2 ;}iii;4.~Þ:' 3 )249.5' 1"1"1'1'1'1'1'1'1'1'(((( 4 :d!14.9Ö! 5 ~¡:¡~~~~¡ 6 )249.0.! ~I 1 0 :¡¡!~~~~: 15 W!ª~~Q: "(¡"¡r¡'l'Ir'll'l.!', 20 ji~â~ii 25 )(24.$$.! :ïlrlr"lfrrfllï 30 \~4ai.¡ Pumped 1.1 Bbls Volume Bled Back t!ittttl Bbls Pumping Strks psi o 0 5 160 !tt¡/MJ@!ttØ$.Øl :,;¡¡,:i;¡::!i·:II:¡i:i:ij·;:11 . . . . . . . . . . . . .. ......"."... ........ !$.-.... ·OO$. :!:':¡::':::'¡:"~~:'i::¡~:íij 11~1I il:I!lililll:'I'¡~I;'!'/'~¡I¡~ ¡j¡1¡¡¡¡¡¡¡¡¡¡¡[j~~i¡i¡ilö· i.i'i'!'!:!:!¡·i~I:'!!il~~~ !!!!)!!!!!!':1:$.~}!$.ØQ :ïl"lïlïl11ïl I 1'.'1'111 1'11'1'11', t l' ~rmr~rtrm~t¡~t1t~1tjj~r !1!~!'!I'·'!!!!'!¡¡:'!.:!i·!I!:!·i!!·!!!!!!i:i.¡.¡·!':·: ,:¡:¡:,.: ,/!!!!::ii!iii:::.I!¡:¡'i¡:!i:::I!i/:J1'!:1.:i =- !¡!¡!!i¡.j.:i!·¡!\:!¡':ii::~¡'I::"'!'!·!:i!I·I:I:i!::1 . Pumped 3.1 Bbls ... Hole Depth 4.537IFt-MD I 2,t':,17IFt-TVD "'I annulus and DP. Pumping down ... Casing Shoe Depth t;27 IFt-MDI 2.643 Ft-TVD 19-5/8" 4O#/Ft L-80 BTC Casing Shoe Test LOT/FIT 4 Hole Size: 18-1/2' '" RKB-CHF:I 2B.3 Ft CasinQ Size and Description Type of Test: ppg Lb/100 Ft2 GOD Lbs 000 Lbs :8.0 ppg 1250 psi Pressure Inteq.ritvTest Mud Weight: 8.8 Mud 10 min Gel: 0.0 Rotating Weight: Blocks/Top Drive Weight: Desired PIT EMW: Estimates for Test: 8~): 29.. ppg Lb/100 Ft2 psi Lbs Lbs bbls 9,6 42.0 2. ::iOO 85,000 :,?9,OCO 3 CasinQ Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: Blocks/Top Drive Weight: Estimates for Test: 1.5 bbls I '" I PIT 15 Second Shut-in Pressure, psi 395 8.8 ppg E Lost 15 pSI during test. held 99.4% of l I. test pressure, ,.. ,I .. ..J I I .k%:~:~~::~.??~,:,«:~: ~~¥.~:$.~«. + Go to PIT Plot. 0.052 X 2613 = 13,96 "'L (2613 Ft-TVD) = = Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 4527 Ft-MD 3000 2500 2000 500 EMW w ~ ;:¡ Cf Cf w ~ 0.. 30 . r~;::::::::::':::::r:::::':':::':'::;i;:=r , 40 5 10 15 20 25 Shut-In time, Minutes o PIT Point 000 , 2 3 Barrels -ø-CASING TEST -£I- LEAK-OFF TEST Comments: . . FRANK H. MURKOWSKI, GOVERNOR AI/A.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W, 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk 3S-24A ConocoPhillips Alaska, Inc. Permit No: 204-061 Surface Location: 2565' FNL, 1266' FEL, SEC 18, TI2N, R8E, UM Bottomhole Location: 264' FNL, 2498' FEL, SEC 25, TI2N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ITom 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector 9-3607 (pager). BY ORDER OF THE COMMISSION DATED this ~ay of April, 2004 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. illips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com April 12, 2004 RECEIVED APR 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage Alaska Oil and Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 3S-24A Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 3S-24A, a development well. ./ Note: it is planned to abandon the original wellbore then set a CIPB at 10548' MY and place a permanent whipstock on top of the CIBP at 10547' MD. We will then cut and mill a window in the existing 7" production casing after squeezing cement into the 7" x 8-1/2" annulus at the whipstock depth. Planned KOP point from the 7" casing is +/- 10530' MD. Note: this well is to be temporarily completed as a 3-1/2" mono-bore producer. The spud date is expected to be approximately 5-1-04. If you have any questions or require any further information, please contact Kelly McLure at 265-6059. Sincerely, ~~~ Randy Thomas GKA Drilling Team Leader OR\G\NAl 1a, Type of Work: Drill 0 Re-entry 0 2, Operator Name: ConocoPhíllips Alaska, Inc. 3, Address: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 e RedrillU e RECEIVEO)ti/l ~ APR 13 2004 ExploratoryU Dev~ ~~ Gas Cons. ~~ooœ~~tJ Service 0 Development Gas []Anchorage Single Zone 0 5, Bond: U Blanket U Single Well 11. Well Name and Number. Bond No. 59-52-180 3S-24A 6. Proposed Depth: 12. Field/Pool(s): ,;' ,/ MD: 12483' TVD: 6022' Kuparuk River Field 7, Pro"rty Designation: ,j.JÇ-.of A~380107 & 25551 1b, Current Well Class: Stratigraphic Test 0 89' FNL, 2464' FEL, Sec. 25, T12N, R7E, UM Total Depth: 264' FNL, 2498' FEL, Sec. 25, T12N, R7E, UM ,/ 4b, location of Well (State Base Plane Coordinates): ./ Surface: x- 475994 y- 5993852 16. Deviated wells: P.O. Box 100360 Anchorage, AK 99510-0360 4a. location of Well (Governmental Section): Surface: 2565' FNL, 1266' FEL, Sec. 18, T12N, R8E, UM ,/ Top of Productive Horizon: Kickoff depth: 10530' 18, Casing Program Size Hole Casing 8.5" 7" 6.125" 3.5" 19 Total Depth MD (It): 13656' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filin9 Fee Property Plat ft. Maximum Hole Angle: Specifications Weight Grade Coupling 26# 9.3# L-80 L-80 BTC-Mod SLHT 8, land Use Permit: Kuparuk River Pool 13, Approximate Spud Date: 5/1/2004 ADL 2616 & 4624 9. Acres in Property: 2560 14, Distance to Nearest Property: 10. KB Elevation 15. Distance to Nearest " Zone- (Height above GL): 56' RKB feet Well within Pool: 3S-Z,í SY IH> 17, Anticipated Pressure (see 20 AAC 25,035) Max. Downhole Pressure: 3463 psig I Max. Surface Pressure: 2817 psig Setting Depth Quantity of Cement Top Bottom c, f, or sacks MD TVD MD TVD (including stage data) 4 70° length 2103' 28' 10180' 416 sx Class G 28' 5185' 10530' 12483' 6776' 6022' PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) 6068' Length Size 108' 4503' 9.625" 11231 ' 2534' 3.5" 13294'-13370' o BOP SketchU o Diverter Sketch 0 21, Verbal Approval: Commission Representative: 22, I hereby certify that the foregoing is true and correct to the best of my knowledge, Printed Name R. Thomas ~\~ Commission Use Only Permit to Drill , / I API Number: Þl> !j~'1 Æ:!'''/ ¡II Permit Approval Number: :2D 7 -~ I 50/08 - L.U7'.;)b -l) Date: ¥þ:r/ð t../ Conditions of approval: Samples required 0 Yes ~NO Mud log required H og sulfide measures 0 Yes%No Directional survey required Signature Other: (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) 13550' 6028' Cement Volume MD TVD 16" 81 sx ArcticCrete 525 sx AS III lite. 415 sx liteCrete 108' 2613' 108' 4527' 7" 184 sx LiteCrete 950 sx Class G IPerfOration Depth TVD (ft): 5929'-5959 Drilling Program~ Time v, Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis 0 20 AAC 25,050 requirements 0 11255' 13650' 5139' 6066' Contact Kelly McLure @ 265-6059 ·K.it[~ Á'1r~' j:j,A"" Title Kuparuk Drilling Team Leader Phone ¡<: fÆ, () Date 0/ I( 3/0« PreDared bv Sharon Al/suD-Drake Isee cover letter for other requirements lJ.?s K No ~ Yes 0 No " '\"'-.~ \~\Sa ~ -\(~ ~ Form 10-401 Revised 3/2003 . .--' COMMISSIONER BY ORDER OF THE COMMISSION 'irff v Date: ORIGINAL Submit in duplicate e .lícation for Permit to Drill, Well 3S-24A Revision No.O Saved: 12-Apr-04 Permit It - Kuparuk Well 3S-24A Application for Permit to Drill Document MoximizE W~II I/Qhn Table of Contents 1. Well Name.. ..... ................ ............ .............. ..... ....... ......... .............. ............................. 2 Requirements of 20 MC 25.005 (f) .......................................................................................................2 2. Location Sum mary ......... ........ .............. ... ..... ....... ........ .......... .......................... ......... 2 Requirements of 20 MC 25.005(c)(2) ......... .......... ........... .......... ........ ......... ....... ................ ................... 2 Requirements of 20 AAC 25. 050(b) .................................. ... .......... ..... ..... ......................... .......... ........ ... 2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 MC 25.005(c)(3) ............. .......... ....... .......... ............. ....................... ............ ........... 3 4. Dri II i ng 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)(5) .................................................................................................. 3 6. Casing and Cementi ng Program........ ........ ....... ......... .......... ......................... .......... 3 Requirements of 20 AAC 25.005(c)(6) .... ............ .......... ..... ........ ............ ......... .... .......................... ......... 3 7. Diverter System Information ...................................................................................4 Requirements of 20 MC 25.005(c)(7) ..... .......... ....................... ............... ................. ............. ......... ....... 4 8. Dri II i n9 FI u id Program .......... ............. .... ..... ........ ......... ......... ...... .................... ......... 4 Requirements of 20 MC 25.005(c)(B) .. ................ .................. ............ ..... ...... ......... ........ .................. ..... 4 9. Abnormally Pressured Formation Information...................................................... 5 Requirements of 20 MC 25.005 (c)(9) .................................................................................................. 5 1 O. Seism ic Analysis...... ...... ........ ... .................. ........ ........... ........................... ......... ...... 5 Requirements of 20 MC 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bond i ng ........ ...... ... .................... ...... ........... ......................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program .....................................................................................5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 ORIGINAL 3S-24A PERMIT /T,DOC Page 1 of 6 Printed: 12-Apr-04 e iA plication for Permit to Drill, Well 3S-24A Revision No.O Saved: 12-Apr-04 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 5 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................5 15. Attachments .................... ............... ... ............ ... .... ......... ......... .............. .................... 5 Attachment 1 Drilling Program ..... ........... ....... .... ......................... .... .......... .................. ......... ................. 5 Attachment 2 Directional Plan.......... ...................... ................................. ............................6 Attachment 3 Well Schemaics...................... ......... ................................... ...........................6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multip/e well branches; each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3S-24A. / 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file witll the commission and identified in the application: (2) a plat identifying the property and the property's owners 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 ::.-ection lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) tIle proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,993,851 12565' FNL,' 126,6' FEL"r See 18, T12N, R8E,'UM /' " RKB Elevation I Eastings: 475,993 o· Pad Elevation 55.7' AMSL 27.7' AMSL Location at Top of Productive Interval (Kuparuk C-4 Sand) NGS Coordinates Northings: 5,985,790 89' FNL, 2464' FEL, See 25, T12N, R7E, UM Eastings: 469,960 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 12249 5870 5814 ,/ / Location at Total Depth 1 264' FNL, 2498' FEL, NGS Coordinates Northings: 6,000,818 Eastings: 499,370 See 25, T12N, R7E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 12483' 6022' 5966' " .'/ and (D) other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a PemJit to Drill (FOI7n 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the propœ;ed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those we/Is, to the extent that those names are known or discoverable in public records; and show that each named operator has been furnished a copy of the application by certified mail; or ORtG1NAL 3S-24A PERM/T IT.DOC Page 2 of 6 Printed: 12-Apr-04 e Application for Permit to Drill, We1l3S-24A _ Revision No.O __ Saved: 12-Apr-04 (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 Dnll must be accompanied by each of the fa/lowing items¡ except for an item already on file with the commission and identified in the application: (3) a diagram and descliption ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.03{i or 20 MC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items¡ except for an item already on file with the commission and identified in the application: (4) information on drilling hazards¡ including (A) the maximum downhole pressure that may be encountered- criteria used to determine it, and maximum potential surface pressure based on a methane gradient; BHP data on offset injectors indicates ~hat the current reservoir pressure for 3S-24A is ~ 3267 psi at 6009' 1VD, 0.59 psi/ft or 10.46 ppg EMW. v The maximum potential surface pressure (MPSP) while drilling 3S-24A is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at '1VD: MPSP =( 5870 ft)*(0.59 - 0.11 psi/ft) = 2817 psi (B) data on potential gas zones¡' KOP is in the C-40 Sand. The well bore is not expected to penetrate any gas zones between KOP and TD. " And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones¡ and zones that have a propensity for differential sticking; 1. The first potential hazard is the LOT at the window. It is planned to cement this annular void with enough class "G" cement to cover and seal this section of the original wellbore. Once that is achieved, a LOT/FIT of at least 13 ppg should be attained. 2. Sloughing shales in the Kalubik near the fault zone could cause hole trouble while drilling, tripping and running the liner. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items¡ except for an Item a/ready on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity testS¡ as required under 20 MC 25.030(1); A procedure is on file with the commission for performing LOT's. For 3S-24A the procedure will be followed after milling the window, with one exception. The formation at the window depth will be pressured until leak-off occurs or to 13.0 ppg EMW, which ever comes first (see step 6 in the procedure). 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dnll must be accompanied by each of the fa/lowing items¡ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted line0 pre- perforated line0 or screen to be installed; ORIGINAL 3S-24A PERMIT IT,DOC Page 3 of 6 Printed: 12-Apr-04 e Casing and Cementing Program I CsglTbg I ~~: I Weight I I I Length I 00 (in) (in) (/blft) Grade Connection (ft) Oringial Wellbore 3S-24 7" 8-1/2 26 L -80 3-1/2" 8-1/2" 9.3 L -80 liner 3-1/2 8-1/2" 9.3# L-80 Tubing Top MD/TVD (ft) BTC-Mod EUE 8 RD 8RD EUE MOD 2546' 28'/28' 11104' MD 24'/24' 10530 3S-24A Sidetrack Plan Window In the 7" Casing 3-1/2" liner 8-1/2" L-80 BTC-Mod 28'/28' 26 6-1/8" 9.3# L-80 SLHT 2103' Plann TOC 10180/5185' 3-1/2 Tubing 6-1/8" 9.3# L -80 8RD EUE 10530 MOD 28'/28' Application for Permit to Drill, Well 3S-24A .. Revision No,O __ Saved: 12-Apr-04 Btm MD/TVD (ft) 11255'/5139 13650' / 6066' 11154/5102 10530'/ 6776' 12483'/ 6022' Cement Program Original TOC = 9500' MD Packer/PBR w/ wireline entry guide stung below the ZXP Squeeeze shoe if insufficient LOT 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Pelmit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); 416 sx 15.8 Class G, 1.16 f't3/sk (TOC 150' abovetop of liner) 10530'/6776 Packer/PBR w/ wireline entry guide stung below the ZXP :{( This is a mono-bore completion requiring a waiver of ACC 20.25.412 (b). This rotary sidetrack will exit pre-existing casing at ± 10530' MD. BOPE will be installed prior to exiting the casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (8) a dril/ing fluid program, including a diagram and description of the drilling fiUld system as required by 20 MC 25.033; ,/ Drilling will be done using a LSND mud systems having the following properties: Sidetrack Hole mud properties initial Top HRZ Top Kalubik Density (ppg) 9.5 - 10.2 10.5 10.5 Funne/ Viscosity 45-55 45-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 (cP) Plastic Viscostiy (lb1100 6-12 8-18 8-18 sf) 10 second Gel Strength 2-5 4-7 4-7 (1b/1 00 sf) 10 minute Gel Strength 4-10 7-12 7-12 (/b/1 00 sf) pH 9-9.5 9-9.5 9-9.5 AP/ Filtrate(cc) <6 <6 <4 Solids (%) 6-11 10-15 10-15 ORIGINAL Kuparuk- TO ~ 10.9 ,/ 42-58 20-25 15-25 4-8 8-16 9-9.5 <4 15-19 3S-24A PERMIT IT. DOC Page 4 of 6 Printed: 12-Apr-04 e Application for Permit to Drill, Well 3S-24A _ Revision No.O __ Saved: 12-Apr-04 Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Pemlit 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: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applícation 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: (iO) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items" except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating dri/ling vessel, an analysis of seabed conditions as required by 20 MC 25.061(b); N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 (Bonding}have been met; 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 Penmt 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: 1. See attachment 1, and refer to Attachment 3, Well Schematics. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of on DS-3S into the 3S-17A well. All cuttings will be processed through Doyon's ulta-sonic processor and then disposed of either at 3S- ./ 17A or KRU's, lR-18 Class II disposal well. 15.Attachments: Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 Well Schematics ./ ORIGINAL 3S-24A PERMIT /T.DOC Page 5 of 6 Printed: 12-Apr-04 e 3S-24A Drilling Program Pre-Rig Well Work: 1. Notify the AOGCC field inspector 24 hours prior to commencing pre-rig work. 2. Set Cement retainer at 13240' MD with the top perforations at 13294'. (PT to ensure it is set correctly) 3. Rig CTU: Sting into retainer and squeeze off perforations. Pull above and lay in 50' of cement above plug. 4. Tag cement plug, pull OV, load IA and tubing with seawater. 5. CMIT against cement plug. (AOGCC present as witness) 6. Freeze protect well with diesel. 7. Set BPV and VR plug. e Rig Work: 1. Notify the AOGCC field inspector 24 hours before spud and BOP test. MI/RU Doyon 141. Install a TWC. ND the upper tree assembly. NU and test the 13-5/8" BOPE to 250# 1 3500# (note: a 11" x 13-5/8" DSA or spool is required). Retrieve the TWC. (11"x 5M- it is FMC Gen 5 wellhead) 2. Pull VR plug. 3. Screw into the 3-112" tubing with the landing joint. Back out lockdown screws. UD the tubing hanger. Screw in to the tubing and circulate the well clean with seawater. UD the tubing and GLM's. 4. R/U E-Line. Run a CCU 6-1/8" Gage Ring to ± 10600' MD'. 5. Set 7" CIBP at 10548' MD (Note: CIBP must be ~ 2.0' above a casing collar and ~ 20' below a casing collar- actual depth is adjustable). POOH, RD E-line. 6. PU and RIH with Baker's "WindowMaste¡" whipstock system, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Orient and set the whipstock using the MWD with the bottom of the whipstock set at 10548' MD (basically on top of CIBP) 7. Shear off the whipstock. Displace the 7" casing and the pits with LSND mud. Mill the window in the 7", 26#, L-80 casing, and continue milling until the upper watermelon mill is outside the casing: ~ 29'. After reaming through the window to eliminate burrs and other irregularities. Minimum acceptable EMW = 13.0 ppg. (f:'¡¿~ A{c'-~rr t;,.e/Æ?ð/,tV'é¿¿-~/~ÆJ2> ß ¥-/).ói 8. P/U a 6-1/8" PDC bit, PDM, MWD, LWD, non-mag flex collars and jars as required. RIH with the HWDP from the derrick, and then P/U an additional 30 stands of 4.0" DP. Finish RIH with DP from the derrick. Carefully wash the last 15'-20' to bottom. 9. Drill ahead using directional program as per Baker-Inteq. The sidetrack depth is in the C-40 and no thief zones are expected near this depth. Maintain the LSND mud properties as per the MI program. Watch the ECD and limit ROP as necessary to maintain ECD .:5. 13.5 ppg. The MW should be ~ 10.5 ppg at the T/HRZ: 5500' TVD. The MW should be ± 10.9 ppg before drilling into the T/Kuparuk: 5870' MD. ,/' ^'" 1 O. Control drill as needed through the Kuparuk as needed for good quality LWD logs. Continue drilling into the Miluveach Shale to give ± 200' of rat hole below the base of the Kuparuk C. The proposed TD is ± 12483' MD, 6022' TVD. At TD, circulate bottoms and make a wiper trip up near the window. RIH to TD. Circulate and condition the hole to run the liner. POOH. 11. R/U and run the 3-1/2" liner to TD. The required overlap is ~ 150': TOL = 10,380' MD. Rotate and reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. 12. Pump 10 bbl of CW100. Test Lines to 4000 psi. Rotate & reciprocate the liner throughout the job. Pump 15 bbl of Mud Push Spacer. Mix and pump 420 sx of Class G. Drop the DP dart and displace with mud. Watch for the liner wiper plug to shear. Stop reciprocating the liner and finish displacement. Rotate the liner as long as possible. Slow the pump rate for the last 3 bbl and bump the plug with 1000 psi over final displacement pressure. Check the floats. Pressure up to ± 2500 psi and set the liner hanger. Pressure up to 3500 psi to n P , G ! ",. \, J~ L '<C~"~ .;.; < .:~._,,' ,j, oJ;/ '1 , e e release the HR setting tool and set the ZXP using slack off weight: ~ 25,000#. Pressure up to ± 500 psi and slowly pull up out of the Liner hanger. When the pressure bleeds off to the annulus, immediately circulate bottoms up (± 90 bbl) at high rate. Note any cement and/or spacer returns. SID and test the ZXP to 1000 psi. RU and reverse out cement. Test casing. Flush all lines and change well over to freshwater. RID Dowell. 13. Displace the well above the Top of liner with seawater and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. 14. R/U and run the 3-1/2" tubing with the PBR seal nipple. RIH and tag the TOL. Space out the tubing string with pup joints such that there remains 1 '-2' of free travel in the seal assembly. Install the tubing hanger and landing joint. Displace the well above the TOL with clean seawater. Sting into the PBR and land the tubing hanger. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the lA, PBR and TOL to 3500 psi. Bleed off all pressures. 15. Install a TWC. ND BOPE. NU and test the 4-1/16" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to ± 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve (114 bbl). Install a BPV. RID and M/O Doyon 141. Post-Rig Well Work: 1. Change out shear valve 2. Coil tubing mud clean out 3. Run Cement Bond Log 4. Perforate 5. Obtain Initial Pressure measurement 6. Change out dummy valves to GL V x 5 OR'GJ~LÄL ConocJPl,illips ConocoPhillips Ala.lnc.,Slot #24 Pad 3S, Palm, North Slope, Alaska PROPOSAL alNG Page 1 Wellbore: 24A Wellpath: 24A Version #1 Date Printed: 26-Mar-2004 r&ií. BAKER HUGHES INTEQ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon 141 55,7ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 219,67 degrees Bottom hole distance is 10231.60 Feet on azimuth 216,20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated nn,f""~'" f ConocÓPhillips ConocoPhillips Alas'lnC.,Slot #24 Pad 3S, Palm, North Slope, Alaska PROPOSAL .ING Page 2 Well bore: 24A Wellpath: 24A Version #1 Date Printed: 26-Mar-2004 ',CiI. BAKER HUGHES INTEQ 10400,O( 66.72. 220,4' 4812.6~ 5987188,8 470438S N70 22 33.861( W150 14 25.0982, 8675.4~ 10412,O( 68.3& 219,3!;. 4817.2¿ 5987180,3 470431,4~ N70 22 33,777; W150 14 25.3062. 8686.5~ 10430,O( 68.3E, 219,3~ 4823.8i 5987167,4 470420.71 N70 22 33,6501 W150 14 25.6166 8703.3' 10500.0( 69,31;1 216.5~ 4849.1 ' 5987116,1' 470380.4' N70 22 33,1437 W150 14 26.790~ 8768.5; 10530.0( 69.7~ 215.3~ 4859,5f 5987093.4' 470363.81 N70 22 32.9198, W150 14 27,2737 8796.6, 10600.0( 67,6€ 213.4' 4884.9i 5987039.7, 470326.8~ N70 22 32.3902- W150 14 28.3509 8861.5; 10700.0( 64,7Q, 210.4!;. 4925.3~ 5986962,3 470278,11 N70 22 31,626& W150 14 29.7662, 8952.2' 10800,O( 61,7€ 207.4; 4970.3f 5986884.4 470234,61 N70 22 30,8585 W150 14 31.030Q 9039.9; 10900.0( 58,94 204.1~ 5019,8L 5986806.3 470196.5~ N70 22 30.0891 W150 14 32.1361 9124.3C 11000.0( 56,1€ 200.7t 5073.4~ 5986728.5 470164.0; N70 22 29.322:;' W150 14 33,0791 9204.9( 11100.0( 53,52. 197.1' 5131.Of 5986651.3 470137.2' N70 22 28.561~ W150 14 33.8545 9281.3~ 11200.0( 50,9€ 193.2(, 5192,3' 5986575.1 470116.2" N70 22 27.8116 W150 14 34.4584 9353.2€ 11252.8¡ 49,6~ 191.a¡ 5226,O~ 5986535.3' 470107.6' N70 22 27.420& W150 14 34.7072 9389,3~ 11300,O( 49.6~ 191.0:; 5256.5~ 5986500.1 470100.6; N70 22 27.073~ W150 14 34,9075 9420,9C 11400,O( 49.6~ 191.0:;' 5321.2.1 5986425.3 470085.8' N70 22 26.337C W150 14 35,3322 9487,8:; 11500.0( 49,6~ 191.0, 5385,9~ 5986350.5 470071,Ol N70 22 25.6007 W150 14 35.7569 9554.7.1 11600.0( 49,6~ 191.0, 5450,6¡ 5986275.7 470056.1t N70 22 24.864!;¡¡ W150 14 36.181!;¡¡ 9621.6~ 11700,O( 49,69 191.0:;' 5515.3' 5986200.9 470041.3" N70 22 24.1282. W150 14 36,6062 9688,5; 11800.0( 49,6~ 191.0, 5580.0( 5986126.1 470026.5( N70 22 23.391~ W150 14 37,030& 9755,4~ 11900,OC 49.6~ 191,0, 5644.6~ 5986051.3: 470011.7t N70 22 22,6557 W150 14 37,455!;¡¡ 9822,4' 12000,O( 49,69 191,0:;' 5709.3~ 5985976,5 469996,9' N70 22 21,9194 W150 14 37,8801 9889,3~ 12100.0( 49,6~ 191.0, 5774,O¡ 5985901,7 469982,1 : N70 22 21,1831 W150 14 38.3047 9956.2~ 12200,O( 49.6~ 191.0, 5838,7~ 5985826.9 469967.3' N70 22 20.446~ W150 14 38.729~ 10023,1¡ 12249,3i 49.69 191,0:< 5870.7( 5985790,0 469960.0( N70 22 20,0834 W150 14 38,9389 10056,2' 12283,3~ 49,6~ 191,0:<' 5892.7( 5985764,5 469954.9( N70 22 19,833C. W150 14 39,083~ 10078,9; 12300.0( 49,6~ 191.0:<' 5903,4~ 5985752.1 469952,5l N70 22 19,7106 W150 14 39.153~ 10090.0! 12400,O( 49,69 191,0:< 5968.1.1 5985677.3 469937,6! N70 22 18,974:; W150 14 39,5785 10157,0' 12483.3~ 49.69 191,0:<' 6022,Of 5985614,9 469925,3- N70 22 18,3604 W150 14 39,9325 10212,8' All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon 141 55,7ft above Mean Sea Level) Vertical Section is from O.OON O,OOE on azimuth 219.67 degrees Bottom hole distance is 10231.60 Feet on azimuth 216.20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ~illips ConocoPhillips Alaslnco,Slot #24 Pad 3S, Palm, North Slope, Alaska PROPOSAL ~ING Page 3 Wellbore: 24A Well path: 24A Version #1 Date Printed: 26-Mar-2004 r&ii. BAKER HUGHES INTEQ 8472,O~ 10400.0( 10412.0( 10430.0~ 10530.0( 11236.7~ 11252,8~ 11685,1< 11971.1" 12141,1~ 12200,O( 12249.3i 12283,3~ 12483.3f 4095.7~ 4812.6{ 4817,2< 4823,8i 4859,5f 5215.7( 5226,O~ 5505,7( 5690.7( 5800.7~ 5838.7t, 5870.7( 5892.7~ 6022.Of 5310.99~ 6681.19~ 6689.70~ 6702.63~ 6776.84~ 7323.78~ 7335.80~ 7659,40~ 7873.46~ 8000,74~ 8044,78~ 8081,73~ 8107,19~ 8256.89~ 4383,47\1\C-40 (K-3) 5534,06\1\ TOD WhiDstock Face 5541.17\1\ Base WhiDstock Face 5551.79\1\End Milled Openhole, KOP4/100 BldlTm 5608.48\1\4/100 DroDlTm 5860.55\1\ TOD Morraine 5862.96\1\ EOC 5925.96\1\ TOD HR7 5967.64\1\ Base HR7 5992.42\1\ K-1 6000.99\1\51/2 Continoencv Cso PI. 6008.19\1\3S-24A TOD KUDaruk Tot 6013,15\1\ Miluveach 6042.29"" TO 24A Top Kuparuk TGT 24 Feb 04 5870.7( N70 22 20,( 5985790.0 21-Jan-200< W150 1438,9: 469960,01 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon 141 55.7ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 219.67 degrees Bottom hole distance is 10231,60 Feet on azimuth 216,20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORfGINAL -:I: III<ì'EQ - Scale 1 cm = 50 ft <!nocoPhillips Alaska, II: Location: North Slope, Alaska Field: Palm Installation: Pad 3S Slot: Slot #24 Well: 24 Well bore: 24A East (feet) -> ConocJi)hillips Created by: Planner Date plotted: 26-Mar -2004 Plot reference is 24A. Ref wellpath is 24A Version #1. Coordinates are in feet reference Slot #24. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon 141 Rig Datum to Mean Sea Level: 55.70 It. Plot North is aligned to TRUE North. -6600 -6500 -6400 -6300 -6200 -6100 -6000 -5900 -5800 -5700 -5600 -5500 -5400 -5300 -5200 -5100 -6500 / / / / @ 24A Top Kuparuk TGT 24 Feb 04 KOP LOCATION: 1312'FSL,1991'FEL SEC, 24, T12N, R7E I I t; / / Top Whipstock Face Base Whipstock Face End Milled Openhole, KOP 4/100 Bld/Trn / Top HRZ Base HRZ TARGET LOCATION: SEC, 25, T12N, R7E 89' FNL, 2464' FEL 51/2 Contingency Csg PI. 3S-24A Top Kuparuk Tgt Miluveach 3 1/2in Casing TO TD LOCATION: ;' 264' FNL, 2498' FEL SEC. 25, T12N, R7E ORIGINAL - -6600 - -6700 - -6800 - -6900 - -7000 - -7100 - -7200 - -7300 ^ I - -7400 ~ ~ ::r - -7500-:;; CD CD - - - -7600 - -7700 - -7800 - -7900 L - -8000 - -8100 en - -8200 £ ã> o - -8300 3 II (]I o _ -8400;::t! ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Slot: Slot #24 Field: Palm Well: 24 Installation: Pad 3S Well bore: 24A Scale 1 cm = 200 ft East (fee~ -> -10000 -9600 -9200 -8800 -8400 -8000 -7600 -7200 -6800 -6400 -6000 -56 0 -5200 -4800 -4400 -4000 -3600 -3200 -2800 -2400 -2000 -1600 -4000 I I I I -4000 & & / I 4600 -4400 / 3600 / -4400 ,( 4700 / / / 3700 I 4800 / / 3800 <' 4600 /' / -4800 / 5000 -4800 / T ;' 3600 - / 5100 / / / I 5200 4000 / -5200 / <' S300 -52_ / 4100 , "'" / / I .... / 4200 I 5600 -5600 , -5600 / / .700 ;' 4300 , / " 5600 / I 5900 I .... /' ~ 6000 -6000 / -6000 ,/ 4500 C) / / 4"'" / ~ -6400 / -6400 ^ 4700 / I - / 4800 Z - G1$ -6800 -6800 0 --t:. 4000 :+ ::r ~ sooo - -7200 5100 -7200 ø' ~ CD 5200 - 5200/ 5300 - r- 5300/ "'" -7600 /' .... -7600 "",I' 5600 /' / .700 -8att -8000 5500/ ."'" / 5600/ /' OJOO / 5700/ -8400 / -8400 / 5800/ / 5900/ / -8800 / / -8800 ~ OJOO_ (j) 0 / () !II 0 ~ m N II -9200 -9200 E () 0 3 II Q) -9600 \,) 13 -9600 0 0 (j) ;:: ! -10000 -9600 -9200 -8800 -8400 -8000 -7600 -7200 -6800 -6400 -6000 -5600 -5200 -4800 -4400 -4000 -3600 -3200 -2800 -2400 -2000 -1600 Scale 1 cm = 200 ft East (feet) -> -- ..: l,rrEQ <I: 0 4560 CD " E u =~- 4680 Q) ~ C/) 4800 4920 5040 - - CÞ CÞ 5160 .... - .s:: - Co 5280 CÞ C ii 5400 CJ :e CÞ > 5520 CÞ ::::J a.. I- 5640 I V 5760 5880 6000 6120 6240 8400 8520 8640 Scale 1 cm = 60 ft <!OOCOPhilliPS Alaska, I.!- Location: North Slope, Alaska Field: Palm Installation: Pad 3S Slot: Slot #24 Well: 24 Wellbore: 24A Conoc;phillips Created by : Planner Date plotted : 26-Mar -2004 Plot reference is 24A. Ref wellpath is 24A Version #1. Coordinates are in feet reference Slot #24. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon 141 Rig Datum to Mean Sea Level: 55.70 ft Plot North is aligned to TRUE North. WELL PROFILE DATA Point MD Inc Azi TVD North East deg/10OO V. Sect Tie on 10400,00 66,72 220.41 4812,65 -6681,19 -5534,06 0,00 8675.49 End of BuildlTum 10412.00 68,38 219,39 4817.24 -6689,70 -5541,17 15,90 8686.58 End of Hold 10430,00 68,38 219,39 4823.87 -6702,63 -5551,79 0.00 8703,31 KOP 10530,00 69,79 215,38 4859.58 -6776,84 -5608.48 4,00 8796,62 End of DroplTum 11252.82 49,69 191,02 5226,03 -7335,80 -5862,96 4.00 9389,33 Target 24A Top Kuparuk 12249,37 49,69 191,02 5870.70 -8081,73 -6008,19 0.00 10056.21 End of Hold 12283,38 49,69 191,02 5892.70 -8107,19 -6013.15 0,00 10078,97 T.D, & End of Hold 12483,38 49,69 191,02 6022,08 -8256,89 -6042,29 0,00 10212,81 Top Whipstock Face Base Whipstock Face 6936 --'' End Milled Open hole, KOP 4/100 BldlTrn '67,68 - ---. 4/100 DroplTrn 64,70 -"-, _ DLS: 4,00 deg/100ft 58,94 56.18 53,52 50,98 -'- '-'- -'-- ---'-'- Top Morraine EOC '-'. ""'-"'-' "-, "..'..-.--.,..,..-,-, Top HRZ -"~ "._'-~ 24A Top Kuparuk TGT 24 Feb 04 K-1 5 1/2 Contingency Csg PI. 3S-24A Top Kuparuk Tgt Miluveach in Casing TO 8760 8880 9000 9120 9240 9360 9480 9600 9720 9840 9960 10080 10200 10320 10440 Vertical Section (feet) -> Azimuth 219.67 with reference 0.00 N, 0.00 E from Slot #24 ORIGINAL <:onocJPt,illips ConocoPhillips AlaS'lnC.,Slot #24 Pad 3S, Palm, North Slope, Alaska PROPOSAL ~lNG Page 1 Well bore: 24A Well path: 24A Version #1 Date Printed: 29-Mar-2004 J&ií. BAKER HUGHES INTEQ 'I Grid Northin>l '/'IGñd Eastil\9 5993851,5800 475993,5000 Palm INOrth Alionment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon 141 55,7ft above Mean Sea Level) Vertical Section is from Q.OON Q,OOE on azimuth 219,67 degrees Bottom hole distance is 10231,60 Feet on azimuth 216.20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ConocÓPhillips ConocoPhillips Alas'lnc.,Slot #24 Pad 3S, Palm, North Slope, Alaska PROPOSAL .1NG Page 2 Well bore: 24A Wellpath: 24A Version #1 Date Printed: 29-Mar-2004 r&ií. BAKER HUGHES INTEQ 10400.00 66.72 220,41 4812,65 6681.19S 5534.06W 0,00 8675.49 Too Whiostock Face. Tie on 10412,00 68,38 219.39 4817,24 6689,70S 5541,17W 15,90 8686.58 Base Whipstock Face, End of BuildlTum 10430.00 68.38 219.39 4823.87 6702,63S 5551,79W 0.00 8703.31 End Milled Openhole, KOP 4/100 BldlTm, End of Hold 10500.00 69.36 216,58 4849.11 6754,09S 5591.96W 4,00 8768.57 10530,00 69,79 215.38 4859,58 6776.84S 5608.48W 4,00 8796.62 4/100 DroolTm. 3DJ Kick off Poi 10600.00 67,68 213.41 4884,97 6830,66S 5645,34W 4,00 8861.57 10700,00 64,70 210.49 4925,35 6908,25S 5693.76W 4,00 8952.21 10800,00 61.78 207,43 4970.38 6986,34S 5737.01W 4.00 9039.93 10900,00 58.94 204,19 5019.84 7064,54S 5774,88W 4.00 9124.30 11000,00 56.18 200,76 5073.49 7142,48S 5807,17W 4,00 9204.90 11100,00 53.52 197,11 5131.08 7219.78S 5833.72W 4.00 9281.35 11200,00 50.98 193,20 5192.31 7296,05S 5854,43W 4.00 9353.28 11236,79 50.08 191.69 5215.70 7323,78S 5860,55W 4,00 9378.53 Top Morraine 11252.82 49.69 191.02 5226.03 7335,80S 5862,96W 4,00 9389,33 EOC. End of DroolTum 11300.00 49.69 191,02 5256.55 7371,11S 5869.83W 0,00 9420,90 11400,00 49.69 191,02 5321.24 7445,97S 5884.41W 0,00 9487.82 11500,00 49.69 191,02 5385.93 7520,82S 5898,98W 0,00 9554.74 11600,00 49.69 191,02 5450,62 7595.67S 5913,55W 0.00 9621.65 11685.14 49,69 191.02 5505,70 7659.408 5925.96W 0,00 9678,63 Top HRZ 11700.00 49.69 191.02 5515,31 7670.52S 5928.13W 0,00 9688,57 11800.00 49.69 191.02 5580.00 7745.37S 5942.70W 0,00 9755.49 11900,00 49,69 191,02 5644,69 7820,23S 5957,27W 0,00 9822,41 11971.12 49,69 191.02 5690,70 7873.46S 5967.64W 0.00 9870,01 Base HRZ 12000.00 49,69 191.02 5709,38 7895.088 5971.85W 0,00 9889,33 12100,00 49,69 191.02 5774.07 7969.938 5986.42W 0,00 9956,25 12141.16 49,69 191.02 5800,70 8000.748 5992.42W 0,00 9983,80 K-1 12200.00 49,69 191.02 5838,76 8044.788 6000,99W 0.00 10023.17 51/2 Continoencv Cso pt, 12249.37 49,69 191.02 5870,70 8081.738 6008.19W 0.00 10056,21 38-24A Top Kuparuk Tgt, 24A Top Kuparuk TGT 24 Feb 04, En. of Hold 12283.38 49,69 191,02 5892,70 8107,198 6013.15W 0.00 10078,97 Miluveach. End of Hold 12300,00 49.69 191.02 5903.45 8119.63S 6015.57W 0.00 10090,09 12400.00 49,69 191.02 5968,14 8194.48S 6030,14W 0.00 10157,01 12483,38 49,69 191,02 6022.08 8256,898 6042,29W 0,00 10212,81 TO, C-40 (K-3), 3 1/2in Casing, End of Hold All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon 141 55,7ft above Mean Sea Level) Vertical Section is from O,OON O,OOE on azimuth 219,67 degrees Bottom hole distance is 10231,60 Feet on azimuth 216,20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ConocJPhillips ConocoPhillips Alas'lnc.,Slot #24 Pad 3S, Palm, North Slope, Alaska PROPOSAL -'ING Page 3 Well bore: 24A Well path: 24A Version #1 Date Printed: 29-Mar-2004 J&ií. BAKER HUGHES INTEQ MDlftl Cômi'tîêôt 8472,02 4095.70 5310,998 4383.47W ,C-40 (K-3) 10400.00 4812,65 6681.198 5534,06W Too Whiostock Face 10412,00 4817,24 6689.70S 5541,17W Base Whiostock Face 10430,00 4823,87 6702,63S 5551,79W End Milled Openhole. KOP 4/100 Bld/Tm 10530,00 4859.58 6776,84S 5608.48W 4/100 Droo/Tm 11236,79 5215.70 7323,78S 5860.55W Too Morraine 11252,82 5226.03 7335,80S 5862,96W EOC 11685,14 5505,70 7659.40S 5925,96W Too HR7 11971,12 5690.70 7873,46S 5967.64W Base HRZ 12141,16 5800.70 8000,74S 5992.42W K-1 12200,00 5838,76 8044.78S 6000,99W 5 1/2 Continaencv Cso PI. 12249,37 5870.70 8081,73S 6008.19W 3S-24A Too Kuoaruk Tat 12283,38 5892.70 8107,19S 6013,15W Miluveach .-" 12483,38 6022.08 8256,89S 6042.29W TO Tarøets Name 'I NOrthfftl EastfftJ TVDlftl 24A Top Kuparuk 8081.73S 6008.19W 5870,70 TGT 24 Feb 04 latitude N70 22 651651 Planned 12483,38 6022,08 ISCWSA MWD Error Model MWD+IIFR - ISCWSA - 28 Jan 03 OJH MWD+SAG - ISCWSA - 28 Jan 03 OJH 10400.00 4812.65 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon 141 55,7ft above Mean Sea Level) Vertical 8ection is from O,OON O.OOE on azimuth 219.67 degrees Bottom hole distance is 10231.60 Feet on azimuth 216,20 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL 35-24 PROPOSED SIDE~CK Producer COMPLETION - Planned ~ngstring Case Car&CO~íllips -n n H U n n n u n n n In '- ~ n p ~ ~ 9-5/S" LSO casing 1.1 @4527' MD /2613 ~ TVD ~ ~ ~ ~ ~ ~ ~ '- ~ ~ ~ ~ ~ 3-1/2" X 7" Liner Top 10,380' MD /4800' TVD Sidetrack KOP @ +/- 10,530' MD, +/- 6776" TVD Baker "K-1" CIBP @ +/- 10548' MD Original Well bore 7" 26# L-80 shoe at 11255' MD/5139' TVD Original Wellbore 3- Y:z" liner 11104'-13650' MD .. - .. .. ID .. ... ~ 1 , , I ~ ~ jJ r ~ ~ ~ I ... I ¡ "j~il~ I ti,'--..-----'~ f·· .¡ i r I i ~ , ~ ~ ~ I ~ , '- ~ ~ J. ~ , ~ ~ I J. ~ ~ I ~ ~ ~ I '- ~ IIIIIIIIIII - -- n II d II ~ ~ I S ~~q I ~ ~ II L J. J. J. I J. i ,,~ J. J. J. J. J. J. J. i 3-1/2" 5M FMC Gen V tubing hanger with 3-1/2" L-80 EUE 8rd pin down SPECIAL DRIFT TO 2.91" 3-1/2",9,3#, L-80 EUE 8rd tubing to surface SPECIAL DRIFT TO 2.91" 3-1/2" Camco 'DS' landing nipple with 2,875" ID No-Go profile set at +/-500' MD 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to GLM GLM Placement: Valves #1-4: 3-%" x 1" KBUG mandrels & 6 Ft. handling pups instlled on top and bottom Place gas-lift mandrels at the following depths: TVD Approx MD ValveGL 2500 4204 1,00 wI Dummy 3675 7354 1.00 wI Dummy 4375 9231 1.00 wI Dummy 4774 10301 1.00 wI Shear Valve 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary 3-1/2" Camco 'D'landing nipple with 2.81" ID No-Go profile and 6 ft, Handling pups One Joint 3-1/2" 9,3# L-80 EUE 8rd Mod tubing Baker 80-40 GBH-22 Seal Assembly (4,00" OD) wI 3-%" EUE-Mod Box up and 6 Ft. Handling Sub 3-1/2" LINER ASSEMBLY Sidetrack then drill 6-118" hole size then run the 3-W' SLHT liner to TD 5" X 7" ZXP Liner Hanger Packer w/ HR Profile 5" X 7" Flexlock Hydraulic Liner Hanger 80-40 Casing Sealbore Receptacle 3-%" SLHT Liner as needed 3-%" Landing Collar wI SLHT box x pin One Joint 3-%" SLHT Tubing 3- y." Float Collar wI SLHT Box x Pin Two Joints 3-y." SLHT Tubing 3-%" Float Shoe w/ SLHT Box up Estimated BHP = 3267 psi TO @ 12,483' MD /6022' TVD Drawn by JI 3-31-04 ORIGINAL '\ " e e tD ¡aJ,OO DOLLARS ~~ ;go oø>!-m ~ '"'- "....,. N """'"", C) c::::> ..þ ~ = " II:' CD g ~ :Þ CP =' CD ,(") CiI gC"'} -.. G~ ß.' "=- '~~:. T" a¡'8L,?¡.gO?g MEMO o:? ¡. ¡'OO ¡'L, 1.,1: e . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# /' Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) I!RtL 3:;; -2tf/! 2o'i-Cfp ( Exploration Stratigraphic "CLUE". The permit is for a new wellbore segment of existing well Permit No, API No. Production. should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), an records, data and logs acquired for the pilot bole must be clearly differentiated 'in both name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing ,exception tbat may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample iJ:itervals tbrougb target zones. Geologic D~t;¡ ¿ÿ?::tt1M¡- Engineering Commissioner: 35 36 37 38 39 Conta.ct nam.elphoneJor weelsly progre::¡s reports [exploratory .only). Yes Yes NA NA NA Appr SFD Date 4/15/2004 Seí.smicanalysjs of $baJlow gaszooes .Seabed condition survey (if off-::¡hp(e) Permit. .D.ata.presented on. potential overpres.sure .zone$ .ConocoPb, t.o.Kuparuk overpre.ssured to I-IZS has.notbeen obseryed J 0,46 ppg. EMVY;. will be. drilled. wit.h 10,9,ppg mud, Geology Appr e Date 4/16/2004 h-J?-nJl 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 ~an be í.ssued wto hydrogen sulfide meaS.U(e$ WQrls will occur .Is presence of Mecbanical coodj!í.on pf weUs wí.thin ,ð.OB Yerified (for. s.eNjce welJ only) H2S gas. probable without.operatjonshutdown tn .commeots) .Choke.manifold compJies w/API RP-53lMay 64) .BOPEs,.dp Jhey meet. reguJatioo .BOPE.press ra.tiog appropriate; .test t.o .(put p::¡ig meet. reguJa.tions .DJilliog fluid program schematic.& equipJistadequat.e Jf.a.re-drilt has. a lOA,03 for .Mequ<:lte .wellbore separatjo.n .propo::¡ed it Jf.diverter JeqJ.Jlred, doe$ abandonment been approved .Adequ<:ltetankageoJ re.serye pit .CMT wi I! coyeraJI .C.asiog design::¡ adeQuate fpr C,.T, B&.permafr.ost koown ,pro.ductiYe horizon.s known USDW::¡ .CMT vol adequate to circutate. on .conductor. & su.rf. C$g .CMT v.ot adequ.ate to tie-in Jong .string to surf ç::¡g. .Coodu.ct.or .Surfacecasing. pJote~ts all Yes NA Yes Yes Yes Yes Y.es Yes Yes NA Yes Yes .Yes Yes Yes .No NA 4/15/Z0.04: I:IBZ KeUy McLure, iO aO}l ofthe.3S:F'ad welJs.to date, -- I-IZS has .not b.eeo seen at 3.S.Rig i$ equipp.ed with sensors and.aJa.rms, MAS¡=> Cé!lcuJa.ted.at 2617 psi. 35QOp$lappropriate, . CF'AJ u::¡uaIJy.tests to .5000. ps Max. expected BH¡=> 0,5 EMW. Planned. MW. 1.0,5 10,9. OriginaJ 3Q4: t19,.approved .411.3104.. wellbore js.cJo$est. Big jS.equippe.d.with $teelpit::¡. No resewe.pjtplanned, Waste.to approved annulJJS orClas$ JI.dispos.at well Casjng T'.note we aquifers exempt.ed,4D.C.F .cemented.to $urfaçe '" tied to.9:5J6". Liner.wilt be. fully .cemented, Con.ductor .set ,ð.I[ :n origioaJ 147.1 02.(b)l3), weltbore, Engineering Appr - 4/15/2004 12 13 14 15 16 17 string.provided only) Pre-produced injector; durat.io.n.of pre-production less than. 3. months ACMP. Finding .of Con.si$t.ency. h.as bee.nj::¡sued. for. this proiect. (Forserví.ce well onJy) WeJI AJI weUs.withí.n located wí.thin area and.strata <:Iuthorized by. 114.mite.area.of reyiew ideotified (Fpr servj~.we lojectioo Order # (put 10# in cpmmeots) (For Date 2 3 4 5 6 7 8 9 10 11 Can permit be approved before 5-day wait .O,perator Permit Permit. ~an be í.ssued witbout can be í.ssued wjthout ad.ministratille. apprpvaJ has. appropriate. b.ond í.nJorçe co.n$ervation order .Operator onl}l affected party .S.ufficient Jf.deviated, js weJlbore plaUncJuded acreageayail<:lble Well Well Well .located prpperdí.stance. located proper .dí.stance. from drilling unitbound.ary. .U.ní.que well.n.ame.aod ol!mb.er located in.a. clefine~pool PTD#: 2040610 Administration from other welJs in. driUiog unjt .Leasenumber .appropriat.e. Company CONOCOPHILLlPS ALASKA INC Permit. fee attache~ KUPARUK RIVER, KUPARUK RV OIL Field & Pool 490100 Initial Class/Type Yes Yes .Yes Yes Yes Yes Yes Yes Yes .Yes Yes Yes Yes .NA .NA NA .NA for.origiOal Be-drj of existiog well, Surface Well Name: KUPARUK RIV UNIT 3S-24A DEV / PEND GeoArea 890 in ADL .3801D7;top. prod iotervaland TD jn AQL 025551 Unit 11160 Program DEV On/Off Shore On Well bore seg Annular Disposal o o e e 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 infonnation, 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. e **** REEL HEADER **** LDWG 04/07/06 AWS 01 **** TAPE HEADER **** LDWG 04/07/06 01 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !! !! ! ! !! ! ! !! !! !! ! !! Extract File: LISTAPE.HED TAPE HEADER PALM UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 1 G. SUTING F. HERBERT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD e 3S-24A 501032045601 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 06-JUL-04 MWD RUN MWD RUN 18 12N 8E 55.10 27.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 6.125 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE # REMARKS: 16.000 7.000 108.0 10521. 0 12518.0 ,'-' ~ 1.1 ¿~\ l ( :;x..'(j 1 - "' <0 /25' 7 e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N 70 DEG 23' 39.5895" LONG: W150 DEG 11' 43.1639" LOG MEASURED FROM D.F. AT 55.1 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a Directional Only service to set a whipstock and mill the casing window from 10509 - 10521 feet MD (4856 - 4861 TVD), and drilled to 10540 feet MD (4869 TVD). (2) Baker Hughes INTEQ run 2 utilized the Advantage Porosity LoggingService (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), along with MAP (Modular Annular Pressure) and MPR Resistivity services from 10540 - 12518 feet MD (4869 - 6054 TVD). (3) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) Top of 7" Casing Window: 10509 feet MD (4856 TVD) Bottom of 7" Casing Window: 10521 feet MD (4861 TVD) (2) The interval from 12482 to 12518 feet MD (6028 - 6054 TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 71 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10521. 0 STOP DEPTH 12518.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # e e MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 2 10521.0 MERGE BASE 12518.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 3s-24a 5.xtf 150 ConocoPhillips Alaska, Inc. 3S-24A Palm North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 e 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 211 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10521.000000 12518.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 258 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 e log header data for each bit run in separate files. 2 .2500 START DEPTH 10500.0 STOP DEPTH 12518.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 02-MAY-04 MSB 18655 4.75 TC MEMORY 12518.0 10521. 0 12518.0 o 45.1 65.6 # e TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ # BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # e TOOL NUMBER PAA 10918 SDN 44706 SDN 44706 MPR 54694 SRIG 58019 6.125 10521. 0 LSND 10.70 .0 .0 400 .0 .000 .000 .000 .000 128.0 .0 .0 .0 SANDSTONE .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/MPR/oRD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU e e WDFN LCC CN WN FN COUN STAT 3s-24a.xtf 150 ConocoPhillips Alaska, I 3S-24A Palm North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 e 16 68 1 TCDM MWD DEGF Total Data Records: 577 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10500.000000 12518.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 687 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/07/06 01 **** REEL TRAILER **** LDWG 04/07/06 AWS 01 Tape Sub file: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes 4 ------- - 4 64
