Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
202-091
2025-0715_Location_Clear_KRU_2P-432_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 07/18/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Site Clearance Petroleum Inspector KRU 2P-432 Conoco Phillips Alaska LLC. PTD 2020910; Sundry 324-612 07/15/2025: Went out to KRU 2P Pad for site clearance inspections and met with Roger Mouser (CPAI). We went over the surface area of KRU 2P-432 which has been P&A and buried. The area was clean of debris and had a settling mound for soil over the well location. We verified the well-site with the pad location map and well conductor “as built”. Marker plate and top of well are at 6 feet 7 inches below original tundra. Overall, the site clearance was in good condition. The well site still had barriers around due to other work going on in the area. Only follow up would be a full pad site clearance once CPAI has completed all pad P&A work. Attachments: Photo 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.16 14:03:46 -08'00' 2025-0715_Location_Clear_KRU_2P-432_ksj Page 2 of 2 Surface Abandonment Inspection – KRU 2P-432 (PTD 2020910) Photo by AOGCC Inspector K. StJohn 7/15/2025 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: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: N/A 23. BOTTOM 16" B 108' 9-5/8" L-80 2372' 7" L-80 5297' 5-1/2" L-80 5447' 3-1/2" L-80 5706' 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 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, 50 sx Class G w/GasBlok6.125" TUBING RECORD 72 sx Class G6038' 130 sx LiteCrete 5144' 8.5" 4.75" 5485' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 2/9/2025 202-091 / 324-612 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. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Abandoned N/A 50-103-20420-00-00 KRU 2P-432 ADL0373112 948' FNL, 1894' FWL, Sec. 17, T8N, R7E, UM 2596' FSL, 1446' FWL, Sec. 17, T8N, R7E, UM L 32092 10/31/2003 6043' MD/ 5710' TVD Surface/ Surface P.O. Box 100360, Anchorage, AK 99510-0360 443855 5868930 2594' FNL, 1469' FWL, Sec. 17, T8N, R7E, UM 11/20/2003 N/A PACKER SET (MD/TVD) 5439' 42" 9.3# 12.25" 110 sx LiteCrete 28'527 sx AS Lite, 225 sx LiteCrete 15.5# 28' 5533' 2449'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 41-2395' 180 bbl 15.8 ppg Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 2395-2515' 3724' (SW TOC)-5394' ABANDONED 5778-5798' MD and 5462-5481' TVD (below cement plug) 5806-5826' MD and 5488-5507' TVD (below cement plug) 5838-5860' MD and 5518-5539' TVD (below cement plug) Gas-Oil Ratio:Choke Size: 53 bbls 15.8 ppg Class G cement Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 21.5 bbl 15.8 ppg Cement 5602' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 5762' 25' 5233' 62.5# 40# 108' 25' WT. PER FT.GRADE 443422 443399 CEMENTING RECORD 5867287 1358' MD / 1352' TVD SETTING DEPTH TVD 5867197 TOP HOLE SIZE AMOUNT PULLED Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:16 pm, Mar 03, 2025 Abandoned 2/9/2025 JSB RBDMS JSB 030625 xGDSR-4/7/25VTL 7/30/2025 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1358' 1352' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations, Photos 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Shane Germann Digital Signature with Date:Contact Email: shane.germann@conocophillips.com Contact Phone:(907) 263-4597 Senior RWO/CTD 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: Formation Name at TD: 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 N/A- Abandoned 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. 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. TPI (Top of Producing Interval). Authorized Name and Authorized Title: N/A - Abandoned 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. 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. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2025.03.03 13:27:16-09'00' Foxit PDF Editor Version: 13.0.0 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 5,787.0 2P-432 6/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: AOGCC Rep, Guy Cook, witnessed the TOC, cut depth & marker plate (6' 7" below tundra) 2P-432 2/25/2025 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: Rep gave the ok for backfilling the excavation.Removed the "Shoring Can" from the excavation 2/8/2025 pproven NOTE: NES welder welded the marker plate to the well stub. 2/8/2025 pproven NOTE: AOGCC Rep, Guy Cook, witnessed the TOC, cut depth and the marker plate 2/8/2025 pproven NOTE: Temporary waiver allowing OA pressure up to 1800 psi 11/3/2020 jbyrne NOTE: TREE: FMC / GEN V / WKM 3 1/8"" / 5K, TREE CAP CONNECTION: OTIS 3"" 11/22/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.1 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.1 2,449.5 2,372.5 40.00 L-80 BTC Production 7 6.28 2,515.0 5,602.3 5,297.4 26.00 L-80 BTC-MD PRODUCTION 7 6.28 41.1 5,602.3 5,297.5 26.00 L-80 BTC-MD LINER 3 1/2 2.99 5,438.7 6,038.0 5,705.6 9.30 L-80 511 Hydril Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 42.0 Set Depth … 2,390.0 Set Depth … 2,317.4 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Top (ftKB) 2,660.0 Set Depth … 5,485.0 Set Depth … 5,187.5 String Max No… 3 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,334.6 5,046.6 20.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,384.1 5,092.9 20.70 SLEEVE 4.500 Sliding Sleeve (run closed when well drilled in 2003 & never opened since) BAKER CMU 2.810 5,400.7 5,108.5 20.60 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,445.2 5,150.1 20.32 LOCATOR 5.000 LOCATOR SUB 3.000 5,473.5 5,176.7 20.15 SEAL 4.000 GBH-22 SEAL ASSEMBLY GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 41.1 41.1 0.00 MARKER PLATE 1/4" x 30" Marker plate 2/8/2025 0.000 2,515.0 2,433.4 21.33 CUT MSC on rig 1/27/2025 6.000 2,520.0 2,438.1 21.32 CIBP CIBP@2520' 12/26/2024 0.000 2,660.0 2,568.7 20.98 CUT JET CUT @ 2660' RKB 10/7/2024 2.992 5,355.0 5,065.7 20.83 LEAK - CASING Leak @ 5355' RKB on acoustic log run 9/3/22 (possible PC leak) 9/3/2022 6.280 5,379.0 5,088.2 20.73 TUBING PUNCH TBG PUNCH FROM 5379' TO 5383.5' RKB W/ 4 SPF 9/11/2024 2.992 5,623.0 5,316.8 20.48 TIGHT SPOT Tight spot with CIBP drift. Able to tap through with drift to set CIBP below tight spot. 6/20/2024 2.700 5,745.3 5,431.4 20.48 CIBP CIBP MID-ELEMENT AT 5746' RKB, OAL = 1.37' 6/30/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,438.7 5,144.0 20.36 TIE BACK 5.760 Liner Tie-Back W/NO GO @ Btm ZXP 5.250 5,450.0 5,154.7 20.29 PACKER 5.980 ZXP LINER TOP PACKER 4.370 5,457.6 5,161.7 20.25 NIPPLE 5.590 RS NIPPLE RS 4.250 5,488.9 5,191.1 20.24 XO BUSHING 5.010 CROSSOVER BUSHING 3.000 5,494.6 5,196.5 20.28 XO THREAD 3.500 2.992 5,935.1 5,609.2 20.48 XO THREAD 3.500 2.992 5,937.7 5,611.6 20.48 LANDING COLLAR 4.250 Liner BOT Landing Collar 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,778.0 5,798.0 5,462.0 5,480.8 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60° phase 5,806.0 5,826.0 5,488.2 5,507.0 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60° phase 5,838.0 5,860.0 5,518.2 5,538.8 T-3, 2P-432 1/3/2004 6.0 IPERF 2-7/8" HSD PJDP, 60° phase 2P-432, 2/25/2025 5:29:46 PM Vertical schematic (actual) LINER; 5,438.7-6,038.0 IPERF; 5,838.0-5,860.0 APERF; 5,806.0-5,826.0 APERF; 5,778.0-5,798.0 CIBP; 5,745.3 Cement Plug; 5,683.0 ftKB TIGHT SPOT; 5,623.0 PRODUCTION; 2,515.0-5,602.3 Production; 2,515.0-5,602.3 TUBING PUNCH; 5,379.0 LEAK - CASING; 5,355.0 GAS LIFT; 5,334.6 Cement Plug; 3,724.0 ftKB CUT; 2,660.0 CIBP; 2,520.0 CUT; 2,515.0 SURFACE; 41.1-2,449.5 Plug – Plug Back / Abandonment Plug; 2,395.0 ftKB Cement Casing; 41.1 ftKB CONDUCTOR; 41.1-108.0 MARKER PLATE; 41.1 Cement Plug; 41.1 ftKB KUP SVC KB-Grd (ft) 34.41 RR Date 11/23/200 3 Other Elev… 2P-432 ... TD Act Btm (ftKB) 6,043.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032042000 Wellbore Status SVC Max Angle & MD Incl (°) 23.52 MD (ftKB) 5,011.58 WELLNAME WELLBORE2P-432 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 41.1 2,449.0 41.1 2,372.0 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 106000Drag up (lbs): 121000Time started reciprocating: 01:30Time stopped reciprocating: 06:35Annular flow after cement job (Y/N): NPressure before cementing (psi): 250Hours circulated between stages: 3Bbls cmt to surf: 188Method used to measure density: DesometerMethod used for mixing cement in this stage: On flyReturns (pct): FULLTime cementing mixing started: 05:22 11/2/2003 5,683.0 5,745.3 5,373.0 5,431.4 Cement Plug Dump bail cement on CIBP 7/5/2024 3,724.0 5,394.5 3,556.1 5,102.7 Cement Plug PUMPED 53 BBLS OF 15.8 PPG CLASS G CEMENT 9/15/2024 41.1 2,395.0 41.1 2,322.0 Cement Plug 12/30/2024 2,395.0 2,515.0 2,322.0 2,433.4 Plug – Plug Back / Abandonment Plug 12/28/2024 2P-432, 2/25/2025 5:29:46 PM Vertical schematic (actual) LINER; 5,438.7-6,038.0 IPERF; 5,838.0-5,860.0 APERF; 5,806.0-5,826.0 APERF; 5,778.0-5,798.0 CIBP; 5,745.3 Cement Plug; 5,683.0 ftKB TIGHT SPOT; 5,623.0 PRODUCTION; 2,515.0-5,602.3 Production; 2,515.0-5,602.3 TUBING PUNCH; 5,379.0 LEAK - CASING; 5,355.0 GAS LIFT; 5,334.6 Cement Plug; 3,724.0 ftKB CUT; 2,660.0 CIBP; 2,520.0 CUT; 2,515.0 SURFACE; 41.1-2,449.5 Plug – Plug Back / Abandonment Plug; 2,395.0 ftKB Cement Casing; 41.1 ftKB CONDUCTOR; 41.1-108.0 MARKER PLATE; 41.1 Cement Plug; 41.1 ftKB KUP SVC 2P-432 ... WELLNAME WELLBORE2P-432 Plug #4 – Surface TOC 15' RKB BOC @ ±2395' RKB 3 Production Casing Cement: 51 bbls of 12.5# Class G Cement Calculated TOC @ 3,334' KB Liner Cement: 51.7 bbls of 15.8# Class G Cement Calculated TOC @ 5,438.7' KB 2P-432 Well Final P&A Schematic Conductor: 16" Conductor 108' KB 1 2 4 Production Casing: 7" 26# L-80 BTC Mod Set @ 5,602.3’ KB T-3 Peforations: @ 5,778' – 5,860' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,449.5' KB (2372' TVD) Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,485' KB /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,E' Z ϭϰ͘ϵΖ Ϯ ^d/ZKEZ/' W>h'ϮϱϮϬΖ ϯ < ZDh^>//E'^> s ϱ͕ϯϴϰ͘ϭΖ ϰ DKE/WW> ϱ͕ϰϬϬ͘ϳϬ ϱ >/E Zd/ Ͳ<tͬEK'KΛ KddKD ϱϰϯϴ͘ϳΖ ϲ >KdKZ^hϱ͕ϰϰϱ͘ϮΖ ϳ yW>/E ZdKWW< Z ϱ͕ϰϱϬΖ ϴ Z^E/WW> ϱ͕ϰϱϳ͘ϲΖ ϵ &> yͲ>K<,zZh>/>/E Z ,E' Z ϱ͕ϰϲϬ͘ϯΖ ϭϬ ^ >KZ yd E^/KEϴϬͲϰϬ ϱ͕ϰϲϵ͘ϳΖ ϭϭ ',ͲϮϮ^ >^^ D>z ϱ͕ϰϳϯ͘ϱΖ ϭϮ ZK^^Ks Zh^,/E'ϱ͕ϰϴϴ͘ϵΖ 6 7 8 10 12Liner: 3.5" 9.3# L-80 511 Hydril Set @ 6,038’ KB 9 11 C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5683' RKB Plug #2 – Intermediate TOC ±3724' RKB BOC @ ±5394' RKB Plug #3 – Surface Shoe TOC 2395' RKB (2322' TVD) BOC @ ±2520' RKB Page 1/3 2P-432 Report Printed: 2/25/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/25/2024 12:00 12/25/2024 15:00 3.00 MIRU, MOVE MOB P Set mats for pulling off well on doubles // Pull off well and stage on pad 0.0 0.0 12/25/2024 15:00 12/25/2024 21:30 6.50 MIRU, MOVE MOB P Spot mats and herculite around new well // pull rig on well and center/level MIRU 0.0 0.0 12/25/2024 21:30 12/26/2024 00:00 2.50 MIRU, MOVE MOB P Take on 9.8 Brine R/U hard lines test lines t/2500psi All good OA 340 psi IA 0 Tubing 0 Rig Accept 21:30 0.0 0.0 12/26/2024 00:00 12/26/2024 01:00 1.00 MIRU, WELCTL SEQP P PT hardlines to 2500 psi. 0.0 0.0 12/26/2024 01:00 12/26/2024 02:30 1.50 MIRU, WELCTL KLWL P Start pumping down tubing taking returnes through choke manifold. pump 35 bbl deep clean pill and chase with 107 bbls 9.8 ppg NaCl. ICP 445 psi/FCP 612psi. Shut down No flow monitor well 30 mins All good Blow down all lines. 0.0 0.0 12/26/2024 02:30 12/26/2024 07:30 5.00 MIRU, WHDBOP NUND P Pull tree off and inspect hanger threads. NU BOP stack. 0.0 0.0 12/26/2024 07:30 12/26/2024 14:30 7.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular on 3.5" and 7", UVBR's, w/ 3 ½” donut test joints. Test blinds rams. Test LPR 7" on 7" test joint, Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 4 1/2" FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure = 3000 PSI, after closure = 1650 PSI, 200 PSI attained = 25 sec, full recovery attained =126 sec. UVBR's = 4 sec Annular = 24 sec. Simulated blinds = 5 sec. HCR choke & kill = 1 sec each. 4 back up nitrogen bottles average = 1925 PSI. Test gas detectors, PVT and flow show. AOGCC witness waived by Kam StJohn 0.0 0.0 12/26/2024 14:30 12/26/2024 16:30 2.00 MIRU, WHDBOP THGR P R/U Landing jt BOLDS Pull Hanger to Floor L/D same up wt 52K Monitor well 30 All good 0.0 2,660.0 12/26/2024 16:30 12/26/2024 19:30 3.00 COMPZN, RPCOMP PULL P POOH LD 3 1/2" EUE Tubing UWT 54K LD 83 jts and a 18.68' cut jut (with two cuts) 2,660.0 0.0 12/26/2024 19:30 12/26/2024 20:00 0.50 COMPZN, RPCOMP BHAH P Swap out handling equipment 0.0 0.0 12/26/2024 20:00 12/26/2024 20:30 0.50 COMPZN, RPCOMP BHAH P PU BHA #1 CIBP 0.0 0.0 12/26/2024 20:30 12/26/2024 21:30 1.00 COMPZN, RPCOMP TRIP P TIH on 3-1/2" DP out of derrick to 2521'. UWT 65K / SOW 65K 0.0 2,521.0 12/26/2024 21:30 12/26/2024 22:00 0.50 COMPZN, RPCOMP MPSP P Set CIBP with top at 2520'. Pressure up then pull 3K to shear off. 2,521.0 2,521.0 Rig: NORDIC 3 RIG RELEASE DATE 12/30/2024 Page 2/3 2P-432 Report Printed: 2/25/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/26/2024 22:00 12/26/2024 23:30 1.50 COMPZN, RPCOMP TRIP P TOOH with plug setting tool. 2,521.0 0.0 12/26/2024 23:30 12/27/2024 00:00 0.50 COMPZN, RPCOMP PRTS P PT CIBP tp 1000 psi for 10 minutes. 0.0 0.0 12/27/2024 00:00 12/27/2024 00:30 0.50 COMPZN, RPCOMP BHAH P PU Yellow Jacket 7" casing cutter. 0.0 0.0 12/27/2024 00:30 12/27/2024 02:00 1.50 COMPZN, RPCOMP TRIP P TIH with casing cutter to 2515' 0.0 2,515.0 12/27/2024 02:00 12/27/2024 06:00 4.00 COMPZN, RPCOMP FISH P Set Cutter @ 2515' and cut casing Attempt to circ no OA pres P/U t/2414' recut Attempt t/ circ OA No circulation 2,515.0 2,414.0 12/27/2024 06:00 12/27/2024 07:00 1.00 COMPZN, RPCOMP TRIP P POOH L/D Cutter R/U Pull packoff L/D same P/U 7" landing jt RIH M/U t/ Hanger 2,414.0 0.0 12/27/2024 07:00 12/27/2024 10:00 3.00 COMPZN, RPCOMP CIRC P P/U 102K pipe move freePU /5' Communication on OA Circ Down casing up on the OA pump 70 bbls heated deep clean pill and chase w/ 9.8 brine @ 3 bbls min w/ 260 PSI All Good monitor well 15 mins 0.0 2,414.0 12/27/2024 10:00 12/27/2024 14:00 4.00 COMPZN, RPCOMP TRIP P POOH L/D Landing JT and 7"casing W/ GBR casing crew TOT L/D 58 Jts 1 cut Jt 11.76' TOT Footage 2414' 2,414.0 0.0 12/27/2024 14:00 12/27/2024 19:00 5.00 COMPZN, RPCOMP BHAH P Load pipe shed w/ BHA # 3 and M/U BHA # 3 w/spear 0.0 0.0 12/27/2024 19:00 12/27/2024 21:00 2.00 COMPZN, RPCOMP TRIP P RIH to 2425 latch jars, 180K straight pull and let jars go off once and fish free. POOH. 0.0 2,425.0 12/27/2024 21:00 12/27/2024 22:00 1.00 COMPZN, RPCOMP TRIP P TOOH on DP and LD fish 2,425.0 232.0 12/27/2024 22:00 12/27/2024 23:00 1.00 COMPZN, RPCOMP BHAH P LD fishing BHA. 232.0 0.0 12/27/2024 23:00 12/28/2024 00:00 1.00 COMPZN, WHDBOP PULD P RIH with 3-1/2" EUE 8RD as work string to pump cement. F/p T782' SOW 35K 0.0 782.0 12/28/2024 00:00 12/28/2024 02:00 2.00 COMPZN, WHDBOP TRIP P TIH with 3-1/2" EUE work string F/782 T/2520 Tag top of plug at 2520' PU 5' and space out. 782.0 2,515.0 12/28/2024 02:00 12/28/2024 06:00 4.00 COMPZN, WHDBOP RURD P RU Halliburton Cementers and R/U all trucks 2,515.0 2,515.0 12/28/2024 06:00 12/28/2024 08:00 2.00 COMPZN, WHDBOP CMNT P PJSM w/ Crews Pump 5 bbls 9.8 Brine Test lines t/ 2500 PSI all good pump 10lb Spacer chase w/ Cement 15.8 lb 21.5 bbls chase w/ 10 bbls spacer chase w/9.8 brine 13.9 bbls Shut down Blow lines down (CIP @ 0815) 2,515.0 2,515.0 12/28/2024 08:00 12/28/2024 09:30 1.50 COMPZN, WHDBOP TRIP P POOH 8' min t/258' then spead up to last 258' @ 12' min All good R/U. 2,515.0 1,999.0 12/28/2024 09:30 12/28/2024 10:30 1.00 COMPZN, WHDBOP CIRC P CBU @ 5 bbls min w/ 175 psi, All good. 1,999.0 1,999.0 12/28/2024 10:30 12/29/2024 00:00 13.50 COMPZN, WHDBOP WOC P WOC to reach 500psi compressive strength. 1,999.0 1,999.0 12/29/2024 00:00 12/29/2024 09:00 9.00 COMPZN, WHDBOP WOC P WOC 1,999.0 1,999.0 12/29/2024 09:00 12/29/2024 12:00 3.00 COMPZN, WHDBOP WASH P RIH Wash and Tag Cement @ 2395' P/U 5" and CBU 1,999.0 2,390.0 12/29/2024 12:00 12/29/2024 15:00 3.00 COMPZN, WHDBOP OTHR P Test casing t/ 1000 psi 10 mins /1500 PSI f/ 30 mins w/ AOGCC Inspector All Good 2,390.0 2,390.0 12/29/2024 15:00 12/29/2024 16:30 1.50 COMPZN, WHDBOP THGR P Space out and M/U hanger Land hanger @ 2390' RILDS 2,390.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/30/2024 Page 3/3 2P-432 Report Printed: 2/25/2025 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/29/2024 16:30 12/29/2024 22:30 6.00 COMPZN, WHDBOP NUND P N/D BOP and N/U Tree prep F/ Surf t/Surf Cement Job Wash cement out of BOPE NU tree and test void to 5000 psi for 10 minutes. 0.0 0.0 12/29/2024 22:30 12/30/2024 00:00 1.50 COMPZN, WHDBOP CMNT P RU for cement job 0.0 0.0 12/30/2024 00:00 12/30/2024 04:00 4.00 COMPZN, WHDBOP CMNT P Safety meeting to pump cement. test lines T/ 2500 PSI all good Surf t/Surf Tot 196 BBLS 15.8 and Wash up R/D 0.0 0.0 12/30/2024 04:00 12/30/2024 06:00 2.00 DEMOB, MOVE RURD P Clean up pits cuttings box /RDMO Release Rig F/ 2P-432 @ 0600AM 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 12/30/2024 DTTMSTART JOBTYP SUMMARYOPS 10/18/2024 CHANGE WELL TYPE CUT TUBING AT 2650' RKB W/ 2.5" JET CUTTER (10' ABOVE PREVIOUS CUT) JOB COMPLETE, READY FOR RIG 12/25/2024 RECOMPLETION Pull off 2P-434 and MIRU on 2P-432. KIll well with 9.8 ppg NaCl. 12/26/2024 RECOMPLETION ND tree/NU BOPE. PUll and LD 3-1/2" tubing from 2660'. Run and set CIBP at 2520'. 12/27/2024 RECOMPLETION Make a second 7" cut and fish both pieces out of the well. 12/28/2024 RECOMPLETION TIH with 3-1/2" tubing and pump cement plug F/2515' T/2287' and pull up out of it. WOC 12/29/2024 RECOMPLETION AOGCC witness Tag and PT cement. Space out and RILDS, Pump final abandonment cement plug surface to surface. 12/30/2024 RECOMPLETION Pump Cement t/Surf t/Surf 15.8 All good 1/20/2025 CHANGE WELL TYPE (P&A) DDT-T TO 0 PSI (PASSED), DDT-IA X OA TO 0 PSI (PASSED) 1/26/2025 CHANGE WELL TYPE (P&A) REMOVE TREE, IA AND OA VALVES (COMPLETE) TOC THA SF, IA 5', OA SF. NEXT STEP CUT/REMOVE WELLHEAD AND CELLAR BOX. 1/28/2025 CHANGE WELL TYPE (P&A) PREP IN PROGRESS. CUT/ REMOVED 7'-3" OF WELLHEAD/CONDUCTOR & STEEL CELLAR. ***NEXT STEP- BEGIN EXCAVATING TO 14' FOR SHORE CAN INSTALL.*** 2/2/2025 CHANGE WELL TYPE (P&A) PREP-BEGIN EXCAVATIION, TD 14' -OBTAINED 5-6'. NEXT STEP: CONTINUE TO EXCAVATE TO TD 14', SET SHORE CAN. 2/3/2025 CHANGE WELL TYPE (P&A) STANDBY FOR EQUIPMENT REPAIR. (IN PROGRESS) 2/4/2025 CHANGE WELL TYPE (P&A) PREP-BEGIN EXCAVATIION, TD 14' -OBTAINED 8'. NEXT STEP: CONTINUE TO EXCAVATE TO TD 14', SET SHORE CAN. 2/5/2025 CHANGE WELL TYPE (P&A) PREP-BEGIN EXCAVATIION, TD 14' -OBTAINED 13'. JOB STOPPED FOR WEATHER. NEXT STEP:POST STORM CLEAN UP, CONTINUE TO EXCAVATE TO TD 14', SET SHORE CAN. 2/6/2025 CHANGE WELL TYPE (P&A) EXCAVATE TO 14' (COMPLETE) SET "SHORING CAN" (COMPLETE) 2/7/2025 CHANGE WELL TYPE (P&A) BACKFILL AROUND SHORING CAN (COMPLETE) CUT AND REMOVE WELLHEAD (COMPLETE ~7' 4" OF WELL STUB) 2/8/2025 CHANGE WELL TYPE (P&A) AOGCC REP, GUY COOK, WITNESSED & APPROVED THE TOC, CUT DEPTH, & MARKER PLATE (6' 7" BELOW TUNDRA) WELDED THE MARKER PLATE (COMPLETE) PULLED THE "SHORING CAN" (COMPLETE). BACKFILL THE EXCAVATION (IN PROGRESS) 2/9/2025 CHANGE WELL TYPE (P&A) BACKFILL EXCAVATION (COMPLETE) 2P-432 Rig Plug and Abandon Summary of Operations 2025-0208_Surface_Abandon_KRU_2P-432_gc Page 1 of 6 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 2/09/2025 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector KRU 2P-432 ConocoPhillips Alaska Inc. PTD 2020910; Sundry 324-612 2/08/2025: I arrived on location and met with Brennen Green (ConocoPhillips). We talked about the well, what I needed to document and headed out to the wellsite. Good hard cement to surface was found in the tubing and all casing annuli. The identification plate was inspected and the information welded onto it was correct. We confirmed the casing was cut 6 feet 7 inches below tundra level. I told them they could install the identification plate and asked them to send me pictures of it installed. Mr. Green sent me pictures and I gave them permission to bury the well on 2/09/2025. Attachments: Photos 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.14 15:18:13 -09'00' 2025-0208_Surface_Abandon_KRU_2P-432_gc Page 2 of 6 Surface Abandonment – KRU 2P-432 (PTD 20209120) Photos by AOGCC Inspector G. Cook except as noted 2/8/2025 Welhead and casing section cutoff 2025-0208_Surface_Abandon_KRU_2P-432_gc Page 3 of 6 Well cut off – cement to surface 2025-0208_Surface_Abandon_KRU_2P-432_gc Page 4 of 6 Confirming cutoff depth Marker plate informnation 2025-0208_Surface_Abandon_KRU_2P-432_gc Page 5 of 6 Marker Plate installed – photo courtesy of CPAI 2025-0208_Surface_Abandon_KRU_2P-432_gc Page 6 of 6 Marker plate welded to outermost casing – photos courtesy of CPAI MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Nordic 3 Rig Elevation: 30.5 ft Total Depth: 6043 ft MD Lease No.: 0373112 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 2450 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 5602 Feet Csg Cut@ 2515 Feet Liner: 3-1/2" O.D. Shoe@ 6038 Feet Csg Cut@ Feet Tubing: 3-1/2" O.D. Tail@ 5485 Feet Tbg Cut@ 2650 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 2520 ft 2395 ft 9.8 ppg Drillpipe tag Initial 10 min 30 min 45 min Result Tubing N/A N/A IA N/A N/A OA 1200 1180 Initial 15 min 30 min 45 min Result Retest Tubing N/A N/A N/A IA N/A N/A N/A OA 1680 1650 1580 Initial 15 Min 30 Min 45 Min Retest 2 Tubing N/A N/A N/A IA N/A N/A N/A OA 1680 1650 1630 Remarks: Attachments: Tagged with 10K lbs down weight using drill pipe after wasing down to plug. Tubing has been cut and pulled from 2515 ft MD and Production casing cut @ 2650 ft MD and pulled uphole (not removed) - Tubing and IA in communication. Had issues with cold air impacting the test. December 29, 2024 Kam StJohn Well Bore Plug & Abandonment KRU 2P-432 ConocoPhillips Alaska Inc. PTD 2020910; Sundry 324-612 Test Chart Test Data: I Casing Removal: Ronnie Dalton I Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): P rev. 3-24-2022 2024-1229_Plug_Verification_KRU_2P-432_ksj – KRU 2P- 12/29/2024 Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Pull Tubing Change Approved ProgramOther StimulatePerforateSuspend Alter CasingPerforate New Pool Re-enter Susp Well Other:Plug for Redrill 5. Permit to Drill Number:2. Operator Name: 4. Current Well Class: DevelopmentExploratory 3.Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoYes 10.Field:9. Property Designation (Lease Number): 11. Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): None6043' CollapseCasing Structural Conductor Surface Intermediate Production Liner Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13.Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic Development ServiceExploratory StratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14. Estimated Date for WDSPLWINJOILCommencing Operations:Suspended WAG SPLUGGAS GSTORDate:16.Verbal Approval: AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? NoYes APPROVED BY Date:COMMISSIONER THE AOGCCApproved by: Sr Pet Geo Sr Res EngSr Pet EngComm.Comm. 12/11/2024 6038'599' 3-1/2" 5706' Packer: GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2421' 5778-5798', 5806-5326', 5838- 5860' 5577' 3-1/2" 5462-5481', 5488-5507', 5518- 5539' 7" Perforation Depth TVD (ft): 108' 2450' 5297'5602' 16" 9-5/8" 80' 5485' MD 108' 2373' ConocoPhillips Alaska, Inc. SizeLength Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Abandoned BurstTVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 202-091 P.O. Box 100360, Anchorage, AK 99510 50-103-20420-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing MD (ft):Tubing Grade: 5473' MD and 5177' TVD N/A Shane Germann Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: 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: Tubing Size: shane.germann@conocophillips.com (907) 263-4597 Senior CTD/RWO Engineer KRU 2P-432 3556'3724'5710' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov MPSP (psi): 866 Plugs (MD): 5683', 5745', 3724' By Grace Christianson at 7:52 am, Oct 24, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2024.10.23 16:39:25-08'00' Foxit PDF Editor Version: 13.0.0 324-612 SFD 10/27/2024VTL 11/29/2024 DSR-10/29/24 X BOP test to 2500 psig Annular preventer test to 2500 psig See attached "Conditions of Approval" X 10-407 X June 30, 2025 X ($8 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.02 10:09:54 -09'00'12/02/24 RBDMS 120324 JSB KRU 2P-4ϯϮ Abandonment Conditions of Approval: ͳǤ A variance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata. ʹǤ A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as the recovery of 50' of production casing below the surface casing shoe and a cement plug placed across this open hole section and 150' into the surface casing. The plug must pass a State Witnessed pressure test and tag according to 20 AAC 25.112(g). ͵Ǥ A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. ͶǤ A failed pressure test of the surface casing shoe plug requires the submission of a new sundry (10-403) to cover the rigless abandonment scope if planned. Completion of workover operations under the original sundry will be complete and a 10-407 Well Completion or Recompletion Report and Log must be filed with the Commission within 30 days following the completion of workover operations. ͷǤ If surface abandonment operations are not initiated within 0 days after the successful placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407 Well Completion or Recompletion Report and Log must be filed with the Commission within30 days after the completion of workover operations to date. Ǥ Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20 AAC 25.120. Ǥ AOGCC witness is required after the wellhead cutoff and prior to a top job. Variances granted provide for at least equally effective plugging of the well and prevention of fluid movement into sources of hydrocarbons or freshwater. W͘K͘KyϭϬϬϯϲϬ E,KZ' ͕>^<ϵϵϱϭϬͲϬϯϲϬ KĐƚŽďĞƌϭϴ͕ϮϬϮϰ ŽŵŵŝƐƐŝŽŶĞƌ ^ƚĂƚĞŽĨůĂƐŬĂ ůĂƐŬĂKŝůΘ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ ϯϯϯtĞƐƚϳƚŚǀĞŶƵĞ^ƵŝƚĞϭϬϬ ŶĐŚŽƌĂŐĞ͕ůĂƐŬĂϵϵϱϬϭ ĞĂƌŽŵŵŝƐƐŝŽŶĞƌ͗ ŽŶŽĐŽWŚŝůůŝƉƐůĂƐŬĂ͕/ŶĐ͘ŚĞƌĞďLJƐƵďŵŝƚƐĂŶƉƉůŝĐĂƚŝŽŶĨŽƌƉƉƌŽǀĂůƚŽWůƵŐΘďĂŶĚŽŶϮWͲϰϯϮ͘dŚŝƐƐƵŶĚƌLJ ĐŽǀĞƌƐƚŚĞƉŽƌƚŝŽŶƚŽďĞƉĞƌĨŽƌŵĞĚŽŶͲƌŝŐďLJEŽƌĚŝĐϯƐƚĂƌƚŝŶŐŝŶŵŝĚͲĞĐĞŵďĞƌϮϬϮϰ͘ ϮWͲϰϯϮǁĂƐĂŶŝŶũĞĐƚŽƌƚŚĂƚŚĂƐďĞĞŶƐŚƵƚŝŶƐŝŶĐĞůĂƚĞϮϬϮϬ͘dŚŝƐǁĞůůŝƐŝŶƉƌŽĐĞƐƐŽĨďĞŝŶŐƐƵƐƉĞŶĚĞĚǁŝƚŚĂ ƌĞƐĞƌǀŽŝƌĐĞŵĞŶƚƉůƵŐĂŶĚŝŶƚĞƌŵĞĚŝĂƚĞĐĞŵĞŶƚƉůƵŐ;ĐŽǀĞƌĞĚŝŶƐĞƉĂƌĂƚĞϭϬͲϰϬϯͿ͘dŚĞƌĞŵĂŝŶŝŶŐƐƚĞƉƐƚŽWΘ ƚŚŝƐǁĞůůŝŶĐůƵĚĞƉƵŵƉŝŶŐƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐƐŚŽĞĐĞŵĞŶƚƉůƵŐĂŶĚĨŝŶĂůĂďĂŶĚŽŶŵĞŶƚĐĞŵĞŶƚƉůƵŐǁŝƚŚEŽƌĚŝĐϯ ĂŶĚƵůƚŝŵĂƚĞůLJĞdžĞĐƵƚĞĨŝŶĂůĂďĂŶĚŽŶŵĞŶƚ͘ dŚŝƐƐƵďŵŝƐƐŝŽŶŝŶĐůƵĚĞƐŝƚĞŵƐĚŝƐĐƵƐƐĞĚĚƵƌŝŶŐƚŚĞ:ƵŶĞϮϬ ƚŚϮϬϮϰŵĞĞƚŝŶŐďĞƚǁĞĞŶKWĂŶĚƚŚĞK'͗ x dĂƌŐĞƚdKŚĞŝŐŚƚŽĨƐƵƌĨĂĐĞƐŚŽĞƉůƵŐǁŝůůďĞΕϭϱϬ͛dsŝŶƚŽƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐ͘ x /ĨƉƌĞƐƐƵƌĞƚĞƐƚŽĨƐƵƌĨĂĐĞĐĂƐŝŶŐƐŚŽĞĐĞŵĞŶƚƉůƵŐĨĂŝůƐ͕ƚŚĞǁĞůůǁŝůůďĞƐƵƐƉĞŶĚĞĚǁŝƚŚ<t&ĂŶĚĂŬŝůů ƐƚƌŝŶŐŝŶƉƌĞƉĂƌĂƚŝŽŶĨŽƌŽĨĨͲƌŝŐƌĞŵĞĚŝĂƚŝŽŶ͘ /ĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐŽƌƌĞƋƵŝƌĞĂŶLJĨƵƌƚŚĞƌŝŶĨŽƌŵĂƚŝŽŶ͕ƉůĞĂƐĞĐŽŶƚĂĐƚŵĞĂƚϰϬϲͲϲϳϬͲϭϵϯϵ͘ ^ŚĂŶĞ'ĞƌŵĂŶŶ ^ĞŶŝŽƌZŝŐtŽƌŬŽǀĞƌ ŶŐŝŶĞĞƌ W/ƌŝůůŝŶŐĂŶĚtĞůůƐ Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E=shane.germann@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.10.23 16:39:44-08'00' Foxit PDF Editor Version: 13.0.0 2P-432 Plug and Abandonment Background & Objective 2P-432 was an injector that has been shut in since late 2020. This well will be P&A’d as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for the Willow development project in 2026. This well was suspended via reservoir cement plug and intermediate cement plug. The objective of this procedure is to pump the surface casing shoe cement plug and final abandonment cement plug with Nordic 3 and ultimately execute final abandonment. Well Data Meltwater Formation: x Reservoir pressure 7/19/2016 = 2866 psi @ 5400’ TVD x MASP = 2326 psi C-80 Formation: x OAP = 286 psi (11/5/22) (fluid packed with diesel) x MASP = 866 psi Intermediate plug TOC = 3724’ MD Tubing cut depth = 2660’ MD Well Name Previous plug tag depth (RKB)PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-432 3724' Pass 10/5/2024 0 psi 0 psi 300 psi 10/18/2024 3 Production Casing Cement: 51 bbls of 12.5# Class G Cement Calculated TOC @ 3,334' KB Liner Cement: 51.7 bbls of 15.8# Class G Cement Calculated TOC @ 5,438.7' KB 2P-432 Well Suspension Schematic Conductor: 16" Conductor 108' KB 1 2 4 Production Casing: 7" 26# L-80 BTC Mod Set @ 5,602.3’ KB T-3 Peforations: @ 5,778' – 5,860' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,449.5' KB (2372' TVD) Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,485' KB /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D' Es ϭϰ͘ϵΖ Ϯ DK^E/WW> ϱϬϴ͘ϭΖ ϯ < ZDh^>//E'^> s ϱ͕ϯϴϰ͘ϭΖ ϰ DKE/WW> ϱ͕ϰϬϬ͘ϳϬ ϱ >/E Zd/ Ͳ<tͬEK'KΛ KddKD ϱϰϯϴ͘ϳΖ ϲ >KdKZ^hϱ͕ϰϰϱ͘ϮΖ ϳ yW>/E ZdKWW< Z ϱ͕ϰϱϬΖ ϴ Z^E/WW> ϱ͕ϰϱϳ͘ϲΖ ϵ &> yͲ>K<,zZh>/>/E Z ,E' Z ϱ͕ϰϲϬ͘ϯΖ ϭϬ ^ >KZ yd E^/KEϴϬͲϰϬ ϱ͕ϰϲϵ͘ϳΖ ϭϭ ',ͲϮϮ^ >^^ D>z ϱ͕ϰϳϯ͘ϱΖ ϭϮ ZK^^Ks Zh^,/E'ϱ͕ϰϴϴ͘ϵΖ 6 7 8 10 12Liner: 3.5" 9.3# L-80 511 Hydril Set @ 6,038’ KB 9 11 C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5683' RKB Plug #2 – Intermediate TOC ±3724' RKB BOC @ ±5394' RKB Surface Casing Plugs – Rig Date: 10-18-2024 Prepared by: Shane Germann Estimated Start Date: 12-11-2024 MIRU 1. MIRU on 2P-432. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed oƯ IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead before proceeding. 3. ND Tree and NU BOPE. Test rams and annular to 250/2,500 PSI. a. Will not set BPV due to two tested cement plugs below providing two barriers to formation. b. BOPE ConƱguration: Annular / Variable Bore Rams / Blind Rams / Pipe Rams 4. Circulate tubing and IA to brine. Retrieve Tubing 5. MU landing joint and BOLDS. 6. Pull tubing from pre-rig cut to surface and LD. Execute First Surface Casing Abandonment Plug 1. Set bridge plug in production casing 100’ below surface casing shoe 2. Cut production casing 50’ below surface casing shoe 3. Circulate OA to brine and complete 30-minute NFT. a. Punch holes in production casing at the surface casing shoe if unable to achieve circulation from production casing cut. 4. MU landing joint for production casing hanger and conƱrm casing is free from cut. a. Contingency: If unable to pull production casing from original cut depth i. Perform second cut inside surface casing shoe ii. Pull casing down to upper cut and laydown iii. PU DP and Ʊshing assembly iv. TIH and engage cut stub of prod casing. Fish stub free. v. Retrieve to surface. LD DP 5. Pump cement plug through the production casing cut. Utilize 19 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 7” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 7” casing is between 150’ – 200’ TVD inside the surface casing shoe based on space out of a casing collar at the Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe ii. Pump cement plug across the shoe through the tubing. PU and circulate the base of the tubing clear b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon bearing zones. It is our intention to recover 50’ of production casing from the open hole section. c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to drill out the cement plug once pumped. 6. WOC 7. Tag cement and PT to 1,500 PSI with state witness a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to increasing pressure to full 1,500 PSI for 30-min state witness 3 Production Casing Cement: 51 bbls of 12.5# Class G Cement Calculated TOC @ 3,334' KB Liner Cement: 51.7 bbls of 15.8# Class G Cement Calculated TOC @ 5,438.7' KB 2P-432 Well Surface Shoe Cement Schematic Conductor: 16" Conductor 108' KB 1 2 4 Production Casing: 7" 26# L-80 BTC Mod Set @ 5,602.3’ KB T-3 Peforations: @ 5,778' – 5,860' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,449.5' KB (2372' TVD) Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,485' KB /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ&D,E' Zϭϰ͘ϵΖ Ϯ ^d/ZKEZ/' W>h'ϮϱϱϬΖ ϯ < ZDh^>//E'^> s ϱ͕ϯϴϰ͘ϭΖ ϰ DKE/WW> ϱ͕ϰϬϬ͘ϳϬ ϱ >/E Zd/ Ͳ<tͬEK'KΛ KddKD ϱϰϯϴ͘ϳΖ ϲ >KdKZ^hϱ͕ϰϰϱ͘ϮΖ ϳ yW>/E ZdKWW< Z ϱ͕ϰϱϬΖ ϴ Z^E/WW> ϱ͕ϰϱϳ͘ϲΖ ϵ &> yͲ>K<,zZh>/>/E Z ,E' Z ϱ͕ϰϲϬ͘ϯΖ ϭϬ ^ >KZ yd E^/KEϴϬͲϰϬ ϱ͕ϰϲϵ͘ϳΖ ϭϭ ',ͲϮϮ^ >^^ D>z ϱ͕ϰϳϯ͘ϱΖ ϭϮ ZK^^Ks Zh^,/E'ϱ͕ϰϴϴ͘ϵΖ 6 7 8 10 12Liner: 3.5" 9.3# L-80 511 Hydril Set @ 6,038’ KB 9 11 C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5683' RKB Plug #2 – Intermediate TOC ±3724' RKB BOC @ ±5394' RKB Plug #3 – Surface Shoe TOC 2287' RKB (2222' TVD) BOC @ ±2550' RKB Base of 7” Casing 200'-250' MD Inside Surface Shoe Execute Final Abandonment Plug 8. Land workstring in casing hanger proƱle. 9. Circulate cement surface to surface until full cement returns observed on surface. See table below for cement volumes. RDMO 10. ND BOPE. NU dry hole tree. a. Note: this step may be performed prior to pumping Ʊnal surface to surface abandonment plug. 11. RDMO. Cement Plug TOC BOC Section ID BBL/FT Volume Notes Surface Shoe 2500 2550 Open Hole 8.5 0.060898 3.0 Displacement of Prod Casing Stub Included in BBL/FT calc 2450 2500 Open Hole 8.5 0.070187 3.5 2287 2450 Surface Casing 8.83 0.075742 12.3 18.8 Total Volume of Plug Surface Casing 23 2287 Surface Casing 8.83 0.066453 150.4 Displacement of Prod Casing Included in BBL/FT calculation Execute Final Abandonment Surface Excavation 12. DHD to perform drawdown test on tubing, IA, and OA 13. Remove well house. 14. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system. 15. Remove tree in preparation for excavation and casing cut. 16. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 17. Cut oƯ wellhead and all casing strings at 4 feet below original ground level. 18. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 19. Send the casing head with stub to materials shop. Photo document. 20. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. a. ConocoPhillips b. KRU 2P-432 c. PTD #: 202-091 d. API #: 50-103-20420-00-00 21. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground level. 22. Obtain site clearance approval from AOGCC. RDMO. 23. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location condition after work is completed Plug #4 – Surface TOC 15' RKB BOC @ ±2287' RKB 3 Production Casing Cement: 51 bbls of 12.5# Class G Cement Calculated TOC @ 3,334' KB Liner Cement: 51.7 bbls of 15.8# Class G Cement Calculated TOC @ 5,438.7' KB 2P-432 Well Final P&A Schematic Conductor: 16" Conductor 108' KB 1 2 4 Production Casing: 7" 26# L-80 BTC Mod Set @ 5,602.3’ KB T-3 Peforations: @ 5,778' – 5,860' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,449.5' KB (2372' TVD) Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,485' KB /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ&D,E' Zϭϰ͘ϵΖ Ϯ ^d/ZKEZ/' W>h' ϮϱϱϬΖ ϯ < ZDh^>//E'^> s ϱ͕ϯϴϰ͘ϭΖ ϰ DKE/WW> ϱ͕ϰϬϬ͘ϳϬ ϱ >/E Zd/ Ͳ<tͬEK'KΛ KddKD ϱϰϯϴ͘ϳΖ ϲ >KdKZ^h ϱ͕ϰϰϱ͘ϮΖ ϳ yW>/E ZdKWW< Z ϱ͕ϰϱϬΖ ϴ Z^E/WW> ϱ͕ϰϱϳ͘ϲΖ ϵ &> yͲ>K<,zZh>/>/E Z ,E' Z ϱ͕ϰϲϬ͘ϯΖ ϭϬ ^ >KZ yd E^/KEϴϬͲϰϬ ϱ͕ϰϲϵ͘ϳΖ ϭϭ ',ͲϮϮ^ >^^ D>z ϱ͕ϰϳϯ͘ϱΖ ϭϮ ZK^^Ks Zh^,/E' ϱ͕ϰϴϴ͘ϵΖ 6 7 8 10 12Liner: 3.5" 9.3# L-80 511 Hydril Set @ 6,038’ KB 9 11 C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5683' RKB Plug #2 – Intermediate TOC ±3724' RKB BOC @ ±5394' RKB Plug #3 – Surface Shoe TOC 2287' RKB (2222' TVD) BOC @ ±2550' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 5,787.0 2P-432 6/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cut Tbg 2P-432 10/18/2024 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: Temporary waiver allowing OA pressure up to 1800 psi 11/3/2020 jbyrne NOTE: TREE: FMC / GEN V / WKM 3 1/8"" / 5K, TREE CAP CONNECTION: OTIS 3"" 11/22/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.1 2,449.5 2,372.5 40.00 L-80 BTC PRODUCTION 7 6.28 25.4 5,602.3 5,297.5 26.00 L-80 BTC-MD LINER 3 1/2 2.99 5,438.7 6,038.0 5,705.6 9.30 L-80 511 Hydril Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 14.9 Set Depth … 5,485.0 Set Depth … 5,187.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 14.9 14.9 0.00 HANGER 8.000 FMC GEN V 3.500 508.1 508.1 0.17 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 5,334.6 5,046.6 20.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,384.1 5,092.9 20.70 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE (run closed when well drilled in 2003 and never opened since) BAKER CMU 2.810 5,400.7 5,108.5 20.60 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,445.2 5,150.1 20.32 LOCATOR 5.000 LOCATOR SUB 3.000 5,473.5 5,176.7 20.15 SEAL 4.000 GBH-22 SEAL ASSEMBLY GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,010.0 1,964.5 21.94 TUBING PUNCH TBG PUNCH FROM 2010' TO 2013' RKB W/ 4 SPF 9/18/2024 2.992 2,650.0 2,559.3 21.00 CUT JET CUT @ 2650' RKB 10/18/2024 2.992 2,660.0 2,568.7 20.98 CUT JET CUT @ 2660' RKB 10/7/2024 2.992 5,355.0 5,065.7 20.83 LEAK - CASING Leak identified @ 5355' RKB on acoustic log run 9/3/22 (possible PC leak) 9/3/2022 6.280 5,379.0 5,088.2 20.73 TUBING PUNCH TBG PUNCH FROM 5379' TO 5383.5' RKB W/ 4 SPF 9/11/2024 2.992 5,623.0 5,316.8 20.48 TIGHT SPOT Found tight spot with CIBP drift. Able to tap through with drift to set CIBP below tight spot. 6/20/2024 2.700 5,745.3 5,431.4 20.48 CIBP CIBP MID-ELEMENT AT 5746' RKB, OAL = 1.37' 6/30/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,334.6 5,046.6 20.91 1 GAS LIFT DMY BTM 1 0.0 12/23/2003 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,438.7 5,144.0 20.36 TIE BACK 5.760 LINER TIE-BACK W/NO GO @ BOTTOM ZXP 5.250 5,450.0 5,154.7 20.29 PACKER 5.980 ZXP LINER TOP PACKER 4.370 5,457.6 5,161.7 20.25 NIPPLE 5.590 RS NIPPLE RS 4.250 5,488.9 5,191.1 20.24 XO BUSHING 5.010 CROSSOVER BUSHING 3.000 5,494.6 5,196.5 20.28 XO THREAD 3.500 2.992 5,935.1 5,609.2 20.48 XO THREAD 3.500 2.992 5,937.7 5,611.6 20.48 LANDING COLLAR 4.250 Liner BOT Landing Collar 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,778.0 5,798.0 5,462.0 5,480.8 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,806.0 5,826.0 5,488.2 5,507.0 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,838.0 5,860.0 5,518.2 5,538.8 T-3, 2P-432 1/3/2004 6.0 IPERF 2-7/8" HSD PJDP, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,683.0 5,745.3 5,373.0 5,431.4 Cement Plug Dump bail cement on CIBP 7/5/2024 3,724.0 5,394.5 3,556.1 5,102.7 Cement Plug PUMPED 53 BBLS OF 15.8 PPG CLASS G CEMENT 9/15/2024 2P-432, 10/18/2024 1:15:41 PM Vertical schematic (actual) LINER; 5,438.7-6,038.0 FLOAT SHOE; 6,036.0-6,038.0 FLOAT COLLAR; 5,970.8- 5,972.1 LANDING COLLAR; 5,937.7- 5,938.9 IPERF; 5,838.0-5,860.0 APERF; 5,806.0-5,826.0 APERF; 5,778.0-5,798.0 CIBP; 5,745.3 Cement Plug; 5,683.0 ftKB TIGHT SPOT; 5,623.0 PRODUCTION; 25.4-5,602.3 FLOAT SHOE; 5,600.9-5,602.3 FLOAT COLLAR; 5,520.9- 5,522.2 XO BUSHING; 5,488.9-5,490.8 SBE; 5,469.7-5,488.9 SEAL; 5,473.5 HANGER; 5,460.3-5,469.7 NIPPLE; 5,457.5-5,460.3 PACKER; 5,450.0-5,457.6 LOCATOR; 5,445.2 TIE BACK; 5,438.7-5,450.0 NIPPLE; 5,400.7 SLEEVE; 5,384.1 TUBING PUNCH; 5,379.0 LEAK - CASING; 5,355.0 GAS LIFT; 5,334.6 Cement Plug; 3,724.0 ftKB CUT; 2,660.0 CUT; 2,650.0 SURFACE; 28.1-2,449.5 FLOAT SHOE; 2,447.8-2,449.5 FLOAT COLLAR; 2,360.5- 2,362.0 TUBING PUNCH; 2,010.0 NIPPLE; 508.1 CONDUCTOR; 28.0-108.0 HANGER; 28.1-31.6 HANGER; 25.4-27.0 HANGER; 14.9 KUP SVC KB-Grd (ft) 34.41 RR Date 11/23/200 3 Other Elev… 2P-432 ... TD Act Btm (ftKB) 6,043.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032042000 Wellbore Status SVC Max Angle & MD Incl (°) 23.52 MD (ftKB) 5,011.58 WELLNAME WELLBORE2P-432 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE ϮWͲϰϯϮϴĂůĐƵůĂƚĞĚWdKΛϯϯϯϰ͛Z<^^ŚŽĞΛϮϰϱϬ͛Z</WΛϮϱϱϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϮϴϳ͛Z<WƵƚΛϮϱϬϬ͛Z<ϴϬdŽƉΛϮϱϮϬ͛Z<ϴϬĂƐĞΛϯϱϰϬ͛Z< ORIGINATED TRANSMITTAL DATE: 10/30/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5107 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5107 2P-432 501032042000000 Tubing Cut Record 7-Oct-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 202-091 T39721 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.30 12:46:13 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINAL TRANSMITTAL DATE: 10/21/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5129 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5129 2P-432 50103204200000 Tubing Cut Record 18-Oct-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 202-091 T39705 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.21 15:21:07 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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: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: N/A 23. BOTTOM 16" B 108' 9-5/8" L-80 2372' 7" L-80 5297' 5-1/2" L-80 5447' 3-1/2" L-80 5706' 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 5602' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 5762' 25' 5233' 62.5# 40# 108' 25' WT. PER FT.GRADE 443422 443399 Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 3724' (SW TOC)-5394' 53 bbls 15.8 ppg Class G cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 5778-5798' MD and 5462-5481' TVD (below cement plug) 5806-5826' MD and 5488-5507' TVD (below cement plug) 5838-5860' MD and 5518-5539' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 5439' 42" 9.3# 12.25" 110 sx LiteCrete 28'527 sx AS Lite, 225 sx LiteCrete 15.5# 28' 5533' 2449'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# CEMENTING RECORD 5867287 1358' MD / 1352' TVD SETTING DEPTH TVD 5867197 TOP HOLE SIZE AMOUNT PULLEDTOP 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. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 50-103-20420-00-00 KRU 2P-432 ADL0373112 948' FNL, 1894' FWL, Sec. 17, T8N, R7E, UM 2596' FSL, 1446' FWL, Sec. 17, T8N, R7E, UM L 32092 10/31/2003 6043' MD/ 5710' TVD 3724' MD / 3556' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443855 5868930 2594' FNL, 1469' FWL, Sec. 17, T8N, R7E, UM 11/20/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/7/2024 202-091 / 324-410 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, 50 sx Class G w/GasBlok6.125" TUBING RECORD 72 sx Class G6038' 130 sx LiteCrete 5144' 8.5" 4.75" 5485' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 8:06 am, Oct 22, 2024 Suspended 10/7/2024 JSB RBDMS JSB 103024 xGDSR-11/22/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1358' 1352' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions 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: 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. 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. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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. TPI (Top of Producing Interval). Authorized Name and Authorized Title: N/A - SuspendedFormation Name at TD: 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 N/A- Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.10.21 13:54:50-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 5,787.0 2P-432 6/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added jet cut @ 2660' RKB 2P-432 10/7/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Temporary waiver allowing OA pressure up to 1800 psi 11/3/2020 jbyrne NOTE: TREE: FMC / GEN V / WKM 3 1/8"" / 5K, TREE CAP CONNECTION: OTIS 3"" 11/22/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.1 2,449.5 2,372.5 40.00 L-80 BTC PRODUCTION 7 6.28 25.4 5,602.3 5,297.5 26.00 L-80 BTC-MD LINER 3 1/2 2.99 5,438.7 6,038.0 5,705.6 9.30 L-80 511 Hydril Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 14.9 Set Depth … 5,485.0 Set Depth … 5,187.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 14.9 14.9 0.00 HANGER 8.000 FMC GEN V 3.500 508.1 508.1 0.17 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 5,334.6 5,046.6 20.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,384.1 5,092.9 20.70 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE (run closed when well drilled in 2003 and never opened since) BAKER CMU 2.810 5,400.7 5,108.5 20.60 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,445.2 5,150.1 20.32 LOCATOR 5.000 LOCATOR SUB 3.000 5,473.5 5,176.7 20.15 SEAL 4.000 GBH-22 SEAL ASSEMBLY GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,010.0 1,964.5 21.94 TUBING PUNCH TBG PUNCH FROM 2010' TO 2013' RKB W/ 4 SPF 9/18/2024 2.992 2,660.0 2,568.7 20.98 CUT JET CUT @ 2660' RKB 10/7/2024 2.992 5,355.0 5,065.7 20.83 LEAK - CASING Leak identified @ 5355' RKB on acoustic log run 9/3/22 (possible PC leak) 9/3/2022 6.280 5,379.0 5,088.2 20.73 TUBING PUNCH TBG PUNCH FROM 5379' TO 5383.5' RKB W/ 4 SPF 9/11/2024 2.992 5,623.0 5,316.8 20.48 TIGHT SPOT Found tight spot with CIBP drift. Able to tap through with drift to set CIBP below tight spot. 6/20/2024 2.700 5,745.3 5,431.4 20.48 CIBP CIBP MID-ELEMENT AT 5746' RKB, OAL = 1.37' 6/30/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,334.6 5,046.6 20.91 1 GAS LIFT DMY BTM 1 0.0 12/23/2003 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,438.7 5,144.0 20.36 TIE BACK 5.760 LINER TIE-BACK W/NO GO @ BOTTOM ZXP 5.250 5,450.0 5,154.7 20.29 PACKER 5.980 ZXP LINER TOP PACKER 4.370 5,457.6 5,161.7 20.25 NIPPLE 5.590 RS NIPPLE RS 4.250 5,488.9 5,191.1 20.24 XO BUSHING 5.010 CROSSOVER BUSHING 3.000 5,494.6 5,196.5 20.28 XO THREAD 3.500 2.992 5,935.1 5,609.2 20.48 XO THREAD 3.500 2.992 5,937.7 5,611.6 20.48 LANDING COLLAR 4.250 Liner BOT Landing Collar 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,778.0 5,798.0 5,462.0 5,480.8 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,806.0 5,826.0 5,488.2 5,507.0 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,838.0 5,860.0 5,518.2 5,538.8 T-3, 2P-432 1/3/2004 6.0 IPERF 2-7/8" HSD PJDP, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,683.0 5,745.3 5,373.0 5,431.4 Cement Plug Dump bail cement on CIBP 7/5/2024 3,724.0 5,394.5 3,556.1 5,102.7 Cement Plug PUMPED 53 BBLS OF 15.8 PPG CLASS G CEMENT 9/15/2024 2P-432, 10/10/2024 5:00:24 PM Vertical schematic (actual) LINER; 5,438.7-6,038.0 IPERF; 5,838.0-5,860.0 APERF; 5,806.0-5,826.0 APERF; 5,778.0-5,798.0 CIBP; 5,745.3 Cement Plug; 5,683.0 ftKB TIGHT SPOT; 5,623.0 PRODUCTION; 25.4-5,602.3 TUBING PUNCH; 5,379.0 LEAK - CASING; 5,355.0 GAS LIFT; 5,334.6 Cement Plug; 3,724.0 ftKB CUT; 2,660.0 SURFACE; 28.1-2,449.5 TUBING PUNCH; 2,010.0 NIPPLE; 508.1 CONDUCTOR; 28.0-108.0 KUP SVC KB-Grd (ft) 34.41 RR Date 11/23/200 3 Other Elev… 2P-432 ... TD Act Btm (ftKB) 6,043.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032042000 Wellbore Status SVC Max Angle & MD Incl (°) 23.52 MD (ftKB) 5,011.58 WELLNAME WELLBORE2P-432 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 8/2/2024 ACQUIRE DATA (P&A) T DDT (IN-PROGRESS) 8/3/2024 ACQUIRE DATA (P&A) T DDT (PASS) 9/1/2024 ACQUIRE DATA (P&A) FUNCTION TEST ALL T LDS/GNS (COMPLETE), T POT (PASS) T PPPOT (PASS), FUNCTION TEST ALL IC LDS (COMPLETE), IC POT (PASS) IC PPPOT (PASS), 9/11/2024 CHANGE WELL TYPE PERFORM TUBING PUNCH WITH 4.5', 4 SPF TBG PUNCHER PUNCH INTERVAL: 5379' - 5383.5' RKB LRS ASSIST PRESSURING UP TBG BEFORE SHOOTING, PRESSURE DROP AFTER SHOOTING, POOH, CONFIRM GUN SHOT. JOB COMPLETE, READY FOR INTERMEDIATE CEMENT PLUG. 9/15/2024 CHANGE WELL TYPE PUMPED INTERMEDIATE BALANCED CEMENT PLUG. PUMPED 53 BBLS OF 15.8PPG CLASS G CEMENT. TRAPPED 400 PSI OF PRESSURE ON WELL TO KEEP OVERBALANCE PER PROCEDURE. READY FOR ELINE TUBING PUNCH FOR FREEZE PROTECT IN 24-48 HOURS. 9/18/2024 CHANGE WELL TYPE PUNCH HOLES IN TUBING AT 2010' - 2013' RKB (4 SPF), CIRCULATED 78 BBLS DIESEL FREEZE PROTECT. JOB COMPLETE, READY FOR SL 9/21/2024 CHANGE WELL TYPE TAGGED TOP OF CEMENT @ 3707' SLM, OBTAINED GOOD SAMPLE OF CEMENT, OBTAINED PASSING CMIT TO 1500 PSI, PERFORM PASSING DDT TO 0 PSI. READY FOR SW TAG & TEST. 10/5/2024 CHANGE WELL TYPE STATE WITNESS (SEAN SULLIVAN) TAG TOC @ 3724' RKB. PERFORM PASSING CMIT T x IA TO 1500 PSI. READY FOR E-LINE. 10/7/2024 CHANGE WELL TYPE CUT TUBING AT 2660' RKB W/ 2.5" JET CUTTER LOG CORRELATED TO TUBING TALLY DATED 11/22/2003 WELL LEFT S/I 2P-432 Intermediate Suspend Summary of Operations MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: N/A Rig Elevation: N/A Total Depth: 6,043 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 2450 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 5602 Feet Csg Cut@ Feet Liner: 3 1/2" O.D. Shoe@ 6038 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 5,485 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 5,390 ft 3,724 ft 10.2 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1880 1840 1825 IA 1980 1920 1900 OA 407 383 374 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Traveled to KRU 2P pad for plug tag and MIT-TxIA combo test of the intermediate balanced plug on 2P-432. Wire line tool was 28 ft long with 150lbs of weight bar and a flap bailer on the end. Initial tag at 3,709 ft MD and beat down to 3,724 ft MD for final tag. The bailer returned a good cement sample. 1.3bbl in and 1.2 bbl out during the MIT. October 5, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-432 ConocoPhillips Alaska Inc. PTD 2020910; Sundry 324-410 none Test Data: P Casing Removal: rev. 3-24-2022 2024-1005_Plug_Verification_KRU_2P-432_ss 9 9 9 99 9 99 9 9 9 9 9 9 99 9 9 9 9 9 9999 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.18 16:01:25 -09'00' ORIGINATED TRANSMITTAL DATE: 9/19/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5066 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5066 2P-432 50103204200000 Tubing Puncher Record 18-Sep-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 202-091 T39576 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.19 10:07:43 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com Originated: Delivered to:12-Sep-24 Alaska Oil & Gas Conservation Commiss 12Sep24-NR ATTN: MeredithGuhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD2-58 50-103-20457-00-00 203-085 Colville River WL SBHPS-RBP FINAL FIELD 16-Aug-24 CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 18-Aug-24 CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24 1B-07 50-029-20616-00-00 181-089 Kuparuk River WL MechCutter FINAL FIELD 24-Aug-24 2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24 3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24 2A-20 50-103-20196-00-00 193-151 Kuparuk River WL IPROF FINAL FIELD 30-Aug-24 3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24 3J-18 50-029-22701-00-00 196-147 Kuparuk River WL Lee-PPROF FINAL FIELD 3-Sep-24 2U-12 50-029-21304-00-00 185-041 Kuparuk River WL PPROF FINAL FIELD 4-Sep-24 1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24 2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24 2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # 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 media. # Schlumberger-Private T39555 T39556 T39557 T39558 T39559 T39560 T39561 T39562 T39564 T39565 T39566 T39567 T39668 T39563 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.13 08:31:59 -08'00' 2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 T39567 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: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: N/A 23. BOTTOM 16" B 108' 9-5/8" L-80 2372' 7" L-80 5297' 5-1/2" L-80 5447' 3-1/2" L-80 5706' 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 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, 50 sx Class G w/GasBlok6.125" TUBING RECORD 72 sx Class G6038' 130 sx LiteCrete 5144' 8.5" 4.75" 5485' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 7/12/2024 202-091 / 323-547 50-103-20420-00-00 KRU 2P-432 ADL0373112 948' FNL, 1894' FWL, Sec. 17, T8N, R7E, UM 2596' FSL, 1446' FWL, Sec. 17, T8N, R7E, UM L 32092 10/31/2003 6043' MD/ 5710' TVD 5683' MD / 5373' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443855 5868930 2594' FNL, 1469' FWL, Sec. 17, T8N, R7E, UM 11/20/2003 CEMENTING RECORD 5867287 1358' MD / 1352' TVD SETTING DEPTH TVD 5867197 TOP HOLE SIZE AMOUNT PULLEDTOP 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. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A N/A PACKER SET (MD/TVD) 5439' 42" 9.3# 12.25" 110 sx LiteCrete 28'527 sx AS Lite, 225 sx LiteCrete 15.5# 28' 5533' 2449'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 26# 5683 (SW TOC)-5745' ~0.26 bbls 15.8 ppg Class G cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 5778-5798' MD and 5462-5481' TVD (below cement plug) 5806-5826' MD and 5488-5507' TVD (below cement plug) 5838-5860' MD and 5518-5539' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 5602' SIZE DEPTH SET (MD) 9. Ref Elevations: KB: 28' 5762' 25' 5233' 62.5# 40# 108' 25' WT. PER FT.GRADE 443422 443399 Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Received by James Brooks on 7/17/2024 at 9:59AM Suspended 7/12/2024 JSB RBDMS JSB 071824 xGDSR-8/27/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1358' 1352' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions 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: Formation Name at TD: 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 N/A- Suspended 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. 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. TPI (Top of Producing Interval). Authorized Name and Authorized Title: N/A - Suspended 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. 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. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this documentLocation: Date: 2024.07.17 08:58:09-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor DTTMSTART JOBTYP SUMMARYOPS 6/17/2024 CHANGE WELL TYPE PULL 2.75" CA-2 PLUG FROM D NIPPLE @ 5400' RKB, TAG TD @ 5787' RKB W/ 2.5" DD BAILER, ATTEMPT TO DRIFT 2.625" DUMMY CIBP TO 5740' RKB, UNABLE TO WORK PAST TIGHT SPOT @ 5635' RKB, JOB IN PROGRESS 6/20/2024 CHANGE WELL TYPE ATTEMPT TO DRIFT WITH VARIOUS CIBP DRIFTS, 2.70'' GAUGE, TAG @ 5,763' SLM 2.79'' GAUGE, TAG D-NIPPLE @ 5,381' SLM / 5,400' MD (19' CORRECTION) 5' X 2.625 DUMMY CIBP, TAG @ 5,616' SLM, COULDN'T WORK PASSED 2.68'' CENT., 3-1/2 BLB, 2.70'' GAUGE (oal= 50 1/2''), SEEN BOBBLE @ 5,616' SLM, TAG @ 5,763' SLM 15' X 1-7/8'' STEM, 2.68'' CENT., 3-1/2 BLB, 2.70'' GAUGE (oal= 230 1/2''), (cent. to gauge = 44''), TAG @ 5,623' JAR DOWN ONE TIME FALL THROUGH TAG @ 5,763' SLM. SUGGEST RELAY SET THIS CIBP. READY FOR RELAY. 6/30/2024 CHANGE WELL TYPE LOAD TBG W/ 45 BBLS 10.2 PPG BRINE & 18 BBLS DSL FREEZE PROTECT, SET 2.63" CIBP MID-ELEMENT AT 5746' RKB, PERFORM 1500 PSI MIT-T (PASS). JOB COMPLETE, READY FOR SL. 7/4/2024 CHANGE WELL TYPE MAKE MULTIPLE ATTEMPTS TO DRIFT TO CIBP @ 5745' RKB BUT TAGGED KNOWN TIGHT SPOT @ 5623' RKB. DRIFT W/ 10' X 2.25'' BAILER & TAG CIBP @ 5745, RDMO. JOB IN PROGRESS 7/5/2024 CHANGE WELL TYPE DUMP BAIL THREE BAILERS OF CEMENT ON TOP OF CIBP @ 5745' RKB, LDFN. JOB IN PROGRESS 7/6/2024 CHANGE WELL TYPE DUMP BAIL SEVEN BAILERS OF CEMENT ON TOP OF CEMENT STARTING @ 5732' RKB. LEAVING TOC EST 5710' RKB. READY FOR STATE WITNESS TAG & TEST IN 72 HOURS. 7/12/2024 CHANGE WELL TYPE STATE WITNESS (SEAN SULLIVAN) TAG TOC @ 5683' RKB. MIT-T 1500 PSI PASSSED. READY FOR NEXT P&A STEPS. 2P-432 Suspend Summary of operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 5,787.0 2P-432 6/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump Bail Cement on CIBP 2P-432 7/6/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Temporary waiver allowing OA pressure up to 1800 psi 11/3/2020 jbyrne NOTE: VIEW SCHEMATIC W/Alaska Schematic9.0 11/23/2010 haggea NOTE: TREE: FMC / GEN V / WKM 3 1/8"" / 5K, TREE CAP CONNECTION: OTIS 3"" 11/22/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.1 2,449.5 2,372.5 40.00 L-80 BTC PRODUCTION 7 6.28 25.4 5,602.3 5,297.5 26.00 L-80 BTC-MD LINER 3 1/2 2.99 5,438.7 6,038.0 5,705.6 9.30 L-80 511 Hydril Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 14.9 Set Depth … 5,485.0 Set Depth … 5,187.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 14.9 14.9 0.00 HANGER 8.000 FMC GEN V 3.500 508.1 508.1 0.17 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 5,334.6 5,046.6 20.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,384.1 5,092.9 20.70 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE (run closed when well drilled in 2003 and never opened since) BAKER CMU 2.810 5,400.7 5,108.5 20.60 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,445.2 5,150.1 20.32 LOCATOR 5.000 LOCATOR SUB 3.000 5,473.5 5,176.7 20.15 SEAL 4.000 GBH-22 SEAL ASSEMBLY GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,355.0 5,065.7 20.83 LEAK - CASING Leak identified @ 5355' RKB on acoustic log run 9/3/22 (possible PC leak) 9/3/2022 6.280 5,623.0 5,316.8 20.48 TIGHT SPOT Found tight spot with CIBP drift. Able to tap through with drift to set CIBP below tight spot. 6/20/2024 2.700 5,745.3 5,431.4 20.48 CIBP CIBP MID-ELEMENT AT 5746' RKB, OAL = 1.37' 6/30/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,334.6 5,046.6 20.91 1 GAS LIFT DMY BTM 1 0.0 12/23/2003 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,438.7 5,144.0 20.36 TIE BACK 5.760 LINER TIE-BACK W/NO GO @ BOTTOM ZXP 5.250 5,450.0 5,154.7 20.29 PACKER 5.980 ZXP LINER TOP PACKER 4.370 5,457.6 5,161.7 20.25 NIPPLE 5.590 RS NIPPLE RS 4.250 5,488.9 5,191.1 20.24 XO BUSHING 5.010 CROSSOVER BUSHING 3.000 5,494.6 5,196.5 20.28 XO THREAD 3.500 2.992 5,935.1 5,609.2 20.48 XO THREAD 3.500 2.992 5,937.7 5,611.6 20.48 LANDING COLLAR 4.250 Liner BOT Landing Collar 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,778.0 5,798.0 5,462.0 5,480.8 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,806.0 5,826.0 5,488.2 5,507.0 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,838.0 5,860.0 5,518.2 5,538.8 T-3, 2P-432 1/3/2004 6.0 IPERF 2-7/8" HSD PJDP, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,683.0 5,745.3 5,373.0 5,431.4 Cement Plug Dump bail cement on CIBP 7/5/2024 2P-432, 7/16/2024 4:46:48 PM Vertical schematic (actual) LINER; 5,438.7-6,038.0 IPERF; 5,838.0-5,860.0 APERF; 5,806.0-5,826.0 APERF; 5,778.0-5,798.0 CIBP; 5,745.3 Cement Plug; 5,683.0 ftKB TIGHT SPOT; 5,623.0 PRODUCTION; 25.4-5,602.3 LEAK - CASING; 5,355.0 GAS LIFT; 5,334.6 SURFACE; 28.1-2,449.5 NIPPLE; 508.1 CONDUCTOR; 28.0-108.0 KUP INJ KB-Grd (ft) 34.41 RR Date 11/23/200 3 Other Elev… 2P-432 ... TD Act Btm (ftKB) 6,043.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032042000 Wellbore Status INJ Max Angle & MD Incl (°) 23.52 MD (ftKB) 5,011.58 WELLNAME WELLBORE2P-432 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 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: Suspend-Intermediate Plug 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6043'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 7/22/2024 6038'599' 3-1/2" 5706' Packer: GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2421' 5778-5798', 5806-5326', 5838- 5860' 5577' 3-1/2" 5462-5481', 5488-5507', 5518- 5539' 7" Perforation Depth TVD (ft): 108' 2450' 5297'5602' 16" 9-5/8" 80' 5485' MD 108' 2373' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool- Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 202-091 P.O. Box 100360, Anchorage, AK 99510 50-103-20420-00-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5473' MD and 5177' TVD N/A Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: Plugs (MD): 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: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Senior Well Interventions Engineer KRU 2P-432 5710' 5683' 5373' 5400' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov MPSP (psi): 2623 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@conocophillips.com , C=US Reason: I am the author of this document Location: Date: 2024.07.17 13:40:29-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 324-410 By Grace Christianson at 2:22 pm, Jul 17, 2024 VTL 7/18/2024 A.Dewhurst 19JUL24 X DSR-7/17/24 X 10-407 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.22 11:18:58 -08'00'07/22/24 RBDMS JSB 072324 2P-432 Intermediate Plug Date Wrien: 5-14-24 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-432 was an injector shut-in in late 2020. This well has a casing leak at 5355’ KB but had tubing integrity as of 2020. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 7/19/2016 = 2866 psi at 5400’ TVD 0.531 psi/ft MASP = 2623 psi Last TD tag 5892’ KB with 1.75” bailer Liner impingement at 5685’ KB, tagged with 2.25” bailer Casing leak at 5355’ KB. LLR = 0.31 bpm @ 2550 psi Procedure Wireline & Pumping 1. Punch tubing at ±5390’ RKB 2. Pump the following schedule taking returns up the IA: a. ±50 bbls surfactant wash b. ±125 bbls 9.8 brine c. ±31 bbls cement d. ±34 bbls 9.8 brine displacement e. Pump methanol across tree and valves for freeze protect 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 3890’ MD 1. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline/Relay 4. Cut tubing at ±2670’ RKB Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 5390 3.5" 9.3# 2.99" 0.0087 5390 46.8 115.1 from punch depth 3-1/2" x 5-1/2" Annulus 0 5390 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 5390 64.2 84.0 from punch depth Tubing Cement 3890 5390 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 3890 5390 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0 Liner Cement: 51.7 bbls of 15.8# Class G Cement Calculated TOC @ 5,438.7' KB 2P-432 Well Suspension Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 51 bbls of 12.5# Class G Cement Calculated TOC @ 3,334' KB 1 2 3 4 Production Casing: 7" 26# L-80 BTC Mod Set @ 5,602.3’ KB T-3 Peforations: @ 5,778' – 5,860' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,449.5' KB Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,485' KB Item Depth - tops (KB) 1 FMC GEN V 14.9' 2 CAMCO DS NIPPLE 508.1' 3 BAKER CMU SLIDING SLEEVE 5,384.1' 4 CAMCO D NIPPLE 5,400.70 5 LINER TIE-BACK W/ NO GO @ BOTTOM 5438.7' 6 LOCATOR SUB 5,445.2' 7 ZXP LINER TOP PACKER 5,450' 8 RS NIPPLE 5,457.6' 9 FLEX-LOCK HYDRAULIC LINER HANGER 5,460.3' 10 SEAL BORE EXTENSION 80-40 5,469.7' 11 GBH-22 SEAL ASSEMBLY 5,473.5' 12 CROSSOVER BUSHING 5,488.9' 6 7 8 10 12Liner: 3.5" 9.3# L-80 511 Hydril Set @ 6,038’ KB 9 11 C80 @ 2520' KB Plug #1 – Reservoir TOC ±5683' RKB Plug #2 – Intermediate TOC ±3890' RKB BOC @ ±5390' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 5,787.0 2P-432 6/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump Bail Cement on CIBP 2P-432 7/6/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Temporary waiver allowing OA pressure up to 1800 psi 11/3/2020 jbyrne NOTE: VIEW SCHEMATIC W/Alaska Schematic9.0 11/23/2010 haggea NOTE: TREE: FMC / GEN V / WKM 3 1/8"" / 5K, TREE CAP CONNECTION: OTIS 3"" 11/22/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.1 2,449.5 2,372.5 40.00 L-80 BTC PRODUCTION 7 6.28 25.4 5,602.3 5,297.5 26.00 L-80 BTC-MD LINER 3 1/2 2.99 5,438.7 6,038.0 5,705.6 9.30 L-80 511 Hydril Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 14.9 Set Depth … 5,485.0 Set Depth … 5,187.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 14.9 14.9 0.00 HANGER 8.000 FMC GEN V 3.500 508.1 508.1 0.17 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 5,334.6 5,046.6 20.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,384.1 5,092.9 20.70 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE (run closed when well drilled in 2003 and never opened since) BAKER CMU 2.810 5,400.7 5,108.5 20.60 NIPPLE 4.500 CAMCO D NIPPLE CAMCO D 2.750 5,445.2 5,150.1 20.32 LOCATOR 5.000 LOCATOR SUB 3.000 5,473.5 5,176.7 20.15 SEAL 4.000 GBH-22 SEAL ASSEMBLY GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,355.0 5,065.7 20.83 LEAK - CASING Leak identified @ 5355' RKB on acoustic log run 9/3/22 (possible PC leak) 9/3/2022 6.280 5,623.0 5,316.8 20.48 TIGHT SPOT Found tight spot with CIBP drift. Able to tap through with drift to set CIBP below tight spot. 6/20/2024 2.700 5,745.3 5,431.4 20.48 CIBP CIBP MID-ELEMENT AT 5746' RKB, OAL = 1.37' 6/30/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,334.6 5,046.6 20.91 1 GAS LIFT DMY BTM 1 0.0 12/23/2003 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,438.7 5,144.0 20.36 TIE BACK 5.760 LINER TIE-BACK W/NO GO @ BOTTOM ZXP 5.250 5,450.0 5,154.7 20.29 PACKER 5.980 ZXP LINER TOP PACKER 4.370 5,457.6 5,161.7 20.25 NIPPLE 5.590 RS NIPPLE RS 4.250 5,488.9 5,191.1 20.24 XO BUSHING 5.010 CROSSOVER BUSHING 3.000 5,494.6 5,196.5 20.28 XO THREAD 3.500 2.992 5,935.1 5,609.2 20.48 XO THREAD 3.500 2.992 5,937.7 5,611.6 20.48 LANDING COLLAR 4.250 Liner BOT Landing Collar 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,778.0 5,798.0 5,462.0 5,480.8 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,806.0 5,826.0 5,488.2 5,507.0 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,838.0 5,860.0 5,518.2 5,538.8 T-3, 2P-432 1/3/2004 6.0 IPERF 2-7/8" HSD PJDP, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,683.0 5,745.3 5,373.0 5,431.4 Cement Plug Dump bail cement on CIBP 7/5/2024 2P-432, 7/16/2024 4:46:48 PM Vertical schematic (actual) LINER; 5,438.7-6,038.0 IPERF; 5,838.0-5,860.0 APERF; 5,806.0-5,826.0 APERF; 5,778.0-5,798.0 CIBP; 5,745.3 Cement Plug; 5,683.0 ftKB TIGHT SPOT; 5,623.0 PRODUCTION; 25.4-5,602.3 LEAK - CASING; 5,355.0 GAS LIFT; 5,334.6 SURFACE; 28.1-2,449.5 NIPPLE; 508.1 CONDUCTOR; 28.0-108.0 KUP INJ KB-Grd (ft) 34.41 RR Date 11/23/200 3 Other Elev… 2P-432 ... TD Act Btm (ftKB) 6,043.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032042000 Wellbore Status INJ Max Angle & MD Incl (°) 23.52 MD (ftKB) 5,011.58 WELLNAME WELLBORE2P-432 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:17 Township:8N Range:7E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:6,043 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9-5/8"O.D. Shoe@ 2450 Feet Csg Cut@ Feet Intermediate:N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet Production:7"O.D. Shoe@ 5,602 Feet Csg Cut@ Feet Liner:3-1/2"O.D. Shoe@ 6,038 Feet Csg Cut@ Feet Tubing:3-1/2"O.D. Tail@ 5,485 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 5,745 ft 5,683 ft 9.6 ppg KWF Wireline tag Initial 15 min 30 min 45 min Result Tubing 2330 2250 2220 IA 1750 1740 1725 OA 240 265 266 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Traveled to KRU 2P pad for multiple P&A's.This is the initial witnessed Tag and MIT-T of the 1st cmt plug for 2P-432. Upon arrival I met with CPAI rep Sid Ferguson, Little Red Services (LRS) operators, and wireline crew to go over the plan for the day. They began with a wireline tag with bailer and 300 lbs weight bar. A solid tag was made at 5,683 ft MD and returned a good cmt sample that was grey in color and clay like. E-line rigged down and started rigging up on the next well while LRS rigged up for MIT-T. MIT was performed with no noticable losses to the plug or to the IA. Data was recorded and we moved to the next well. July 12, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-432 ConocoPhillips Alaska Inc. PTD 2020910; Sundry 323-547 none Test Data: P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0712_Plug_Verification_KRU_2P-432_ss Originated: Delivered to:9-Jul-24 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 # E SET# 1 2C-12 50-029-21222-00 909383030 Kuparuk River Correlation Record Field- Final 1-Jul-24 0 1 2 2H-03 50-103-20031-00 n/a Kuparuk River Plug Setting Record Field- Final 13-May-24 0 1 3 2P-432 50-103-20420-00 909422477 Kuparuk River Plug Setting Record Field- Final 30-Jun-24 0 1 4 2W-01 50-029-21273-00 n/a Kuparuk River Patch Setting Record Field- Final 20-May-24 0 1 5 2X-05 50-029-20985-00 909358554 Kuparuk River Multi Finger Caliper Field & Processed 28-May-24 0 1 6 2X-05 50-029-20985-00 909358554 Kuparuk River Patch Setting Record Field- Final 29-May-24 0 1 7 2Z-06 50-029-20957-00 n/a Kuparuk River Plug Setting Record Field- Final 23-May-24 0 1 8 3B-16A 50-029-21289-01 909336135 Kuparuk River Perforation Record Field- Final 18-May-24 0 1 9 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 22-Jun-24 0 1 10 3H-33A 50-103-20578-01 909382823 Kuparuk River Patch Setting Record Field- Final 24-Jun-24 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: T39162 T39163 T39164 T39165 T39166 T39166 T39167 T39168 T39169 T39169 184-206 184-070 202-091 185-010 183-107 183-077 223-125 209-103 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.10 13:26:17 -08'00' 2P-432 50-103-20420-00 909422477 Kuparuk River Plug Setting Record Field- Final 30-Jun-24 0 1 T3916 202-091 From:Jacob Flora To:Brian Glasheen Subject:FW: Cementing Follow Up Report: Excape Control Lines Date:Wednesday, October 25, 2023 10:24:20 AM Boom From: Jake Flora - (C) <Jake.Flora@hilcorp.com> Sent: Monday, July 12, 2021 2:20 PM To: bryan.mclellan@alaska.gov Cc: Taylor Wellman <twellman@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jake Flora - (C) <Jake.Flora@hilcorp.com> Subject: Cementing Follow Up Report: Excape Control Lines Bryan, Below are the ¼” control lines we squeezed with the grease pump and Halliburton’s FineCem squeeze cement on the Excape IA squeezed wells we did in early January 2021. As you will notice the lines took a varying amount of cement. The 0.25” lines have an ID of 0.152” and capacity of 0.00094 gllons/ft. 2 gallons equates to 2127’ of control line. I plan on updating the WBDs and notating the cement volume pumped on each. Let me know if there is anything additional you would like to see here- Thanks, Jake PTD Well cement volume pumped date cemented 202-091 KBU 11-08Y 2 gallons on each line (7/2/2021) 205-141 KBU 41-06 1.5 gal red, 2 gal yellow and 2 gal green 202-091 KBU 11-08Y 2 gallons on each line (7/2/2021) (7/2/2021) 204-209 KBU 42-06 2 gal yellow, 1.5 green and 1 gal red (7/2/2021) 200-179 KBU 44-06 1 gal red and 2 gal green (7/2/2021) 207-149 KBU 14-06Y 1.5 gal green and 0.5 gal red (7/2/2021) 203-217 KBU 23-07 1 gal red, .5 gal green and 1 gal yellow (7/2/2021) 203-025 BCU-11 2 gallons on each line (7/3/2021) 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:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6043'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11/20/2023 6038'599' 3-1/2" 5706' Packer: GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2421' 5778-5798', 5806-5826', 5838- 5860' 5577' 3-1/2" 5462-5481', 5488-5507', 5518- 5539' 7" Perforation Depth TVD (ft): 108' 2450' 5297'5602' 16" 9-5/8" 80' 5485' MD 108' 2373' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 202-091 P.O. Box 100360, Anchorage, AK 99510 50-103-20420-00-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5474' MD and 5177' TVD N/A Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Well Interventions Engineer KRU 2P-432 5710' 5400' 5108' 2623 5400' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:09 am, Oct 05, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.10.04 11:28:18-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 323-547 10-407 DSR-10/5/23VTL 11/14/2023 X December 31, 2024 X SFD SFD 10/6/2023*&:JLC 11/15/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.15 14:29:40 -09'00'11/15/23 RBDMS JSB 111623 2P-432 Suspension Date Wrien: 9-21-23 Execuon Date: Nov 20, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-432 was an injector shut-in in late 2020. This well has a casing leak at 5355’ KB but had tubing integrity as of 2020. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 7/19/2016 = 2866 psi at 5400’ TVD MASP = 2623 psi Last TD tag 5892’ KB with 1.75” bailer Liner impingement at 5685’ KB, tagged with 2.25” bailer Procedure Wireline & Pumping 1. Tag TD. If unable to get within 50’ of perforations, contact Katherine O’Connor 2. Fluid pack tubing with KWF and freeze protect 3. Set CIBP @ ±5,740’ RKB (must be set within 50’ of the top of perforations) 4. Perform MIT-T to 1500 psi, record results 5. Dump bail at least 30’ of cement on top of CIBP 6. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 7. RIH and tag TOC, approx. 5,710’ RKB (MUST BE AOGCC WITNESSED) 8. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 9. Perform DDT and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval Liner Cement: 51.7 bbls of 15.8# Class G Cement Calculated TOC @ 5,438.7' KB 2P-432 Well Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 51 bbls of 12.5# Class G Cement Calculated TOC @ 3,334' KB 1 2 3 4 Production Casing: 7" 26# L-80 BTC Mod Set @ 5,602.3’ KB T-3 Peforations: @ 5,778' – 5,860' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,449.5' KB Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,485' KB Item Depth - tops (KB) 1 FMC GEN V 14.9' 2 CAMCO DS NIPPLE 508.1' 3 BAKER CMU SLIDING SLEEVE 5,384.1' 4 CAMCO D NIPPLE 5,400.70 5 LINER TIE-BACK W/ NO GO @ BOTTOM 5438.7' 6 LOCATOR SUB 5,445.2' 7 ZXP LINER TOP PACKER 5,450' 8 RS NIPPLE 5,457.6' 9 FLEX-LOCK HYDRAULIC LINER HANGER 5,460.3' 10 SEAL BORE EXTENSION 80-40 5,469.7' 11 GBH-22 SEAL ASSEMBLY 5,473.5' 12 CROSSOVER BUSHING 5,488.9' 6 7 8 10 12Liner: 3.5" 9.3# L-80 511 Hydril Set @ 6,038’ KB 9 11 C80 @ 2520' KB C80 @ 2520' KB Liner Cement: 51.7 bbls of 15.8# Class G Cement Calculated TOC @ 5,438.7' KB 2P-432 Well Suspension Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 51 bbls of 12.5# Class G Cement Calculated TOC @ 3,334' KB 1 2 3 4 Production Casing: 7" 26# L-80 BTC Mod Set @ 5,602.3’ KB T-3 Peforations: @ 5,778' – 5,860' KB (82') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 2,449.5' KB Production Tubing: 3.5" 9.3# L-80 EUE-8rd Set @ 5,485' KB Item Depth - tops (KB) 1 FMC GEN V 14.9' 2 CAMCO DS NIPPLE 508.1' 3 BAKER CMU SLIDING SLEEVE 5,384.1' 4 CAMCO D NIPPLE 5,400.70 5 LINER TIE-BACK W/ NO GO @ BOTTOM 5438.7' 6 LOCATOR SUB 5,445.2' 7 ZXP LINER TOP PACKER 5,450' 8 RS NIPPLE 5,457.6' 9 FLEX-LOCK HYDRAULIC LINER HANGER 5,460.3' 10 SEAL BORE EXTENSION 80-40 5,469.7' 11 GBH-22 SEAL ASSEMBLY 5,473.5' 12 CROSSOVER BUSHING 5,488.9' 6 7 8 10 12Liner: 3.5" 9.3# L-80 511 Hydril Set @ 6,038’ KB 9 11 C80 @ 2520' KB C80 @ 2520' KB Plug #1 – Reservoir TOC ±5710' RKB C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-09-03_15871_KRU_2P-432_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15871 KRU 2P-432 50-103-20420-00 LeakPoint Survey 03-Sep-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:202-091 T36988 Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.09 09:29:57 -08'00' 1 Regg, James B (OGC) From:Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent:Wednesday, August 17, 2022 10:00 AM To:Regg, James B (OGC); Wallace, Chris D (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:CPAI 2P-Pad shut in tests 08-16-22.xlsx Attachments:MIT KRU 2P PAD SI TESTS 08-16-22.xlsx All Attached is the 10 426 form for the shut in tests performed on 2P pad on the 16 th of Aug 2022. Please let me know if you have any questions or concerns. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040170 Type Inj N Tubing 2605 2620 2610 2610 Type Test P Packer TVD 5209 BBL Pump 3.2 IA 470 3590 3500 3480 Interval V Test psi 2900 BBL Return 3.1 OA 203 360 310 290 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011820 Type Inj N Tubing 827 827 828 828 Type Test P Packer TVD 5428 BBL Pump 1.0 IA 460 3210 3145 3130 Interval V Test psi 2900 BBL Return 0.9 OA 277 363 319 309 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020180 Type Inj N Tubing 808 1001 980 953 Type Test P Packer TVD 5456 BBL Pump 2.3 IA 410 3200 3090 3075 Interval V Test psi 2900 BBL Return 2.0 OA 277 576 515 484 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011020 Type Inj N Tubing 875 876 876 876 Type Test P Packer TVD 5219 BBL Pump 2.1 IA 390 3200 3110 3100 Interval V Test psi 2900 BBL Return 1.8 OA 236 569 539 531 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020910 Type Inj N Tubing 1091 1091 1091 Type Test P Packer TVD 5177 BBL Pump 3.2 IA 450 3200 2105 Interval V Test psi 2900 BBL Return OA 278 405 345 Result F Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031530 Type Inj N Tubing 886 887 887 887 Type Test P Packer TVD 5141 BBL Pump 1.6 IA 470 3210 3110 3090 Interval V Test psi 2900 BBL Return 1.6 OA 254 356 321 312 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2010820 Type Inj N Tubing 112 288 298 294 Type Test P Packer TVD 5274 BBL Pump 1.7 IA 950 3210 3110 3100 Interval V Test psi 2900 BBL Return 1,6 OA 211 428 303 253 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031540 Type Inj N Tubing 882 882 882 882 Type Test P Packer TVD 5234 BBL Pump 2.0 IA 210 3210 3110 3110 Interval V Test psi 2900 BBL Return 1.8 OA 438 444 444 443 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 2P-438 2P-447 MITIA every 2 yr to max anticipated injection pressure per AIO 21C.002 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-429 2P-432 2P-434 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-427 Notes:MITIA every 2 yr to max anticipated injection pressure per AIO 21C.001 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 ConocoPhillips Alaska Inc, Kuparuk / KRU / 2P Pad Witness Waived by Guy Cook Beck / Borge 08/16/22 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Tubing plug set at 8110' MD Notes: Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-419 2P-420 Form 10-426 (Revised 01/2017)2022-0816_MIT_KRU_2P-pad_8wells 2P-432 F CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2P-432 (PTD #202-091) failed MIT-IA Date:Wednesday, August 17, 2022 10:00:17 AM Attachments:image001.png AnnComm Surveillance TIO for 2P-432.pdf MIT KRU 2P PAD SI TESTS 08-16-22.xlsx From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, August 17, 2022 9:48 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: KRU 2P-432 (PTD #202-091) failed MIT-IA Chris- KRU 2P-432 (PTD #202-091) failed the shut in UIC compliance MIT-IA yesterday (declined witnessed by Guy Cook). The well was previously shut in for the 2P-pad P&A program. A tubing plug will be set to conduct further diagnostics and identify the failure mechanism. After the diagnostics are complete, an evaluation will be conducted to determine if a repair will be required to complete a competent P&A. If a repair will be required the proper paperwork will be submitted at that time. If the failure mechanism does not impact the ability to competently plug and abandon the well, the information will be included on the sundry application for P&A. Attached is a copy of the well bore schematic, 90 day TIO plot and 10-426 form with the failing MIT-IA. Please let me know if you have any questions or disagree with the plans. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: RKB (Est. 38' of Rathole) 5,898.0 11/16/2019 2P-432 zembaejLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: Pulled Inj Valve & Updated Tag Depth 11/16/2019 2P-432 zembaejCasing StringsCasing DescriptionCONDUCTOR 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 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)9 5/8 ID (in)8.83 Top (ftKB)28.1 Set Depth (ftKB)2,449.5 Set Depth (TVD) …2,372.5 Wt/Len (l…40.00 GradeL-80 Top ThreadBTCCasing DescriptionPRODUCTION OD (in)7 ID (in)6.28 Top (ftKB)25.4 Set Depth (ftKB)5,602.3 Set Depth (TVD) …5,297.5 Wt/Len (l…26.00 GradeL-80 Top ThreadBTC-MDCasing DescriptionLINER OD (in)3 1/2 ID (in)2.99 Top (ftKB)5,438.7 Set Depth (ftKB)6,038.0 Set Depth (TVD) …5,705.6 Wt/Len (l…9.30 GradeL-80 Top Thread511 HydrilLiner DetailsTop (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,438.7 5,144.0 20.36 TIE BACK LINER TIE-BACK W/NO GO @ BOTTOM 5.250 5,450.0 5,154.7 20.29 PACKER ZXP LINER TOP PACKER 4.370 5,457.6 5,161.7 20.25 NIPPLE RS NIPPLE 4.250 5,460.3 5,164.3 20.23 HANGER FLEX-LOCK HYDRAULIC LINER HANGER 4.410 5,469.7 5,173.1 20.17 SBE SEAL BORE EXTENSION 80-40 4.000 5,488.9 5,191.1 20.24 XO BUSHING CROSSOVER BUSHING 3.000 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 14.9 Set Depth (ft… 5,485.0 Set Depth (TVD) (… 5,187.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 14.9 14.9 0.00 HANGER FMC GEN V 3.500 508.1 508.1 0.17 NIPPLE CAMCO DS NIPPLE 2.875 5,384.1 5,092.9 20.70 SLEEVE BAKER CMU SLIDING SLEEVE 2.810 5,400.7 5,108.5 20.60 NIPPLE CAMCO D NIPPLE 2.750 5,445.2 5,150.1 20.32 LOCATOR LOCATOR SUB 3.000 5,473.5 5,176.7 20.15 SEAL GBH-22 SEAL ASSEMBLY 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,778.0 5,798.0 5,462.0 5,480.8 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,806.0 5,826.0 5,488.2 5,507.0 T-3, 2P-432 3/4/2004 6.0 APERF 2-7/8" HSD PJDP, 60 deg phase 5,838.0 5,860.0 5,518.2 5,538.8 T-3, 2P-432 1/3/2004 6.0 IPERF 2-7/8" HSD PJDP, 60 deg phase Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 5,334.6 5,046.6 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 12/23/2003 Notes: General & Safety End Date Annotation 11/22/2003 NOTE: TREE: FMC / GEN V / WKM 3 1/8"" / 5K, TREE CAP CONNECTION: OTIS 3"" 6/14/2004 NOTE: WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR 11/23/2010 NOTE: VIEW SCHEMATIC W/Alaska Schematic9.0 2P-432, 11/17/2019 7:56:55 AMVertical schematic (actual) LINER; 5,438.7-6,038.0 IPERF; 5,838.0-5,860.0 APERF; 5,806.0-5,826.0 APERF; 5,778.0-5,798.0 PRODUCTION; 25.4-5,602.3 SEAL; 5,473.5 LOCATOR; 5,445.2 NIPPLE; 5,400.7 SLEEVE; 5,384.1 GAS LIFT; 5,334.6 SURFACE; 28.1-2,449.5 NIPPLE; 508.1 CONDUCTOR; 28.0-108.0HANGER; 14.9 KUP INJ KB-Grd (ft)34.41 Rig Release Date11/23/20032P-432...TDAct Btm (ftKB)6,043.0Well AttributesField NameMELTWATER Wellbore API/UWI501032042000 Wellbore StatusINJ Max Angle & MDIncl (°)23.52 MD (ftKB)5,011.58WELLNAME WELLBORE2P-432 AnnotationLast WO:End DateH2S (ppm) DateCommentSSSV: NIPPLE Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2040170 Type Inj N Tubing 2605 2620 2610 2610 Type Test P Packer TVD 5209 BBL Pump 3.2 IA 470 3590 3500 3480 Interval V Test psi 2900 BBL Return 3.1 OA 203 360 310 290 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2011820 Type Inj N Tubing 827 827 828 828 Type Test P Packer TVD 5428 BBL Pump 1.0 IA 460 3210 3145 3130 Interval V Test psi 2900 BBL Return 0.9 OA 277 363 319 309 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2020180 Type Inj N Tubing 808 1001 980 953 Type Test P Packer TVD 5456 BBL Pump 2.3 IA 410 3200 3090 3075 Interval V Test psi 2900 BBL Return 2.0 OA 277 576 515 484 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2011020 Type Inj N Tubing 875 876 876 876 Type Test P Packer TVD 5219 BBL Pump 2.1 IA 390 3200 3110 3100 Interval V Test psi 2900 BBL Return 1.8 OA 236 569 539 531 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2020910 Type Inj N Tubing 1091 1091 1091 Type Test P Packer TVD 5177 BBL Pump 3.2 IA 450 3200 2105 Interval V Test psi 2900 BBL Return OA 278 405 345 Result F Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2031530 Type Inj N Tubing 886 887 887 887 Type Test P Packer TVD 5141 BBL Pump 1.6 IA 470 3210 3110 3090 Interval V Test psi 2900 BBL Return 1.6 OA 254 356 321 312 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2010820 Type Inj N Tubing 112 288 298 294 Type Test P Packer TVD 5274 BBL Pump 1.7 IA 950 3210 3110 3100 Interval V Test psi 2900 BBL Return 1,6 OA 211 428 303 253 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2031540 Type Inj N Tubing 882 882 882 882 Type Test P Packer TVD 5234 BBL Pump 2.0 IA 210 3210 3110 3110 Interval V Test psi 2900 BBL Return 1.8 OA 438 444 444 443 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 2P-438 2P-447 MITIA every 2 yr to max anticipated injection pressure per AIO 21C.002 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-429 2P-432 2P-434 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-427 Notes:MITIA every 2 yr to max anticipated injection pressure per AIO 21C.001 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 ConocoPhillips Alaska Inc, Kuparuk / KRU / 2P Pad Witness Waived by Guy Cook Beck / Borge 08/16/22 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Tubing plug set at 8110' MD Notes: Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-419 2P-420 Form 10-426 (Revised 01/2017)MIT KRU 2P PAD SI TESTS 08-16-22 (002) Wallace, Chris D (CED) From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, March 25, 2021 1:31 PM To: Wallace, Chris D (CED) Cc: Earhart, Will C; Abbas, Sayeed; Well Integrity Specialist CPF2 Subject: RE: KRU 213-432 (PTD 202-091) Update and plan forward Attachments: 213-432 90 Day TIO plot.pdf Chris - This email is to serve as an update to the most recent information gathered on Kuparuk Meltwater injector 213-432 (PTD 202-091). Most recently the OA pressure decrease was thought to be associated with 2P-419 (PTD# 204-017) being shut in. 213-419 resumed injection on the 25th of Jan 21 and 213-432's OA was closely monitored for pressure trend deviations. The OA did not show indications of influence from the injection of 213-419. The next step in the process was to eliminate the possibility of a surface casing failure. DHD conducted a passing surface casing leak detect, which indicates a competent surface casing from surface to the OA shoe. During the re -installation of the well head jewelry, DHD noted that there was a leak within the previously installed equipment. The small leak was repaired and the OA was left with an elevated pressure (^'1218 psi as of 25 March 21). The well will be closely monitored to see if the faulty jewelry was the cause of the OA pressure decline or if the OA pressure decline is a repeatable event. Attached is a copy of the current 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM ps From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, January 22, 20215:08 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: KRU 2P-432 (PTD 202-091) Update and plan forward Chris- Kuparuk Injector 2P-432 (PTD# 202-091) has had a recent discovery in information regarding the charging OA. As portrayed in previous emails the OA was being monitor for pressure stabilization not to exceed 1800 psi. In early November, the upward pressure trend reversed and the OA has since seen a downward pressure trend. An investigation into the change of trend eventually associated the shutting in of KRU 213-419 (PTD# 204-017) in the same time frame the downward pressure trend started. It is CPAI's intention to bring 213-419 back on injection and closely monitor the OA pressure of 2P-432 to see if there is a pressure response. CPAI will relay the information to AOGCC regarding the results of the injection/pressure response trial. At that point in time a plan forward will be developed depending on the outcome. Please let me know if you have any questions or disagree with the plan. Attached is a 90 day TIO plot of 2P-432 & 213-419 and a snapshot of the 213-432 OA pressure trend in relation to the shutting in of 213-419. Dusty Freeborn Wells Integrity Specialist Wallace, Chris D (CED) From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, January 22, 2021 5:08 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler; Well Integrity Specialist CPF2 Subject: KRU 2P-432 (PTD 202-091) Update and plan forward Attachments: 2P-432 90 Day TIO.pdf; 2P-419 90 Day TIO.pdf, MicrosoftTeams-image.png Chris- Kuparuk Injector 2P-432 (PTD# 202-091) has had a recent discovery in information regarding the charging OA. As portrayed in previous emails the OA was being monitor for pressure stabilization not to exceed 1800 psi. In early November, the upward pressure trend reversed and the OA has since seen a downward pressure trend. An investigation into the change of trend eventually associated the shutting in of KRU 2P-419 (PTD# 204-017) in the same time frame the downward pressure trend started. It is CPAI's intention to bring 2P-419 back on injection and closely monitor the OA pressure of 2P-432 to see if there is a pressure response. CPAI will relay the information to AOGCC regarding the results of the injection/pressure response trial. At that point in time a plan forward will be developed depending on the outcome. Please let me know if you have any questions or disagree with the plan. Attached is a 90 day TIO plot of 2P-432 & 2P-419 and a snapshot of the 2P-432 OA pressure trend in relation to the shutting in of 213-419. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 �WELLS From: Well In ty Compliance Specialist CPFl & 2 <n1617@conocophillips.com> Sent: Monday, Octo 9, 2020 4:28 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conoc6plalllips.con1>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Subject: RE: KRU 2P-432 (PTD 202-091) Update aIan forward Chris, Kuparuk injector 2P-432 (PTD# 202-091) has completed its OA pressu -monitor period. The OA was initially bled weekly and did indicate some success in overall OA pressure reduction. The 90 day trends indicates that the pressure build up between the weekly bleeds was steadily decreasing. The OA bleeds were concbded and OA pressure build up rate has been monitored for the last ^30 days. It is CPAI intention to allow the OA to continu44Q build pressure until stabilization, not to exceed 1800 psi, has been reached to identify the stabilization point. The as 9 5/8" 401b L-80 surface casing which has a burst rating of 5750 psi. Once the stabilization point has been identified a iew with the Containment Team will be conducted to review a path forward and that decision will be communicated wi a AOGCC for approval. Attached is a copy of the current 90 day TIO plot and the well bore schematic. Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Monday, October 19, 2020 4:28 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: RE: KRU 2P-432_(PTD 202-091) Update and plan forward Attachments: 2P-432 90 Day TIO plot.pdf; 2P-432.pdf Chris, Kuparuk injector 2P-432 (PTD# 202-091) has completed its OA pressure monitor period. The OA was initially bled weekly and did indicate some success in overall OA pressure reduction. The 90 day TIO trends indicates that the pressure build up between the weekly bleeds was steadily decreasing. The OA bleeds were concluded and OA pressure build up rate has been monitored for the last ^30 days. It is CPAI intention to allow the OA to continue to build pressure until stabilization, not to exceed 1800 psi, has been reached to identify the stabilization point. The OA has 9 5/8" 401b L-80 surface casing which has a burst rating of 5750 psi. Once the stabilization point has been identified a review with the Containment Team will be conducted to review a path forward and that decision will be communicated with the AOGCC for approval. Attached is a copy of the current 90 day TO plot and the well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM torwca�hlNips From: VV4Q Integrity Compliance Specialist CPF1 & 2 Sent: Tuesday, July 21, 202010:59 AM To: Wallace, Cfir4 D (CED) <chris.wallace@alaska.gov> Cc: CPA Wells Supt 0300conoconhillios.com> Subject: KRU 2P-432 (P 02-091) Update and plan forward Chris, KRU 2P-432 (PTD 202-091) (AID 21C) After bo'urconversation this morning and discussing the details with the Drill site Production Engineer, COPA intends to extend thonitor period for 90 days. DHD will be mobilized to the well to perform an extended bleed on the OA approximatelyce per week unless the OA pressure has stabilized at an acceptable pressure. This is in attempt to determine if th essure source is trapped and if the area below the surface casing shoe can be de -pressured allowing the OA pressure to b aintained at an acceptable level. 90 days should provide sufficient time to establish if progress is being made. A fol up email at completion of the monitor period will outline the path forward at that time. A 90 day TIO trend is at Please let us know if you disagree or have any questions with this plan. MEMORANDUM TO: Jim Regg P.I. Supervisor t/47�7 ' \��1�� FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 6, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2P-432 KUPARUK RJV U MELT 2P-432 Src: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RIV U MELT 2P-432 API Well Number 50-103-20420-00-00 Inspector Name: Guy Cook Insp Num: mitGDC200803111158 Permit Number: 202-091-0 Inspection Date: 8/1/2020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min YP J Well 2P432 Type In' w ITVDp s1�5 Tubing lobo lobo lobo lobo PTD 2020910 T e Test I jtj 440 3220 3135 �I 3115 ' ' 2900 sPT Test st�� BBL Pumped: I 2 BBL Returned: 2 OA 560 565 566 566 - Interval REQVAR iP/F P Notes: MIT -IA every 2 years to max anticipated surface injection pressure per AIO 2 1 C rule 4. Testing was completed with a Little Red Services pump truck and calibrated gauges. Thursday, August 6, 2020 Page 1 of 1 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, July 21, 2020 10:59 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 2P-432 (PTD 202-091) Update and plan forward Attachments: 2P-432 90 day TIO trend 7.21.20.pdf Chris, KRU 2P-432 (PTD 202-091) (AIO 21C) After our conversation this morning and discussing the details with the Drill site Production Engineer, COPA intends to extend the monitor period for 90 days. DHD will be mobilized to the well to perform an extended bleed on the OA approximately once per week unless the OA pressure has stabilized at an acceptable pressure. This is in attempt to determine if the pressure source is trapped and if the area below the surface casing shoe can be de -pressured allowing the OA pressure to be maintained at an acceptable level. 90 days should provide sufficient time to establish if progress is being made. A follow up email at completion of the monitor period will outline the path forward at that time. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM Co.rQac11 —1 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, June 23, 2020 1:48 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 2P-432 (PTD 202-091) Report of charging OA pressure Attachments: 2P-432 90 day TIO trend 6.23.20.pdf, 2P-432.pdf Chris, KRU 2P-432 (PTD 202-091) (AID 21C) was reported by Operations to be requiring OA pressure bleeds to maintain the OA pressure below DNE. The plan is for DHD to perform initial diagnostics and perform a substantial bleed of the OA pressure to allow for gas sampling and set the well up to monitor the OA pressure for Build Up Rate. A 30 day monitor period will begin once the OA pressure bleed has been completed. At the conclusion of the monitor period the proper paperwork for continued injection or corrective action will be submitted. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS f�eJ 1. Operations Abandon LJ Plug Perforations Fracture Stimulate Li Pull Tubing Operations shutdownLi Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Convert GINJ to WAG _❑✓ 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development p ❑ Exploratory ❑ Stratigraphic ❑ Service ❑� 202-091 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 6. API Number: 50-103-20420-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: Surface: ADL 373112 KRU 2P-432 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Ku aruk River Field/Meltwater Oil Pool 11. Present Well Condition Summary: Total Depth measured 6043 feet Plugs measured NA feet true vertical 5710 feet Junk measured NA feet Effective Depth measured 5860 feet Packer measured 5450 feet true vertical 5539 feet true vertical 5155 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' Surface 2421' 12' 2450' 2373' Intermediate Production 5577' 10" 5602' 5298' Liner 599' 3.5" 6038' 5706' Perforation depth Measured depth 5,778 - 5,860' feet True Vertical depth 5,462 - 5,539' feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 5485' 5188' Packers and SSSV (type, measured and true vertical depth) Packer: ZXP Liner Top Packer Packer: MD= 5,450' TVD= 5,155' SSSV: A-1 INJ VLV - 2.875" CS -LOCK ON A-1 INJ VLV (.882" BEAN) SSSV: MD= 508' TVD= 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure I Tubing Pressure Prior to well operation: 2200 10 1450 psi 1 2220 psi Subsequent to operation: 0 1 3800 1650 psi 1 800 psi 14. Attachments (required per 20 MC 25.070, 25.071, x 25.283) 15. Well Class after work: Daily Report of Well Operations 2 Exploratory ❑ Development❑ Service ❑� Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑� GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-452 Authorized Name: Sayeed Abbas Contact Name: Sayeed Abbas Authorized Title: Staff Petroleum Engineer Contact Email: Sa eed.abbaS cofloc0 hllll s.com Authorized Signature: —!5 t4'0(' � Date: D '1 D'4 2V11 Contact Phone: M 9 Form 10-404 Revised 4/2017 ':3BDMSSEP 1 12019 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 September 4th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. has completed changing the service of the Kuparuk River Unit (Meltwater) Well 2P-432 from Gas Injection to Water Alternating Gas Injection. Enclosed you will find a 10-404 report of Sundry Well Operations for ConocoPhillips Alaska, Inc. If you have any questions regarding this matter, please contact me at 907-265-1109. Sincerely, S41et-1— Sayeed Abbas Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Report of Sundry Well Operations Daily report of Well Operations Well Schematic 2P-432 DAILY REPORT WELL OPERATIONS 8/23/2019: 2P-432 started water injection as part of the process to change the well from Gas Injection (GINJ) designation to Water -Alternating -Gas (WAG) designation 10 A'--, KUP INJ 2P-432 CornocoPhilfi NaSka. Inc. ., Wall Attrlbutss Max Angle 8 MD TG Rne xeme wnleoNapBlrvn wnleom sed. nc117 mDlnKel an 91m (rtKel MELTWATER 501WXN2000 INJ 352 5,011.58 6,503.0 SSSV: NIPPLE xas (ppnl ad Anmmdn Eq Deu Le51 WO: KBGm DB RS ReNam Dm 39.41 11123/2003 maTx. aKmle r;unPM Last Tag Va�ep'e"a'k (^a'°5 Am,BdBnn EMpRe MIBKe) Lw Maaq Leat Te9: SIM e/4rz01fi 5,012.0 pproven - Last Rev Reason IWKiE1419.8 cow- TT.2 1m.o ME mpn Su FACE: M.1a,"9.5- GAS un; 5,5%6 KEEVE; 5.5".I NIPPLE; SI 7- LocATCR sK,S.B BELL S.Kns PRC W CiK1N: B! 45,SYL] OPERF: S.T5p3145.0�� APERF; 5,806.655I IPERF', S'.a5.EI 1 I LINER, S,.X.]d NflO A Reel EM D9d YY eadq RReaso ev n: RepiacM A-1 Injettlon Valre Bl4/2pt8 BSmbeej Casing Songs Gems Deemlptlon Go (in) IDPm IT"( R6e) Is.. GlKn lrtlSa) s.L omm mm... wuLen 0... w.ae top Tnrv.e CONDUCTOR 16 15.06 280 108.0 108.0 62.W H40 WELDED GSIIq Ceecrlglon pB ID lmlTopBa(BI BeL DeMIKK01 aH OepIn I..., I .11-V. hp TMM 948 8.83 28.1 2.649.5 2375 4000 490BTC nlpaon OOlinl 0BM Top MKBI aM pqn lrtKBl aM DepM (rvDl- WlM1en p... Bade Tnlro0ION ] 6.28 25A 5,W2.3 529].5 26.00 L-80 BTC -MD npNon BO (In1 IB (N1 To...ON. Top31/2 298 430) 6038.0 SJO56 950 480 511 Hyd1I tailsB T op (1 No)W opfTVpllRKe) T mn' nam or Com pn1638.> 5,166.0 X1.36 TIEBACK LINER TIEBACK WMO �BDTTOM 5.250 w 450.0 5,154.) X1.29 PACKER Z%PLINER TOP PA KER 4.xII 45].6 5,161.) W.$NPPLE RSNIPPLE•-1 9.2509W.3 5,166.3 2021 HrWGER FLEX -LOCK HtteiAULI LINER MANOER 491W.7 51MA WA7 SBE SEAL BORE EXTENSION 0 4,00088.9 5,191.1 20.24 XORUSHING CROSSOVER BUSHING 3.000 Tubing Swings Tudnp Deso,I" SM„p Me... IDlln) Top IRK81 s-D'.(R..Sn DepB, ITVB1 t.. Pnpb1L1 GFaM Top Connecxon TUBING 31/2 2.99 14.9 S485.0 5.1825 930 L-80 EUE-8,d Completion Details TapINBI Top Nd Nomlml TW (I InKB1 (� IS Ge C. ID11nl 14.9 14.9 O.W HANGER FMC GENV grip W8.1 508.1 0.17 NIPPLE CNACO D6 NIPPLE 2875 5,386.1 5092.9 .m SLEEVE RAI( USLIDINGSLEEVE 2810 9 W7 BiMS W.W NIPPLE CAMCO D NIPPLE 2 7 5,645.2 5,150.1 .32 LOCATOR LOCATOR UB 3000 64 5 5,17 .7 20.15 SEAL BH -22 SEAL ASSEMBLY 3500 Other in HON (Vllirellne retrievable plugs, valvas, pumps, fish, etc.) TopmKB1 T PITVD) Top Inn (nKBI fl Dee C- Run Dem ID Pn) 5000 508.0 0.17 A-1 lnjetllCn 2.08-CS-LOCK(290•NO-GO)ONA-IINJVLV(SN'. 8/4 018 Valve HSN-2391,882 0.682 Pertomt1ons 8 Slots TWIRKBI TaP1 BM(I (RKBI aan(rv0) IMIBI L1nLed Zpx Wd 8Mt n pmy1L 1 Type C. 5.78.0 S,A6D SA62.0 6480.8 T3.2P4M WV2W9 8.0 APERF 2-7/8• HSD PJDP, W deg pxase 5,816.0 5,826.0 5,486.2 5,50TO T-3, 2PJ 2 3/9rz6W 6.0 APE 2-]/8• HBO PJDP, W tlep pMx 5.838.0 5,060.0 5,518.2 5,538.8 T3, 2P 4M 1/31X06 6.0 IPFRF 2-7/8• HSD PJDP, W deg pxase Frac Summary &IaR DYe gepldm GNpna1B1 Pe mm!Kvnl l0) SIBS venom Tapp (ft n 1191 u,mnPloa gedm vol clxn(aN1 vq &u„yryep Mandrel Inserts m N Top IRKS TRK% 1 pLKB) MBFe Mo4e1 0D(M1 Seri Nlw Tyq Ydn Trye Pon91m (d) 1RO qun (q1) Run oad Can 1 5.334.6 5,046.6 CAMCO KBG2- 9 1 LIFT DMY BTM 0.650 0.0 1212Y Nous: General 8 SaNty PM DNe ITREE 11Y227W3 NOTE: TREE: FMC / GEN V I WKM 31/8^/5K, TREE CAP CONNECTION: OTIS 3� 6114!2006 NOTE: WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR 116312010 NOTE: VIEW EI WINII SONE II THE STATE °fALASKA GOVERNOR BILL WALKER Adam Childs Staff Petroleum Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Meltwater Oil Pool, KRU 2P-432 Permit to Drill Number: 202-091 Sundry Number: 318-452 Dear Mr. Childs: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair 4-� DATED this (et day of October, 2018. RMSLL OCT 2 2 2018 Loepp, Victoria T (DOA) From: Childs, Adam G <Adam.G.Childs@conocophillips.com> Sent: Thursday, October 11, 2018 9:59 AM To: Loepp, Victoria T (DOA) Subject: 2P Injector Sundry Requests Victoria, I received your voicemail regarding the 2P sundry requests. The majority of those MITIAs performed last month were state witnessed, but not all of them. Three of the injectors were shut-in at the time of testing, and were therefore non - state witnessed tests. A separate 10-426 form was sent to the state with the results of these tests. Please see table below including which of the wells tested in August were state witnessed, and when the last witnessed tests were for those that were shut-in. Well Name 212-419 August 2018 State Witnessed Test? Yes Status Of Test Passed Last State Witnessed Test Status of Last Test 2P-420 Yes Passed 2113-427 No Passed 8/20/16 Passed 2P-429 Yes Passed 2P-432 Yes Passed 2P-434 No Passed 1 11/09/14 1 Passed 2P-438 No Passed 9/30/16 Passed 2P-447 Yes Passed Let me know if you have any other questions. Thanks, Adam Childs 907-263-4690 01C 08 20118 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION A0GCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Convert GINJ to WAG_❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ©s - Stratigraphic ❑ Service 202-091 3. Address: 6. API Number: r0% P. O. Box 100360, Anchorage, Alaska 99510 4 50-103-20420-00 ^U a 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2P-432 Will planned perforations require a spacing exception? Yes E] No Q 9. Paoperty Designategn (Lease Number): . l T 1$ w 10. Field/Pool(s): btlR2CB ADL 3731121.8 4;;:* Kuparuk River Field /Meltwater Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,043' 5,710' 5,860' 5,539' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' Surface 2,421' 12" 2,450' 2,373' Intermediate Production 5,577' 10" 5,602' 5,298' Liner 599' 3.5" 6,038' 5,706' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,778 - 5,86( 5,462 - 5,539' 3.500" L-80 5,474' Packers and SSSV Type: Packer: ZXP Liner Top Packer Packers and SSSV MD (ft) and TVD (ft): Packer: MD= 5,450' TVA 5,155' SSSV: A-1 INJ VLV - 2.875" CS -LOCK ON A-1 [NJ VLV (.882" BEAN) SSSV: MD= 508' TVD= 508' 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development fo}-- Service Evr� 14. Estimated Date for 15. Well Status after proposed work: - r - I Commencing Operations: 10/15/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑� GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Adam Childs Contact Name: Adam Childs Authorized Title: Staff Petroleum Engineer Contact Email: adam.g.childs@conocphillips.com Contact Phone: 907-263-0690 Authorized Signature: Date: to/81(s COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ^ �' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑i/J� Other: Post Initial Injection MIT Req'd? Yes ❑ No [� Spacing Exception Required? Yes ❑ No Subsequent Form Required: 16-4(217L 6-4(2<f- APPROVED APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ( D f I Q C,DN1 Form 1'/.0018 V%L /O/!7 // ic �� j� �J,�� 1'"T I \ `� � OCT 2 2 20t0 Submit Form and Form 10-403 Revised 4/2017 Approved app8cati0 i vR }"G j O ,� Attachments in Duplicate p �l �W/8 �.�rB.ID/SlfO ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 October 8th, 2018 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to change the service of the Kuparuk River Unit (Meltwater) Well 213-432 from Gas Injection to Water Alternating Gas Injection. Enclosed you will find a 10-403 Application seeking Sundry Approval for ConocoPhillips Alaska, Inc. If you have any questions regarding this matter, please contact me at 907-263-4690. Sincerely, Adam Childs Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary Well Schematic 2P-432 DESCRIPTION SUMMARY OF PROPOSAL Commensurate with the recently revised and approved AIO 21 C. ConocoPhillips Alaska Inc. is in the process of facility and wellbore modifications to enable water injection in Meltwater. As part of these changes, ConocoPhillips Alaska Inc. is seeking approval to change the service type of Meltwater injector 2P-432 from its current Gas Injection (GINJ) designation to Water -Alternating -Gas (WAG). The 2P-432 successfully passed an MIT -IA test to 3310 psia on 8/15/18 ✓ KUP INJ 2P-432 Alaska.Inc.MELTWATER CommiPhillip$%01=7ZIPFUE Well Attributes Mas Angle & MD TD Fltle wme weleon Avuuva weluwrt stave ul•) MDInKSI Ap BM IXKBI 501032062000 INJ 3.52 5,011.58 6,043.0 11QLas(WO: 31.41 11232003 zr.eu. wrzma 7:a:n PM Last Tag wau w"^aK(°R"tll AnN4tlm Fn46ate DelE, 111KB) YNNW ar last Tag: SLAC 042ITS5,812.0 PPOven --" RANGERi'I conlxcraa. zeD1ro.D wPPlE SM.I w, IxNm vwm: sura SURFACE xa-I,ae.d- DnauFi: Saxe SIEEYE:A.., xlvvLE: BWOT LIX'ATgt: s,usx sFu, a.ns _ - PRC0.CiK)H:x4afM.P� .WERE: ATFa.Da.Taae� APEW:a.Poa.Da,aK1.0� IPERF: 4.Bx05.lE0.0� 1 uxOZ s.4x7a,Pxe Last Rev Reason Btl DYa YA Ma4 B) Rev ReasoI Rapp A -I Inleam Valve &42018 zemS-i Casing Strings caYnP Deac,mtlon W(In) Jo(In)T"MMI) stleryXnlRl(el Sww onnn mol-. .'.n II- V.. Top Thread CONDUCTOR 16 15.06 280 108.0 1080 62.W H40 WELDED Cnlnp anKrMe. oDIN) IDQn) Top61KBl SYoepN IRNBI SN oepIR Mo.- WYLen R... Gnne Tap TMM SURFACE 959 883 28.1 2,619.5 2.3]2S 40.00 L -W BTC GeMp opCaplpn Won) -(-) TBP IRKaj etl Deptl, IRRBI sn"n D, I1VD1... VMen a... en0e TOPThM4 PRODUCTION J 6.28 250 S,W23 5.29].5 26.00 L-80 BTC -MD Caslnp DlMlptlM oDINI Bl Dnl Tpp..) S6l Dv,wV( B) SN DepM RVD1..w n ... G. TOP Thrum LINER 312 2.99 15.4U.7 EMN10 5.7056 9.30 L80 511 MVddl LJner Details Nm(Inj TIP 15,4 Top(NDI IRKa) TBOwcll9 BAC De. Com 115) 5 e38.> 5,1410 20.30 TIE BACK LINER TIE43ACKWMO GO Bll BOTTOM 5.250 5,450.0 5, SIJ X1.29 PACKER D(P LINER TOP PACKER .7 5,4576 5,161.) 20.25 NIPPLE RS NIPPLE 4.2W 5.460.3 5.101.3 20.23 HANGER FLEXiOCK HYDRAULIC LINEA HANGER 4.410 5,469.7 5,1]3.1 X1.1) WE SEPT BORE EXTENSION 8010 4.000 5088.9 5.191.1 X119 KO BUSHING CROSSOVER BUSHING 3.Ia)0 Tubing Strings TUNnp Deoc,lpUan BWIV Ma... lD 115) Top I11Ka1 as Depth (IL. YI DeVVI1Tm11 mOMO Gnde TBP Donned. TUBING 312 299 149 5.485.0 5,1875 930 Ld0 EUE-Od Completion Details TBP (TV.) F.I nc1 Nomina .PMBM MKS) 1•I nem Des Com ID llnl 14.9 W.9 0.00 MANGER FMC GENV 3500 508.1 508.1 0.17 NIPPLE CAMCO DS NIPPLE 2.875 7384.1 5,092.9 X1.70 SLEEVE BAKER CMU SLIDING SLEEVE 2.810 5,40075,108.5 20.60 NIPPLE CAMCO D NIPPLE 2.750 S,R51 SJSDA 20.32 LOCATOR LOCATOR SUB 3.000 5,473.5 5.96.7 X1.15 SEAL GBH -22 SEAL ASSEMBLY 3.000 Other In Hole (Wireline rebievable plugs, valves, pumps, fish, etc.) TBPIMMST Top MDI 1( 8) Top Me PI Dee cam a„Bum 5o(I 508.0 508.0 0.17 A-1151 on 2.8"11LOC1(290'NO-GO) ON A4 INJ VLV IBR: ValOn HSK-2391 88213EAN/48.OATI 84/2018 0.882 Perforations & Slots T MKB1 eMRKS TACD MKS) 9I MKIII l6wed2mm One slur oxw (MOFM J type cam 5,]]8.0 5,5,4620 5,480.8 T3, 2P432 3142004 64 APERF 2r79•H$D PJ .Wde9 pRau 5 .0 5,826.0 5.4881 5,W7.0 TJ, 2P432 31NX0a 6.0 APEBE 2-79'HSD PJOP,Wdes pm.5.838.0 5.8W.0 5,518.2 5,538.8TJ.2P432 138004 80 IPFAF 2-79' HSDPJDP,Wde9 phase Fmc Summary Blurt Une vrvwent IRKNIK IIS) pmppAA In Folm.ponbe) Spa rUR ACh TBp ppMIRKSI BW,MKBI UnkWIFWSWne ValpgnlaNl Vq SNtry lath) Mandrel Inserts St x Tap Mo* TBp (NO) MKBL Make Modtl Oollnl Sary vAM LnNh TJM Type Po,lalm (in) TRDRm IpFll Pun Dae Com 1 5.334.6 5045.6 CA nCu KBG-2- 9 1 GAS LIFT DMY BTM J.O 0.0 122W2003 Notes: General 7L Safety Ene D.be n 1122/2003 NOTE TREE: FMC / GEN VIWI(M31/8•/SK TREE CAP CONNECTION: OTIS 3� REE -CA 6/14200/ NOTE:WAIVEREOCA PRESSURE CHARGING FROM RESERVOIR 1123(21111 NOTE: VIEW SCHEMATIC W/A1aska5dFwOt9.0 STATE OF ALASKA ALPOIPA OIL AND GAS CONSERVATION COMISION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations E Fracture Stimulate r Pull Tubing E Operations shutdown 1" Performed: Suspend Perforate P 1— Other Stimulate n Alter Casing 1-- Change Approved Program E Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to GINJ 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 202 0910 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20420-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL373112 KRU 2P-432 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Meltwater Oil Pool 11.Present Well Condition Summary: Total Depth measured 6043 feet Plugs(measured) None true vertical 5710 feet Junk(measured) None Effective Depth measured 5938 feet Packer(measured) 5474 true vertical 5612 feet (true vertical) 5177 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 108' 108' SURFACE 2421' 9 5/8 2450' 2373' PRODUCTION 5577' 7 5602' 5297' RECLINER 599' 3 1/2 6038' 5706' E I E D OCT 10 2016 Perforation depth: Measured depth: 5778-5860 NWED FEB 2 ori, JGCC True Vertical Depth: 5462-5539 �� YJ V Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 5188 MD, 5177 TVD Packers&SSSV(type,MD,and TVD) NIPPLE=CAMCO DS NIPPLE @ 508 MD and 508 TVD SEAL=GBH-22 SEAL ASSEMBLY @ 5474 MD and 5177 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 296 4112 353 370 1555 Subsequent to operation 0 3016 0 1088 2367 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development E Service F Stratigraphic 1- 16.Well Status after work:Copies of Logs and Surveys Run r Oil r Gas r WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG E GINJ F SUSP E SPLUG I- 17. 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: 316-405 Contact Darrell Humphrey Email: n1139 conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature �\ ��` , Phone:659-7535 Date `6` y. i / Form 10-404 Revised 5/2015" v-T-L to I —i G .. m°j 4i Submit Original Only RBDMS LL- OCT 1 0 2016 • 2P-432 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/30/16 State witnessed (Bob Noble) MITIA to 3320psi, passed 09/17/16 Convert to Gas Injection, well brought online s KUP PROD III2P-432 N`" o4 ConocoPhillips Well Attributes Max Angle&MD TD '',,... .4.„,,,,,- Alaska,INC. Wellbore API/UWI Field Name Weilbore Status Incl(") MD(ftKB) Act Btm(ftKB) con«oPIv6IIx4111' 501032042000 MELTWATER PROD 23.52 5,011.58 6043.0 -- Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2P-432.8/5201612:03;12 PM SSSV:NIPPLE Last WO: 3441 11/23/2003 Verscel schematic(actual) Annotation Depth(9KB) End Date Annotation Last Mod By End Date Last Tag:SLM 5,812.0 8/4/2016 Rev Reason:TAG,SET C-LOCK ON At INJ VLV pproven 8/5/2016 HANGER;14.9.-- Casing Strings Casing Description OD(In) ID(In) Top(060) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 108.0 108.0 62.50 H-40 WELDED J Casing Description OD(In) ID(Int Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread L� SURFACE 95/8 8.835 28.1 2449.5 2,372.5 40.00 L-80 BTC Casing Description OD(In) 10(in) Top(1160) Set Depth MKS) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 25.4 5.602.3 5,297.5 26.00 L-80 BTC-MD Casing DescriptionIL OD(In) ID(in) Top(ftKB) Set Depth(605) Set Depth(TVD)...WI/Len(I...Grade Top Thread as.Ad "LINER 31/2 2.992 5.438.7 6,038.0 5,705.6 9-30 L-80 511 Hydril _ Liner Details Nominal ID -- Top(ftKB) Top(TVD)(600) Top Incl(3 Item Des Com (in) CONDUCTOR 280-toga r. 5.438.7 5.144.0 2036 TIE BACK LINER TIE-BACK W/NO GO @BOTTOM 5.250 _ 5,450.0 5.154.7 20.29 PACKER ZXP LINER TOP PACKER 4.370 5.457.6 5,161.7' 20.25 NIPPLE RS NIPPLE 4.250 5.460.3 5,164.3 20.23 HANGER FLEX-LOCK HYDRAULIC LINER HANGER • 4.410 NIPPLE;508.1 6469.7 5,173.1 20.17 SBE SEAL BORE EXTENSION 80 0 4.000 VALVE 508 0 _ 5.488.9 5.191.1 20.24 XO BUSHING CROSSOVER BUSHING 3.000 Tubing Strings Tubing Description String Ma...ID(In) Top(1860) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING I 3 1/21 2.9921 14.91 5,485.01 5.187.5, 9.301 L-80 I EUE-8rd Completion Details f Nominal ID Top(kKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (In) I 14.9 14.9 0.00 HANGER FMC GEN V 3.500 508.1 508.1 0.17 NIPPLE CAMCO DS NIPPLE 2.875 • 5,384.1 5,092.9 20.70 SLEEVE BAKER CMU SLIDING SLEEVE 2.810 5,400.7 5,108.5 20.60 NIPPLE CAMCO D NIPPLE 2.750 • SURFACE;28.1.2,449.5-J I 5,445.2 5,150.1 20.32 LOCATOR LOCATOR SUB 3.000 5,473.5 5,176.7 20.15 SEAL GBH-22 SEAL ASSEMBLY 3.000 GAO LIFT.6.3340 !_S Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top not Top(ftKB) (kK8) 1") Des Com Run Date ID(in) '- 508.0 508.0 0.17 VALVE 2.875"C-LOCK(2.90"NO-GO)ON A-1 INJ VLV(SN: 8/4/2016 0.882 HLS-58/.882"BEAN/48"DAL) SLEEVE 5.384.1 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotsfi NIPPLE:5400.7 -- Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date I) Type Com 5,778.0 5,798.0 5,462.0 5,480.8 T-3,2P-432 3/4/2004 6.0 APERF 2-7/8"HSD PJDP,60 -. deg phase 5,806.0 5.826.0 5,488.2 5,507.0 T-3.2P-432 3/4/2004 6.0 APERF 2-7/8"HOD PJDP,60 deg phase 5,838.0 5.860.0 5,518.2 5,538.8 T-3.2P-432 1/3/2004 6.0 IPERF 2-7/8"HOD PJDP,60 LOCATOR.6.44521 deg phase Mandrel Inserts s1 ati 4 # on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (kKB) Make Model OD(In) Sera Type Type (In) (psi) Run Date Corn 1 5,334.6 5,046.6 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 12/23/2003 g ( s Notes:General&Safety End Dale Annotation SEAL 5,473.5 11/22/2003 NOTE:TREE: FMC/GEN V/WKM 3 1/8""/5K,TREE CAP CONNECTION:OTIS 3"" ILI 6/14/2004 NOTE:WAIVERED OA PRESSURE CHARGING FROM RESERVOIR ...X.-111 11/23/2010 NOTE:VIEW SCHEMATIC W/Alaska Schematic9.0 PRODUCTION;25.4-5,602.3-A APERF;5,776.0-5,796.0 APERF;5.806.0-5,826.0 IPERF,5.8380-58800 { LINER;5,436.7-6.038.0 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,October 03,2016 TO: Jim Regg P.I.Supervisor f ( (1 3(R. SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2P-432 FROM: Bob Noble KUPARUK RIV U MELT 2P-432 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U MELT 2P-432 API Well Number 50-103-20420-00-00 Inspector Name: Bob Noble Permit Number: 202-091-0 Inspection Date: 9/30/2016 Insp Num: mitRCNl61001063904 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2P-432 Type Inj G TVD 5177 Tubing 2460 2460 - 2460 - 2460 --- —� ----_ PTD 2020910 Type Test SPT Test psi 2900 IA 950 3320 3230 ' 3220 Interval INITAL P/F P ' OA 790 - 800 800 800 - Notes: MITIA per AIO 21B Rule 4,to max anticipated surfac pressure. 1.2 bbls pumped. SCANNED JUN p 72rr Monday,October 03,2016 Page 1 of 1 • • V OF Tit �1)**1 yy,�6. THE STATE Alaska Oil and Gas N�►'�'��14 Of LASKA Conservation Commission 'l itf_ 333 West Seventh Avenue .., _:-_ _ Anchorage, Alaska 99501-3572 ,, GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Robert Christensen NSK Production Engineering Specialistfj - ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, KRU 2P-432 Permit to Drill Number: 202-091 Sundry Number: 316-405 Dear Mr. Christensen: 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, Cathy . Foerster Chair DATED this � day of September, 2016. RBDMS U%,_,- - 1 2016 STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION ' 0 3 2016 APPLICATION FOR SUNDRY APPROVALS gay7f /( 20 AAC 25.280 AO C 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing E Other: PROD to GINJ Fol. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 17 . 202-0910• 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage, Alaska 99510 50-103-20420-00 - 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No KRU 2P-432 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL373112 Kuparuk River Field/Meltwater Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6043 ' 5710 ' 5938' ' 5612'' 1988 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 108' 108' SURFACE 2421' 9 5/8 2450' 2373' PRODUCTION 5577' 7 5602' 5297' LINER 599' 3 1/2 6038' 5706' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5778-5860 . 5462-5539 3 1/2 L-80 5188 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=CAMCO DS NIPPLE • MD=508 TVD=508 PACKER=ZXP LINER TOP PACKER . MD=5450 TVD=5155 12.Attachments: Proposal Summary ' WellBore Schematic p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service J' ' 14.Estimated Date for 15. Well Status after proposed work: 08/16/16 OIL WIND Suspended Commencing Operations: WDSPI p 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ - Op Shutdown " Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n1139na.conocophillips.com Title: NSK Production Engineering Specialist Signature /3/ ` �1 Date: .1/ l • • Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\CD — L{ OC Rug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: ij)re err, Tv ►Jzrl OC C C d f"dQjyj C-e .•(14 )11o2. Q 4'5C- t Post Initial Injection MIT Req'd? Yes V No r Spacing Exception Required? Yes r No r,' Subsequent Form Required: )('— 4 a 1- RBDMS 1---SEP - 1 tot) by ��/ n'jo# APPROVEDMM BSY Approved b : /�-/ COMMISSIONER THE COMMISSION Date:9 f!� it VTL f3/31/1/,, ///^i 3��^^l/ '6ijaI4ilL1or kI / c/� �NstandForm 10-403 Revised 11/2015 IA i 12 months from the date of approval. Attachments in Duplicate • • RECEIVEDRobert Christensen/Darrell Humphrey Production Engineering Specialists. AUG 0 3 2016 Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhillips AOGcc AnchoPhoner(907 659 -79535-6105 Fax:659-7314 August 1, 2016 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert KRU/Meltwater Well 2P-432 from Production service to Dedicated Gas Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2P-432 (PTD#202-091). If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659-7535. Sincerely, kgita0 :4111! Robert D. Christensen Attachments Sundry application Proposal Summary Well schematic Area Map AOR Detail • • 2P-432 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Meltwater Well 2P-432 (PTD# 202-091) from Oil Production service to Gas Injection service. Area of Review: Meltwater Well 2P-432 is waiting to be converted to dedicated gas injection to provide injection into the reservoir to increase the ultimate recovery of oil. 2P-432 is anticipated to support 2P-417 and 2F\-451. ckG The top of the Meltwater reservoir was found at 5728' and/5415'tvd. ✓ eaZ e Area Map with 1/4 mile radius around target injection zone(s tta ed): The map attached shows there are no wells with penetratio of the Meltwater interval located within a 1/4 mile radius of 2P-432. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2P-432 is good and is classified as a 'Dual Casing -Single'well. The injection tubing/casing annulus is isolated via a liner top packer at 5450 MD/5144 TVD. A passing MIT-IA to 3300 psi was performed on 7/14/16. `y. CBL and interpretation of the cement quality: See attached AOR Detail Conditions for approval (if applicable): An Al injection SSSV will be placed in the nipple located at 508' and prior to first gas injection. 7 f a.e/7 w45 met,''44/; S IV"G i iVecro! �ohcv�. l r- Gvy f CoepecitPc/ ' efe f,o,�. �re;5vre of q CTO of Waitron -'v1 i4zk o q ��oo t/ce/ r o rQ vet r (col o4 '' J IT 'Ofttme , rtth. � vac( M (cove ' rd rocdvc / r4e INahr f'P 40, � lie v t( CvT C�u.4 of off " •VA,e f e o, n cr(tike&' Sv�570'77,,cdy. ( 11;5 wq5 ,'", ,'id,'c t'OO► O dti'ec.F Coin cob* be won we G pi ono 7'4e/ r Je(tOc, I'lve ry rtie ' ie of µe re fOr ,/I J(Gt' On gofef cola /die /1„,,T n h^ctiro- of /f Gt,Q$ 47Ie 6. Eta/ 14' VGA nor 8nocyb r, ect'44 f(v,'c4 r cif! of %fie ,`n e409 k, AP-1113 fenfo,'"eo/ rc5fv� %� i4�� °rrb►n � (fir ��l• �oe rD ro�uc er a►�d tor r-e��c r rhe � � f ��f r1 roof 7ti.r 0W4 0^ of Th( kc �obc na'rvrt Of rhe r an IDS I61ect0r S o✓f d , ,�/rv's' ( LI I ll 70 l fif or)p 4?l pvcf Oce o� (e co ver frost �1 foo'00 of Ike fool • 2P-438 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Meltwater Well 2P-438 (PTD# 201-082) from Oil Production service to Gas Injection service. Area of Review: Meltwater Well 2P-438 is waiting to be converted to dedicated gas injection to provide injection into the reservoir to increase the ultimate recovery of oil. 2P-438 is anticipated to support 2P-431 and 2P-449. The top of the Meltwater reservoir was found at 8201' and/5296'tvd Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that wells 2P-419 and 2P-447 are the only wells with penetrations of the Meltwater interval located within a 1/4 mile radius of 2P-438. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2P-438 is good and is classified as a'Single Casing'well. The injection tubing/casing annulus is isolated via Baker 194-47 Seal asst'at 81-59 MD/5274 TVD. A MIT-IA will be performed prior to well 2P-438 being converted to dedicated gas injection. CBL and interpretation of the cement quality: See attached AOR Detail Conditions for approval (if applicable): An Al injection SSSV will be placed in the nipple located at 507' and prior to first gas injection. • 0 0 s o 0 a ` a o\ m m m L F f d • 0 0 E u u 6 C C O C C O_ E •i N v 6 O u O O O d E m ✓ , N 0 co u, >o a� � s e 5 — a r. 71; ad+ ,.0 m o u m a T. o Ii: , %O Q V N N W F:, m Y 0 Cm 3 o • `• o_ o 2 • a t a E n ad' i 6 a v n u . u W c m > d S N W V•£ - -=- - O.« 0 V V F D CI' p N Q E W 2 ^o m V O t�v ,n re 0 O v1 .i. Q O 10- C V C hN O 6 O F O,,. L 0 to N N m v "5.. 0 0 c IL' S G 2 co 2 C_ O F O t' i, O y O -'3- h .O U d a 3 3 0 4 a z 0 Y 3 N N N 0 0 0 c F; Q N O N N I- O 6 0 . • • 06Jun16 ConocoPhillips ' Alaska, Inc. 2P-432 and 2P-438 N 100.1 Sundry n 0 0.1 0.2 0.3 0.4 ,/,\V Miles ADL373112 2Prs) -2P-417 2P-451 ik 1 41, ° 72P-447 2P-449 2P-429 2P-438 2P-431 2P-419 2P-427 ADL389058 Kuparuk River —2P-432 Trajectory Unit 42P-432 Open Interval 01/4 Mi. 2P-432 Open Interval Radius —2P-438 Trajectory amil2P-438 Open Interval ❑ 1/4 Mi. 2P-438 Open Interval Radius —Well Within or Near 1/4 Mi. Radius *Well Pad L1 Meltwater PA ❑ CPAI Lease KUP_ • 2P-432 ConocoPhillipS ,- Well Attributes Max Angle&MD _ TD AlaskaInc. ,. Wellbore API/UWI Field Name Well Status Incl 1°) MD(ftKB) Act Btm(ftKB) cnncoPtvlkps 501032042000 MELTWATERj PROD 23.52 5,011.58 6,043.0 '' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE 15 1/14/2010 Last WO: 34.41 11/23/2003 -- - Well Canfia:-S -0m3a2ti,c7/7A/U20i3 6:18:53 AM Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 5,893.0 7/13/2013 Rev Reason:TAG haggea 7/17/2013 Casing Strings Casing Description String0.. String ID...I Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String . Str ng Top Thrd HANGER,15 ' CONDUCTOR 16 15.062 28.0 108.0 108.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 28.1 2,449.5 2,372.5 40.00 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 25.4 5,602.3 5,297.5 26.00 L-80 BTC-MD Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd LINER 31/2 2.992 5,438.7 6,038.0 5,705.6 9.30 L-80 511 Hydril ri , Liner Details '•>® Top Depth (ND) Top Incl Nomi... Top(ftKB) (ftKB) (") Item Description Comment ID(In) 5,438.7 5,144.0 19.89 TIE BACK LINER TIE-BACK WINO GO @ BOTTOM 5.250 CONDUCTOR. 5,450.0 5,154.6 19.97 PACKER ZXP LINER TOP PACKER 4.370 28-106 5,457.6 5,161.7 20.02 NIPPLE RS NIPPLE 4.250 11/ 5,460.3 5,164.3 20.04 HANGER FLEX-LOCK HYDRAULIC LINER HANGER 4.410 NIPPLE,508 5,469.7 5,173.1 20.10 SBE SEAL BORE EXTENSION 80-40 4.000 5,488.9 5,191.1 20.24 XO BUSHING CROSSOVER BUSHING 3.000 Tubing Strings Tubing Description String 0... String ID...Top(9103) Set Depth(f...Set Depth(ND)... String Wt...String.. String Top Thrd TUBING 31/2 2.992 14.9 5,455.0 5,187.5 9.30 L-80 EUE-8rd Completion Details Top Depth i i (ND) Top Incl Nomi... Top(ftKB) (MB) (°) Item Description Comment ID(in) 3.500 2.812 14.9 14.9 -0.51 HANGER FMC GEN V 508.1 508.1 0.17 NIPPLE CAMCO DS NIPPLE 5,384.1 5,092.4 19.50 SLEEVE BAKER CMU SLIDING SLEEVE 2.810 SURFACE, 28-2,449 _ 5,400.7, 5,108.2 19.62 NIPPLE CAMCO D NIPPLE 2.750 5,445.2 5,150.1 19.93 LOCATOR LOCATOR SUB 3.000 GAS LIFT, - 5,473.5 5,176.71 20.13 SEAL GBH-22 SEAL ASSEMBLY 3.000 5,335 Perforations&Slots Shot Top(ND) Btm(ND) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh.•. Type Comment 5,778.0 5,798.0 5,462.0 5,480.8 T-3,2P-432 3/4/2004 6.0 APERF 2-7/8"HSD PJDP,60 deg phase SLEEVE,5,384 i..I II 5,806.0 5,826.0 5,488.2 5,507.0 T-3,2P-432 3/4/2004 6.0 APERF 2-7/8"HSD PJDP,60 deg phase 5,838.0 5,860.0 5,518.2 5,538.8 T-3,2P-432 1/3/2004 6.0 IPERF 2-7/8"HSD PJDP,60 deg phase NIPPLE,5,401 - Notes:General&Safety End Date Annotation 11122/2003 NOTE:TREE: FMC/GEN V/WKM 3 1/8""/5K,TREE CAP CONNECTION: OTIS 3- 6/14/2004 NOTE:WAIVERED OA:PRESSURE CHARGING FROM RESERVOIR _ 11/23/2010 NOTE:VIEW SCHEMATIC W/Alaska Schematic9.0 LOCATOR, j--__-3 5,445 i'll ; SEAL,5,474 - - -L � Mg I PRODUCTION, . I 255,602 PERF, 5nA6-5.796 Mandrel Details Top Depth f Top Port APERF, 5... (ND) Incl OD Valve Latch Size TRO Run 5,8065,826 N...Top(ftKB) (ftKB) (') Make Model (In) eery Type Type (in) (psi) Run Date Com... 1 5,334.6 5,046.7 20.91 CAMCO KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 12/23/2003 (PERF, 5,8385,860 i 1 LINER, 5,4396.038 ID 6,043 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. d Q 4 - 0 q 1 Well History File Identifier Organizing (done) D Two-sided 111111111111111111I D Rescan Needed 1111111111111111111 R]8CAN 'V6 Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NofType: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date LfILf/t20 I J Date Lfhl00 .5 x 30 = LSû_ + Date: Ó D Other:: BY: ~ 151 me 111/11111111111111I tl1£ /50 Project Proofing BY: ~ 151 Scanning Preparation BY: (r; = TOTAL PAGES (Count does not include cover sheet) 151 /111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: l5..J- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: ~ Date:4-! if/ O~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 151 mP NO BY: Maria Date: 151 //1111111/111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111/1111111111 1111I BY: Maria Date: 151 Comments about this file: Quality Checked 111111/11111111111I 10/6/2005 Well History File Cover Page.doc ~., .~ - .t',~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,~ISI ~g~ d:;Gli~ t;rrt111iS~i0f~ REPORT OF SUNDRY WELL OPERATI~QB 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^/ WAG to oil Alter Casin Pull Tubin g ^ g ^ Perforate New Pool ^ Waiver Conversion ^ Time Extension ^ 2/12/os Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: ~ 9 i ,~,},~>=1 5. Permit to Drill Number: ConOCOPhiIIIpS Alaska, InC. Development ~' Exploratory ^ . 202-091 ` 3. Address: Stratigraphic ^ Service ['f ''D ``~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 <> z~. 50-103-20420-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 252' 2P-432 8. Property Designation: 10. Field/Pool(s): ADL 373112 • Kuparuk River Field / Meltwater Oil Pool 11. Present Well Condition Summary: Total Depth measured 6043' feet true vertical 5710' feet Plugs (measured) Effective Depth measured 5938 feet Junk (measured) true vertical 5612 feet Casing Length Size MD TVD Burst Collapse Conductor 108' 16" 108 108' Surface 2449' 9-5/8" 2479 2372' Production 5602' 7" 5602 5297' Liner 588' 3-1/2" 6038 5706' Perforation depth: Measured depth: 5778-5798; 5806-5826; 5838-5860 . *~„';~~'`,~~"~,,,,` J ~~ ~ ~ ~ ~ ~~U true vertical depth: 5462-5481; 5488-5507; 5518-5539 Tubing (size, grade, and measured depth) 3-1/2", L-80, 5484 MD . Packers &SSSV (type & measured depth) Packer = ZXP LINER PACKER WITH HR PROFILE Packer = 5450' SSSV =Nipple SSSV = 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1354 277 Subsequent to operation 0.72 - 7.43 2672 1647 1692 14. Attachments 15. Well Class after proposed work: Copies of logs and Surveys run _ Exploratory ^ Development '^ • Service ^ Daily Report of Wel! Operations _ 16. Well Status after proposed work: Oil^ • Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-026 Contact B. Christensen/ D. Humphrey Printed Name Darrell Hum hr Title Production Engineering Specialist Signature ~~~~ Phone: 659-7535 Date 3./3.09 Form 10-404 Revised 04!2004 j Submit O grt'inaTC~rfl~~©1~ • S~~~u~l~~ 0~ G~~l"~i~5~~i ALASSA OIL AI~TD GA5 CO1~T5ERQA'1'IO11T COrIl-II55IO1~T Robert Christensen Production Engineering Specialist ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 276-7542 ~~ Re: Kuparuk River Field, Meltwater Oil Pool, 2P-432 Sundry Number: 309-026 ~.~ -- ~~ Dear Mr. Christensen: ~ a ~ _:. - )t Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair r°~ DATED this ~ day of February, 2009 Encl. • Conoco~illips Robert Christensen / Darrell Humphrey Production Engineering Specialist Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 ~ 1~C~1 V ~tmi January 26, 2009 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 JAN 2 7 2009 Alaska ®il & Gas Cons. Commissiar Anchorage Dear Mr. Maunder, ConocoPhillips Alaska, Inc requests approval to convert Meltwater We112P-432 (PTD 202-0910) from WAG Injection Service to Oil Production Service. Enclosed you will find 10-403 Application for Sundry Approval. If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659-7535. Sincerely, Robert D. Christensen • Attachments _ ___ ,o°~ 2'~ ~'~ STATE OF ALASKA ` ALASKA OIL AND GAS CONSERVATION COMMISSION ~~- ~-~~ ~I ~' f ~ ; 7 APPLICATION FOR SUNDRY APPROVA:~~°; 20 AAC 25.280 .. zed., 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver*~ ~'~ ^"~1 Other . Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ WAG to Oil • Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Conversion 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 202-091 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20420-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO^ 2P-432 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 373112 RKB 252' Kuparuk River Field / Meltwater Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6043' 5710' • 5938' 5612' Casing Length Size MD TVD Burst Collapse Conductor 108 16" 108' 108' Surface 2449 9-5/8" 2479' 2372' Production 5602 7" 5602' 5297' Liner 588 3-1 /2" 6038' 5706' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5778-5798; 5806-5826; 5838-5860 5462-5481; 5488-5507; 5518-5539 3-1 /2" L-80 5484 Packers and SSSV Type: Packers and SSSV MD (ft) Packer = ZXP LINER PACKER WITH HR P ROFILE Packer = 5450' SSSV =Nipple SSSV = 508' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 8, 2009 Oil ~ • Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: B. Christensen/ D. Humphrey Printed Nam Bert D. ChriStenSen ~ Title: Production Engineering Specialist Signature Phone: 659-7535 Date ~}l_ Z (o •- Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~i p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ W ti` ` ~ ~ ~'~~ O d~ C I~l ~i 9 ~ ll~~ ("~ ~ " ther: ~ , Subsequent Form Required: "'~~~w (~~~~ ~C7~ ~~~~. ~~ e ~ APPROVED BY 2 ~ ?~ Approved by: COM t H COMMISSION Date: ~J i~' Form 10-403 Revised 0006 ~ ~ ~, I i ~ f ", L, ~~' ~ iT ~ Submit in Duplic~ ~/~ • 2P-432 DESCRIPTION SUMMARY f~J OF PROPOSAL ConocoPhillips Alaska, Inc. Meltwater Well 2P-432 (PTD 2020910) Sundry Notice 10-403 Request January 26, 2009 ConocoPhillips Alaska Inc. requests approval to convert Meltwater Well 2P-432 from WAG Injection Service to Oil Production Service. The purpose of this conversion is to reduce the Meltwater Oil Pool Bermuda ~ reservoir pressure in support of a Coil Tubing Drilling development program planned for Q4 2009. 2P-432 is currently operating with an Outer Annulus pressure waiver due to OA charging from formation. .~ Last MITIA was performed on 08/18/06 (passed). Annulus trends and recorded bleeds do not indicate charging is from an internal source. IA x OA communication does not appear to exist at this time. TheTubing/Casing annulus is isolated via ZXP Liner Packer with HR profile (5450' and / 5155' tvd). The top of Bermuda T3 sand was found at 5778' and / 5462' tvd. ------- KUP ~ 2P-432 _ COI'1000 1 135 . _ w ,. 1A~elt'Attributes :- _, .. .i•<• , Alaska ltlc Walllwm API/UWI Fteld Name Well Swws tncl,natwn (') MD (tUCd) Tolal Uepw (RK8) , . 501032042000 MELTWATER INJ 23.52 5,011.58 6,043.0 Comment N28 (ppm) DaCS Annotahon End Date KB-0b (tt) Rig Release Date ... - w.tcenr:- Bresrmoelas¢z7Ara-~ - SSSV:NIPPLE 0 7/1/2008 Last WO: 34.41 11/23/2003 - dxmstie- ACNaI -. Annotation Depth (RKB) End Dale Annotation Entl Date Last Tag: 5,926.0 6/152008 R ev Reason: TAG FILL SLM 7/20/2008 a~§I'"n S in S~u~° "fi '_ rf t4 .~.t t .+!'~':~ >v ^,=?%~' '~ :' ~ - --- - -- , Set Depm . ~, Set Uepm (ivD) -Wt-- Casing Description GD (in) ID (in) Top (RKB) (RKB) (RKB) (IbaRt) Gentle Top Threatl HANGER, 75 CONDUCTOR 16 15.062 0.0 108.0 108.0 62.50 H-00 WELDED SURFACE 95/8 8.697 0.0 2,449.0 2,372.0 40.00 L$0 BTC CONDUCTOR, PRODUCTION 7 8.151 0.0 5,602.0 5,297.1 26.00 L-80 BTC-MD tos LINER 31/2 2.992 5,450.0 6,038.0 5,705.6 9.30 L-80 511 Hyddl ,.,. ~?+ti~}!..aq ~ ~~y rytats4!?%h '.f:7c'~ x e~. !~'?~ t ,y.~,.. ,-, te. .- in $tS U .• ,. r ; ,_ r ~ ., ,: ,-r-. set o~~m NIP sDe Tuhing Descdpaon DD (In) ID In) Top (lu(el {nMB) Sct DCpU (I yU DIKeI ~ It lio ntl red. Top rn ea TUBING 31 2 2.992 0.0 5,484.0 S,i,ls.a ~ JL2o EUEriRDtv~D ~' ~ e~• Hobe A ICJe w ... , - e Yu n -_Ru~&Re~~'eva~ie-~lsh etc.~~°'~ _ ~ :. .. ~,: Top (RKB) Description Comment Nun Uam lU pn) suRFACE, 15 0 HANGER FMC GEN V TUBING HANGER 11222003 3.500 z,ass . 508.0 NIP CAMCO'DS' LANDING NO GO NIPPLE 11222003 2.812 GAS LIFp, 6 ~ 5,335.0 GAS LIFT CAMCO/KBG-2-9/1/OMY/BTMI// Comment: STA 1 12232003 2.900 ' 5,384.0 SLEEVE-C BAKER CMU SLIDING SLEEVE -CLOSED 1122/2003 2.810 5,401.0 NIP CAMCO'D' NO GO NIPPLE 112212003 2.750 SLEEVE-C, 5,439.0 TIEBACK LINER TIEBACK SLEEVE WMO GO AT THE BOTTOM 11/212003 5.250 s.3e4 5,445.0 LOCATOR LOCATOR SUB (NO~a0 SHOULDER) 11222003 3.000 5,450.0 PACKER LINER ZXP LINER PACKER WffH HR PROFIL 11212003 4.370 5,458.0 NIP LINER RS NIPPLE 11212003 4.250 NIP, 5,401 5,460.0 HANGER LINER FLEX-LOCK HYDRAULIC DOUBLE GRIP LINER HANGER 11212003 4.410 5,470.0 SBE LINER SEAL BORE EXTENSION 80-40 1121/2003 4.000 5,474.0 SEAL GBH-22 SEAL ASSEMBLY W/800 SEALS AND 1/2"MULE SHOE 11222003 3.000 5,489.0 BUSHING LINER CROSSOVER BUSHING 11212003 3.000 TIEBACK 5,939.0 COLLAR LINER BOT LANDING COLLAR 11212003 3.000 , 5,439 5,971.0 SHOE LINER BOT FLOAT SHOE - 11212003 - 2.980 LOCATOR. 5,445 ;~ .-.~ PBrfOfil~ - _ - Y F: lOn3 ~~ ' ,r ~ r::;U ~ ~•.~. _ .. _ _ _~ _.. ~ '. snot - lop (TVD) Btm (TVD) Dens ~ PUP 5 448 Top (RKB) Btm (RKB) (RKB) (RKB) Type Zone (shot... Dale Comment , , 5,778.0 5,798.0 5,462.0 5,480.8 APERF 6.0 3/42004 2-7/8" HSD PJDP, 60 deg phase ', 5,806.0 5,826.0 5,488.2 5,507.0 APERF 6.0 3/42004 2-7/8" HSD PJDP, 60 deg phase 5,838.0 5,860.0 5,518.2 5,538.8 IPERF 6.0 1/32004 2-7/8" HSD PJDP, 60 deg phase PACKER, 5,450 - - I~ote'General 8 Safe ~ .g4 ;e- . - - Entl Date ~ Annohtlon 6/142004 NOTE: WAIVERED OA: PRESSURE CHARGING FROM RESERVOIR NIP, 5,458 HANGER, 5,460 SBE, 5,470 REAL, 5,474 BUSHING, 5,489 PRODUCTION, S,B02 APERF, 5,7785,798 APERF, 5,8065.826 IPERF, 5,83&5,880 COLLAR, 5,939 SNOE, 5,977 LINER, 6,038 TD, 8,043 • :~--,. MICROFILMED 03J01 /2008 DO NOT PLACE ;~"- . ~,- :~~` ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFichetCvrPgs_InsertstMicrofilm Marker.doc 1ð 11/10/06 Sc~luIIbepgep (~:. ;;"" k:"~~;"~'~~',:~:r~:,,\"," NO. 4~¥; ...,A~. ' (, {, Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NOV 1 3, 2006 !(~ G~~ Q1f!1ti!. (),)ffimi!j~!1 Aiìf;;OOf~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 u:c~ 808 -OC] I Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R·26 11416225 INJECTION PROFILE 10/23/06 1 1 R-22A 11416224 PROD PROFILE WIDEFT 10/22/06 1 2K.28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE WIDEFT 10/24/06 1 3G..16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J·101 11445123 GLS 11106/06 1 2~-432 11415644 INJECTION PROFILE 10/26106 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1 R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28106 1 1 D-04 11445121 PROD PROFILE WIDEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N..305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2L:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2K.27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . e Con 0 cdJ'hiiii ps Alaska e i o c" ,., r¡¡,o" ij 9 c...ù 10 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ') d AJ1cÎ10i3ge June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ,~.<" ~~\\jci;;;:O ;JJ\i1f>i' ~. ~~-' 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, Royfi1l404B, 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 May 05,2006. Schlumberger Well Services mixed 15.7 ppg Arcticset 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 on May 18th, 19th and 31 S\ 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. Sincerely, (" t.. oS f.........J A ~ CJ6!~O lOb Attachment ____d"" , ¿¡úfd e e ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Well Name PTD# Vol. of cement Final top of Cement top um ed cement off date bbls ft Corrosion inhibitor/ sealant date 5/19/2006 x '0:;" ) ConocJÃ,illips Alaska '): ~,VtØ :t: 1~ iU¡\\ 1 2 'l... 'ì ;~\~~~~::(8m~&. G¡¡¡S Cm~~, An¡;h¡0 r~ í~le P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ 0 ~ - Dc¡ ( June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED JUN 2 1'1 2GOB 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, Royfi1l404B, 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 May 05,2006. Schlumberger Well Services mixed 15.7 ppg Arcticset 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 onMa y 18th, 19th and 31 st, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. ¿ ConocoPhillips Problem Well Supervisor Attachment ) ) ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Initial top Vol. of cement Final top of Cement top of cement ft :4'.' .' 5.5 . 7':5:,"~ .'. ," 1 : ~ ':~~5.· "'0 f.. " 13.5 ;:4.5:: '.:"':'!: ..::. 10 .'2:; .. ,;1·'.' 13 .' .'.8'.5':.: .." .', 14 '... "."5,:',:: ,',:"~:' . 15 . :3~5:..' ',' ¡o·. 2.5 ·,··tS··.·· 3 ,:10' ,". . ;·:'t'2'.~,~·~ ~ "', :l,:""~\:IU 2P-415 ~:)::1i2P;¡17' 2P-419 ~':·.::~iP_'o:~· ".~ 2P-422 ;.::.: 12P.~4:,<:~ . : 2P-427 :/:~~*: 2P-431 . '. ';2~:ø-ï; '. 2P-434 ····,;,ì~&:,·:'·;>· 2P-441 . . ':~3>:-.}. 2P-447 ·2R~:··.:,;:·,:· 2P-449 :.2P~1·. pumped bbls . .:·.:O~.O···. ," " ~ 0.0 'Ô~7" . '" 0.0 "::' . :·..&~,a:~·. .'~'"- . I.:.~ ;~.' . ,"' 2.3 . ·"'a:o:·· 1.6 . ·.tfej', " .' 1.9 :·Oi9:.. 2.0 . ':ott1":: 2.0 ~; '.0.0 :': ". 0.0 " ·,0:0.· .' . 0.0 , 2~1' cement ft .·,4·:· 5.5 ·:·<2i5· 1 :"::3.5:', 2.5 ····:;4~.5·::.·· 2.5 '..::2, :~' ~ 2.5 ·~Z:5~.· . ::~: 2.5 ·.::·.:::5·.··:· 2.5 : ,::3~5:, :.. '. 2.5 1 . <. . . ,~..~5 '.. . 3 '2.5'· . Kuparuk Field June 6,2006 off date ." , .na ,.' na ·..5/112006.:. "..;.'" na 'aa;'~ .,' 5/1/2006 '.. 'ne" ',... ",', . ,I···.':..... . 5/1/2006 ':.~ r·.... .,;i1à:,':.'., 5/1/2006 :: 5It/2006;:"', .'. 5/1/2006 ......: ·:.·::...ia'· .. . 5/1/2006 .... 'ha:: '~.' na "'na '. ' na "·51.112006 . RG2041 voi J gal . ,,' ,..5:,7 7.1 ..:~5;~J' . 6.7 :: '.' .,7':1.-':' 7.1 ". .5~'7;····· 7.1 ..... '3:~8,' 7.1 :"'5~7' .... 5.7 . .' . ,>::5~i·:· 7.1 . ·.··,:8.1. . 9.5 :. ..' 9.5;····, ' 5.7 : '7.1· Royfill4048 vol. qal ¡ . '1:7..1" 30.9 '·"9"::'" . o ·1'73 .. . i . ,., . . '; -.. .. ,." 10.7 '. ···t7·~6:··· 13.7 ';. ·.5~7.·· 10.1 " 1;~.8:' 6.2 ;;. :21;:9. ': . 13.1 '. .':·1}.4· o .. O· '.' 11.5 .·6~5 . Corrosion inhibitor/ sealant date 5/19/2006 . . . :'-' '·StH)12:0Ð~· < 5/19/2006 ..: ·..~h1._6;:: 5/18/2006 ...·$k.1'~·::::' 5/18/2006 " '~. ·.·:.5/11!:8IæOa,!. ".' 5/18/2006 .: ; ,~':5'~1Sl2ØQ);c:::- 5/18/2006 . '. ,·:.:t:.I/iditrJr,i¢¡'.~:.; . . "~ '~~~:~."" 5/18/2006 ::..:'..i"":'::'~_.:':..::.: 5/18/2006 . .'. ': '6I_O(Jß':~' 5/18/2006 .. , 5l"'Þ:~ðrið.· ~: . " .::.'9l~~.,.' 5/31/2006 511812006' '.' t-{. IJ.p ~ d À ò ~ 1,0 DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 .s1;1~ 1/ t¿t Æ6~J API No. 50-103-20420-00-00 Permit to Drill 2020910 Well Name/No. KUPARUK RIV U MELT 2P-432 Operator CONOCOPHILLlPS ALASKA INC MD 6043_ Current Status WAGIN (.......·~I~~~~_c¿--;-- ----/ Directional surve~ ~- ..----.--.--- TVD 5710-- Completion Date 3/4/2004 _.. Completion Status WAGIN -- ------ REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Den/New, USIT Well Log Information: Electr Digital Dataset Med/Frmt Number Cement Evaluation Casing collar locator C Lis 12387 LIS Verification LIS Verification I r C Pdf 12387 Neutron ~D C Pdf 12387 Density I t' Neutron ), hrr og 12387 Density I I I I l...ro C Pdf 12387 I nd uction/Resistivity I I C Pdf 12387 Rate of Penetration Mud Log No Samples No .____'m~~_~__._~__ ----,---,.~,--- Name Sonic (data taken from Logs Portion of Master Well Data Maint Log Log Interval OH/ . Run Scale Media No Start Stop CH Received Comments 5 Blu 1 5313 6037 Open 12/12/2003 Slim Sonic Logging Tool- Borehole Compensated Sonic 5 Col 4720 5525 Case 12/12/2003 Ultrasonic Imaging Tool - USIT/GRlCCL 5 Col 4720 5525 Case 12/12/2003 Ultrasonic Imaging Tool - USIT/GRlCCL 294 5613 1/27/2004 294 5613 1/27/2004 25 r-1/) 108 6043 Open 1/27/2004 Caliper Corrected Neutron, Optimized Rotational Density - RWD 25 108 6043 Open 1/27/2004 Caliper Corrected Neutron, Optimized Rotational . Density - RWD 25 Blu ìl/ð/IV;~ 108 6043 Open 1/27/2004 Caliper Corrected Neutron, Optimized Rotational Density - RWD 25 Blu IV I) )f1Þ 108 6043 Open 1/27/2004 Caliper Corrected Neutron, Optimized Rotational Density - RWD 25 108 6043 Open 1/27/2004 Multiple Propagation Resistivity, Gamma Ray - RWD 25 108 6043 Open 1/27/2004 Multiple Propagation Resistivity, Gamma Ray - RWD 0 6043 1/23/2004 15 Blu 5254 5923 Case 1/30/2004 Perforating Record & SBHP Directional Survey Perforation DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2020910 Well Name/No. KUPARUK RIV U MELT 2P-432 Operator CONOCOPHILLlPS ALASKA INC ~_M..?__.~~.~~~____. ____~~___~~____~m~~~~~~_~:~~4/2004 ED C Pdf 12968 Injection Profile '6g 12968 Injection Profile rD C -Pes t. I S 13408 Sonic Completion Status 5 5 Blu Current Status WAGIN WAGIN 52000 52000 5313 5900 5900 6037 2/1/2005 2/1/2005 "¡'~( ease 1/24/2006 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? y~ Chips Received? ,~ Analysis ~ Received? Daily History Received? ~ [j1N Formation Tops ~~_.__,_.__.,,_.u_____ ~~--------- --_._-,._~- Comments: ComO""'" Rev;.,... By, -==--~ Date: API No. 50-103-20420-00-00 _......~. ._-<--~~ -----. I I i I i SLIM SONIC LOG~ING i TOOL BOREHOLE COMPENSATED SONIC . JH~~. . . ConocdJhillips . RECEIVED TRANSM ITTAL Production Data JAN 2 4 2006 I\IaiIa 011 & Gas eons. eomm\IIIOR Anchorage FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Librarian/Data Control AOGCC 333W. ih Avenue Anchorage, Alaska 99501 RE: 2P-432 omitted slim hole sonic data from 2003 # I )'10~ DATE: 01/17/2006 Via mail Transmitted: CDROM-diaitalloaaina data _ Schlumberger LDWG Format Open Hole edit for Slim line BHC Sonic· 302.5-6027.5'; logged Nov 21, 2003. Reference Job #10709654. · This data was omitted from Schlumberger delivery of OH data from this well in 2003. This is delivery of identified 'data gap' by CPA!. If you have further questions, contact Cathy Worley at 265-1129. Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for our records. CC: Derik Kleibacker, CPAI, 2P-padsite Geologist Recejp~ ~_ Date: Return ipt to: donocoPhilliPS Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 I Sandra.D. Lem,ke(ó)conoco/Jhillips. com Signed It£. Date Print Name: ÛM.a.d PRoAClivE DiA(jNOSTic SERvicES, INC., PO Box I }69 STAHoRd IX 77477 Phonc:(28I ) 565-9085 Fax:(28 565-1369 E-mail . com Wcbsitc: w\V\v.mcmol1'log.colll LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole 2P-432 9-1 8-04 Res. Eva!. CH 1 1 1 I ). ~ ~g Mech. CH 1 Caliper Survey 1 Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 The technical data listed below is being submitted herewith this transmittal letter to the attention of : RE Distribution Final Print(sJ Please acknowledge receipt by returning a signed copy of State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage. Alaska 99501 To: ProActive Diagnostic Services, Inc. e WELL LOG TRANSMITTAL . Q,:.e;)~:'7 ~~~bð{ ~·OP/ . Conoc;';"illips March 18, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2P-432 (APD # 202-091) Dear Commissioner: . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Meltwater well 2P-432. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, ~\~. ~"-- R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad ORIGINAL . STATE OF ALASKA . ALA . Oil AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas U Plugged D Abandoned D Suspended D WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development D Exploratory D GINJ D WINJ D WDSPL D No. of Completions _ Other - Service 0 Stratigraphic Test D 2. Operator Name: 5. Date Comp., sa:..;....,., 1.£ ~ 1J' Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: g¡ulr-hSI f . otIS 202-091 I 3. Address: 6. Date Spudded: / .y.foe. ¡¡.G. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 October 31, 2003 50-103-20420-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 948' FNL, 1894' FWL, Sec. 17, T8N, R7E, UM . 2P-432 November 20, 2003 At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: 2594' FNL, 1469' FWL, Sec. 17, T8N, R7E, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): Meltwater Oil Pool 2596' FSL, 1446' FWL, Sec. 17, T8N, R7E, UM 5938' MD 15612' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 443855 y- 5868930 Zone-4 ~ 6043' MD I 5710' TVD ADL 373112 TPI: x-443422 y- 5867287 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 443399 y- 5867197 Zone- 4 Landing Nipple @ 508' L 32092 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of NIA feet MSL Permafrost: 1358' MD 21. Logs Run: GR/Res/DenlNeu, US IT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# B Surface 108' 42" 110 sx LiteCrete 9.625" 40# L-80 Surface 2449' 12.25" 527 sx AS Lite, 225 sx LiteCrete 7" 26# L-80 Surface 5602' 8.5" 130 sx LiteCrete 5.5" 15.5# L-80 5533' 5762' 6.125" 50 sx Class G w/GasBlok 3.5" 9.3# L-80 5439' 6038' 4.75" 72 sx Class G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 1 3.5" 5485' 5450' 5838'-5860' MD 5518'-5539' TVD 6 spf 5778'-5798' MD 15462'-5481' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5806'-5826' MD ¡ 5488'-5507' TVD 6spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED NIA 26. PRODUCTION TEST Date First Injection Method of Operation (Flowing, gas lilt, etc.) March 10, 2004 WAG Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO NIA Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> not available 27. CORE DATA 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". r"'~';\;j ¡~_!ì(ó _ [ NONE ~ :1 ·'WT;o,;OIO. t ,'" oF} . 'þ''''' ._n .. ______1 OR\G\~JÞJ- ",..,.."'".,...,....;,.,.._,-~;.'...,,,_"'.<ì',.,J< Form 1 0-407 Revised 2/2003 CONTINUED ON REVERSE SIDE Submit in duplicate G GF R.OOMS Bfl WRO!;', . 28. 29. GEOLOGIC MARKERS 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". 2P-432 T3 T2 5778' 5914' 5462' 5589' NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed N Title: rI. _ Kuparuk Team Leader ~S-," )0 Date "hi' IÓ y 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 1 0-407 Revised 2/2003 O·Di , \ \ ! L_ Page 1 of 14 ConocoPhillips Alaska Operations SUrnmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-432 2P-432 ROT - DRILLING Doyon Doyon 141 Date Sub Code Code Phase From - To Hours 10/29/2003 14:00 - 16:00 2.00 MOVE MOB MOVE 16:00 - 00:00 8.00 MOVE MOVE MOVE 00:00 - 02:00 2.00 MOVE POSN RIGUP 02:00 - 03:30 1.50 MOVE POSN RIGUP 03:30 - 07:30 4.00 MOVE RURD RIGUP 07:30 - 10:00 2.50 MOVE RURD RIGUP 10:00 - 12:00 2.00 MOVE RURD RIGUP 12:00 - 14:00 2.00 MOVE RURD RIGUP 14:00 - 22:00 8.00 MOVE RURD RIGUP 10/30/2003 22:00 - 00:00 2.00 MOVE SFTY RIG UP 10/31/2003 00:00 - 01 :30 1.50 WELCT BOPE RIGUP 01 :30 - 05:00 3.50 DRILL PULD RIG UP 05:00 - 09:30 4.50 DRILL PULD SURFAC 09:30 - 12:00 2.50 DRILL SFTY SURFAC 12:00 - 14:30 2.50 DRILL DRLG SURFAC 14:30 - 15:00 0.50 DRILL RIRD SURFAC 15:00 - 00:00 9.00 DRILL DRLG SURFAC 11/1/2003 00:00 - 14:00 14.00 DRILL DRLG SURFAC 14:00 - 15:30 1.50 DRILL CIRC SURFAC 15:30 - 16:30 1.00 DRILL TRIP SURFAC 16:30 - 17:00 0.50 DRILL CIRC SURFAC 17:00 - 20:30 3.50 DRILL TRIP SURFAC 20:30 - 21 :30 1.00 CASE RURD SURFAC 21 :30 - 00:00 2.50 CASE RUNC SURFAC 11/212003 00:00-01:15 1.25 CASE RUNC SURFAC 01:15 - 02:15 1.00 CASE CIRC SURFAC 02:15 - 02:45 0.50 CASE RURD SURFAC 02:45 - 05:00 2.25 CASE CIRC SURFAC 05:00 - 07:15 2.25 CEMEN PUMP SURFAC Start: Rig Release: Rig Number: Spud Date: 11/1/2003 End: 11/23/2003 Group: 10/22/2003 11/23/2003 141 Description of Operations ____________________________M_____ De-Mob rig off W-400 well - BP WOA - W pad Move Sub,Pits,Pump,Motor and Boiler modules from "W" pad to 2P pad. Mile move = 49.7 miles. Spot Sub over 2P - 432 Spot pit,pump,motor & boiler modules. Spot and set rock washer module. Hook up service lines( air-water-steam-glycol-RIU mud lines - Take on water to pits Mix spud mud - CIO saver sub on Top Drive Finish N/U Diverter - Con't Mix spud mud '" Note'" Accept Rig @ 12:00 hrs 10/30/03 Spot pipe sheds - Spot and set rig camp & SDU Con't mix spud mud - load DP into shed - Set MWD unit on top of pits - Spot & berm 2 400 bbl "Kill" mud storage tanks - In stall landing for pits mud mixing dust collector. Pre Spud meeting with all crew members and contractors. Pick up 3 joints drill pipe, Level Sub, Perform Accumulator and Diverter function test. Waived by AOGCC Chuck Scheve. Pick up 114 joints 5",19.5#, G-105, 4-1/2" IF drill pipe and 29 joints 5" HWDP and stand back in derrick. Pick up 12-1/4" BHA #1, Pick up 3-8" NMDC's and stand back in derrick, Pick up motor, Bit, Stab, XIO, MPR, MWD, UBHO, Oreint same, Program same, RIH & tag at 108'. Rig up kill mud system, Held Diverting shallow gas drill & Kill mud system drill with all personal. Spud at 1200 hrs. 10/31/2003 and drill f/108' to 272' Rig up Haliburton slick line unit and run GYRO survey @ 272'. Drill fl 272' to 998' ART = 5.0 hrs, AST = 1.6 hrs, Pumping unweighted sweeps every 3-4 stands, UP 86K, DN 86K, ROT 86K, TQ on 21</ off 0, WOB 20K, 80 RPM, 500 GPM @ 1150 psi Drill fl 998' to 2454' (2377' TVD) ART = 6.8 hrs, AST = 2.4 hrs, Pumping Hi-vis (Unweighted) sweeps every 3-4 stands, WOB 5/30K, RPM 80/85, 600 GPM @ 1900 psi, UP 115K, DN 108K, ROT 113K, TQ on 41</ off 3K Pump Hi-vis weighted sweep, Circ hole clean w/3 times btm's up at 600 gpm @ 1700 psi. Back ream out of hloe to 1400' (Above ghost reamer depth) at drilling rate parameters. Circ. hole clean with 1-1/2 times btm's up. Monitor well, POOH & stand back HWDP & DC's, Lay down remainder of BHA, Clear rig floor. Rig to run 9-5/8" casing, PJSM with all personal. Run 9-5/8", 40#, L-80, BTC casing to 1445' Con't to run 9.625" 40# BTC csg to 2449' MD ( ran total 57 jts) - M/U hanger - MU landing jt Circ BU wI Franks tool - Stage pumps up slowly to 6 bpm @ 400 psi RID Frank's circu tool - Blow dn TD - MU DS cmt head Circu & Condition mud - Circu @ 6 bpm - Final 6 bpm = 250 psi Rig Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.6 bpm @ 70 psi, Shut down, Test lines to 3000 psi, Continue pumping CW100 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 6.0 bpm @ 100 psi, Shut down and drop btm plug, Mix & pump 527 sxs (401.7 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg wI Printed: 3/16/2004 10:42:50 AM Page 2 of 14 GonocoPhillips Alaska Operations Summary Report 2.25 CEMEN PUMP SURFAC additives at rate of 7.0 bpm @ 320 psi, Followed by 225 sxs (91.3 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg wI additives at rate of 7.0 bpm @ 325 psi, Shut down and drop top plug, Displace cmt wI 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 158.8 bbls 8.9 ppg mud (total of 178.8 bbls to bump plug) at rate of 7.0 bpm @ 670 psi, Slowed rate to 3.0 bpm @ 600 psi for last 10 bbls of displacement, Bump plug w/1150 psi, Floats held- OK, CIP @ 0705 hrs 11/2/03, Had good returns thru out job, Reciprocate csg. 15' until dropped plug, Had 188 bbls good cmt returns to surface. Rig down cmt head, Lay down landing joint. Nipple down diverter system. Nipple up casing head & tubing spool, Orient same, Set test plug, Test seals to 1000 psi- OK. Nipple up BOPE. Rig & test all BOPE to 250 psi low & 5000 psi high, Hydril to 3500 psi. Test waived by AOGCC Chuck Scheve. Pick up 18 joints 5" drill pipe and stand back in derrick. Make up BHA #2, Orient motor, program MWD, Load RA sources. Pick up 3- NMDC's, XO, HWDP, Surface test MWD, RIH wI HWDP. Pick up 36 jts 5" DP to 2,039' Rig & Perform detailed stripping & well kill drill with all rig personal. RIH to 2,317', Rig & test 9-5/8" casing to 3500 psi f/30 min. on chart. RIH & tag float collar @ 2,360', Drill out shoe track and cmt. to TD 2,454'. Change over to 9.6 ppg LSND Mud. Drill 20' new hole for LOT to 2,474' Circ. btm's up for LOT. Perform FIT with 9.6 ppg mud, 1046 psi, 2,395' TVD= 18.1 ppg EMW. Held Production hole Safety meeting with all rig personal. Perform PWD baseline test. Drill f/2,474' to 3,552' (3,398' TVD) ART = 8.8 hrs AST = 1.9 hrs, WOB 5-20K, RPM 90, 510 GPM @ 2200 psi, TQ 2/8K on, 4K off, UP 138K, DN 116K, ROT 126K, ECD's 10.4 to 10.7 ppg, Control drilling at 150'/hr to control ECD's, Pumping unweighted sweeps every 4 stands, No noticable mud losses, BGG +- 50 units. 18.00 DRILL DRLG INTRM1 Drill f/3,552' to 5,222' (4,941' TVD) ART = 10.0 hrs AST = 1.6 hrs, WOB 10-20K, RPM 90, 510 GPM @ 2400 psi, TO 5/12K on, 7K off, UP 185K, DN 140K, ROT 156K, ECD's 10.5 to 10.7 ppg, Control drilling at 150'/hr to control ECD's, Pumping unweighted sweeps every 4 stands, No noticable mud losses, BGG 50 to 70 units. 0.50 DRILL CIRC INTRM1 Had 3400 units connection gas from connection at 5,193' MD (4,911' TVD) mud cut to 7.6 ppg, Check flow- No flow, Gas circ. down to 2000 units, then back up to 3800 units from flow check, Cuttings sample showed 70% clay stn, 20% silt stn, 10% sand, Gas hanging in around 1000 units BGG. Raise mud weight from 9.6 ppg to 9.9 ppg, BGG down to 150 to 250 units. Get new slow pump rates with 9.9 ppg mud, Drill f/5,222' to 5,287' ART = .5 hrs, BGG 80 units, Had 900 units from getting slow pump rates, ECD's 11.0 ppg, Connection gas at 5,287' = 550 units over BGG. Drill fl 5,287' to 5,394' (5,102' TVD) ART = 1.5 hrs AST =.1 hrs, WOB 10-20K, RPM 90, 510 GPM @ 2400 psi, TO 5/12K on & 7K off, UP 185K, DN 140K, ROT 156K, ECD's 11.0 ppg, BGG 50 to 60 units, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2P-432 2P-432 ROT - DRILLING Doyon Doyon 141 From - To Hours Code I ¿ouJe Phase 11/2/2003 05:00 - 07:15 07:15 - 07:45 0.50 CEMEN SURFAC 07:45 - 10:30 2.75 WELCT SURFAC 10:30 - 11 :15 0.75 WELCT SURFAC 11 :15 - 14:30 3.25 WELCT SURFAC 14:30 - 20:00 5.50 WELCT SURFAC 20:00 - 21 :00 1.00 DRILL PULD SURFAC 21 :00 - 00:00 3.00 DRILL PULD SURFAC 11/3/2003 00:00 - 01 :45 1.75 DRILL PULD SURFAC 01 :45 - 03:00 1.25 DRILL TRIP SURFAC 03:00 - 04:45 1.75 DRILL SFTY SURFAC 04:45 - 05:45 1.00 DRILL DEOT SURFAC 05:45 - 06:30 0.75 DRILL DRLG SURFAC 06:30 - 07:15 0.75 DRILL CIRC SURFAC 07:15 - 07:30 0.25 DRILL DRLG SURFAC 07:30 - 07:45 0.25 DRILL CIRC SURFAC 07:45 - 08:30 0.75 DRILL FIT SURFAC 08:30 - 08:45 0.25 DRILL SFTY INTRM1 08:45 - 09: 15 0.50 DRILL CIRC INTRM1 09:15 - 00:00 14.75 DRILL DRLG INTRM1 11/4/2003 00:00 - 18:00 18:00 - 18:30 18:30 - 20:00 1.50 DRILL CIRC INTRM1 20:00 - 21 :30 1.50 DRILL DRLG INTRM1 21 :30 - 00:00 2.50 DRILL DRLG INTRM1 Start: Rig Release: Rig Number: Spud Date: 11/1/2003 End: 11/23/2003 Group: 10/22/2003 11/23/2003 141 Description of Operations Printed: 3/16/2004 10:42:50 AM ~ ..' GonocoPhillips Alaska Page 3 of 14 Operations Summary Report . Legal Well Name: 2P-432 Common Well Name: 2P-432 Spud Date: 11/1/2003 Event Name: ROT - DRILLING Start: 10/22/2003 End: 11/23/2003 Contractor Name: Doyon Rig Release: 11/23/2003 Group: Rig Name: Doyon 141 Rig Number: 141 , Sub I I Date From - To Hours I Code Code Phase Description of Operations I -- '--.-- .--- ----- 11/4/2003 21 :30 - 00:00 2.50 DRILL DRLG INTRM1 Connection gas at 5,377' 715 units over BGG. 11/5/2003 00:00 - 01 :00 1.00 DRILL DRLG INTRM1 Drill fl 5,394' to 5,500' (5,200' TVD) ART = 1.0 hrs AST =0 hrs, WOB 10-20K, RPM 90, 510 GPM @ 2400 psi, TQ 5/12K on & 7K off, UP 185K, DN 140K, ROT 156K, ECD's 11.0 ppg, BGG 70 units, Connection gas at 5,471' 566 units over BGG. 01 :00 - 03:45 2.75 DRILL CIRC INTRM1 Shut down pump & work pipe for 15 min., Circ btm's up- had 1285 units gas, Pump Hi-vis sweep, Raise mud weight to 10.1 ppg BGG 40 units, Obtain new SPR's, Shut down pump & work pipe for 15 min., Circ btm's up- had 1140 units gas. 03:45 - 04:15 0.50 DRILL WIPR INTRM1 Wipe hole 3 stands to 5,196', Hole in very good shape, No swabbing or tight hole. 04:15 - 06:00 1.75 DRILL CIRC INTRM1 Circ btm's up - 1920 units trip gas, mud cut to 8.1 ppg, Raise mud weight to 10.3 ppg, Obtain new SPR's. 06:00 - 06:30 0.50 DRILL WIPR INTRM1 Wipe hole 3 stands to 5,196', Hole in very good shape, No swabbing or tight hole. 06:30 - 09:00 2.50 DRILL CIRC INTRM1 Circ btm's up - 1400 units trip gas, mud cut to 8.8 ppg, Raise mud weight to 10.6 ppg, Obtain new SPR's. 09:00 - 09:30 0.50 DRILL WIPR INTRM1 Wipe hole 3 stands to 5,196', Hole in very good shape, No swabbing or tight hole. 09:30 - 11 :30 2.00 DRILL CIRC INTRM1 Circ btm's up - 509 units trip gas, mud cut to 10.1 ppg, Raise mud weight to 10.8 ppg, Obtain new SPR's, Blow down top drive. 11 :30 - 13:30 2.00 DRILL WIPR INTRM1 Wipe hole to 4,000', Hole in very good shape, No swabbing or tight hole. 13:30 - 14:30 1.00 DRILL CIRC INTRM1 Stage pumps to 500 gpm @ 2300 psi, Started losing mud at 3 bpm, Slow rate to 460 gpm @ 1900 psi, Start Adding LCM at 5 ppb with G-Seal and Mix II (Lost total of 77 bbls), Had excess Clay and Shale on btm's up, Trip gas 1820 units. 14:30 - 19:30 5.00 DRILL DRLG INTRM1 Drill f/5,500 to 5,613' (5,307' TVD) ART= 1.1 hrs AST= 2.1 hrs Had 2840 units gas from 5,583' 5,280' TVD mud cut to 9.8 ppg, BGG holding at 1400 to 1700 units, Increase pump rate to 550 gpm wI ECD's of 11.7 ppg. 19:30 - 22:30 3.00 DRILL CIRC INTRM1 Raise mud weight to 11.1 ppg, Began loosing 168 bph, Slowed pump rate to 330 gpm, Losses slowed to 20 bph (Lost total of 65 bbls), Gas down to 65 units BGG, Shut down pumps to cycle pumps for survey (Well appears to flow). 22:30 - 00:00 1.50 DRILL CIRC INTRM1 Pump 30 bbl LCM sweep of 15 ppb G-Seal & Mix II, Circ & add 5+ ppb LCM to entire mud system, Loses seem to subside at 390 gpm with ECD's 11.6 ppg, Gas fluctuating from 350 units to 4000 units, Had 2600 units from shuting down pumps for survey. 11/6/2003 00:00 - 11 :00 11.00 DRILL CIRC INTRM1 Circ wI slight loses at rate of 350 gpm, BGG 110 to 400 units, Raise mud weight f/11.1 to 11.3 ppg, When 11.3 ppg mud came around began loosing mud at 120 bph with gas 850 to 950 units, Slowed rate down to 75 gpm, Loosing 94 bph with gas 500 units, Water back mud weight to 11.1 ppg. 11 :00 - 20:30 9.50 DRILL CIRC INTRM1 Increase flow rate to 330 gpm with minor loses BGG 5-600 units, when 11.1 back to surface gas increased to an average of 3000 units. Increase LCM concentration to 18 ppb, Pump 2 30 ppb 50 LCM sweeps. able to increase ECD to 11.8 ppg with pump rate at 450 gpm. Pump 100 bbls LCM sweep @ 35 ppb. Attempt to squeeze away LCM with ECD's. Well apprently taking fluid right on botttom. Pump sweep around No losses ECD 11.67. BGG 400-500 units with occasional spikes. Shut down pumps and check flow for 4 min.- well flowing, gain 7 bbls, Circ. btm's up, Had 5390 units gas on btm's up, BGG 5-600 Printed: 3/16/2004 10:42:50 AM ; A ,., ConocoPhillips Alaska Page 4 of 14 Operations Summary Report Legal Well Name: 2P-432 Common Well Name: 2P-432 Spud Date: 11/1/2003 Event Name: ROT - DRILLING Start: 10/22/2003 End: 11 /23/2003 Contractor Name: Doyon Rig Release: 11/23/2003 Group: Rig Name: Doyon 141 Rig Number: 141 I Sub Date From - To Hours I Code Phase Description of Operations I Code --------- _.. ---- 11/6/2003 11 :00 - 20:30 9.50 DRILL CIRC INTRM1 units. 20:30 - 23:15 2.75 DRILL CIRC INTRM1 Raise mud weight to 11.3 ppg, Pumping 40 ppb LCM sweeps with 2 ppb Celloflakes, 8 ppb Nut plug med., 10 ppb Mix 1\ med., 10 ppb Safe Carb 250, 10 ppb Safe Carb 500 to control loses, With 11.3 ppg in & out had 270 units BGG, Monitor well for one hour with no loses pumping at rate of 200 gpm at 600 psi. 23:15.. 00:00 0.75 DRILL CIRC INTRM1 Begin raising mud weight to 11.4 ppg. Note; Total mud lost in hole to date = 1342 bbls 11/7/2003 00:00 - 06:30 6.50 DRILL CIRC INTRM1 Finish raising mud weight from 11.3 to 11.4 ppg, Pumping 25 bbl 40 ppb LCM sweeps periodically of 3 ppb Celloflake, 10 ppb Mix 1\ med, 10 ppb Nut plug med, 15 ppb Safe Carb 250, 6 ppb Safe Carb 500, to control loses, Vary pump rates from 250 gpm to 200 gpm, lose rates vary from 120 bph to 0 bph, BGG decreased from 250 units to 150 units, Circ & monitor well for loses. 06:30.. 14:00 7.50 DRILL CIRC INTRM1 Raising mud weight from 11.4 to 11.5 ppg, Pumping 25 bbl 40 ppb LCM sweeps periodically of 3 ppb Celloflake, 10 ppb Mix 1\ med, 10 ppb Nut plug med, 15 ppb Safe Carb 250, 6 ppb Safe Carb 500, to control loses, Vary pump rates from 200 gpm to 125 gpm, lose rates vary from 25 bph to 0 bph, BGG decreased from 150 units to 25 units, Circ & monitor well for loses. 14:00.. 15:00 1.00 DRILL CIRC INTRM1 Spot 50 bbl 40 ppb LCM pill of 3 ppb Celloflake, 10 ppb Mix 1\ med, 10 ppb Nut plug med, 15 ppb Safe Carb 250, 6 ppb Safe Carb 500 on btm. 15:00.. 15:30 0.50 DRILL WIPR INTRM1 POOH 5 stands to 5100', Gained 18 bbls while pulling out. 15:30 - 18:00 2.50 DRILL CIRC INTRM1 Circ btm's up at rate of 125 gpm @ 500 psi, losing 90 bph, Slow rate to 90 gpm @ 375 psi wI lose rate of 15 bph, Had no gas on btm's up BGG 25 units, Continue to eire, Increase rate to 125 gpm @ 500 psi w/15 bph loses. 18:00 .. 19:00 1.00 DRILL OBSV INTRM1 Shut down pumps and observe well for 1 hour, Flowed back 25.7 bbls, Flow decreased from 4.2 bbls in first 5 min. to 1.3 bbls in the last 5 min. of the hour. 19:00 .. 21 :30 2.50 DRILL CIRC INTRM1 Circ btm's up at rate of 105 gpm @ 450 psi, Had no gas on btm's up, loses decreased to 12 bph. BGG 25 units. 21 :30 - 00:00 2.50 DRILL TRIP INTRM1 Pump out of hole pulling pipe at 45 fVmin, pumping at 90 gpm, Pipe displacement from 13.7 bbls gain for first 5 stands to 1.25 bbls loss for last 5 stands. Note; Total loss for day = 461 bbls, Accum. total = 1803 bbls 11/8/2003 00:00.. 00:15 0.25 DRILL TRIP INTRM1 Finish pumping out to shoe 00:15.. 00:30 0.25 DRILL OBSV INTRM1 Monitor well, Very slight flow and decreasing. 00:30 - 01 :45 1.25 DRILL CIRC INTRM1 Circ. btm's up at shoe at rate of 105 @ 380 psi, lost 36 bbls, Slow pump to 90 gpm @ 250 psi with no loses, BGG 25 units. 01 :45 - 02:30 0.75 DRILL OBSV INTRM1 Monitor well- Flowing, Observe well on trip tank for 30 min., Flowed back 6.3 bbls, Flow decreased f/1.4 bbl in first 5 min. to .7 bbl in last 5 min. 02:30.. 04:15 1.75 DRILL TRIP INTRM1 Precautionary Pump out of hole to HWDP, 85 gpm @ 200 psi, pulling at 45 fVmin., Gained 6 bbls. 04:15 - 04:45 0.50 DRILL OBSV INTRM1 Monitor well, Very slight flow and decreasing. 04:45 - 06:30 1.75 DRILL TRIP INTRM1 Pump out to DC's @ 196', HWDP took proper fill. 06:30 .. 09:00 2.50 DRILL PULD INTRM1 Monitor well- static, Stand back DC's, PJSM, Remove A.A. sources, Lay down BHA #2, Clear floor. 09:00 .. 10:00 1.00 CASE RURD INTRM1 Pull wear bushing, Change out top pipe rams to 7", Test door seals to 2500 psi. 10:00 - 10:45 0.75 CASE RURD INTRM1 Rig to run casing, PJSM. 10:45 .. 00:00 13.25 CASE RUNC INTRM1 Run 7", 26#, L-80, BTCM casing to 4,226', Stopped and broke eire, @ Printed: 3/16/2004 10:42:50 AM Page 5 of 14 ConocoPhillips Alaska Operations Summary Report ... 1,200',2,440',3,240',4,050' only able to circ at 1 to 1.5 bpm with 75% returns, Pipe displacement diminishing as run in hole losing 5 to 10 bbls per 5 joints. Note; Lost 211 bbls for day, 2014 bbls total. 3.50 CASE RUNC INTRM1 Finish Running 7", 26#, L-80, BTCM casing f/ 4,226' to 5,602' and land same, Stopped and eire, @ 5,287' only able to circ at 1 to 1.5 bpm with possible 20% returns at best, No Pipe displacement at all on last 10 joints, Lost total of 208 bbls mud running casing, Pipe ran in hole with no trouble. Attempt to circ at rate of 1.5 bpm at 350 psi, 20% to trace returns, Lost 72 bbls while eire, Reciprocate pipe 10-15'. Lay down Franks fill up tool, Pick up Dowell cement head. Attempt to circ at rate of 1.0 bpm at 250 psi, 20% to trace returns, Reciprocate pipe 10-15', Lost 48 bbls mud while circ. Batch mix cement. Turn over to Dowell, Pump 5 bbls CW1 00 @ 8.3 ppg, Test lines to 4000 psi, Continue pumping 25 more bbls CW100 at rate of 1.5 bpm @ 100 psi, followed by 40 bbls MudPUSH II Mixed at 12.0 ppg at rate of 1.5 bpm at 180 psi, Shut down, Drop btm plug, Pump 51 bbls (130 sxs) LiteCRETE cement mixed at 12.5 ppg wI .9%D65, .020%C359, .20%D47, 1.5%D600G at rate of 1.5 bpm at 200 psi, Shut down, Drop top plug, Displace cement w/1 0 bbls fresh water, followed by 204 bbls 11.5 ppg mud at rate of 1.5 bpm at 200 psi, Did not bump plug, Gained 3.9 bbls thru out displacement, C.I.P. @ 10:00 hrs. 11/9/03, Observe well- Mild flow, Reciprocated pipe until last 20 bbls of displacement. Close Hydril and monitor well, Pressure built to 55 psi and slowly decreased to 44 psi, Bleed off pressure, Monitor well- Static. Rig down cement head & Landing joint, Change bails & elevators. Install 9-5/8" x 7" Pack off, Test same to 5000 psi for 10 min- OK Install test plug, Change top pipe rams to 3-1/2" x 6", Change btm pipe rams to 4", Change saver sub on top drive to HT-39 Test all BOPE to 250 psi low & 5000 psi high, Hydril to 3500 high, BOPE test waived by AOGCC Lou Gramaldi., Pull test plug, Set wear bushing. Note: Total mud lost for the day= 413 bbls, Accum. total= 2427 bbls. Slip & cut drilling line 80'. Transfer 10 stands 5" HWDP & 16 stands 5" Drill pipe to left side of derrick for surface hole on next well. Lay down 120 joints 5" drill pipe from derrick in mouse hole. Change out 5" handling tools to 4" Service rig & top drive. Pick up 8 stands 4" drill pipe and stand back in derrick. Bring BHA tools to rig floor, Make up 6-1/8" BHA #3. Pick up 4" HWDP, Pick up 4" drill pipe from pipe shed to 4,490' (tag em!) Change over from 11.5 ppg to 9.6 ppg mud weight. Drill soft cement from 4,490' to 5,266' Stand back 10 stands drill pipe in derrick, Pick up 30 joints drill pipe from pipe shed. Drill soft cement fl 5,266' to 5,520'. Circ btm's up & hole clean. Rig & test 7" casing to 3500 psi fl 30 min. - OK Record slow pump rates, Drill on float collar @ 5,520'. Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 11/8/2003 10:45 - 00:00 13.25 CASE RUNC INTRM1 11/9/2003 00:00 - 03:30 03:30 - 04:30 1.00 CEMEN CIRC INTRM1 04:30 - 05:00 0.50 CEMEN PULD INTRM1 05:00 - 06:00 1.00 CEMEN CIRC INTRM1 06:00 - 10:15 4.25 CEMEN PUMP INTRM1 10:15 - 15:00 4.75 CEMEN OTHR INTRM1 15:00 - 16:00 1.00 CEMEN PULD INTRM1 16:00 - 17:00 1.00 CASE NUND INTRM1 17:00 - 19:00 2.00 WELCT NUND INTRM1 19:00 - 00:00 5.00 WELCT BOPE INTRM1 11/10/2003 00:00 - 01 :00 1.00 RIGMNT RSRV INTRM1 01 :00 - 02:45 1.75 DRILL PULD INTRM1 02:45 - 06:30 3.75 DRILL PULD INTRM1 06:30 - 07:30 1.00 DRILL RIRD INTRM1 07:30 - 08:00 0.50 RIGMNT RSRV INTRM1 08:00 - 09:30 1.50 DRILL PULD INTRM1 09:30 - 10:45 1.25 DRILL PULD INTRM1 10:45 - 15:00 4.25 DRILL TRIP INTRM1 15:00 - 16:00 1.00 DRILL CIRC INTRM1 16:00 - 19:30 3.50 DRILL DRLG INTRM1 19:30 - 21 :00 1.50 DRILL PULD INTRM1 21 :00 - 22:00 1.00 DRILL DRLG INTRM1 22:00 - 22:30 0.50 DRILL CIRC INTRM1 22:30 - 23:30 1.00 DRILL DEQT INTRM1 23:30 - 00:00 0.50 DRILL DRLG INTRM1 Start: Rig Release: Rig Number: Spud Date: 11/1/2003 End: 11/23/2003 Group: 10/22/2003 11 /23/2003 141 Description of Operations Printed: 3/16/2004 10:42:50 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2P-432 2P-432 ROT - DRILLING Doyon Doyon 141 From - To I Hours Code I ¿'ou:e Phase Page 6 of 14 Start: Rig Release: Rig Number: Spud Date: 11/1/2003 End: 11/23/2003 Group: 10/22/2003 11/23/2003 141 11111/2003 00:00 - 00:45 .-...-- "--------- ..------- "----."-.-" ------- Description of Operations 0.75 CEMEN DSHO INTRM1 Drilled out float collar, 10' of hard cement in shoe track and float shoe at 5,602', cleaned out rat hole to 5,613', drilled shoe track with 15-20K wob, 60-120 rpm's, 255 gpm at 750 psi, rot wt 115K, up wt 122K, dn wt 105K, off btm torque 3K ft-Ibs, on btm 3.5K ft-Ibs Monitored well-static Drilled 20' of 61/8" hole from 5,613' to 5,633' MD/5,325' TVD for FIT, had drilling break last 2' Monitored well and had slight flow Began circ hole clean for FIT, after 760 strokes (1,300 stks Btms Up) had 1,300 units gas at surface and a 15 bbl pit gain PU to 5,604' and shut well in, monitored well, ISIDPP 20 psi, ISICP 150 psi, final SIDPP 350 psi, final SICP 570 psi Circ hole on choke using drillers method to circ out gas, max gas 5,500 units, final gas 1,700 units Monitored well while raising mw from 9.6 ppg to 10.0 ppg, ISIDPP 30 psi, ISICP 10 psi, Final SIDPP 130 psi, SICP 130 psi Circ kill weight mud per pump schedule, btms up gas 2,000 units, cont t o circ on choke and BGG stabilized at 1,700 units, circ a total of 3 btms up at 20 spm at 150 psi Cont to circ well on choke holding constant circ press at 20 spm at 150 psi and raised MW to 10.2 ppg, final circ press at 20 spm 180 psi with 1 ,520 units BGG Cont to circ well thru full open choke and staging up pump rates to use Dynamic kill method and increased ECD's, gas ave 1,600 - 2,000 units, increased pump rate from 26 spm, 110 gpm at 290 psi DP, 10 psi Ann with an est ECD of 10.7 ppg, staged up to 71 spm, 300 gpm at 1,160 psi DP, 30 psi Ann, Est ECD at 11.3 ppg, BGG decreased to 300 units, with 10.2 ppg mud initially gas cut to 9.2 ppg mw increased to 9.8 ppg out on balanced scale INTRM1 Cont to stage up pump rate and ECD's, BGG ave 250 units and 10.2 ppg mud gas cut ave 10.1 ppg, at 400 gpm and an est ECD of 11.6 BGG stabilized and mw's were 10.2 in & out NOTE: Performed Dynamic FIT by increasing rate to 475 gpm (final rate) with 10.2 ppg mud for a FIT to 12.0 ppg EMW with no mud loss, 0.50 WELCT CIRC INTRM2 Cont to circ on full open choke at 400 gpm at 1,700 psi DP, 40 psi Ann, circ maintaining est ECD of 11.6 ppg with no losses, ave BGG 190 units 2.50 WELCT COND INTRM2 Circ & raised MW from 10.2 to 10.6 ppg maintaining a ECD of 11.6 ppg with no loss, cont to circ & raise MW from 10.6 to 11.0 ppg maintaining 11.6 ppg ECD, final circ rate thru choke 47 spm, 200 gpm at 750 psi, BGG down to 90 units with 11.0 ppg mud in & out Took SPR with 11.0 ppg mud, shut down for 5 min simulating a connection Circ btms up thru full open choke at 47 spm, 200 gpm at 750 psi, max gas at btms up 1,600 units, 11.0 ppg mud gas cut to 10.4 ppg, cont to circ till 11.0 ppg mud in & out and BGG down to 110 units Shut down and opened BOP, well appeared static, circ btms up at 47 spm, 200 gpm at 750 psi, max gas at btms up 2,100 units, 11.0 ppg mud gas cut to 9.5 ppg, circ till 11.0 ppg mud in & out Washed 29' to btm at 5,633',47 spm, 200 gpm at 950 psi, 50 rpm's and 2K ft-Ibs torque, no problem washing to btm Circ btms up, max gas 180 units dropped down to 80 units Drilled 6 1/8" hole from 5,633' to 5,637', 20K wob, 100 rpm's, 182 gpm, 00:45 - 01 :00 0.25 DRILL OBSV INTRM1 01 :00 - 01 :45 0.75 DRILL DRLG INTRM1 01 :45 - 02:00 0.25 DRILL OBSV INTRM1 02:00 - 02:15 0.25 DRILL CIRC INTRM1 02:15 - 03:15 1.00 WELCT INTRM1 03:15 - 04:45 1.50 WELCT INTRM1 04:45 - 05:30 0.75 WELCT INTRM1 05:30 - 11 :30 6.00 WELCT INTRM1 11 :30 - 14:00 INTRM1 14:00 - 20:00 INTRM1 20:00 - 00:00 11/12/2003 00:00 - 00:30 00:30 - 03:00 03:00 - 03:15 0.25 WELCT INTRM2 03:15 - 04:00 0.75 WELCT INTRM2 04:00 - 04:45 0.75 WELCT CIRC INTRM2 04:45 - 05:00 0.25 DRILL REAM INTRM2 05:00 - 05:30 0.50 DRILL CIRC INTRM2 05:30 - 06:00 0.50 DRILL DRLG INTRM2 Printed: 3/16/2004 10:42:50 AM ..... .............. ConocoPhillips Alaska ··Page 7 of 14 Operations Summary Report Legal Well Name: 2P-432 Common Well Name: 2P-432 Spud Date: 11/1/2003 Event Name: ROT - DRILLING Start: 10/22/2003 End: 11/23/2003 Contractor Name: Doyon Rig Release: 11/23/2003 Group: Rig Name: Doyon 141 Rig Number: 141 .. ¡ Sub I Date From- To Hours· . Code Code Phase Description of Operations .---.. 11/12/2003 05:30 - 06:00 0.50 DRILL DRLG INTRM2 730 psi, ADT 1/4 Hr 06:00 - 07:15 1.25 DRILL CIRC INTRM2 Circ btms up, no change, made conn at 5,637', circ btms up, max gas at btms up 2,500 units, 11.0 ppg mud gas cut to 9.2 ppg, circ till 11.0 ppg mud in & out, BGG down to 70 units 07:15 - 17:30 10.25 DRILL DRLG INTRM2 Drilled 6 1/8" hole from 5,637' to 5,731' MD/5,417' TVD, ADT 10 1/4 Hrs, (94') 20K wob, 100 rpm's, 35 spm, 150 gpm at 650 psi, off btm torque 3K ft-Ibs, on btm 3.5K ft-Ibs, rot wt 115K, pu wt 123K, dn wt 105K, 11.0 ppg mud wt with 15 ppb Icm in mud, ave bgg 25-30 units, drilled at 150 gpm to maintain calc ECD of 11.9 ppg with no mud loss 17:30 - 19:45 2.25 DRILL CIRC INTRM2 Made conn at 5,731' and circ btms up, max gas was 5,300 units and 11.0 ppg mud gas cut to 8.6 ppg, cont to circ hole at 44 spm, 186 gpm at 700 psi till 11.0 ppg mud in & out, BGG down to 200 units, circ 4X btms up, began increasing LCM concentration from 15 ppb to 20 ppb 19:45 - 22:00 2.25 DRILL DRLG INTRM2 Drilled from 5,731' to 5,757' MD/5,441' TVD ADT 2114 Hrs, 20K wob, 100 rpm's, 150 gpm at 650 psi, had 2' drlg break from 5,755' to 5,757', ROP went from 10-15' per hr to 35' per hr 22:00 - 22:45 0.75 DRILL CIRC INTRM2 Circ btms up, at btms up had a 100 unit gas increase to 230 units, then dropped back to 130 units BGG, no mud loss, circ at 150 gpm at 600 psi 22:45 - 23:00 0.25 DRILL DRLG INTRM2 Drilled from 5,757' to 5,762' MDI 5,446' TVD, ADT 1/4 Hr, Drilling break cont to 5,759' (4' total) fin drilling jt down to conn point, last 3' ave 10'lhr ROP, 20K wob, 100 rpm's, 150 gpm at 650 psi, off btm torque 3K ft-Ibs, on btm 3.5K, rot wt 115K, up wt 123K, dn wt 105K, ave BGG 130 units, 11.0 ppg mud with 20 ppb LCM, calc ECD 11.9 ppg with no mud loss 23:00 - 00:00 1.00 DRILL CIRC INTRM2 Circ btms up for cuttings sample, no gas increase at btms up, circ at 150 gpm at 600 psi, ave BGG 130 units 11/13/2003 00:00 - 01 :00 1.00 DRILL CIRC INTRM2 Fin circ btms up for cuttings sample, no gas increase at btms up, circ at 150 gpm at 600 psi, ave BGG 130 units, decision made to run 51/2" liner at 5,762' 01 :00 - 05:00 4.00 DRILL CIRC INTRM2 Circ and raised MW from 11.0 to 11.3 ppg, maintaining a 11.9 ppg ECD, with 11.3 in & out BGG down to 80 units, raised MW from 11.3 to 11.5 ppg, slowed rate to 55 gpm at 250 psi to maintain calc ECD of 11.9 ppg, no mud loss, BGG down to 50 units 05:00 - 05:15 0.25 DRILL OBSV INTRM2 Monitored well 1 0 min-static 05:15 - 08:00 2.75 DRILL CIRC INTRM2 Circ btms up, max gas 70 units, circ at 54 gpm at 250 psi, no gas cut mud 08:00 - 08:45 0.75 DRILL CIRC I NTRM2 Spotted 15 bbl, 40 ppb LCM pill at bit 08:45 - 09:30 0.75 DRILL TRIP INTRM2 Pumped out of hole spotting LCM pill from 5,762' to 5,230', pumped at 42 gpm at 200 psi, pulled pipe at 45'1 min 09:30 - 10:00 0.50 DRILL OBSV INTRM2 Monitored well- static, dropped 2 5/16" rabbit on wire 10:00 - 13:00 3.00 DRILL TRIP INTRM2 Began pumping out of hole from 5,230', hole taking 1/2 bbl over calc fill per 5 stds, observed well every 10 stds and hole was static,while monitoring well at 3,480' with 22 stds out of hole, observed well flowing slightly 13:00 - 14:30 1.50 DRILL CIRC INTRM2 Circ btms up at 3,480', had a max gas of 4,500 units at btms up and 11.5 ppg mud gas cut to 8.8 ppg, circ till 11.5 MW in & out and BGG down to 100 units 14:30 - 15:00 0.50 DRILL REAM INTRM2 Washed down from 3,480' to 4,145', washed down at 150 gpm at 500 psi at 45'1 min 15:00 - 16:00 1.00 DRILL CIRC INTRM2 Circ btms up at 4,145', max gas 2,500 units, 11.5 ppg mud gas cut to 9.0 ppg, circ at 230 gpm at 900 psi, circ till gas out and 11.5 mw in & out 16:00 - 16:30 0.50 DRILL REAM INTRM2 Washed down from 4,145' to 4,612',150 gpm at 525 psi, 45'1 min ... Printed: 3/16/2004 10:42:50 AM ,.,. ConocoPhillips Alaska. Page 8 of 14 Operations Summary Report Legal Well Name: 2P-432 Common Well Name: 2P-432 Spud Date: 11/1/2003 Event Name: ROT - DRILLING Start: 10/22/2003 End: 11/23/2003 Contractor Name: Doyon Rig Release: 11/23/2003 Group: Rig Name: Doyon 141 Rig Number: 141 Date From ~To I Hours I Code I d'ou~e Phase Description of Operations . ...------- 11/13/2003 16:30 - 17:00 0.50 DRILL CIRC INTRM2 Circ btms up at 4,612', max gas 3,700 units, 11.5 ppg mud gas cut to 8.8 ppg, circ at 220 gpm at 900 psi, circ till BGG down to 200 units and 11.5 ppg mw in & out 17:00 - 17:30 0.50 DRILL REAM INTRM2 Washed down from 4,612' to 5,080',140 gpm at 500 psi, 45'1 min 17:30 - 18:30 1.00 DRILL CIRC INTRM2 Circ btms up at 5,080', max gas 2,800 units, 11.5 ppg mud gas cut to 9.3 ppg, circ at 200 gpm at 900 psi 18:30 - 19:00 0.50 DRILL REAM INTRM2 Washed down from 5,080' to 5,578',125 gpm at 500 psi, 45'1 min (csg shoe at 5,602') 19:00 - 20:00 1.00 DRILL CIRC INTRM2 Circ btms up at 5,578', max gas 2,800 units, 11.5 ppg mud gas cut to 9.6 ppg, circ at 200 gpm at 900 psi, circ till BGG down to 200 units and 11.5 ppg mw in & out, increase LCM from 20 ppb to 25 ppb, calc ECD 12.9 ppg, circ with no losses 20:00 - 21 :00 1.00 DRILL CIRC INTRM2 Circ and raised MW from 11.5 to 11.7 ppg, initial circ rate 200 gpm at 870 psi, final rate 150 gpm at 650 psi, bgg down to 115 units, calc ECD at 150 gpm with 11.7 ppg mud is 12.7 ppg 21 :00 - 21 :30 0.50 DRILL OBSV INTRM2 Monitored well, had very slight flow, gained less than 1 bbl in 30 min 21 :30 - 22:30 1.00 DRILL CIRC INTRM2 circ btms up after monitoring well, max gas at btms up 130 units, up ffom a BGG of 100 units, no gas cut mud, circ 1 complet circ at 150 gpm at 600 psi 22:30 - 22:45 0.25 DRILL TRIP INTRM2 TIH to btm from 5,578' to 5,762', washed last 95' to btm with no problems 22:45 - 00:00 1.25 DRILL CIRC INTRM2 Circ btms up from 5,762', initial BGG 60 units, max gas at btms up 240 units, no gas cut mud, circ at 150 gpm at 650 psi, no mud loss, rot wt 116K, up wt 130K, dn wt 106K 11/14/2003 00:00 - 00: 15 0.25 DRILL OBSV INTRM2 Monitored well, had very slight flow 00:15 - 01 :30 1.25 DRILL WIPR INTRM2 Wiped hole 10 stds to 4,830', Monitored well at 5,295' well-static, hole took calc fill 01 :30 - 02:00 0.50 DRILL OBSV INTRM2 Monitored well 30 min- static 02:00 - 02:30 0.50 DRILL TRIP INTRM2 TIH, washed 90' to btm, no problems, rot wt 113K, pu wt 128K, dn wt 104K 02:30 - 04:00 1.50 DRILL CIRC INTRM2 Circ btms up, max gas 3,300 units, 11.7 ppg mud gas cut to 10.0 ppg, max gas up at 1,100 stks calc gas up from 4,830', circ at 150 gpm at 650 psi, BGG down to 80 units with 11.7 ppg mud in & out 04:00 - 06:45 2.75 DRILL CIRC INTRM2 Circ hole and raised MW from 11.7 to 11.9 ppg, circ at 125 gpm at 580 psi to maintain 12.7 ppg ECD, BGG down to 60 units with 11.9 ppg mud in & out 06:45 - 07:00 0.25 DRILL OBSV INTRM2 Monitored well-static 07:00 - 08:30 1.50 DRILL WIPR INTRM2 Wiped hole 10 stds to 4,830', Monitored well at 5,295' well-static, hole took calc fill 08:30 - 09:00 0.50 DRILL OBSV INTRM2 Monitored well 30 min- static 09:00 - 09:45 0.75 DRILL TRIP INTRM2 TIH, washed 90' to btm 09:45 - 11 :45 2.00 DRILL CIRC INTRM2 Circ btms up, max gas 90 units, 11.9 ppg mud gas cut to 10.6 ppg, 11 :45 - 14:00 2.25 DRILL CIRC INTRM2 Circ & raised MW for trip margin from 11.9 to 12.1 ppg, circ at 100 gpm at 400 psi, BGG down to 40 units with 12.1 ppg mud in & out 14:00 - 14:30 0.50 DRILL CIRC INTRM2 Spotted 20 bbl 43 ppb LCM pill at bit 14:30 - 15:00 0.50 DRILL CIRC INTRM2 Pumped out 5 stds to 5,295' spotting LCM pill 15:00 - 21 :45 6.75 DRILL TRIP INTRM2 Pumped out of hole from 5,295' to 1,062' to BHA, monitored well every 5 stds and well-static, pumped out at 110 gpm Initial circ press 350 psi, final 250 psi, pulled at 30'1 min, ave BGG 20 units, SLM, no corr, Calc fill on trip out 38 bbls, Actual fill 45 bbls 21 :45 - 23:00 1.25 DRILL TRIP INTRM2 Monitored well at BHA-static, POOH standing back HWDP & jars, LD 1-4 3/4" Spiral DC & stab's 23:00 - 23:15 0.25 CASE RURD INTRM2 RU Doyon's 5 1/2" Liner running equipment & Held PJSM - Printed: 3/16/2004 10:42:50 AM tA ...,. -. ..... GonocoPhillips Alaska Page 9 of 14 Operations Summary Report Legal Well Name: 2P-432 Common Well Name: 2P-432 Spud Date: 11/1/2003 Event Name: ROT - DRILLING Start: 10/22/2003 End: 11/23/2003 Contractor Name: Doyon Rig Release: 11/23/2003 Group: Rig Name: Doyon 141 Rig Number: 141 Date From- To Hours I Sub Phase I Description of Operations Code Code - , 11/14/2003 23:15 - 00:00 0.75 CASE PULR INTRM2 MU 5 1/2" 15.5# L-80 Hydril 511 Liner and RIH to 208', MU BOT Float Shoe, 1 Jt 51/2" Liner, 1- Centralizer Sub, 1 Jt Liner, BOT Insert Float Collar, 1- Centralizer Sub, 1 Jt Liner, Insert Landing Collar and 2 Jts liner (5 jts total), 208.65', thread locked conn below landing collar, check float equip & ck ok 11/15/2003 00:00 - 00:30 0.50 CASE PULR INTRM2 MU Baker 5 1/2" x 7" HMC hanger with CHP liner top packer, (overall Liner & hanger assembly 228.57') 00:30 - 04:45 4.25 CASE RUNL INTRM2 PU 13 jts of 4" DP from Pipe shed and TIH out of derrick with 51/2" liner to 2,985', TIH slow at 15'1 min due to mud loss, ave 5-10% returns 04:45 - 07:30 2.75 CASE CIRC INTRM2 Circ and cond mud to 12.1 ppg at 2,985', est circ at 1/2 bpm and increased to 3/4 bpm at 130 psi, ave 85% returns with max BGG gas 53 units 07:30 - 12:00 4.50 CASE RUNL INTRM2 Cont RIH slow with 5 1/2" liner on 4" DP to 5,538' (7" csg shoe at 5,602') 12:00 - 16:30 4.50 CASE CIRC INTRM2 Circ and cond mud at 5,538', staged pumps up to 2 bpm at 400 psi, shook out LCM and lowered MW to 11.9 ppg to improve circ and for cementing, ave 85% returns, max gas 50 units, ave 40 units, string up wt 104K, dn wt 94K, MU cement head and pup jt wlcirc 16:30 - 17:00 0.50 CASE RUNL INTRM2 RIH to 5,740', MU cement head and washed down at 1.5 bpm at 300 psi, tagged btm at 5,762', no problems in open hole 17:00 - 20:45 3.75 CEMEN CIRC INTRM2 Circ and cond mud for cementing liner, circ at 2 bpm at 350 psi and reciprocated liner, st up wt 114K, dn wt 98K, MW 11.9 in & out and lowered YP from 30 to 20 and PV from 29 to 26 max gas 58 units, ave 20 units, circ with 85% returns, Held PJSM and batch mixed cement while circ 20:45 - 21 :00 0.25 CEMEN PUMP INTRM2 Turned over to Dowell, pumped 2 bbls water, tested lines to 4,000 psi, Pumped 10 bbls MudPush at 13.0 ppg at ave 2 bpm at 365 psi, pumped 10 bbls, 50 sxs of Gasblok cmt with additives including .34#/sx celloflake at 15.8 ppg and 1.17 yield, ave pump rate 1.75 bpm at 300 psi, shut down and washed up to rig floor 21 :00 - 21 :45 0.75 CEMEN DISP INTRM2 Dropped DP wiper plug and displaced cement with 11.9 ppg mud, ave pump rate of 2.5 bpm, initial press 250 psi, final press 460 psi, slowed pump rate to 1.5 bpm and saw LWP shear, bumped plug on calc displacement, press up to 3,500 psi, reciprocated liner until 3 bbls cement was out of shoe, bled off press and floats held, cemented liner with 70% returns, CIP at 21 :35 21 :45 - 22:00 0.25 CASE OTHR INTRM2 Set Baker 5 1/2" x 7" HMC Liner Hanger and CPH liner top packer per Baker procedure, tested seals to 1,000 psi and ck ok Landed 5 1/2" Liner with Float Shoe at 5,762', Float Collar at 5,677', Landing Collar at 5,635' and TOL at 5,533' 22:00 - 22:15 0.25 CEMEN CIRC INTRM2 Picked up and circ out from TOL, had 2 bbls of cement back at btms up, circ 1.5X ann cap, circ at 380 gpm, 2,200 psi 22:15 - 22:45 0.50 CEMEN RURD INTRM2 RD cement head and 1 single of DP 22:45 - 23:45 1.00 CEMEN CIRC INTRM2 Circ hole clean after cementing, circ at 380 gpm at 1,700 psi and reciprocated pipe, 11.9 mw in & out 23:45 - 00:00 0.25 DRILL OBSV INTRM2 Monitored Well - static NOTE: Lost 134 bbls mud while RIH, Circ & Cond Mud and Cementing liner 11/16/2003 00:00 . 04:00 4.00 DRILL TRIP INTRM2 Pumped dry job and POOH LD Baker Liner setting tool, cleared rig floor 04:00 - 04:15 0.25 LOG SFTY INTRM2 Held PJSM with Schlumberger and crew on RU E-line 04:15·07:15 3.00 LOG ELOG INTRM2 MU US IT logging tool & RIH on E-line, ran USIT log from 5,525' to Printed: 3/16/2004 10:42:50 AM Page 10 of 14 ConocoPhillips Alaska . Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/16/2003 Phase 1 Description of Operations ELOG INTRM2 4,200', POOH & RD wireline NOTE: Bond log showed 80% bond from 5,525' to 5,402' and 50% bond from 5,402' to 4,900' 2.25 DRILL PULD INTRM2 Fin LD 6 1/8" BHA #3, PU 43/4" spiral DC and broke out 6" stab's and LD same, RIH with 10 stds 4" HWDP & Jars, POOH LD, LD 1 std of flex dc's Changed out Top Drive saver sub, manual and hydraulic IBOP's Pulled wear bushing and installed test plug Tested BOPE, tested rams, valves and manifold to 250 psi low and 5,000 psi high, tested annular to 250 psi then 3,500 psi NOTE: Jeff Jones with AOGCC waived witnessing of test INTRM2 RU 3 1/8" pipe handling equipment and double stack tongs INTRM2 Began PU & MU 4 3/4" BHA #4 with PDC bit and 3 1/8" MM, TIH with BHA, PU 27/8" Spiral WT DP to 350' Fin PU 20 jts of 2 718" Spiral Wt DP on 4 3/4" BHA #4, RIH to 735' TIH with BHA #4 to 5,128' Held Stripping drill with rig crew TIH from 5,128' to 5,595', no problems at top of 5 1/2" liner Circ hole for csg test, 135 gpm at 1,100 psi with 11.4 ppg mud RU & tested 51/2" liner to 3,500 psi for 30 min, good test RIH & tagged plugs on landing collar at 5,632' (3' high) drilled out landing collar, drilled hard cmt to float collar at 5,675', cont to drill hard cmt to 5,757', tagging insert float, drilled hard cement from 5,716' to 5,757' with 2K wob, 40 rpm's, 145 gpm at 900 psi, rot wt 104K, up wt 112K, dn wt 94K, off btm torque 1 K ft-Ibs, on btm 2.5K ft-Ibs 1.50 DRILL CIRC INTRM2 Displaced out 11.5 ppg mud with 9.6 ppg mud and est SPR's with 9.6 ppg mud INTRM2 Monitored well 15 min and well flowing, Shut well in and had 6 bbl gain INTRM2 Monitored well and pressures stabilized with SIDPP at 380 psi and SICP at 760 psi INTRM2 Circ well thru choke using drillers method, circ at 20 spm at 880 psi DP press, max gas at 11 :00 hrs 3,300 units, cont to circ at 20 spm with 880 psi on DP, with 9.7 ppg mud, ave bgg 1,500 units and 9.7 mud gas cut to 8.5 ppg INTRM2 Cont to circ thru choke and drillers method, increased rate to 30 spm holding 1,010 psi on DP, BGG at 450 units with 9.7 mud gas cut to 9.5 ppg INTRM2 Shut in well and monitored pressures, SIDPP 330 psi, SICP 390 psi, calc KWM at 10.8 ppg INTRM2 Circ and raised MW in pits from 9.7 to 11.0 ppg INTRM2 Killed well pumping 11.0 ppg mud thru choke and kill rate schedule, max gas at btms up 3,300 units, circ 1.5x btms up after 11.0 ppg mud wt out and BGG down to 205 units 0.25 WELCT OBSV INTRM2 Shut down & shut well in, monitored 10 min with -0- SIDPP & -0- SICP, opened choke and monitored for 5 min with no flow, opened BOP's and monitored well for 5 min - static INTRM2 Circ btms up, at 125 gpm at 780 psi, max gas at btms up 175 units and decreased to 140 units INTRM2 Monitored well 10 min - static INTRM2 Circ btms up at 125 gpm at 850 psi, max gas 240 units, BGG decreased to 145 units with 11.0 ppg mud in & out INTRM2 Fin drilling up insert float at 5,757' and began drilling on float shoe at 5,758' with 3-5K wob, 100 rpm's, 145 gpm, 1,150 psi off btm, 1,450 psi 2P-432 2P-432 ROT - DRILLING Doyon Doyon 141 I Sub From - To I Hours Code Code 04:15 - 07:15 3.00 LOG 07:15 - 09:30 09:30 - 14:30 5.00 RIGMNT RSRV 14:30 - 15:00 0.50 DRILL OTHR 15:00 - 20:30 5.50 WELCT BOPE 20:30 - 21 :30 1.00 DRILL RIRD 21 :30 - 00:00 2.50 DRILL PULD 11/17/2003 00:00 - 01 :15 1.25 DRILL PULD 01 :15 - 03:00 1.75 DRILL TRIP 03:00 - 04:15 1.25 DRILL SFTY 04:15 - 04:30 0.25 DRILL TRIP 04:30 - 05:00 0.50 DRILL CIRC 05:00 - 06:15 1.25 CASE DEQT 06:15 - 08:00 1.75 CEMEN DSHO 08:00 - 09:30 09:30 - 09:45 09:45 - 10:30 0.25 DRILL 0.75 WELCT 13:00 - 15:15 10:30 - 13:00 2.50 WELCT 15:15 - 16:00 0.75 WELCT 16:00 - 18:00 18:00 - 20:45 2.00 WELCT 2.75 WELCT 20:45 - 21 :00 21 :00 - 21 :45 0.75 WELCT 21 :45 - 22:00 0.25 WELCT 22:00 - 23:00 1.00 WELCT 23:00 - 00:00 1.00 DRILL DRLG Start: Rig Release: Rig Number: 10/22/2003 11/23/2003 141 Spud Date: 11/1/2003 End: 11/23/2003 Group: INTRM2 INTRM2 INTRM2 INTRM2 INTRM2 INTRM2 INTRM2 INTRM2 INTRM2 INTRM2 Printed: 3/16/2004 10:42:50 AM Page 11 of 14 GonocoPhillips Alaska Operations Summary Report 1.00 DRILL DRLG INTRM2 on btm, off btm torque 2K ft-Ibs, on btm 3K ft-Ibs, rot wt 104K, pu wt 112K, dn wt 95K, ave BGG 110 units with no mud loss 0.50 DRILL DRLG INTRM2 Drilled out float shoe at 5,759' and drilled 3' of med cmt to 5,762', increased LCM f/6 ppb to 10 ppb and 11 .2 ppg MW, drilled with 3-5K wob 100 rpm's, 145 gpm at 1,100 off btm press, 1,400 psi on btm, ave BGG 110 units, rot wt 104K, pu wt 112K, dn wt 95K 0.25 DRILL OBSV INTRM2 Monitored well-static 0.50 DRILL CIRC INTRM2 Circ btms up, max gas 140 units and no gas cut, circ at 145 gpm at 1,000 psi, BGG ave 90 units prior to btms up 2.25 DRILL DRLG PROD Drilled new 43/4" hole from 5,762' to 5,783' MD, ADT 2 Hrs, 3-5K wob, 100 rpm's, 145 gpm off btm pressure 1,000 psi, on btm 1,400 psi with 11.2 ppg MW, BGG ave 55 units, began seeing mud losses of 35% after drilling 5,780', shut down & PU 2.75 DRILL CIRC PROD Monitored well-static, spotted 12 bbl, 40 ppb Icm pill in open hole, PU to shoe & circ at 125 gpm at 800 psi and lowered MW from 11.2 to 11.0 ppg and increased LCM from 10 ppb to 20 ppb, ave BGG 60-70 units, had conn gas of 240 units 10.75 DRILL DRLG PROD Drilled 4 3/4" hole from 5,783' to 5,881' MD/5,558 TVD, (98') ADT 9.7 Hrs, control drilled at 20'/hr ROP due to mud losses & ECD, 3-10K wob, slowed pump from 145 gpm to 85 gpm at 850 psi off btm, 1,000 psi on btm, rpm's to 50, increased LCM f/20 ppb to 25 ppb, initallosses ave 25-30%, slowing to 5-10% losses at 6-9 BPH loss at 2 BPM, Initial BGG at 5,783' ave 120 units, final BGG at 5,881 ave 20 units, conn gas 48 units, rot wt 108K, pu wt 115K dn wt 100K, off btm torque 2K ft-Ibs, on btm 2.5K ft-Ibs, penetration rate slowed to 3'/hr, calc ECD at 2 BPM at 11.95 ppg with 11.0 MW. Note: Checked 7" x 9 5/8" Ann and had -0- pressure Monitored well-static Pumped out of hole 5 stds to 5,408',20 spm, 84 gpm's, 650 psi at 30'/min Monitored well-static, pulled 5 stds on elevators and hole took proper fill, monitored well at 4,940' well-static, pumped dry job and cont POOH to BHA #4 to 735' Monitored well @ BHA-static, RU Tongs & POOH standing back 2 7/8" Spiral WT DP and LD 2-31/8" Flex DC's Calc fill on trip out 32.5 bbls, Actual fill 37 3/4 bbls LD bit #4, MU #5 on 3 1/8" MM Total Mud Lost to 4 3/4" hole last 24 Hrs 157 bbls PU MWD/LWD with gamma ray and resistivity, attempted to program tool with no communication between tools Baker worked on MWD/LWD tool, utilized 2 logging tools in different combinations in an attempt to get 1 to work, had no success in getting tools to communicate between connections Static losses to hole ave 1 bph MU Flex DC's and jars onto BHA #5 TIH with BHA #5 on 2 7/8" spiral wt & 4" DP to 5,685' (5 1/2" shoe at 5,762') Break circu & filled pipe at 2,800' Attempted to break circ and drill string was plugged, unable to clear DP Monitored well-static, POOH wet to BHA to 735', monitored well every 20 stds and at BHA -static RU Double stack tongs, POOH & stood back 2 7/8" spiral wt pipe, LD flex DC's Calc fill on trip out 32.5 bbls, Actual fill 41.75 bbls Date 2P-432 2P-432 ROT - DRILLING Doyon Doyon 141 Ii Sub I . From - To . Hours 'Code Code Phase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/17/2003 23:00 - 00:00 11/18/2003 00:00 - 00:30 00:30 - 00:45 00:45 - 01 :15 01:15 - 03:30 03:30 - 06:15 06:15 - 17:00 17:00 - 17:15 0.25 DRILL OBSV PROD 17:15-18:00 0.75 DRILL TRIP PROD 18:00 - 21:30 3.50 DRILL TRIP PROD 21 :30 - 23:30 2.00 DRILL TRIP PROD 23:30 - 00:00 0.50 DRILL TRIP PROD 11/19/2003 00:00 - 00:30 0.50 DRILL PULD PROD 00:30 - 06:30 6.00 DRILL DEQT PROD 06:30 - 07:15 0.75 DRILL PULD PROD 07:15 - 10:15 3.00 DRILL TRIP PROD 10:15-11:15 1.00 DRILL CIRC PROD 11:15-15:00 3.75 DRILL TRIP PROD 15:00 - 17:00 2.00 DRILL TRIP PROD Start: Rig Release: Rig Number: 10/22/2003 11 /23/2003 141 Spud Date: 11/1/2003 End: 11/23/2003 Group: Description of Operations Printed: 3/16/2004 10:42:50 AM .. ..... ConocoPhillips Alaska Page 12 of 14 Operations Summary Report Legal Well Name: 2P-432 Common Well Name: 2P-432 Spud Date: 11/1/2003 Event Name: ROT - DRILLING Start: 10/22/2003 End: 11/23/2003 Contractor Name: Doyon Rig Release: 11/23/2003 Group: Rig Name: Doyon 141 Rig Number: 141 Date From - To Hours Code Sub Phase Description of Operations Code -----------..---.---- 11/19/2003 17:00 - 17:45 0.75 DRILL PULD PROD Changed out mud motors and bits, MM plugged with LCM and bit was clear, ran Bit #6 with larger jets 17:45 - 18:30 0.75 DRILL PULD PROD MU BHA #6 and RIH with spiral wt DP to 735', RD double stack tongs 18:30 - 22:30 4.00 DRILL TRIP PROD TIH with BHA #6, circ a DP capacity every 10 stds W/RIH, Note isolated 1 pit with 6 ppb Icm to circ DP, TIH to 5,873' 22:30 - 23:30 1.00 DRILL CIRC PROD Washed last 100' to btm at 5,881', began pumping mud from active system with 25 ppb LCM while circ btms up, circ at 106 gpm at 825 psi and 40 rpm's, rot wt 106K, up wt 114K, dn wt 95K, max gas at btms up 525 units 23:30 - 00:00 0_50 DRILL DRLG PROD Drilled 4 3/4" hole from 5,881' to 5,887' MD/5,564' TVD, ADT .5 Hrs, 3-5K wpb, 60 rpm's, 114 gpm, off btm pressure 900 psi, on btm 1,050 psi, off btm torque 1 K ft-Ibs, on btm 2K ft-Ibs rot wt 106K, up wt 114K, dn wt 95K, ave BGG at 20 units Mud lost to hole last 24 hrs 92 bbls, Total losses to hole 249 bbls 11/20/2003 00:00 - 14:30 14.50 DRILL DRLG PROD Drilled 4 3/4" hole from 5,887' to 6,043' MD/5,710' TVD (156') (T.D.) ADT 13.7Hrs, 3-9K wOb, 60 rpm's, staged pump rate up to 150 gpm, off btm pressure 1,300 psi, on btm 1,400 psi, off btm torque 2.5K, on btm 2.5K, rot wt 105K, up wt 114K, dn wt 102K, ave BGG 10 units, ave mud loss 3 BPH with 11.0 ppg mud with 19 ppb LCM 14:30 - 15:15 0.75 DRILL CIRC PROD Circ btms up at 6,043' at 150 gpm at 1,000 psi 15:15 - 15:45 0.50 DRILL TRIP PROD Monitored well-static, POOH to 5,685' with no problems (51/2" shoe @ 5,762') 15:45 - 16:30 0.75 DRILL OBSV PROD Circ at 65 gpm at 375 psi monitoring for gains or losses, -0- gain or loss in 30 min, shut down & monitored well 1 0 min well-static 16:30 - 16:45 0.25 DRILL TRIP PROD TIH with no problems 16:45 - 17:30 0.75 DRILL CIRC PROD Circ btms up at 150 gpm at 1,050 psi, ave BGG 5-7 units, max gas at btms up 90 units with no mud loss and 11.0 ppg MW in & out 17:30 - 17:45 0.25 DRILL OBSV PROD Monitored well-static 17:45 - 21:45 4.00 DRILL TRIP PROD Pumped dry job, dropped 2 1/4" rabbit, POOH to Shoe, Monitored well at shoe-static, cont POOH monitoring well every 20 stds and hole taking over calc fill on trip out, POOH to BHA at 735' 21 :45 - 22:00 0.25 DRILL OBSV PROD Monitored well at BHA-static, RU double stack tongs for 27/8" DP 22:00 - 00:00 2.00 DRILL TRIP PROD POOH & stood back 2 7/8" spiral Wt DP and LD remainder of BHA #6 Calc fill on trip out 33 bbls, Actual fill 39 1/4 bbls Mud lost to hole last 24 hrs - 47 bbls, total losses to hole 296 Checked 7" x 9 5/8" annulus and had -0- pressure 11/21/2003 00:00 - 02:00 2.00 LOG RURD PROD Held PJSM with SWS & crew, RU E-line and MU Induction/Sonic/GR tool & calibrated same 02:00 - 04:30 2.50 LOG ELOG PROD RIH with logging tools, loggers TD, 6,037', logged well from 6,037' to 5,315', (2 passes) POOH, no problems in open hole 04:30 - 05:30 1.00 LOG RURD PROD RD logging tools & E-line 05:30 - 06:00 0.50 CASE RURD PROD RU Doyon's 3 1/2" liner running equipment 06:00 - 06:15 0.25 CASE SFTY PROD Held PJSM on running liner and hangerlpkr assembly 06:15 - 07:30 1.25 CASE PULR PROD MU 3 1/2" float shoe, 2 jts of 31/2" 9.3# L-80 STLH liner, float collar, 1 jt of 3 1/2" liner STLH, thread locked conn below landing collar, XO back to 31/2" Hydril and 2 jts 31/2" 9.3# L-80 Hydril 511, checked floats and ck ok, shut down 07:30 - 11 :30 4.00 LOG OTHR PROD Monitored well while geologist evaluated open hole logs 11 :30 - 14:30 3.00 CASE PULR PROD Cont to MU 3 1/2" liner, made up add. 9 jts of 3 1/2" 9.3# L-80 Hydril 511 and XO back to 31/2" STLH, MU Bakers 5" x 7" Flex Lock Hyd Hanger with ZXP Liner Top Pkr. Ran 14 Bow Spring centralizers on stop rings ,/ Printed: 3/16/2004 10:42:50 AM Page 13 of 14 ConocoPhillips Alaska Operations Summary Report 11/22/2003 00:00 - 01 :00 1.00 CEMEN CIRC PROD Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 ! I S b Date From - To Hours I Code I u Phase ,Code 11/21/2003 11 :30 - 14:30 3.00 CASE PULR PROD 14:30 - 19:30 5.00 CASE RUNL PROD 19:30 - 20:30 1.00 CASE CIRC PROD 20:30 - 21 :30 1.00 CASE RUNL PROD 21 :30 - 00:00 2.50 CEMEN CIRC PROD 01 :00 - 01 :30 0.50 CEMEN PUMP PROD 01 :30 - 02:45 1.25 CEMEN DISP PROD 02:45 - 03:45 1.00 CASE OTHR PROD 03:45 - 04:30 0.75 CEMEN CIRC PROD 04:30 - 05:45 1.25 CEMEN CIRC PROD 05:45 - 06:00 0.25 DRILL OBSV PROD 06:00 - 11 :00 5.00 DRILL PULD PROD 11 :00 - 13:00 2.00 DRILL PULD PROD 13:00 - 13:30 0.50 DRILL PULD PROD Start: Rig Release: Rig Number: Spud Date: 11/1/2003 End: 11/23/2003 Group: 10/22/2003 11/23/2003 141 .. .. Description of Opera.tions Total liner with float equip, 14 jts-3 1/2" 9.3# L-80 (3-jts SLHT, 11 jts Hydril 511) liner, XO's and hanger packer assmbly=599.33' RIH with liner on 4" DP to 5,467' with good pipe displacement Circ btms up above 5 1/2" liner top at 30 spm, 126 gpm at 430 psi, no gas or losses RIH with 3 1/2" liner to 6,000', MU cement head with single, est circ at 50 gpm at 375 psi, washed down 43' to btm with no problems, PU to liner setting depth of 6,038' Began circ and conditioning mud for cementing liner, staged pump rate up to 25 spm, 105gpm at 500 psi with very little mud loss after est eire, then stablized to -0- losses, reciprocating liner with 120K up wt and 95K dn wt, max gas at btms up 33 units, ave BGG 7 units Mud lost to hole last 24 hrs 20 bbls, Total mud lost to hole 316 bbls Fin circ & cond mud for cmtg liner, circ at 126 gpm at 600 psi, reciprocated liner with 122K up wt and 1 OOK dn wt, lowered YP from 20 to 15 with 11.0 ppg mud in & out, no mud loss and ave BGG 7 units, Held PJSM with Cmtrs, vac truck drivers and rig crew and batch mixed cement while circ hole Dowell pumped 2 bbls FW, tested lines to 4,500 psi, then pumped 20 bbls of 12.0 ppg MUDPUSH XL at 2.5 bpm at 500 psi, 15 bbls, 72 sxs of class "G" cmt with additives including celloflake and cemnet LCM add's. at 15.8 ppg and 1.17 yield, ave 2.5 bpm at 500 psi, reciprocated liner, shut down and washed up to rig floor Dropped wiper plug and followed with 10 bbls of 8.5 ppg perf. pill and 10.4 ppg mud, ave rate 3 bpm, initial press 525 psi, max press at 3 bpm 1,000 psi, slowed to 2.5 bpm max press 1,200 psi and after pumping 61.5 bbls, calc displacement saw 250 psi increase then press dropped off, pumped add 1/2 bbl and never saw any press increase, shut down at 02:00 hrs, check floats & held, bled back 1/2 bbl, attempted to re-pressure up and had no press after .75 bbls, shut down, began pumping and after 34 strokes, bumped plug to 1,650 psi, reciprocated pipe until 3 bbls cmt was out of shoe, had full returns during cmt job, CIP at 02:00 hrs Pressured up to 2,900 psi to set 5" x 7" Flex Lock Hyd Double Grip Hanger, bled off staged pump press up to 4,350 psi in attempting to shear off hanger with no success, used left hand torque to release from hanger, PU from hanger and set 40K down on ZXP liner top pkr and set same, press up 500 while PU and cleared top of liner, St wt after setting liner 11 OK up, 95K dn. Landed 31/2" Liner with TOL at 5,439', Landing Collar at 5,938' and Shoe at 6,038' Circ out after cement job, at btms up circ out 25 bbls of cement contaminated mud, max wt out 11.6 ppg, circ 1 add btms up to clean up well, circ at 380 gpm at 2,000 psi and reciprocated pipe Displaced out 11.0 ppg mud in well over to 8.5 ppg seawater, circ 2.5X hole volume with clean seawater out, circ at 380 gpm at 1,525 psi Monitored well with seawater in hole for 15 min-static UD Baker Cmt head. POOH LD 4" DP ( 174 jts.) Broke out & LD Baker running tool and cement head, Clean tools from rig floor TIH with 10 stds 2 7/8" spiral wt drill pipe and POOH LD same Pulled wear bushing Printed: 3/16/2004 10:42:50 AM ... ..... GonocoPhillips Alaska Page 14 of 14 Operations Summary Report Legal Well Name: 2P-432 Common Well Name: 2P-432 Spud Date: 11/1/2003 Event Name: ROT - DRILLING Start: 10/22/2003 End: 11/23/2003 Contractor Name: Doyon Rig Release: 11 /23/2003 Group: Rig Name: Doyon 141 Rig Number: 141 Date From - To Hours Code 5ou~e I Phase I Description of Operations ¡ - 11122/2003 13:30 - 14:00 0.50 CMPL TN RURD CMPL TN RU Doyon's 3 1/2" tbg handling equipment and held PJSM on running completion 14:00 - 19:30 5.50 CMPL TN TRIP CMPL TN Ran 3 1/2" completion per well plan to top of 31/2" liner at 5,439', MU seal assembly wlspace out pups and No-Go, 1 it 3 1/2" tbg, Cameo "D" Nipple, CMU Sliding sleeve with "DS" profile with pup jts, 1 it of 3 1/2" tbg,3 1/2" x 1" KBG 2-9 GLM with pups above & below and "DS" nipple, Ran 3 1/2" 9.3# L-80 EUE 8rd Mod Tbg with ave MU of 2,400 ft-Ibs, st up wt 77K, dn wt 72K 19:30 - 20:30 1.00 CMPL TN CIRC CMPL TN Circ hole clean with new seawater from TOL, circ at 294 gpm at 700 psi 20:30 - 22:45 2.25 CMPL TN SOHO CMPL TN Est circ at TOL and located SBE, spaced out 3 1/2" completion, Began to MU hanger and threads on pin end of pup it galled, LD Hanger and MU back-up, verified space out and landed tbg in hanger and RILDS. String wt when landed 72K with 35K block wt. Landed 3 1/2" tbg 2' above No-Go at 5,445', "D" nipple at 5,401', CMU sliding sleeve at 5,384', Cameo KBG GLM at 5,334' and "DS" nipple at 508', Ran a total of 171 its 5,345.08' of 31/2" tbg 22:45 - 23:45 1.00 CMPL TN DEOT CMPL TN RU & tested 3 1/2" tbg to 3,500 psi for 30 min, good test, bled pressure to 1,500 psi 23:45 - 00:00 0.25 CMPL TN DEOT CMPL TN RU & preparing to test 3 1/2" x 7" annulus to 3,500 psi 11/23/2003 00:00 - 00:45 0.75 CASE MIT CMPL TN Test Csg - Test 7" X 3.5" Ann. to 3500 psi and chart for 30 min. Lost 70 psi. Bleed pressure off Tbg and shear RP valve. 00:45 - 01:15 0.50 CASE RURD CMPL TN UD landing jt - Set TWC 01:15 - 02:00 0.75 CMPL TN NUND CMPL TN NID BOPE 02:00 - 03:30 1.50 CMPL TN NUND CMPL TN N/U Tree - WKM tree asssy on FMC 3.125" X 11" tbg head adapter. Test adapter void to 5000 psi - Hold 15 min. Test tree 250 psi 15000 K for 10 min. 03:30 - 04:30 1.00 CMPL TN FRZP CMPL TN R/U Hot Oil to 7" X 3.5" Ann. - Pump 80 bbls diesel- PR 1.8 bpm @ 1500 psi. Put Tbg & Ann in communication and let fluid U-tube 04:30 - 06:30 2.00 CMPL TN FRZP CMPL TN Preform LOT on 9.625" X 7" Ann. - Pump 3.8 bbls, 11.0 ppg mud had leak off @ 620 psi for a 14.6 ppg EMW LOT, Pumped 120 bbls water to flush annulus, freeze protect with 52 bbls diesel. (1848' MD) 06:30 - 07:00 0.50 WELLSR NUND CMPL TN FMC R/U & Set BPV wI lubricator 07:00 - 07:30 0.50 WELLSF NUND CMPL TN Secure Tree & Well Head - Clean Cellar area 07:30 - 08:00 0.50 WELLSF OTHR CMPL TN Fin cleaning rock washer & pits **Release Rig 0800 hrs 11/23/03** to move to 2P-434 Printed: 3/16/2004 10:42:50 AM Date 10/31/03 12/23/03 01/03/04 01/08/04 01/27/04 01/27/04 01/28/04 01/29/04 01/29/04 01/30104 01/31/04 01/31/04 02/04/04 02/24/04 02/27/04 . 2P-432 Operations Summary . Summary GYRO SURVEY FOR RIG. TAGGED FILL @ 5934' RKB, EST. 84' BELOW PROPOSED PERFS. REPLACED SHEARED SOV WI DV @ 5401' RKB. TESTED TBG & IIA TO 2000 PSI, OK. DRIFTED TBG TO 5928' RKB WI 24' X 2.60" DUMMY GUN.O [Tag, PT Tbg-Csg] PERFORATED: 5838'-5850', 6 SPF -- STUCK 2ND GUN AT 2092' WHILE RIH, to" PROBABLY DUE TO AN ICE SHEATH, UNABLE TO GET FREE. TAG E-LlNE TOOL STRING @ 2078' SLM. RETRIEVED A SAMPLE OF HYDRATES. GET CLEAN IMPRESSION OF FIN WI LlB.O [Fish] PUMP NEAT METH AND HOT DIESEL ON TOP OF FISH AT 2085'CTMD PRESURED WHP UP TO 3500PSI HELD TIGHT RID LET SLICK LINE ATTEMPT TO FISHO [Hydrates-Ice] ATTEMPTED FISH PERF GUN @ 2076' WL. JARRED TO 1600 LBS, NO MOVEMENT. LEFT BAIT SUB ASS'Y ON FISH.O [Fish] JETTED 980 BARRELS OF 160 DEGREE HOT SEAWATER ACROSS TOP OF FISH NO SIGN OF FISH MOVINGo [Hydrates-Ice] 1700 TOTAL BARRELS OF 160 DEGREE WATER PUMPED ACROSS TOP OF FISH TAGGED FISH AT 2082.6 CTMD FISH DIDN'T MOVE THE ENTIRE JOB WELL WAS LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL.o [Hydrates-Ice] ATTEMPTED FISH PERF GUN @ 2076' WL. JARRED TO 1750 LBS, NO MOVEMENT. RECOVERED BAIT SUB ASS'Y.O [ Fish] PUMP 3800BBL HOT SEAWATER ON TOP OF STUCK PERF GUNS AT2075'CTMDo [Hydrates-Ice] PUMPED 4000 TOTAL BBLS ACROSS TOP OF FISH NO CHANGE WELL LEFT SHUT IN WITH 100% METH IN WELLBOREo [Fish, Hydrates-Ice] LATCH FISH @ 2076' SLM. JAR UP @ 1500# TO 1700# LICKS. NO MOVEMENT.O [Fish] PRESSURED UP ON TOP OF FISH AND ATTEMPT TO MOVE FISH DOWNHOLE. FOUND TOP OF FISH @ 2084' WLM, TAP DOWN 20 MIN (NO MOVEMENT). PRESSURE HOLDING. 0 [Tag] ATTEMPTED TO WASH OVER STUCK PERF GUNS @ 2,075' CTMD. WAS ABLE TO WASH OVER TO 2,097.3' CTMD UTILIZING 290 BBLS OF 60/40 METH @ 110 DEG. RELEASE COIL UNIT AND TANK FARM FOR DOYON 141 MOVE.O [Hydrates-Ice] WASHED OVER FISH TO 2,106.5' CTMD. BULLHEADED THIRTY BBLS OF DIESEL INTO THE FORMATION. UNABLE TO DUPLICATE THIS INJECTION. PREP TO FISH GUNS WITH COIL ON 2-28-04. WELL FREEZE PROTECTED WITH DIESEL.O [Hydrates-Ice] 02/28/04 02/28/04 02/29/04 03/01/04 03/02/04 03/04/04 03/09/04 03/14/04 . 2P-432 Operations Summary . SET BAIT SUB FOR CTU @ 2082' SLM. UTILIZED WIRELlNE TO BAIT THE TOP OF SWS PERFORATING TOOLS. PULLED 6,500# OVER STRING WT TO FREE GUNS. PULLED TOOLS TO SURFACE AND PERFORMED A SWAB CHECK. SWAB CHECK CONFIRMED GUNS ACROSS TREE. RUN TOOLS BACK INTO WELL AND DROPED OFF AT 2,89.6' CTMD. RECOVERED PERF GUN @ 2106' SLM. DRIFTED TBG W/ 24' X 2.5" DUMMY GUN TO 5924' RKB. NO OBSTRUCTIONS. PERFORMED AN ICE EXTRACTION TO 2,636' CTMD. CIRCULATED TO SURFACE ALL RETURNS. BULL HEADED 60/40 METH AFTER BREAKING THROUGH.[Vortech, Hydrates-Ice] PERFORATED: 5778'-5798' AND 5806'-5826, 6 SPF POWERJET. D [Perf] TAG W/ 2.55 CENT AT 5898' SLM /5926' RKB. SAMPLE OF MUD. RAN SDI GYRO FROM 5892' SLM / 5920' RKB TO SURFACE. OBTAINED GOOD DATA FROM GYRO. JOB COMPLETED ,/ MITIA initial State Witnessed (John Crisp) - Passed [ANN COM ISSUES, WH Maintenance] TUBING (0-5484, OD:3.500, 10:2.992) ¡I[ BACK (543U·5450. OD:5.7110 BlJS!-iI, G {54/!i'I-f,4!J!I. OJ:f,.Ii~ii\ Conoc:oPhilHps Alaska,lnc" · 2P-432 ~ I S --"r . . KRU 2P-432 API: 501032042000 SSSV Type: NIPPLE Rev Reason: Tag, set DMY, PERF Last U date: 3m2004 Annular Fluid: Reference Lo : 28' RKB Last Ta : 5934 Last Ta Date: 12/23/2003 Casing String : ~L,L ~TRIN§~___. .m ,DescriP~~~DUCTOR : 1:~~gO T~P -T-B~~.~m. J' ..-~~ --~¡.---6f.~Ö- . ~~~e--~, ~~éba:D _ .I... SURFA.CE.nn.---- --!Ü25 0 2449 I 2372 40.00" L-80 I BTC · .... PRO~~~~.IO~ _.._.._ ...i_.......~.:~~~.._.___~.._§~~59___..__.....~~~L _:. ......;~~~ -··-29~30~": "~~~rl5~~~~d~! TlJbina Strina...:...!¥ê!.~G___.._._____._...._._ -T---------i :----r~zöÒ_--..I-..---.T.~P. . .. - :--·-~~:~4m I· .. ~~~---r_-"9~~.........!.....ºt~~e. EU~~~e~~OD ____ _._..______1.._.____..____. _ .. !pe4~~~~~!!-ª~lI!mªfvD--m--r-zone·-..· ..._.._n. _1--"'" r . I 5778 _ 5798 . 5462 _ 5481 i' . .. Sté!tl!.S. '-~~'I ~.~~: 3~~~~~0_4... ~~t~F I: ~~~~~ HSCDO~J~~t60 deg'- 5806'- -5å26-...·--S48!!'=5'5ëf7"--- : 20 : 6 3/4/2004: APERF 2-7/8" HSD PJDP. 60 deg r 5838="5860 5518 - 5539 : 22 ! 6 1/3i2004-':'-ipEF~'F l ~~~~~-H-SÖ PJD~,_~~.~~ Gas Lift MandrelsNalves St ! MD I TVD Man I Man Type V Mfr !- V Type I V aD : Latch I Port ,TRO ~ -I' Vlv , ; Mfr .: .L_..L._ ~un ! Cmnt · 1 . 5335: 5047 CAMCO: KBG-2-9 DMY ; 1.0 . BTM : 0.000 I 0 :12/23/2093 · Other (plugs, e1quip., ~tc.) -IJEWELRY . _ . .. _ _ .. ..... .._._ _...._n__..___....... . : Depth . TVD ~ Type ; Description i 15 ; 15 : HANGER ; FMC GEN V TUBING HANGER ¡ 508 : 508: NIP 'CAMCO 'DS' LANDING NO GO NIPPLE : 5384 : 5093 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED : 5401 5109 NIP CAMCO 'D' NO GO NIPPLE :. 5_445. : 5150 :_L9C~!.@_:_~º-Çð!...Q.R_SU-ª-L~_O-G9~!::!º~.~P_EI3L__.___. ... .... i 5448 : 5153 PUP 8-40 SPACER PUPS i 5474 . 5177 SEAL GBH-22 SEAL ASSEMBLY W!80-40 SEALS AND 1ti' MUCË-·SHÕE---- ~ Other (p'lugs,..e:qlJ~p.,. ~ç.J..-.:L!NER. ~.E.\IY_~'=-I3Y __ _..._ ______ no_n.... . . ..m .- ..--.. ....-- : _~~~~h.: ~~ I:· TI:~eCK : LINE'R TiE BACK SLEEVE W!Nge~Ö~~o;HË B'Õ'TTOM . ~~50. _ 5.1~5 PAC~~B_'I.ZXP._.hINE.R PACKER WITH HR..PI39.FI~_E._.__ 5458 5162 I NIP RS NIPPLE n_~460 _.?1~4_L!- A~~ê'!....T¡~_~~LL=-º-G!<_!!XPRAULlC DOU~.~_~..G.B.!!:.LlN.!~~.Hf.NGER .. _ ......._ 5470 5173! SBE SEAL BORE EXTENSION 80-40 · 5489 . 5191 : BUSHING ! CROSSOVER BUSHING . . . -. .. -. .- . -.. -.- -"""'5939-'. 5613 : COLLAR--rsofT.ANDiNG COLLAR _____m__........ --.-..... 5971 : 5643' SHOE I ŠÕTFLOA T SHOE -G-ëñ~rã¡·Nõtii!¡-~.=-=~.=.~·-"---" Date Note 1122/2003 TREE: FMC 1 GEN V I WKM 3 1/8" 15K TREE CAP CONNECTION: OTIS 3" _____ ___ ._____n ID 3.500 2.812 2.810 2.750 3.000 3.000 3.000 ID 5.250.._ 4.370 4.250_ _ 4.410 4.000 3.000 3.000 2.980 -------------.... ...-..... ...... .... ..... .. ....-----..--- r' i 'H j ¡ ! i .... ¡ I t··.. L._ I. ¡ ¡..n_. l ; . . _...k.........._.___----...J H' , .,i (§o~ -oq \ ConocoPhillips Alasklc.,Slot #432 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LI.G Page 1 Wellbore: 432 Wellpath: MWD <0-6043'> Date Printed: 11-Dec-2003 "~i. BAKER HUGHES INTEQ 1~lIbQre 432 I Created 2-Nov-2003 I Last Revised 2-Dec-2003 I Well ~:;e I Govemment ID I ~~~~~:~~~~ Slot Name North Drill Site 2P 5869891.466 AK-4 on NORTH AMERICAN DATUM 1927 datum True Installation 1f:'1IIId :ater I Eastino I Northino 441964 238 I~~~ 1__ I :698914:< .. · ·</R ... · FRIC"NDA~~,J:m ... ·\>T:,e Creatéd:¡ Comments RECEIVED JAN 2 3 2004 Alaska Oil & Gas Cons. Commission Ancnorage All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 194.29 degrees Bottom hole distance is 1792.25 Feet on azimuth 194.29 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~~~'D Ù\ ~~ ConocoPhillips Alasklc.,Slot #432 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY U.G Page 2 Well bore: 432 Wellpath: MWD <0-6043'> Date Printed: 11-Dec-2003 r'¡. BAKER HUGHES INTEQ Wellpatf1CGrid' Report MD[ft] Inc{deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing dea/100ftl Sectionfftl oor 000 oor oor 0001\ OOOF oor o or ~c. ,? 108.0( 0.00 o or 10R O( n 00" 0001: o or o fir A '~n'" .,. .,.n~nn~'1 ? 170.0( 0.34 160.2 170.0( 0.171' 0.06E 0.5~ 0.1~ 443854.5 5868930.0 260.0( 0.11 2748: 2600( 04?!' 0071' 0.1L1 ~ --:;-~~, ,71 387.1 0.24 130.2' '<R7 l' o I;R<: 011;1' o ?F o I;~ A ...,n.,. ~ ,R' 478.6! 0.19 251.0 478.6! 0.751' 0.15E 0.41 0.6~ 443854.6 5868929.4 570.51 0.14 182.31 570.51 OJI1!' 0001' o ?1 n¡:¡s ~~. ~n~nnn'1 ?I 658.9! o Oq '<I; 1 I;~ RI;R QI O.QI;<: o 01IA o ?F O.Q' 44'<RI;.1.1' c."""0')Q.2: 748.7 0.98 192.9 748.7 1.631' 0.20V\ 1.1S 1.6 443854.3 5868928.5 839.9' 2.19 192.9: R,<Q Q( .10Q<: o 7RIA 1.'<0 d1< 4.d;;¡Ri:;~ 7 c.,,""o,)" 1 Q30,!,1 !'i.7Q 1QR '" Q303( 10 1?~ 2.ROIA '< QÇ 10.1, 44'<R!'i1.R 5868920.1 1019.1 7.79 198.9 1018.2 20.03( 5.97'^ 2.2F 20.8 443848.3 5868910.2 111 R 3: R.QA 1Q!'i.4 111R ,<' '<'< R,<~ 1 O.?1 IA 1.?C '<1;'<1 .1.1'<R.44.0. 5868896.4 1 ?11m 10.1F 1Q!'i.!'i~ 1 ?07 8. 4RRR~ 14.3?IA 1.2Ç !'i0 7' 443R3Q R !'iRARRR 1.A. 1304.1 11.3C 200.2 1299.3 65.15~ 19.67IA 1.5<1 67.9 443834.3 5868865.2 13QA R: 134.1 1 QQ ?~ 1,<RQ R' R'< R.1~ ?R ,<7IA ? '<~ R77< "",>"')71':' 1':"""""" 1':' 14Q01: 16Rf 1QR ?~ 147Q R~ 107 O!'i~ 33 7?IA 37F 11? Of 1':""""?'>.1' 1582.4 19.3~ 188.0 1567.5 135.08~ 39.60IA 3.8F 140.6 443813.9 5868795.4 1R74 R~ ?1 !'iï 1Q? !'iC 1R!'i411 1 RR R!'i~ d!'i ddIA ? Q< 17? Q( dd,<R07 R, 1':"""7"'> 7 17RRO, 224~ 1Q3 R¿ 1740!'i1 ?OOR?~ !'i3 43IA 10f ?07 R( I':A"A7?0 AI 1860.9 22.3f 191.1 f 1826.4 235.36~ 61.09IA 1.0Ç 243.1~ 443791.6 5868695.3 1 Q!'i4 (ù ?? ?r 1Q07' 1Q1? R' ?70 O?~ R7 ROIA n ?< ?7R d( 1':"""""07 ?04R'" 217ï 1Q4 Qf 1 QQR 3~ 30377~ 7!'i 4RIA 177 3130( 4 1':""A"?70, 2139.2 21.6 197.0 2084.5 336.74~ 84.93IA 0.8 347.2f 443767.1 5868594.1 2232 R~ ?13Ç 1QQ R~ 2171.4 3RQ.21!' Q!'i.7RIA 1 1 < '<R1.4 44'<7!'iR()' 5868561.7· 2325.2' 22.1.1 1QORf ??!'i74 402.2?!' 104.7RII' 37r 41!'i.R.1 44374R.7 I':A"AI':?A A 2387.9 22.3S 189.7 2315.4 425.62!' 109.0411' 0.7f 439.3f 443742.3- 5868505.4 ?4QQ 4! ?13F 1Q1.!'i~ ?41 R.Q~ 4RR.4!'i!' Hi:;' 10Ç 4RO.R~ 44'<7'«1 '<I I':A""A"" ", 2593.7: 21.1r 1 Q2.3~ 2!'iOR.8' 499RR!' :;:i '!-II 0.41 !'i14.Qf .1.1'>7?70, !'iRRR4313: 2686.0 20.9 192.1 < 2592.9 532.211' 130.8111' 0.2C 548.0 443719.8 5868399.0 ?7RO!'i1 ?14f 1Q? 3~ ?RR 1 1( !'iR!'i R1!' o !'iF !'iR? 1f .4.4'<71? 31 I':""A'>"I': '" 2873.1: 22.2:: 193 Of 27R7.0: I;QQ ?1<: OAF ~ ~ I':ARA'<'<? 1: 2966.9 22.2 195.7< 2853.8 633.611' 154.4711' 1.0f 652.1 443695.3 5868297.8 30ROO' 22.1' 1Q73~ ?9400: RR7?Q~ A~A An.. OflF "A7 ?< .1.1'<"AI': l' I':A"A?"" ? 3153.8 ?17' 1Q77' ,<n?7 n. 70n RQ~ 0.1· 7??7 "".,':'7A '> 3246.2 21.51 197.6 3112.9 733.16~ 185.41V 0.2 756.2' 443663.7 5868198.5 3338.7 21.21 1Q71;C ,<1QQO' 7RI; ?Q~ n?$ 7ROA( -A~.,,;, c."""."" '«131 !'i: ?1 !'i' 1QO !'i ,<?R!'i!'il 7QR OR~ ? 7C R?,<RS AA'>"A" '" .,..,~.,.".., 7 3524.8 22.1' 192.0 3372.1 832.07~ 210.56V 0.9( 858.2! 443637.8. 5868099.8 3618.n ?? 7! 1Q? R' '«I!'iR ?I RRR.R7~ ?1R 17\1 o 7¿ ·ACI<¡.Q( 44,<R?Q Q' .,..,~nn~.,. n 3710 ?: ??31 1Q? 1 3!'i43.3' Q01 .4'<~ :;"... (Ii' o !'i: Q?Q ?~ 44,<R?? 1 3803.3 23.2 194.3- 3629.2 936.54~ 234.03V 1.3 965.3 443613.6 5867995.5 3RQR.4 ?? RI 1Q.4 '<: 3714 Q: Q71 RR~ ?4'<0!'iV n '<~ 1001 RI 4A'>"OA '>, 3Q890' 228' 1Q371 3800 ?I 1 OOR 7R~ ?!'i1.7RV O.?! 1 037 7! 443!'iQ!'i 3. c.0l>7n",c.4 4084.0 22.6 194.5! 3887.9 1042.34~ 260.75V 0.3 1074.4- 443586.1 5867889.9 417R 01 ???' 1 Q.4 R< 3Q7? R' 1 07R ?!'i~ O,d 110Q !'il 44,<!'i7R Q' .,.0l>70£:.I> n 4?RR !'i: ?1Q.< 1Q.4 R! 40!'iR RI 110Q RR~ o ?! 11.01.01 ?' dd,<!'iR7 R 4360.6 21.5C 194.7 4144.2 1142.83~ 287.2611' 0.41 1178.3 443558.8 5867789.6 44!'i33' ?14Ç 1Q.4 0' d?,<Od' 117!'i 7,<~ n ?C 1?1? ... .1.1'<!'i!'i0 l' .,..,I>77£:.I> 0 4!'i470' ?1R~ 1Q471 4317 R' o 3~ 1 ?dR 71 AA'<I':A1 ,<, £:..,1>77"," !'i 4638.3 21.9S 194.3 4402.'« 1241.89~ 312.75\11 0.4 1280.6 443532ß: 5867690.7 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 194.29 degrees Bottom hole distance is 1792.25 Feet on azimuth 194.29 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocoPhillips Alasktco,Slot #432 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY LI.G Page 3 Well bore: 432 Well path: MWD <0-6043'> Date Printed: 11-Dec-2003 ,,¡¡. 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 ( Actual Datum 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 194.29 degrees Bottom hole distance is 1792.25 Feet on azimuth 194.29 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocoPhillips Alas~c.,slot #432 Drill Site 2P, Meltwater,North Slope, Alaska SURVEY U.G Page 4 Well bore: 432 Well path: MWD <0-6043'> Date Printed: 11-Dec-2003 "~i. 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 ( Actual Datum 252.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 194.29 degrees Bottom hole distance is 1792.25 Feet on azimuth 194.29 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated TIE BACK (5439-5450 OD5.760) KRU 2P-432 Descri tion MC GEN V TUBING HANGER CAMCO 'OS' LANDING NO GO NIPPLE BAKER CMU SLIDING SLEEVE - CLOSED CAMCO '0' NO GO NIPPLE LOCATOR SUB NO-GO SHOULDER 8-40 SPACER PUPS GBH-22 SEAL ASSEMBLY W180-40 SEALS AND 112" MULE SHOE Descri tion LINER TIE BACK SLEEVE WINO GO AT THE BOTTOM ZXP LINER PACKER WITH HR PROFILE RS NIPPLE FLEX-LOCK HYDRAULIC DOUBLE GRIP LINER HANGER SEAL BORE EXTENSION 80-40 CROSSOVER BUSHING BOT LANDING COLLAR BOT FLOAT SHOE ID 5.250 4.370 4.250 4.410 4.000 3.000 3.000 2.980 Note TREE FMC I GEN V I WKM 3 118" 15K TREE CAP CONNECTION OTIS 3" BUSHING (5489-5490. OD5.o20) Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING ._'..~-_... .--..-....--.---.------- String Type: Surface Casing Hole TVD: 2,377.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 3.00 (hr) Manufacturer: FMC Hanger Model: Actual TMD Set: 2,449.49 (ft) Item Casing Hanger Casing Casing - Pup Jt Casing Float Collar Casing Float Shoe Bowspring Centralizer ._-'...... ..--.......,. ..--. ... ... ..-... -.. -. Size . Weight . Grade (in.) (Ib/ft); 9.625 40.00 L-80 9.625 40.00 L-80 9.625 40.00 L-80 9.625 40.00 L-80 9.625 9.625 40.00 L-80 9.625 Accessory Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Drift i Threads (in) ! 8.679 8.679 BTC 8.679 BTC 8.679 BTC 8.679 BTC Manufacturer I ~~ATHE~FOR? .._. Page 1 of 2 GonocoPhillips Alaska Casi ng Report ------ Report #: Start: Spud Date: 11/1/2003 Report Date: 11/2/2003 End: 11/23/2003 1 10/22/2003 ---- General Information Hole Size: Water TMD: Liner Overlap: KB to Cutoff: 12.250 (in) (ft) (ft) 28.11 (ft) 2,454.0 (ft) 121 (Ibs) 22.43 (0) 4.00 (days) KB (atdb) 224.00 (ft) (ft) (bbl) Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: Casing Flange I Wellhead Model: Gen V Packoff Model: Top Hub/Flange: (in) I 5,000 (psi) BTM Hub/Flange: (in) I 5,000 (psi) Integral Casing Detail JTS: Length : (ft) , 1 3.50 23 957.05 1 15.13 32 1,356.73 1 1.50 2 85.77 1 1.70 .. -......,-............. . . "r ... - ......-.-.-.... --. . .... - ...-.-........ . ... .. -.-----...-- .. . ...--.-.,-...... Top (ft) :MU Torq. THD¡ Manufacturer (ft-Ibf), i Condo ¡Max OD. Min ID Compo Name ¡ (in) : (in) Model 28.11 31.61 988.66 1,003.79 2,360.52 2,362.02 2,447.79 2,449.49 Casing Hanger 8.835 9 5/8" 40# L-80 8.835 9 5/8" 40# L-80 8.835 9 5/8" 40# L-80 Float Collar 8.835 95/8" 40# L-8 Float Shoe Non-Integral Casing Accessories Number How Fixed Spacing (ft) Interval Top (ft) . 1,683.0 L.. Bottom (ft) :~~5.0 I Over~~~~a.r 191 Remarks Rig & ran 9-5/8" Float shoe, 2 jts 9-5/8", 40#, L-80, BTC csg, Float collar, 32 jts 9-5/8", 40#, L-80, BTC csg, 9-5/8" PUP jl., 23 jts. 9-5/8",40#, L-80, BTC csg., Placed centralizers 1-5' above shoe on stop collar and 1-5' above float collar on stop collar, and 1 on evert joint from shoe to joint # 18 for a total of 19 centralizers. Printed: 2/3/2004 10:14:25 AM ConQcoPhillips Alaska Casi ng Report Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Report #: Start: .-.----..--..-.--.---..----.------.- Remarks -.... --------- Casing ran in hole fine with very little trouble, Landed casing with shoe at 2449.49' and float collar at 2360.52' 'Page 2 of 2 1 10/22/2003 Spud Date: 11/1/2003 Report Date: 11/2/2003 End: 11/23/2003 Printed: 2/312004 10: 1 4:25 AM GonocoPhillips Alaska Page 1 of 3 Cementing Report Legal Well Name: 2P-432 Spud Date: 11/1/2003 Common Well Name: 2P-432 Report #: 1 Report Date: 11/2/2003 Event Name: ROT - DRILLING Start: 10/22/2003 End: 11/23/2003 Cement Job Type: Primary ......... - ----.-.. --.. ---------------....---....... .-. ... ..-.-.-----.-------..---- ....---...-.- .._. . . ...-.-----....-.....-..... ....-..-- ... ._n_.___. P!i.r:n~_I}I__._..__.__._...._..._._._'.. _. _ _ ... Squeeze Open Hole ___...._...._...._._......__._.........Squeeze Casing ... .--.......................... . Plug. __ _ _._. . Hole Size: 12.250 (in) Hole Size: Hole Size: . Hole Size: TMD Set: 2,449 (ft) sa TMD: (ft) ¡ TMD Set: Top Set: (ft) Date Set: 11/212003 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 9.625 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: ; Cmtd. Csg: Cmtd. Csg: _.... ...u __... . ...-.-... ... .. ... . - ..--.. .... Cement Co: Dowell Schlumberger Cementer: Jerry Culpepper Pipe Movement: Reciprocating .. --.- . .. n .._.___ .. - .-...... ...- Pipe Movement . ..-.-.- ..--..........--......-..--.-..................... .. ...__..............._.. _n. .. . ----.-.......-. ......... . n..__... Rot Time Start: : Time End: RPM: Init Torque: (ft-Ibf) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Rec Time Start:01 :30 Time End: 06:35 SPM: 1 Stroke Length: 15.0 (ft) Drag Up: 121,000 (Ibs) Drag Down: 106.000 (Ibs) - .... . .. . .. .. Stage No: 1 of 1 .. _.... .. -... Type: Cement Casing Start Mix Cmt: 05:22 Disp Avg Rate: 7.00 (bbllmin) Returns: FULL Volume Excess %: Start Slurry Displ: 06:37 Disp Max Rate: 7.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: 188 Start Displ: 06:37 Bump Plug: Y Cmt Vol to Surf: 188.00 (bbl) Time Circ Prior . End Pumping: 07:05 Press Prior: 600 (psi) To Cementing: 3.00 End Pump Date: 11/2/2003 Press Bumped: 1,150 (psi) Ann Flow After: N Mud Circ Rate: 252 (gpm) Top Plug: Y . Press Held: 5 (min) Mixing Method: On fly Mud Circ Press: 250 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Desometer . .n__. . .._.. . n_ on. _._ Mud Data . __..... _._. . ._n .._ ...... .._. . .. .. ....... .... .. ...-...... ..-.--... Type: Spud Mud Density: 8.9 (ppg) Vise: 40 (s/qt) PVIYP: 12 (cp)/8 (lb/10OfF) Gels 10 see: 6 (lb/100fF) Gels 10 min: 8 (lb/100ft2) Bottom Hole Circulating Temperature: ("F) Bottom Hole Static Temperature: ("F) Displacement Fluid Type:Mud Density: 8.9 (ppg) Volume: 178.80 (bbl) ..... .-..... --.... u.... ........_..... . . . ....----.. .. ..__.n Stage No: 1 Slurry No: 1 of 4 ..- .....-.... ... .... .. .--.-.. ... .... .-.... --.--..---...... ..... . . -....-----..... ... Slurry Data Fluid Type: FLUSH Description: CW100 Class: Purpose: SPACER Slurry Interval: (ft) To: :ft) Cmt Vol: (bbl) Density: 8.30 (ppg) Yield: (fP/sk) Mix Water: (gal) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol:40 0 Foam Job: N Test Data Time Temp Pressure Thickening Time: Temperature: CF) Compressive Strength 1: "F) (psi) Free Water: (%) Temperature: ("F) Compressive Strength 2: OF) (psi) Fluid Loss: (cc) Temperature: ("F) Fluid Loss Pressure: CF) --..... Printed: 2/312004 10:24:21 AM Test Data Thickening Time: Free Water: Fluid Loss: Fluid Loss Pressure: (%) (cc) OF) Temperature: Temperature: Temperature: OF) OF) (OF) Compressive Strength Compressive Strength 2: Printed: Temp OF) OF) 2/3/2004 0:24:21 Pressure (psi) (psi) AM Slurry Data Fluid Type: Slurry Interval Water Source: TAIL Description: LiteCRETE ,400.00 (ft¡ro: 2,449.00 (ft) Cmt Vol: 91.3 (bbl) Slurry Vol:225 (sk) Time Density: 12.00 (ppg) Water Vol: 43.0 (bbl) Class: G Yield: 2.28 (ft3/sk) Other Vol: 0 Purpose: TAIL Mix Water: 7.84 (gal) Foam Job: N Stage No: 1 Slurry No: 4 of 4 D53 D79 S001 D124 D46 D65 D44 Units 30.00 %BWOC 1.50 %BWOC 1.50 %BWOC 43.10 %BWOC 0.60%BWOC 0.50 %BWOC 9.00 %BWOW Trade Name '---. ! __.Type .-......---. ConcentratiolJ._ _ _ --. Liquid COI]~.: ...----..- . Units.. Test Data Thickening Time: Free Water: Fluid Loss: %) (cc) Fluid Loss Pressure: OF) Stage No: Temperature: Temperature: Temperature: F) 'F) OF) 1 Slurry No: 3 of 4 Compressive Strength Compressive Strength 2: Additives Temp OF) OF) Pressure (psi) (psi) Slurry Water Slurry Data Fluid Type: Interval: Source: LEAD ft To: .400.00 t Description: ARCTIC SET Cmt Vol: 401 Slurry Vol527 .7 (bbl) (sk) Density: 0.70 Water Vol: 251.0 Time (ppg) (bbl) Class: G Yield: 4.28 (ft3/sk) Other Vol: 0 Purpose: PRIMARY Mix Water: 19.93 (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: OF) Temperature: Temperature: Temperature: "F) "F) CF) Stage No Compressive Strength Compressive Strength 2: 1 Slurry No: 3 of 4 Temp 'F) OF) Pressure (psi) (psi) Slurry Data Fluid Type: Slurry Interval: Water Source: FLUSH ) To: t Description: MUDPUSH XL Cmt Vol: (bbl) Slurry Vol: (sk) Density: Water Vol Time 0.50 (ppg) (bbl) Class: Yield:ft3/sk) Other Vol:40 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Stage No: 1 Slurry No: 2 of 4 Report # Start: Spud Date: 1 Report Date 10/22/2003 End: 11 /1 /2003 11 /2/2003 11/23/2003 Cementi ConocoPh ng Report I ips Alaska Page 2 of 3 - ConocoPhillips Alaska Cementing Report Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2003 1 Report Date: 11/2/2003 10/22/2003 End: 11/23/2003 Stage No: 1 Slurry No: 4 of 4 - Additives Trade Name T e Concentration Units Li uid Cone. Units 0.8 %BWOC 0.6 %BWOC 0.6 %BWOC D65 D46 D79 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey EvallJation Interpretation Summary --.-------..--.----------.-.--...-.--..-.---....-..-- CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Rig Dowell cementers, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.6 bpm @ 70 psi, Shut down, Test lines to 3000 psi, Continue pumping CW100 to a total of 40 bbls, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 6.0 bpm @ 100 psi, Shut down and drop btm plug, Mix & pump 527 sxs (401.7 bbls) Lead ArcticSet III Lite cmt mixed at 10.7 ppg w/30.0%D53, 1.5%D79, 1.5%S001, 43.1%D124, .6%D46, .5%D65, 9.0%D44 pumped at rate of 7.0 bpm @ 320 psi, Followed by 225 sxs (91.3 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg wI .8%D65, .6%D46, .6%D79 pumped at rate of 7.0 bpm @ 325 psi, Shut down and drop top plug, Displace cmt with 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace with 158.8 bbls 8.9 ppg mud (total of 178.8 bbls to bump plug) at rate of 7.0 bpm @ 670 psi, Slowed rate to 3.0 bpm @ 600 psi for last 10 bbls of displacement, Bump plug w/1150 psi, Check floats - OK, CIP @ 0705 hrs 11/212003, Had good returns thru out job, Reciprocated csg. 15' until dropped top plug, Had 188 bbls good cmt retums to surface. Printed: 2/3/2004 10:24:21 AM - Page 1 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report ... ,~". .,..::,. .. WELL NAME JOB NUMBER EVENT CODE 24 HRS PROG TMD ITVD I DFS I REPT ~O. I DATE 2P-432 ODR 2,454.0 2,377.0 4.00 11/212003 SUPERVISOR I RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG ¡CUM. TANGO Gladden I Thornton Dovon Dovon 141 MELTWATER 6,094.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD Drill out shoe track 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Drill out Chance over to LSND mud, LOT, Drill 8-1/2" hole 111212003 339,871 1,088,367 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAK OFF AFE AUTH. 10030793 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 11/1/2003 2,387.98 22.390 189.770 9.625 (in) @ 2,449.0 (ft) 3.500 (in) @ 6,094.0 (ft) 11/212003 DENSITY(ppg) 12.00 ¡ PP I IECDI MUD- DATATDAILVCOST I 0 1 CUM COST I 0 FV 1 PVNP I GELS 1 WUHTHP! FC~.SOL OIUWAT 1 . %Sa~dïMBT I 1 Ca 1 - LIME 1 Ph/pM ' PflMf CI H2S ES 88 1 36/54 1 19/25 1 I I I I 1 I 1 I 1 I 1 1 BHA NO. 1 1 BHA I HOLE CONDITIONS .. ----T BIT NO. ..1 --- 2 2 BHA WT, BELOW JARS I STRING WT. UP I STRING WT. DN STRING WT. ROT ¡ TORQUE I UNITS I BHA LENGTH Bit 1.00 8.500 Turbo-Back Stabilizer 1.05 6.750 1.875 Mud Motor 31.53 6.750 Stabilizer - NonMag 3.70 8.375 2.813 Crossover - Non Mag 2.02 6.250 2.813 Resistivity Tool 16.64 6.750 ORD/CCN 15.50 6.750 MAP (Pressure) 7.22 6.750 MWD 29.49 6.750 Crossover - Non Mag 1.30 6.000 2.813 Drill Pipe - Non-Mag 4 Comp Serv 1 29.20 5.000 2.813 Drill Pipe - Non-Mag 4 Comp Serv 1 29.20 5.000 2.750 Drill Pipe - Non-Mag 4 Comp Serv 1 28.53 5.000 2.750 Crossover 1.22 6.438 2.813 Drill Pipe - Heavy Wgt 4 120.92 5.000 3.000 Jars 30.60 6.250 2.250 Drill Pipe - Heavy Wgt 25 755.05 5.000 3.000 Ghost Reamer 6.95 8.500 2.750 Drill Pipe 5.000 4.281 __·_~_·,__.w..·_'_ ----- BITS BIT I RUN 2+-~~ÖOÞU:~~!~HR ~~-£~~5~~~~~~9L5 NO. : JETS OR TFA 1 DEPTH IN DATE IN r'--I-O-D-L-B-G-O-R -'- 21 14/14/14/14/141 1 2,454.'0 11/2ï200~-0-0-NO-A-D-I-NO-TD- ------ - -, BIT OPERATIONS BIT I RUN 1 WOB 1 RPM l GPMj PRESS ì P BïTl HRS I 24Hr DIST I 24Hr ROP I CUM HRS 1 CUM DEPTH I CUM ROP. ---- .....-..--..-.--- -._--- PUMP I HYDRAtlb!Ç DATA - NÖ. MAKE OF PUMP STROKE (in) LINER (in) SPM Q (gpni) ... PRESS. (psi) TOTAL Q KILL SPM I PRESSURE ----- 1 Emsco 12.000 6.000 71 300.34 1,900 600.68 2 Emsco 12.000 6.000 71 300.34 1,900 600.68 - OPERATIONS SUMMARY FRÖM TO 1 HOURS I CODE ITROUBLE! SUB i PHASE : DESCRIPTION 00:00 01:151 1.25 I CASE P 1 IRUNC 1 SURFAC Con't to run 9.625" 40# BTC csg to 2449' MD ( ran total 57 jts) - M/U hanger - Printed: 2/3/2004 10: 15:29 AM - . ................ " Page 2 of 2 ConocoPhillips Alaska, Inc. Daily DriU~ng Report WELL NAME IJOBNUMBER EVE~DC~DE 24HRSPROG [TMD ITVD DFS REPT ~o. DATE 2P-432 2,454.0 2,377.0 4.00 11/2/2003 ;;' ,; OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE .... SUB PHASE DESCRIPTION 00:00 01:15 1.25 CASE P RUNC SURFAC MU landing jt 01:15 02:15 1.00 CASE P CIRC SURFAC Circ BU wI Franks tool - Stage pumps up slowly to 6 bpm @ 400 psi 02:15 02:45 0.50 CASE P RURD SURFAC RID Frank's circu tool - Blow dn TD - MU DS cmt head 02:45 05:00 2.25 CASE P CIRC SURFAC Circu & Condition mud - Circu @ 6 bpm - Final 6 bpm = 250 psi 05:00 07:15 2.25 CEMENTF PUMP SURFAC Rig Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.6 bpm @ 70 psi, Shut down, Test lines to 3000 psi, Continue pumping CW100 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 6.0 bpm @ 100 psi, Shut down and drop btm plug, Mix & pump 527 sxs (401.7 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg wI additives at rate of 7.0 bpm @ 320 psi, Followed by 225 sxs (91.3 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg wI additives at rate of 7.0 bpm @ 325 psi, Shut down and drop top plug, Displace cmt wI 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 158.8 bbls 8.9 ppg mud (total of 178.8 bbls to bump plug) at rate of 7.0 bpm @ 670 psi, Slowed rate to 3.0 bpm @ 600 psi for last 10 bbls of displacement, Bump plug w/1150 psi, Floats held- OK, CIP @ 0705 hrs 11/2/03, Had good returns thru out job, Reciprocate csg. 15' until dropped plug, Had 188 bbls good cmt returns to surface. 07:15 07:45 0.50 CEMENTF PULD SURFAC Rig down cmt head, Lay down landing joint. 07:45 10:30 2.75 WELCTL F NUND SURFAC Nipple down diverter system. 10:30 11 :15 0.75 WELCTL F NUND SURFAC Nipple up casing head & tubing spool, Orient same, Set test plug, Test seals to 1000 psi- OK. 11 :15 14:30 3.25 WELCTL F NUND SURFAC Nipple up BOPE. 14:30 20:00 5.50 WELCTL F BOPE SURFAC Rig & test all BOPE to 250 psi low & 5000 psi high, Hydril to 3500 psi. Test waived by AOGCC Chuck Scheve. 20:00 21:00 1.00 DRILL P PULD SURFAC Pick up 18 joints 5" drill pipe and stand back in derrick. 21:00 00:00 3.00 DRILL P PULD SURFAC Make up BHA #2, Orient motor, program MWD, Load RA sources. 24 HR SUMMARY: Finish RIH wI 9-5/8" csg to 2449', Cement same, Nipple down diverter system, Nipple up casing head, Nipple up & test BOPE, Make up BHA #2 PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. ! HOURS -----.- ._..~.- ---" --. . -- ConocoPhillips Company 3 Epoch Well Services Inc 4 Doyon Drilling Inc 31 Doyon Universal Service 5 Baker Hughes Inteq 2 M- Drilling Fluids 2 Baker Hughes Inteq - D 2 APC - Alaska Petroleum 2 ...--. -- --, __h_ -.--- MATERIALS I CONS~MPTION -I ITEM 1 UNITS I ., USAGE ! ON HAND ITEM I UNITS USAGE I ON HAND 1 I I -. - Fuel gals 900 17,120 Water, Drilling 1 bbls I 905 1 670 - RESERVOIR AND INTERVAL DATA RESERVOIR NAME I ZONE I TOP BASE I COMMENTS ----,---, --- 2P-422 12P-432 I 1077 21650 Printed: 2/312004 10: 15:29 AM = 0.052 x EMW at 2449 Ft-MD (2372 Ft- TVD) = 1046 4000 3500 3000 IJJ 2500 0:: ;::¡ ~ 2000 IJJ 0:: a.. o Barrels """*"",,CASING TEST ments: Lost 20 psi during test, held 99.4% of test pressure. .........LEAK-OFF TEST 4 0 5 10 15 20 25 Shut-In time, Minutes o PIT Point . , - ".': m.. .. Page 1 of 2 ., ···ConocoPhillips Alaska, Inc. I' .. Daily Drilling Report .. ... ...,. ... WELL NAME I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS I REPT ~O. DATE 2P-432 ODR 1,098.0 3,552.0 3,398.0 5.00 11/3/2003 SUPERVISOR I RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG CUM. TANG Gladden I Thornton Dovon Dovon 141 MELTWATER 6,094.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INT ANG WI MUD Drilling 8-1/2" hole @ 4,130' 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Drill 8-1/2" hole to TD of 6,094' 11/3/2003 126,683 1,215,050 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAKOFF AFE AUTH. 18.09 10030793 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 11/3/2003 3,431.58 21.510 190.510 9.625 (in) @ 2,449.0 (ft) 3.500 (in) @ 6,094.0 (ft) 11/212003 - I pp', iECD IML!ïi DATA DAILYCOST I I CUM COST I . DENSITY(ppg) 12.05 0 0 FV I PVNP GELS I WUHTHP I FCm:~OL OIUWAT I %SandlMBT I Ph/pM I PflMf 'r .. CI Ca I H2SJ LIME ¡ ES I 40/66 19/27 r I I I I 1 I , 9.11 I I I 1 I BHA NO. I I _"A_ ,"BIT NO. ...- 2 BHA I HOLE CONDITIONS 2 BHA WT. BELOW JARS I STRING WT. UP STRING WT. DN I STRING WT. ROT , TORQUE/UNITS BHA LENGTH i --- 13--' I 126 - 6 ft-Ibf 1,111.12 ..~~~- Bit 1.00 8.500 Turbo·Back Stabilizer 1.05 6.750 1.875 Mud Motor 31.53 6.750 Stabilizer· Non Mag 3.70 8.375 2.813 Crossover - Non Mag 2.02 6.250 2.813 Resistivity Tool 16.64 6.750 ORDICCN 15.50 6.750 MAP (Pressure) 7.22 6.750 MWD 29.49 6.750 Crossover - NonMag 1.30 6.000 2.813 Drill Pipe - Non-Mag 4 Comp Serv 1 29.20 5.000 2.813 Drill Pipe - Non-Mag 4 Comp Serv 1 29.20 5.000 2.750 Drill Pipe - Non-Mag 4 Comp Serv 1 28.53 5.000 2.750 Crossover 1.22 6.438 2.813 Drill Pipe - Heavy Wgt 4 120.92 5.000 3.000 Jars 30.60 6.250 2.250 Drill Pipe - Heavy Wgt 25 755.05 5.000 3.000 Ghost Reamer 6.95 8.500 2.750 Drill Pipe 5.000 4.281 ---- ._~____. __ _h___ --_.- -..- BITS -- BIT I RUN I SIZ':.] MANUF. L!!~,: -.[ SERIAL NO. I JETS OR TFA r'DEPTHIN DATE IN I I-O-D-L-B-G-O-R ----.- -.- 21 2 8.500 I HUGHES-CHR I HCM605 17101195 I 14/14/14/14/141 I 2,454.0 11/2/20031 O-O-NO-A-D-I-NO-TD _.._'M . - ..--. BIT OPERATIONS BIT I RUN WOB ! RPM I GPM PRESS 'Pfm I HRS I 24Hr DIST I 24Hr ROP ., CUM HRS CUM DEPTH CUM ROP .--. 21 2 5/20 I 60/90 I 500 2,200 1 391 1 10.70 1 1,098.0 I 102.62 I 10.70 1,098.0 102.62 .' -- ---- - .~-- ... SURVEY DATA· .u --- M.D. INCL. AZIMUTH T.V.D. NISCUM EIW CUM SECTION M.D. INCL. AZIMUTH T.V.D. N/S CUM EIW CUM , SECTION ...--- -- -- 2,499.45 21.380 191.580 2,418.93 -466.45 -116.72 480.82 3,060.01 22.110 197.370 2,940.03 -667.29 -164.49 687.23 2,593.73 21.100 192.320 2,506.81 -499.86 -123.79 514.94 3,153.81 21.750 197.750 3,027.04 -700.69 -175.06 722.21 2,686.02 20.930 192.150 2,592.96 -532.21 -130.80 548.01 3,246.25 21.510 197.610 3,112.97 -733.16 -185.40 756.23 2,780.56 21.460 192.330 2,681.10 -565.61 -138.05 582.16 3,338.71 21.250 197.590 3,199.07 -765.29 -195.60 789.88 2,873.13 22.230 193.080 2,767.02 -599.21 -145.63 616.59 3,431.58 21.510 190.510 3,285.56 -798.08 -203.79 823.68 2,966.97 22.270 195.750 2,853.88 -633.61 -154.47 652.11 Printed: 2/3/2004 10: 17:03 AM ConocoPhilUpsAlaska, Inc. . . .. . Daily [)rilling,Report JOB NUMBER EVENT eODE 24 HRS PROG ITMD ITVD ODR 1,098.0 3,552.0 3,398.0 PUMP I HYDRAULIC DATA STROKE (in) LINER (in) SPM Q (gpm) 12.000 6.000 60 253.81 12.000 6.000 60 253.81 - WELL NAME 2P-432 .NO.' 1 Emseo 2 Emseo MAKE OF PUMP ,...",,/ FROM TO HOURS' ··CODE 'TROUBLE SUB ._- 00:00 01:45 1.75 DRILL P PULD 01:45 03:00 1.25 DRILL P TRIP 03:00 04:45 1.75 DRILL P SFTY 04:45 05:45 1.00 DRILL P DEOT 05:45 06:30 0.75 DRILL P DRLG 06:30 07:15 0.75 DRILL P CIRC 07:15 07:30 0.25 DRILL P DRLG 07:30 07:45 0.25 DRILL P CIRC 07:45 08:30 0.75 DRILL P FIT 08:30 08:45 0.25 DRILL P SFTY 08:45 09:15 0.50 DRILL P CIRC 09:15 00:00 14.75 DRILL P DRLG ..,.,... Page 2 of 2 ',< ,'>;: DFS I REPT N60. 5.00 I DATE 11/3/2003 PRESS. (psi) TOTALQ 2,200 507.62 2,200 507.62 . .KILL SPM I ÞRESSURE 'OPERATIONS SUMMARY PHÂSE DESCRIPTION, .,'" , SURFAC Pick up 3- NMDC's, XO, HWDP, Surface test MWD, RIH wI HWDP. SURFAC Pick up 36 jts 5" DP to 2,039' SURFAC Rig & Perform detailed stripping & well kill drill with all rig personal. SURFAC RIH to 2,317', Rig & test 9-5/8" casing to 3500 psi f/30 min. on chart. SURFAC RIH & tag float collar @ 2,360', Drill out shoe track and emt. to TD 2,454'. SURFAC Change over to 9.6 ppg LSND Mud. SURFAC Drill 20' new hole for LOT to 2,474' SURFAC Circ. btm's up for LOT. SURFAC Perform FIT with 9.6 ppg mud, 1046 psi, 2,395' TVD= 18.1 ppg EMW. INTRM1 Held Production hole Safety meeting with all rig personal. INTRM1 Perform PWD baseline test. INTRM1 Drill f/2,474' to 3,552' (3,398' TVD) ART = 8.8 hrs AST = 1.9 hrs, WOB 5-20K, RPM 90, 510 GPM @ 2200 psi, TO 2/8K on, 4K off, UP 138K, DN 116K, ROT 126K, ECD's 10.4 to 10.7 ppg, Control drilling at 150'/hr to control ECD's, Pumping unweighted sweeps every 4 stands, No noticable mud losses, BGG +- 50 units. 24 HR SUMMARY: Pick up BHA #2, RIH to 2,039', Perform stripping drill, Test csg to 3500 psi, Drill out shoe track to 2,454', Drill to 2,474' & Perform FITto 18.1 ppg EMW, Drill to 3,552'. --_._......_.~..-.__.._---_._-_.- ____.___0. _._~____._.__.__._____ COMPANY ConocoPhillips Company Doyon Drilling Inc Baker Hughes Inteq Baker Hughes Inteq - D , SERVICE ITEM USAGE 920 510 Fuel Water, Drilling UNiTS gals bbls PERSONNEL DATA NO. HOURS - ----- -." 3 30 3 2 COMPANY Epoch Well Services Inc Doyon Universal Service M- Drilling Fluids APC - Alaska Petroleum SERVICE NO. 4 5 2 2 HOURS MATERIALS I CONSUMPTION ON HAND ... ITEM L UNITS 16,200 Wat~~,-Pc;tabï;---I -g;¡;- 540 I USAGE ON HAND 13,980 RESERVOIR AND INTERVAL DATA 2P_42:ESERV~!~_~~~E__..__.._ b-P:432-·...::-~~~~-~,____.:.r-·TÕ~;r BASE 2 :850 COMMENTS Printed: 2/3/2004 10:17:03 AM ConocoPhillips Alaska , '. Casi ng Report Page 1 <:>f 2 Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Report #: Start: 2 10/22/2003 Spud Date: 11/1/2003 Report Date: 11/9/2003 End: 11/23/2003 . .. .. . . . -...... . ... .. ......---,....,. - . General Information .-...-- ...--.... .......... . String Type: Intermediate CasinglLiner Hole TVD: 5,307.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 24.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: KB (atdb) 224.00 (ft) (ft) 208.0 (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: 8.500 (in) (ft) (ft) 25.39 (ft) Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 5,613.0 (ft) 120,296 (Ibs) 23.52 (0) 11.00 (days) ----------. --_._-....__._--_._----_._-_..~_._--~~.. Casing Flange I Wellhead Manufacturer: FMC Hanger Model: Actual TMD Set: 5,602.33 (ft) Model: Gen V Packoff Model: Top Hub/Flange: (in) 15,000 (psi) BTM Hub/Flange: (in) 15,000 (psi) Integral Casing Detail Item· Size Weight Grade Drift Threads JTS Length Top MU Torq.iTHD Manufacturer Model Condo Max OD Mín ID Compo Name (in.) (Ib/ft) (in) (ft) (ft) (ft-Ibf) I (in) (in) Casing Hanger 7.000 BTCM 1 1.58 25.39 Casing Hanger Casing 7.000 26.00 L-80 6.151 BTC-MOD 135 5,493.92 26.97 6.276 7" 26# L-80 Ca Float Collar 7.000 BTCM 1 1.32 5,520.89 Float Collar Casing 7.000 26.00 L-80 6.151 BTC-MOD 2 78.65 5,522.21 6.276 7" 26# L-80 Ca Float Shoe 7.000 1 1.47 5,600.86 Float Shoe 5,602.33 ..---..- Non-Integral Casing Accessories Accessory 1; Manufacturer WEATHERFORD WEATHERFORD j Bottom (ft) 4,500.0 OverCollar 200.0 Floating Number Spacing r Interval (ft) ..-- Top (ft) æ ~œo 19 2,400.0 ---.------ How Fixed Bowspring Centralizer Centering Guides Remarks ---.--..--.. Rig & ran 7" Float shoe, 2 jts 7",26#, L-80, BTCM csg, Float collar, 135 jts 7",26#, L-80, BTCM csg, FMC Gen 5 Casing hanger & landing joint, Placed Bow spring centralizers 1-15' above shoe on stop collar and 1-15' above float collar on stop collar, and 1 on every joint from shoe to joint # 28 for a total of 29 centralizers. Printed: 2/312004 10: 15:00 AM GonocoPhillips Alaska Casing Report Page 2~f 2 legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRilLING Report #: Start: 2 10/22/2003 Spud Date: 11/1/2003 Report Date: 11/9/2003 End: 11/23/2003 Remarks ..------.------....--.---.-.. ------ Casing ran in hole fine with very little trouble, Had very poor pipe displacement while run in hole, Lost total of 208 bbls running pipe in hole, Attempted to circ. casing several times on way in hole at 1,200', 2,440', 3,240', 4,050', Had at best 75% returns pumping at only 1.5 bpm, Had only 20% returns at 4,050', Landed casing with shoe at 5,602.33' and float collar at 5,520.89' Printed: 2/312004 10: 15:00 AM - ConocoPhillips Alaska ... Cementing Report ... Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Prima Hole Size: 8.500 (in) TMD Set: 5,602 (ft) Date Set: 11/8/2003 Csg Type: Intermediate CasinglLi Csg Size: 7.000 (in.) Hole Size: SO TMD: SO Date: SO Type: (ft) Cmtd. Csg: Intermediate CasinglLi Cmtd. Csg: Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start:03:30 Report #: Start: Cementer: Dennis Davis Pipe Movement Time End: : Time End: 09:30 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 15.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 175,000 (Ibs) Drag Down: 125,000 (Ibs) Type: Cement Casing Volume Excess %: 75.00 Meas. From: Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 63 (gpm) Mud Circ Press: 350 (psi) Stage No: 1 of 1 Start Mix Cmt: 05:00 Start Slurry Displ: 05:45 Start Displ: 06:55 End Pumping: 10:00 End Pump Date: 11/9/2003 Top Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 11.5 (ppg) Vise: 67 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud Slurry Data Fluid Type: FLUSH Slurry Interval: 1,606.00 (ftJfo: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: Mud Data Page 1 of 3 Spud Date: 11/1/2003 2 Report Date: 11/9/2003 10/22/2003 End: 11/23/2003 Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating 1.50 (bbl/min) 1.50 (bbl/min) N 200 (psi) (psi) (min) Y (ft) (ft) Returns: None Total Mud Lost: Cmt Vol to Surf: 335.00 (bbl) (bbl) .. .... . Cement Job Type:. Prirnary .... S Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SO Date: Cmtd. Csg: Ann Flow After: Y Mixing Method: Batch Density Meas By: Densometer PVNP: 34 (cp)/34 (lb/100ft2) Gels 10 see: 15 (lb/100ft2) Gels 10 min: 18 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 11.5 (ppg) Volume: 214.00 (bbl) .---"-.----..-----.----..--- Stage No: 1 Slurry No: 1 of 3 Description: CW100 2,730.00 (ft) Cmt Vol: (bbl) Slurry Vol: (sk) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol:30 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: -..----"-- Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 2/3/2004 10:13:40 AM - Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: 2,730.00 (ft¡ro: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: PRIMARY Slurry Interval: 4,500.00 (ft¡ro: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Name D65 C359 D47 D600G ConocoPhillips Alaska, ; ..... Cementing Report ... Page 2 of 3 Report #: Start: Spud Date: 11/1/2003 2 Report Date: 11/9/2003 10/22/2003 End: 11/23/2003 , Stage No: 1 Slurry No: 2 ofª ... Description: MUDPUSH XL Class: 4,500.00 (ft) Cmt Vol: (bbl) Density: 12.00 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol:40 () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 3 Description: LiteCRETE 5,602.00 (ft) Cmt Vol: 51.0 (bbl) Slurry Vol:130 (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 12.50 (ppg) Yield: 2.20 (ft31sk) Water Vol: 24.1 (bbl) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 3 - Additives _!YRe Concentration Li uid Cone. Units 0.9 %BWOC 0.0 %BWOC Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 7.79 (gal) Foam Job: N Pressure (psi) (psi) Units 0.2 G P S 1.5 G P S Printed: 2/312004 10:13:40 AM Printed: 2/3/2004 10:13:40 AM Shut Turn over to Dowell, Pump 5 bbls CW1 00 @ 8.3 ppg, Test lines to 4000 psi. Continue pumping 25 n ¡Is CW1 00 at rate of 1 @ 100 psi. followed by 40 bbls MudPUSH II Mixed at 12.0 ppg at rate of 1.5 bpm at 180 psi, Shut de 'op btm plug, Pump: i1 12.5 ppg wI .9%D65, .020%C359, .20%D47, 1.5%D600G at 1.5 bpm at 200 psi,: w/10 bbls fresh water, followed by 204 bbls 11.5 ppg mud at rate 01 1.5 bpm at 200 psi, I C.I.P. @ 10:00 hrs. 11/9/03, Observe well- Mild flow, Reciprocated pipe until (130 sxs) LiteCRETE cement mixed at down. Drop top plug, Displace cement displacement. well in for 4 hours, pressure raised to 55 psi and slowly decreased to 44 psi bump plug, Gained 3.9 bbls thru out bbls of displacement. Shut Did not last 20 rate of .5bpm bbls CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Remarks Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: f Log/Survey Evaluation nterpretation Summary Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool Test For: Cement Found between Shoe and Collar: (psi) (min) Pressure: Tool: Open Hole: ) Hrs Before Test: Tool: Tool Press: (ppge) Casing Test Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Shoe Test Report # Start: Liner Top Test 2 10/22/2003 Spud Date: Report Date End: 11 /1 /2003 11/9/2003 11/23/2003 Cementing Report ConocoPh ps Alaska Page 3 of 3 . " " """ "" "" Page 1 of 2 . ~ "" " " . . " " """ . .. CortocoPhillips Alaska, Inc.' ,.,.... Daily Drilling Report WELL NAME I JOB NUMBER I EVE~DC~DE 124 HRS PROG TMD TTVD ulDFS · REPT NO. DATE 2P-432 5,613.0 5,307.0 11.00 12 11/9/2003 SUPERVISOR RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD IDAILYTAN~ 1 CUM. TANGO F. Herbert I M. Thornton Dovon Dovon 141 MELTWATER 6,094.0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INT ANG WI MUD Finish Lavina down 5" drill Dipe. 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD UD 5" DP,P/U 4" DP & BHA, RIH & Drill 11/9/2003 290,420 2,341,411 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP 1 LEAKOFF AFE AUTH. 18.09 10030793 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 11/5/2003 5,523.19 20.480 193.760 7.000 (in) @ 5,602.0 (ft) 3.500 (in) @ 6,094.0 (ft) 11/9/2003 DENSITY(ppg) , 11.50 I' PP I ECDI IMUD DATAl DAILY COST I 0 I CUM COST I 0 FV ! PVNP:r GELS ,WUHTHP T FCIT.SOL OIUWAT I %SandlMBT I Ph/pM I PflMf I CI I Ca -H2S-rï:iME'¡-E"s'" 60 31/33 15/20 4.61 11 I I 115.0 I 9.01 I I I I I I ,-- OPERATIONS SUMMARY . FROM TO. HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 03:30 3.50 CASE P RUNC INTRM1 Finish Running 7", 26#, L-80, BTCM casing f/4,226' to 5,602' and land same, Stopped and eire, @ 5,287' only able to circ at 1 to 1.5 bpm with possible 20% retums at best, No Pipe displacement at all on last 10 joints, Lost total of 208 bbls mud running casing, Pipe ran in hole with no trouble. 03:30 04:30 1.00 CEMENT F CIRC INTRM1 Attempt to circ at rate of 1.5 bpm at 350 psi, 20% to trace returns, Lost 72 bbls while eire, Reciprocate pipe 10-15'. 04:30 05:00 0.50 CEMENT F PULD INTRM1 Lay down Franks fill up tool, Pick up Dowell cement head. 05:00 06:00 1.00 CEMENT F CIRC INTRM1 Attempt to circ at rate of 1.0 bpm at 250 psi, 20% to trace returns, Reciprocate pipe 10-15', Lost 48 bbls mud while circ. Batch mix cement. 06:00 10:15 4.25 CEMENT F PUMP INTRM1 Turn over to Dowell, Pump 5 bbls CW1 00 @ 8.3 ppg, Test lines to 4000 psi, Continue pumping 25 more bbls CW1 00 at rate of 1.5 bpm @ 100 psi, followed by 40 bbls MudPUSH II Mixed at 12.0 ppg at rate of 1.5 bpm at 180 psi, Shut down, Drop btm plug, Pump 51 bbls (130 sxs) LiteCRETE cement mixed at 12.5 ppg wI .9%D65, .020%C359, .20%D47, 1.5%D600G at rate of 1.5 bpm at 200 psi, Shut down, Drop top plug, Displace cement w/1 0 bbls fresh water, followed by 204 bbls 11.5 ppg mud at rate of 1.5 bpm at 200 psi, Did not bump plug, Gained 3.9 bbls thru out displacement, C.I.P. @ 10:00 hrs. 11/9/03, Observe well- Mild flow, Reciprocated pipe until last 20 bbls of displacement. 10:15 15:00 4.75 CEMENT DH OTHR INTRM1 Close Hydril and monitor well, Pressure built to 55 psi and slowly decreased to 44 psi, Bleed off pressure, Monitor well- Static. 15:00 16:00 1.00 CEMENT I PULD INTRM1 Rig down cement head & Landing joint, Change bails & elevators. 16:00 17:00 1.00 CASE P NUND INTRM1 Install 9-5/8" x 7" Pack off, Test same to 5000 psi for 10 min- OK 17:00 19:00 2.00 WELCTL F NUND INTRM1 Install test plug, Change top pipe rams to 3-1/2' x 6", Change btm pipe rams to 4", Change saver sub on top drive to HT-39 19:00 00:00 5.00 WELCTL F BOPE INTRM1 Test all BOPE to 250 psi low & 5000 psi high, Hydril to 3500 high, BOPE test waived by AOGCC Lou Gramaldi., Pull test plug, Set wear bushing. Note: Total mud lost for the day= 413 bbls, Accum. total= 2427 bbls. 24 HR SUMMARY: RIH wI 7" csg to 5,602', Circ & Cmt csg, Close hydril on csg f/4 hrs, Set & test 9-5/8" x 7" packoff, Test BOPE. - -.. - PERSONNEL DATA COMPANY SERVICE . . NO. HOURS COMPANY SERVICE NO. ! HOURS . ConocoPhillips Company 3 Baker Hughes Inteq - D 2 Doyon Drilling Inc 31 Epoch Well Services Inc 4 Baker Hughes Inteq 3 Doyon Universal Service 5 Printed: 2/312004 10:17:44 AM WELL NAME 2P-432 .:~.... ConocoPhillips Alaska, Inc. Daily Drilling Report Page 2 of 2 COMPANY SERVICE M- Drilling Fluids ITEM ------".---..--..----... Fuel Water, Drilling RESERVOIR NAME 2P-422 UNITS gals bbls 2P-432 USAGE 990 280 MATERIALS I CONSUMPTION ON HAND ITEM 11,240 Water, Potable 560 UNITS gals DATE 11/9/2003 SERVICE USAGE 4,180 ON HAND 7,748 .. . ... COMMENTS Printed: 2/312004 10:17:44 AM Well Name: Supervisor: utercasmg shoe e Casing Description referen Hole Size is that drilled bel Use estimated roc for Ho Enter inner casing 00 at righ' 9-5/8" 40#/Ft L-80 STC est . in comments 9.6 casing string. 9 casing. 4,500 7 = = EMW at 2449 Ft-MD (2372 Ft- TVD) == 16.5 350 4000 3500 3000 LJ..J 2500 0::: :::J V) 2000 V) LJ..J 0::: CL 1500 1000 500 Lost 20 psi during test, held _ 99.4% of test pressure. 2 4 Barrels o 10 15 20 25 30 Shut-in time, Minutes o PIT Point .......CASING TEST _LEAK-OFF TEST omments: ~ - .................. ... ..mmm ..... ..... Page 1 of 1 . ....... . .... . . .. . .. ...... ConocoP"'illips Alask~".lnc. Daily Drilling Report I WELL NAME I JOB NUMBER 1 EVE~DC~DE 124 HRS PROG TMD ITVD DFS I REPT NO. DATE 2P-432 6,043.0 5,710.0 25.00 26 11/23/200 SUPERVISOR RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD IDAlLYTAN~ CUM. TANG D. Gladden I P. Wilson Doyon Doyon 141 MELTWATER 6,094.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INT ANG WI MUD Rig Released off 2P - 432 @ 0800 hrs 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Move in and RIU on 2P -434 11/23/2003 69,802 4,141,223 LrrHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 10030793 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 11/5/2003 5,523.19 20.480 193.760 3.500 (in) @ 6,038.0 (ft) (in) @ (ft) 11/16/2003 DENSITY(ppg) 8.50 I PP 1 ECDI IMUDDATAI DAILY COST, I 0 I CUM COST 0 _.._~.n --- %SandlMBT I Ph/pM 1 I I, Ca I H2S I LI~E I FV I PVNP I GELS> WLlHTHP FCIT.SOL OILlWAT PflMf ..CI ES -', - I I I I I I I 1 I 1 I I 1 1 1 I OPERATIONS SUMMARY .- FROM TO HOURS CODE TROUBLE . ,SUB PHASE . DESCRIPTION - . 00:00 00:45 0.75 CASE P MIT CMPL TN Test Csg - Test 7" X 3.5" Ann. to 3500 psi and chart for 30 min. Lost 70 psi. Bleed pressure off Tbg and shear RP valve. 00:45 01:15 0.50 CASE P RURD CMPL TN UD landing jt - Set TWC 01 :15 02:00 0.75 CMPL TN F NUND CMPL TN NID BOPE 02:00 03:30 1.50 CMPL TN F NUND CMPL TN NIU Tree - WKM tree asssy on FMC 3.125" X 11" tbg head adapter. Test adapter void to 5000 psi - Hold 15 min. Test tree 250 psi I 5000 K for 10 min. 03:30 04:30 1.00 CMPL TN F FRZP CMPL TN RIU Hot Oil to 7" X 3.5" Ann. - Pump 80 bbls diesel- PR 1.8 bpm @ 1500 psi. Put Tbg & Ann in communication and let fluid U-tube 04:30 06:30 2.00 CMPL TN F FRZP CMPL TN Preform LOT on 9.625" X 7" Ann. - Pump 3.8 bbls, 11.0 ppg mud had leak off @ 620 psi for a 14.6 ppg EMW LOT, Pumped 120 bbls water to flush annulus, freeze protect with 52 bbls diesel. (1848' MD) 06:30 07:00 0.50 WELLSR f NUND CMPL TN FMC RIU & Set BPV wI lubricator 07:00 07:30 0.50 WELLSR f NUND CMPL TN Secure Tree & Well Head - Clean Cellar area 07:30 08:00 0.50 WELLSR f OTHR CMPL TN Fin cleaning rock washer & pits **Release Rig 0800 hrs 11/23/03** to move to 2P-434 24 HR SUMMARY: Test tbg & Ann - NID BOPs - N/U tree & test same - Freeze protect well- Preform LOT on 9.625" X 7" Ann. Pump 120 water flush and freeze protect wI 52 bbls diesel. - Secure well - Release Rig at 08:00 hrs __0- ._.- -..- .. . PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY··· SERVICE NO. HOURS ConocoPhillips Company 2 M-I Drilling Fluids 2 Doyon Drilling Inc 31 APC - Alaska Petroleum 2 Baker Hughes Inteq 1 Baker Oil Tools 1 Baker Hughes Inteq - D 2 FMC Corporation Wellhe 1 Epoch Well Services Inc 2 Quadco I Totco 1 Doyon Universal Service 5 ---- __".0- ... ... "1" I - MATERIAbS I CONSUMPTION._. --- ITEM UNITS . USAGE ON HAND ITEM UNITS USAGE ON HAND -...-.. -- .. Fuel I gals 1 8,210 Water, Potable gals 11 ,376 Water, Drilling 1 bbls 1 300 ____0. -. ._-- RESERVOIR AND INTERVAL DATA RESERVOIR NAME ...¡ ZONE I TOP .... BASE i COMMENTS -.-- 12P-432 1 01 2P-422 0 Printed: 2/3/2004 10:18:21 AM Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING --_.~" - . ----.-.---'" ß20d--&ê)~ \ ConocoPhillips Alaska Casing Report Page 1 of 2 " Spud Date: 11/1/2003 Report Date: 11/2/2003 End: Report #: Start: 1 10/22/2003 ....,.....,-.----.-- ...___'.'.._n . . . ...___ _ ..._____. ._______. . .. ..__. on -.--. . --...... String Type: Surface Casing Hole TVD: 2,377.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 3.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: .. -- ...--.. . ---- - . General Information - - .... ..... .' .. --. .-----..-...-........ ----.-----. ..----... ... ----. ..----. KB (atdb) 224.00 (ft) (ft) (bbl) 12.250 (in) (ft) (ft) 28.11 (ft) 2,454.0 (ft) 121 (Ibs) 22.43 (0) 4.00 (days) . Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: Hole Size: Water TMD: Liner Overlap: KB to Cutoff: -----.--. ....----. -. ---. .......-..-.--... ....-.---. .._-".". Casing Flange I Wellhead ____. ,.__m.. _,_,... .___....... ._.__......._______._.._.. .._.___.___.._....... ..... .... . ..._________._._... _____.________... _.____.... ________ Manufacturer: FMC Hanger Model: Actual TMD Set: 2,449.49 (ft) --.....--.. .____n . ...__ Model: Gen V Packoff Model: Top Hub/Flange: (in) 15,000 (psi) BTM Hub/Flange: (in) 15,000 (psi) ...__.. ______n... ....------- . .......--.....---..,..,. . ..._-- . ..--..-.. ~ ..' ---. ..-. Item Integral Casing Detail .____...., .._._.__..._..,--___.~-_. _"'.... ...__...._~.. ___.__. - ____ ..__._". .._..,-____. _... ._____....... _. .. .:__---.,---.._. .. ...___._..._:-¡-____...___._._. ....,...-__...._ .. _._.......__...___...__[.._ __n._· _ .... ¡ Size i Weight I Grade I Drift ! Threads . JTS. Length! Top 'MU Torq.:THDi Manufacturer! Model ¡ Condo ¡Max OD~ Min ID I Compo Name , (in.) ; (lb/ft) : ¡ (in) , :' (ft) , (ft) '(ft-lbf): I ! I! (in) : (in) ! ._-_._.~-_. ... Casing Hanger Casing Casing - Pup Jt Casing Float Collar Casing Float Shoe 9.625 9.625 9.625 9.625 9.625 9.625 9.625 40.00 L-80 40.00 L-80 40.00 L-80 40.00 L-80 8.679 8.679 BTC 8.679 BTC 8.679 BTC 1 3.50 28.11 23 957.05 31.61 1 15.13 988.66 32 1,356.73 1,003.79 1 1.50 2,360.52 2 85.77 2,362.02 1 1.70 2,447.79 2,449.49 . .-..... .. ._".. Casing Hanger 8.835 95/8" 40# L-80 8.835 9 5/8" 40# L-80 8.835 9 5/8" 40# L-80 Float Collar 8.835 95/8" 40# L-80 Float Shoe 40.00 L-80 8.679 BTC . - ..-.--- . . .-.-..--.-..........-. . ..-. . .-...-.-.-.. . ---.. ...--. . .....-.---- . -...-..--... ..-... . -............ .-..--.-......, ..~ ._.~ .-..... . ...--.... ~ .---.......... ....---... ...---. Non-Integral Casing Accessories Bowspring Centralizer Accessory Manufacturer ...--" ......,_.. ¡WEATHERFORD ..---- .---.. ._--. ....---... ....--. .--..........---..... ..-.. --... ---=1--· N~~~:~i ---s,~;~_..- r~·T~~~J~~::~~-~[~:~_d- -. Remarks --.- ... . -..' --.. --..... -----. . -. . - --.-. .... ..-.-........ ...-.-....... ....-.-....--. ..--..-.---..,..-----. ...-.---. Rig & ran 9-5/8" Float shoe, 2 jts 9-5/8', 40#, L-80, BTC csg, Float collar, 32 jts 9-5/8", 40#, L-80, BTC csg, 9-5/8" PUP jt., 23 jts. 9-5/8", 40#, L-80, BTC csg., Placed centralizers 1-5' above shoe on stop collar and 1-5' above float collar on stop collar, and 1 on evert joint from shoe to joint # 18 for a total of 19 centralizers. Printed: 11/512003 10:48:18 AM ConocoPhillips Alaska Casi ng Report Page 2 of 2 Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Report #: Start: 1 10/22/2003 Spud Date: 11/1/2003 Report Date: 11/2/2003 End: .--'-.'.'..-. .____. . ..,.._..____ ... .______ . ..._.___ . . .... .._.____. .... . . n. ....______.. _ .. ._..____.. .--"'..-... .. ....-.-..---. - . Remarks ----.. .. ---.. . --....-. .-_. ----.... - ..---....". ......... . _.."'. ~ .._._._._......,.... ..._____...... ___._._...__.______............_. ____n .... ___.... ___.. .____. Casing ran in hole fine with very little trouble, Landed casing with shoe at 2449.49' and float collar at 2360.52' . Printed: 1 1/5/2003 10:48: 1 6 AM Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: OF) Temperature: Temperature: Temperature: (OF) ("F) (OF) Compressive Strength 1: Compressive Strength 2: Printed: Temp (OF) OF) /512003 10:48:32 AM Pressure (psi) (psi) ---.- Slurry Data Fluid Type: Slurry Interval: Water Source: FLUSH 't To: f Description: Cmt Vol: Slurry Vol: CW (bbl) (sk) Time Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: fP/sk) Other Vol:40 0 Purpose: SPACER Mix Water: (gal) Foam Job: N 100 ..-.-- -.-...-- .--. Type: Spud Mud Density: 8.9 (ppg) Vise: 40 (s/qt) Bottom Hole Circulating Temperature: ("F) Displacement Fluid Type:Mud -- .. --.. Stage No: 1 --... PVIYP: Density: 8.9 (ppg) Mud Data -----..-.. ...... .--... .---.. .-.- ,..-- 12 (cp)/8 (lb/100ft2) Gels 10 see: 6 (lb/100ft2) Gels 10 min: 8 Bottom Hole Static Temperature: (OF) Slurry No: 1 of 4 Volume: 178.80 (bbl) ......---- . ..--- --- Ib/100ft2) Meas. From: 188 Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 250 (psi) ..-.... . ..... i ¡ End Pumping: End Pump Date: Top Plug: Bottom Plug: Y Y Press Bumped: Press Held: ._....I.Float Held: .. 600 (psi) 1,150 (psi) 5 (min) Y Ann Flow After: . Mixing Method: I Density Meas By: N On Iy Desometer .--. ..- ..- ---. Type: Cement Casing Volume Excess %: J I ! Start Slurry Displ: Start Displ: 05:22 06:37 06:37 07:05 11/2/2003 I Bump Plug: Press Prior: .-. Disp Avg Rate: Disp Max Rate: 7.00 (bbl/min) 7.00 (bbl/min) Y , -. --.---. Returns: FULL Total Mud Lost: Cmt Vol to Surf: (bbl) 188.00 (bbl) Start Mix Cmt: .-- Rot Time Start: Rec Time Start:01 -- _. ...--. ----.-..-... .. Time End: :30 Time End: 06:35 ---- .- RPM: SPM: 1 Stage No: -- ---- Init Torque: Stroke Length: 1 Pipe Movement (ft-Ibf) 15.0 of 1 ) .--- .---.- Avg Torque: Drag Up: 't-Ibf) 121,000 Ibs) _...-:~ .- -.--. Max Torque: (ft-Ibf) Drag Down: 106,000 (Ibs) .___ ._h"_ Cement Co: Dowell Schlumberger .._ ._n..___.. .- Cementer: ¡ Jerry Culpepper Drilled Out: J Cmtd. Csg: -- .--- / ---.-- Pipe Movement: Reciprocating .--- ..---- ... . ..--- . \ Cmtd. Csg: Surface Casing ..-. .. Cmtd. Csg: Csg: I ! Cmtd. Csg Type: sa TMD: sa Date: I Csg Type: Csg Size: Hole Size: TMD Set: Date Set: ~r!!!I-ª!Y.. 12.250 (in) 2,449 (ft) 11/212003 Surface Casing 9.625 (in. I .~_qu_e!!~~..Op~~ Hol~__ Hole Size: sa TMD: sa Date: sa Type: ft) .L____.~queE:!~_Ca~!!!g__._ Hole Size: TMD Set: Date Set: ! Plug Date: Plug Type: -.---- Hole Size: Top Set: BTM set: ) t --.....1 _..f!.yg Legal Well Name 2P-432 Common Well Name: 2P-432 Event Name ROT - DRILLING Cement Job Type Report # Start: Primary 1 10/22/2003 Spud Date Report Date End: 11/1 /2003 11/2/2003 . Cementing Report ConocoPh i ps Alaska . Page 1 of 3 Test Data Thickening Time: Free Water: (%) Fluid Loss: (ce) Fluid Loss Pressure: OF) Temperature: Temperature: Temperature: "F) "F) CF) Compressive Strength 1: Compressive Strength 2: Printed: Temp "F) OF) /5/2003 10:48:32 AM Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Slurry Interval: 1,400.00 Water Source: t To: 2,449.00 f Description: LiteCRETE Cmt Vol: 91.3 (bbl) Slurry Vol225 (sk) Time Density: 12.00 (ppg) Water Vol: 43.0 (bbl) Class: G Yield: 2.28 Other Vol: 0 P/sk) Purpose: TAIL Mix Water: 7.84 (gal) Foam Job: N Slurry No: 4 of 4 .--...---.-.. .. Stage No: 1 D53 D79 S001 D124 D46 D65 D44 I Units 30.00 %BWOC 1.50 %BWOC 1.500/0BWOC 43.10 %BWOC 0.60 %BWOC 0.50 %BWOC ¡ I 9.00 %BWOW ! i ! Trade Name 1 Type ......... Concentration -------...........-.. . .... . I J ._ l,i.ç ujd ç~nc. Units Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: , F Stage No: Temperature: Temperature: Temperature: ('F) OF) OF) 1 Slurry No: 3 of 4 Compressive Strength 1: Compressive Strength 2: Additives Temp OF) 'F) Pressure (psi) (psi) Slurry Interval: Water Source: LEAD f To: 1 Description: ARCTIC SET ,400.00 (ft) Cmt Vol: 401 Slurry Vol527 .7 (bbl) (sk) Time Density: 10.70 (ppg) Water Vol: 251.0 (bbl) Class: G Yield: 4.28 (ft~/sk) Other Vol: 0 Purpose: PRIMARY Mix Water: 19.93 (gal) Foam Job: N Slurry Data Fluid Type: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: OF) Temperature: Temperature: Temperature: ("F) ¡OF) ("F) Stage No: 1 Slurry No: 3 of 4 Compressive Strength 1: Compressive Strength 2: Temp OF) "F) Pressure (psi) (psi) FLUSH Slurry Interval: (f Water Source: Description: MUDPUSH XL Cmt Vol: (bbl) Density: Slurry Vol: (sk) Water Vol Time 10.50 (ppg) (bbl) Class: Yield: :3/sk) Other Vol:40 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Slurry Data Fluid Type: To: t Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name ROT - DRILLING Stage No: 1 Slurry No: 2 of 4 Report #: 1 Start: 10/22/2003 ..-...--..- ..-...-... Spud Date Report Date: End: 11/1/2003 11/2/2003 . Cementing Report ConocoPh ps Alaska . Page 2 of 3 . . ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2003 1 Report Date: 11/2/2003 10/22/2003 End: .__..___Ir.ad_e .I\!ª!!!~__..._. .. Stage No: 1 Slurry No: 4 of 4 . Additives - - rW~-f~œ~_~~T ~2~"~=r~i'~I~~.· ..-_. . "~'- ----- ._.. .... . ..___...__.__. ··.__"o_.__n...._.. Units D65 D46 D79 Casing Test Shoe Test Liner Top Test . __.___..._ "_" .' u____. _. ... . ._, -- ..- ....... . ..n... _.. ..... . - . -----.... .... . ....-. ...---......... ..'---- Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: ..-_.. ----.,..... --,...'...,_. -..... -,."..,.". Log/Survey Evaluation Interpretation Summary .....-...--....".. . . ..--..--. .. ---,_............ . .-_. . .. CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: . ..---""" -.---"..,. --.. Remarks ...---.--......-.. . - -.-----.--.. ., ... . ..,.,-----..-....... ......,---....- ..... . - --.--.-.... --... - . ---........ Rig Dowell cementers, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.6 bpm @ 70 psi, Shut down, Test lines to 3000 psi, Continue pumping CW100 to a total of 40 bbls, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 6.0 bpm @ 100 psi, Shut down and drop btm plug, Mix & pump 527 sxs (401.7 bbls) Lead ArcticSet III Lite cmt mixed at 10.7 ppg w/30.0%D53, 1.5%D79, 1.5%S001, 43.1%D124, .6%D46, .5%D65, 9.0%D44 pumped at rate of 7.0 bpm @ 320 psi, Followed by 225 sxs (91.3 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg wI .8%D65, .6%D46, .6%D79 pumped at rate of 7.0 bpm @ 325 psi, Shut down and drop top plug, Displace cmt with 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace with 158.8 bbls 8.9 ppg mud (total of 178.8 bbls to bump plug) at rate of 7.0 bpm @ 670 psi, Slowed rate to 3.0 bpm @ 600 psi for last 10 bbls of displacement, Bump plug w/1150 psi, Check floats - OK, CIP @ 0705 hrs 11/2/2003, Had good returns thru out job, Reciprocated csg. 15' until dropped top plug, Had 188 bbls good cmt returns to surface. Printed: 11/5/2003 10:48:32 AM Printed: . __...__.___. _ .. . __ ._._________n.. ._.____....._ê.!I 9PI:;.B.~I.IQN~, _. __ .....__.__..___,.. __. __ ______.__ ____ _:_._.!:,_~.~_~t;.....; P BIT._ ___~F.'~. : 24~~_!?~!.....i._._2.~Hr -'-"~~_.~~~N.I HRS i.<?UM..~E"!!!l CUM. ~()~ . .-......--.... ---..-..-..... .. .--------..... -----. .....---. . ._--- PUMP I HYDRAULIC DATA ¡ ... ... ..-----....... .. .:. .---. . ..... ... ...!. ...-----.. ..... ...-... -roo . . __ ._._ _. ...__....... ... . ...... ! STROKE (in)! LINER (in), SPM ! Q (gpm) PRESS. (psi)! TOTAL Q i KILL SPM I PRESSURE ..-.-.-...... . - I . ..----.--... .,.... ! -----.---..... -.. -- p-- .---......... ___._n... .. -...-... ----- . 12.000, 6.000! 71 ! 300.34! 1.900 600.68 u_.____. .-... _u____... _ -. . ..----....- I . ·-..-1--- ---- ..-.--- , _.n1~:000 : 6.00~.__. .71 300.~i.._ _ 1.900! 6.9_~_:~8. __._. ...__... --.. - ... ......--..------ . .........-...--.. .... - ..--.--.-.--- _... .----.... ... .-... . .. .--- OPERATIONS SUMMARY -FÃOM ¡"'-'TO!HOÜRS" ¡- - C-ö'DE---"'~TRÕ-ÜBÚ(' suä--....;--PI.ïisi·"r" - .-. .. .--..---.-.....-" _"'""_h .....----- DESCÃIPT'iori----·-·----- ---.---... .-..-...------ 0ö'~ö(ï¡--õ1'~'Ú5-:' ... . ~ :·~5._ _ ~:ëASE-P· .. . - . -~~ UNë . "lš UR Y. ~~:Q~~~iï~ ~~n 9. 625" 40~! !if.¢'~ ~~g io: ~4.~~MD -(";~n !~taï!57jt~ 1_~'~M;U ï~ange~ _~_:: NO. ! -'1 ..--.-¡ Emsco .I_______n 2 Emsco ......-...--..-.- MAKE OF PUMP ...-.---.-.....-...... 15/2003 0:46:07 AM ---....---..-------..-.---..---.. -.---- --- BIT~.!!.~.f\I........L_ WOB ..--- BITS srr ì'FïüN"T--'''šizE -¡ .... MAÑÜ¡;:...· i' ·-ÑPË---:"'SËRIAL:·NO. : . . '-JETS()R TFA'rï:;ËPTJi iN DATE IÑ'-"T I-O-D-L-B-G.O-R "2-¡-----··2 ..:........ ..~i~~~jHUG~Ù~S-c_I:!.F! ..'H~~605--;-7·1·o·11"9~_·..I~.:-·1~/_1·4Ò.~~1..4~~~ï-·--"·"· 2:~?~:..~ji!2I2ÖO~ o~~~~~~- ---.-..... .. ,[=~.~-~. i .-..... GPM . . -..- ... .~rill Pipe .-_H..e~y.y..Wgt Ghost Reamer · . n__ ____ Drill Pipe ..Re~istivity To,?~. ORD/CCN · _ n_u__ . MAP Wre~~ure) MWD - . -. -. - . Cro~~9..ver - Non Mag Drill Pipe :_!,!on-Mag 4 C?~P Serv Drill Pipe - N.o~fIII~!;I 4 Comp t)~nt I?rill Pipe - Non_-~~~..~ Comp Se~. Crossover .______ . . . .. ____u Drill..£'.~p'_e - Heavy Wgt Jars i ""1 25 ____0" . 4 1 1 r'--- 28.53 1.22 120.92 30.60 755.05 6.95 1.30 29.20 29.20 -.-- 6.750 6.750 6.000 5.000 5.000 5.000 6.438 -.. 5·-~<>'9.--t- 6.250 I ___n . . 5.000 8.500 5.000 3.000 2.250 3.000 2.750 4.281 2.813 2.750 2.750 2.813 .. ..--. 2.813 , 3.70 2.02 16.64 15.50 7.22 29.49 :ECD ¡MUD DATA! DAILY COST . --. -----.--.--. - . ...---.---........ ,... . - ..-- -....---J FCrr.SOL ¡ OIUWAT i "IoSandIMBT: Ph/pM .. _.. _.._____ _-1___.... .. .. _ ..__..__ ___.. . . . ~ . . . .. _ _ _ __.__ _.. I ¡ I : I . I i __._... 1____ I . .. __....___.. ,.._. _ ____._ · 'BHA t-io':--r" 2' , .........---.--. BHA i HOLE-CON DiTION's"-"---" -ã-HA W;::[iE·LOW-JAR~f~~.:~ :STRIN~..W~~.~_:'~.'" ·STRIÑ~~~!.::~~.:. ï ...-... sTIïi~ÙiWT. RO.f'·. ..;:....~-.~~.~~~IE-.'..UNITS- ITEM DESCRIPTION O.D. ...-...-..- .-....-.... 8.500 6.750 Bit ... .. .---.-. .. Turbo-Back Stabilizer Mud Motor . n___. ... S!~bilizer - NonMaQ. Crossover - Non Mag i I I I -LEÑGTH-" T .! 1.00 I 1.05 : 31.53 6.750 8.375 6.250 6.750 6.750 ..D. '-T -.-----.. . 1.875 -. .. . -..-.-. 2.813 2.813 i--·o_.ns - r-'eiT NO:-r .-. 2 :-~i:' ... ·ä-i:.i\t~TH- _.._.__. CONN SIZE ' CONN TYPE I ..I.. ¡ ._9-ºlL_._. ... _. _ ___... ..-+~;~454:º-.L~¿lZ:º__tFS4.00 . nt~~ ~~·....~.~;;/200~.I FIELD NAME I OCS NO. jAUTHMD I DAILY TANG : CUM. TANG Doyo~..Ji!...__: ME~_"J::~~TE:R I _6.!º~~:0: <:1___.__! ..__.._... 0 : ACCIDENTS LAST 24 HRS.? : DAILY INT WIO MUD ¡CUM INT ANG WI MUD ; 0 1- 0 ---..-.------- - I __.__...________.._ . ________ ... n _ ...1..__ . ____ 24 HR FORECAST ! DATE OF LAST SAFETY MEETING DAILY TOTAL I CUM COST WI MUD Drill q~t _~~a,~9.e over t~...1$ND mud, LQ!J...P.~!!!...8-1/2" hole._._ _~. __ ._... .11_~?!2091___.__.._ . ~-ªP.!.º'§Z.. _ _ .!. __ _ 1,08:3.!!!Q1_.. LITHOLOGY ,JAR HRS OF SERVICE 'BHA HRS SINCE INSP ! LEAKOFF ¡ AFE AUTH. .~----.-.... ..--L..--- _ .._ _......l_. . . ~___ .1003079~_ ...___~_ n.___.. _ n._ INC AZIM I LAST CASING . NEXT CASING i LAST BOP PRES TEST 22.3~0_____J-ª9:!70 ! 9.6g§J!!!L~__ 2.4.~!!:º_tft).......i..~:500 (i~1~__§"994,0 (ft) I ____. 11!_?l200~__. O----TCUM CO·S':'--;-" ...-.-.------.. .. . ····-·r:.. PflMf ¡ CI 1 Ca ; H2S i_ .-~~-=~=~:. . '1 - --..... .. .. . . ......--.- - . )ENS!:rv(~!'..9..)... ¡ FV . PVIYP ¡ . n_ __._.. .. .. 88 ¡. _~~!54. :. DATE 2,387.98____ 12.00 : PP : .. ___n.__ _._. : .GELS. !V'..~THP 19/25 I .__{... .---- o ; LIME"r _.L___-I.. ES 11/1/2003 .-----. LAST SURVEY: Thorn.tol'!._ ...l._ STATUS 2P-432 RIG NAME & NO. Gladden CURRENT .- SUPERVISOR .-------- TMD Drill out shoe -ºº~.~ rack WELL NAME JOB NUMBER .__.......l._. Daily Drilling Report EVENT CODE 24 HRS PROG -- . ConocoPhillips Alaska, Inc. Page 1 of 2 2P-422 -. Fuel RESERVOIR NAME ITEM .__9_~~~ ... .. - -. - --...--- MATERIALS I CONSUMPTION USÃG-E- h.h 1 .. ON HAND ...] - . . ..reM' '_h . .. ----..--. .: . ---..----."1:. .----. .m. ___._~o i .____17.12~. ..Wa.t~.r.~'p"~~I!ing .. -. .... --.--.--... . .. .--.. ....-..--.-..- RESERVOIR AND INTERVAL DATA . . u_._.....~.~~.NEu-..-. ~_.~.=·..~!.~P---·-·!"·:~~~~~-r"'~·~.· .-.. ._ 2P:432 ' . !.~~~ I ...?_J ~50 Printed: COMMENTS -jJ~ï~_··"f..· -- b~I.~_ . /5/2003 ............ USAGE ; --90S---r 0:46:07 AM .-.. - ON HAND 670 ....-........ UNITS ---.. Conoco~~!lips Compaf'!.¥..". Doyon ~~~ling Inc ..._!.. Baker HU.Q.~_es Inteq . ___.__ Baker fi~~hes Inteq '.E.J . . ...----... . -.----...- PERSONNEL DATA f-"-NO.._~~~~.~RS~: ··-~~~~-·C-~MPÃN·V~~].. . .._~_~_ . . !I Ep~?~_~ell Services I~.~ .. 31 , Doyon Universal Service; . .---- r .. .-...... ,,--.. . 2 I II M-I Drilling Fluids ' . . ..2..-.....--u.---.. :¡ APC ~ ÄI~ska Petrol~~;:;;_!·· ._.. _._____..'--__..__. . . _____ . ___ ..0. --.--. 4 5 2 2 COMPANY SERVICE SERVICE NO. HOURS ..BOPE, Mak~.~p .BHA #2 .-. .--- - - ...-. .... 24 HR SUMMARY: Finish RIH wI 9-5/8" csg to 2449' . - 20:00 21:00 21:00 00:00 .__n . _ 1.00. ..I DRILL P 3.00 ' DRILL P .-. 11 :15 14:30 14:30 20:00 _n. 3.25 5.50 07:15 07:45 10:30 Öi:45 i 0.50 _ _ _ .i . 10:30 I 2.75 11:15 0.75 i ! I CEMENT P . . WELCTL P WELCTL P i WELCTL P WELCTL , .-.. PULD PULD .--. .-- --- ---.--.. ..- Cement same, Nipple down diverter system. Nipple up casing head, Nipple up & test . . - NUND BOPE PULD NUND NUND to 1000 psi- OK. SURFAC Nipple up BOPE. SURFAC¡ Rig & test all BOPE to 250 psi low & 5000 psi !w~ived by AO~_~.C_C.huck Schev~.. _ n.n S.l!.~FAC. Pick uPn1ß..i?ints 5" dri~IJ:"ipe and stan.d back in de!.~9.k. SUR.F.~~~.Make up ~~A #2, Orient ":I_O!O~, progra~ ~WD. L"?~.~ RA s?,urces. high, Hydril to 3500 psi. Test continue to displace wI 158.8 bbls 8.9 ppg mud (total of 178.8 bbls to bump plug) at rate of 7.0 bpm @ 670 psi, Slowed rate to 3.0 bpm @i 600 psi for last 10 bbls of displacement, Bump plug wI 1150 psi, Floats held- OK, CIP @ 0705 hrs 11/2/03, Had good returns thru out job, Reciprocate csg. 15' until dropped ¡ plug, Had 188 bbls good cmt returns to surface. suï:iFACj ~i~ d~~~'C_l1!t head, Lay d~~n landing'j~int: . SURFAC Nipp~edown divE!~e~ system. n.. SURFAC Nipple up casing head & tubing spool. Orient same, Set .--- . test plug, Test seals ! , i i I I EVENT CODE _... QJ?13 .-.. -...-.. .--- OPERATIONS SUMMARY CODETROUBLËf'sUB!-PHASE 1--- . ..... ...-...-.-.-..-.---- CASE P --¡... ... I RU-N"C- . "SU'RFÃ"C" MU"la~di~g jt'.---. .... CASE P--;- .. ¡ CIÄ-C'" ¡ SURF'AC Ci~c BU wI F~ank~ tool· St, ;~-~ps I I ~O(Jpsi' -~Ä~'~~'- ¡ ...u~:_-~~~~·- . ·~~-:f~â¡~~~::-~:~Jii~~~ :~d- ~B~ ~T~ ~p~ I ;~~~~--.... 1.____.... . _____ "__n_ . ...___.... .. _ _n.__ ._____ . .. _ _un ¡CEMENT P PUMP iSURFAC Rig Dowell, Mix & pump 10 CW101 I 5.6 bpm @ 70 ! I' psi, Shut down, Test lines t DO psi, I I .-_"'.-'''", ",',.100 to total of 40 : bbls, Mix & pump 40 bbls r.. USH II mixl ¡d at 10.5 ppg at rate of 6.0 bpm @ ! 100 psi, Shut down and drc n plug, Mix & pump 527 sxs (401.7 bbls) Lead : ArcticSet III cmt mixed at 1v , ~ .3 bbls) ; I Followed by 225 sxs (91 0 ppg wI additives at rate of 7.0 bpm @ 325 psi, Shut down and drop top plug, Displace cmt wI 20 bbls fresh water, Shut down and turn over to rig pumps and I i ; , ! .... .., Dpg wI additives at rate of 7.0 bpm @ 320 psi Tail LiteCRETE cmt mixed at 12. . ...... FFI~~L_!~ ! .!l0~~~ 00:00' 01 :15 1.25 . ....----. . ... -- -- 01:15,02:15¡ 1.00 .. -'-T'" --1·-·.....· . 02:!~ I 02:~~_L. 0.50 02:45 ; 05:00 ! 2.25 ._ ___ _n.._u.. 05:00 I 07:15 2.25 Continue n' '~n:"n "'" DESCRIPTION WELL NAME . 2P:4:?g,,_ __...1 JOB NUMBER n9 Report 24 HRS PROG !TMD ~. 2,454j) TVD 2,;iZ?...:.º_ DFS 4.00 REPT NO. DATE .5____U.1/21200_:? . Daily Drilli ConocoPh ips Alaska, nc. Page 2 of 2 PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: 2P-432 I Rig: Doyon 141 Date: 11/3/2003 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Dear! Gladden I Mike Thornton I Pump used: I #1 Mud pump I· Strokes I.., O. 1 01 0 Bbls/Strk I .., 5.0 Strk/min I.., Type of Test: I Casing Shoe Test LOTI FIT 1.1 Pumping down I annulus and DP. I. Gas In 1 est Pressure Integrity Test Hole Size: 18-1/2" 1"'1 Casing Shoe Depth I Hole Depth PumpinQ Shut-in PumpinQ Shut-in RKB-CHF: 25.4 Ft I 2,449 Ft-MD 2,372 Ft-TVDI 2,474 Ft-MD 2,395 Ft-TVD Strks psi Min psi Strks psi Min psi Casing Size and Description: 19-5/8" 40#/Ft L-80 BTC I... r 0 0 0 3500 0 0 0 1046 Casing Test Pressure h,tearitvTest 2 50 1 3500 2 115 0.25 1046 Mud Weight: 8.9 ppg Mud Weight: 9.6 ppg 4 123 2 3500 4 366 0.5 1046 Mud 1 ° min Gel: 8.0 Lb/100 Ft2 Mud 10 min Gel: 10.0 Lb/100 Ft2 6 287 3 3500 6 713 1 1046 Test Pressure: 3,500 psi Rotating Weight: 108,000 Lbs 8 541 4 3500 8 900 1.5 1046 Rotating Weight: 110,000 Lbs BlockslTop Drive Weight: 35,000 Lbs 10 820 5 3480 10 1046 2 1044 BlockslTop Drive Weight: 35,000 Lbs Desired PIT EMW: 18.0 ppg 12 993 6 3480 12 2.5 1044 Estimates for Test: 2.1 bbls Estimates for Test: 1036 psi 0.6 bbls 14 1180 7 3480 14 3 1044 1...1 ...1 16 1380 8 3480 16 3.5 1044 EMW = Leak-off Pressure + Mud Weight = 1046 PIT 15 Second 18 1611 9 3480 18 4 1044 0.052 x TVD 0.052 x 2372 + 9.6 Shut-in Pressure, psi 20 1850 10 3480 20 4.5 1044 EMW at 2449 Ft-MD (2372 Ft- TVD) = 18.1 ppg 1046 22 2120 15 3480 22 5 1044 4000 ¡:: Lost 20 psi during test, held ~ 24 2400 20 3480 24 5.5 1041 1= 99.4% of test pressure. 26 2700 25 3480 6 1041 3500 28 2965 30 3480 6.5 1041 30 3275 7 1041 3000 31 3545 7.5 1041 8 1041 LU 2500 8.5 1041 ex:: 9 1040 ::::¡ , 9.5 1040 U) 2000 U) 10 1040 LU ex:: c.. 1500 1000 , I I , , 500 0 0 1 2 3 4 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes Volume oume vo ume -'-CASING TEST _LEAK-OFF TEST 0 PIT Point Pumped ",BaCk Pumped Bled Back 3.1 Bbls I BblS 2.4 Bbls 1.ö tsDIS ,-,omments: ConocoPhillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD rTVD IDFS I I ODR I 1,098.0 3,552.0 3,398.0 5.00 FIELD NAME I OCS NO. AUTH MD DAILY TANG MELTWATER 6 094.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 11/3/2003 127,576 LEAKOFF AFE 18.09 DENSITY(ppg) i 12.05' i pp' -. .. --iecD ;"MÚÓ-DATAi DAILYCosi":-' -6' :'-CUM'CÖST- -"0 . .... --F"Y--:--PV;VP 1...·GEiS ¡ wutirHP' FC¡:¡':SÕi. ¡----öiuviAT i %S-~ndIMBT-"r"" Ph/pM ....-...-·--PiiMf <:,....... .¡ "'--"'c~ r H2S 'r LIME í --ËS"'" --¡-¡Oï66 \--1"9/27'j ..-...."¡' . . ¡I' . r-"'-" I" ï ..--/-...-......¡.. 9.11 ..-T----¡.. .....'j" r·n"'- r----..r.. [--..-. BHA_N.():...~__.._ .... ~ .1..:,.. _.....~: _.......~...._____..~.. ...... . ".:' "'--·"'.:·..__J~_HA.l.._Hº_~:~ .~OÑ_º'TIO"t$~":~..·- _:~"~___....·..·::::---~....._.1.BIT-~~:·......L__.. 2 ..-.-.-- ...s.~~ WT. B1~L~!!~=:-·S.I.. STR'N~3.:~~~~=-:=:_':_[ STRIN;~¡'~:·~~==~:.~_L:. STRI~i;~~~~:~_" I TOR~:~fb.Ë:~~: 1..·:..=.·:..·B~~~~;;i¡-:~~-.-.. . "'_.__ ........ .... _!~~..c..~.~.CR.IPTION _...._.... .. .1 NO JTS . ..._~~~GTH .. ..~~.:..... _.... ¡ I.D. . .: __~ONN S!~~..: _CONN ~!~.. 1.00 8.500 1.05 6.750 31.53 6.750 3.70 8.375 2.02 6.250 16.64 6.750 15.50 6.750 7.22 6.750 29.49 6.750 1.30 6.000 29.20 5.000 29.20 5.000 28.53 5.000 1.22 6.438 120.92 5.000 30.60 6.250 755.05 5.000 6.95 8.500 5.000 . . WELL NAME 2P-432 SUPERVISOR IRIG NAME & NO. Gladden I Thomton Doyon CURRENT STATUS Doyon 141 Drillina 8-1/2" hole @ 4130' 24 HR FORECAST LrrHOLOGY Drill 8-1/2" hole to TD of 6,094' I JAR HRS OF SERVICE I BHA HRS SINCE INSP INC AZIM I LAST CASING 21.510 190.510 9.625 (in) @ 2 449.0 (ft) NEXT CASING 3.500 (in) @ LAST SURVEY: DATE TMD 11/3/2003 3431.58 Bit Turbo-Back Stabilizer Mud Motor Stabilizer - Non Mag Crossover - Non Mag Resistivity Tool ORD/CCN MAP (Pressure) MWD Crossover - Non Mag Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Drill Pipe - Non-Mag 4 Comp Serv Crossover 1 1 1 Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt Ghost Reamer Drill Pipe 4 25 ---..,-.."...,.. .,..... -. ...--.... .. -.-.-------.-. -.-..----..... - Page 1 of 2 IREPT NO. DATE 6 11/312003 CUM. TANG o CUM INTANG WI MUD o CUM COST WI MUD 1,211,480 AUTH. 10030793 6,094.0 (ft) LAST BOP PRES TEST 11/2/2003 1.875 2.813 2.813 2.813 2.813 2.750 2.750 2.813 3.000 2.250 3.000 2.750 4.281 __n._ ____.____.. .------- BITS .. äiT '-RUÑ . .:. S·IZE.....-r-·MAÑ-U¡,;:-..-.... i' "TYPË'" T sERiÄL'Ño~"': JETS-OFITFÃ"''''- ...- .......·-.;Ë'PTii iÑ"'DÄTË INmr..·.. ,-o:D~L-ii~G-o-R ..-.. -----'2 T...... il'-" -"'ã~5-0olHCiG-HES-ëHR I HCM'6ÕS-'ï71'Ö1'Ù}5 I 14/14/1-4/1-4/141 . n·--t-2~454.0 11/2/2ÕÖ~ o~o---:~=--"'" ..- .-- BIT I RUN _n"'-2T'" ... - 2' i -...-...-...... ..-...........-...-....--...,...- -..-----. . ...----- .-. -. ..-- ..--.----..... .... BIT OPERATIONS ..-Wë)"B---;-.....·RPM--· .. ¡. GPM" r"PRESS-T "'-P"BIT I' ·ï·iFis-·-r24H~ DïsT- r" "24H~-Ã'o'p' ! ëü·;';ï"Rsl ëÜMDEPTtîj -6ÜNí'ROP- . 5/2Õ' ....-...¡ "'6"0/ 90"¡ 500 "'12~2ÕO"'''j'' 391 i '1-0-:-70-"T -"1";Ö98.Ö -"r"'1oÚi2 i '10:70-" ï ·-Ü98.0 ·...1 -1"Õ2.62"'· .._,--"'..._-_......... ...,_... ,...-...". .m..'.___.._n ......... .-.--.. -- ..-..-. ...,..,... . ....-. SURVEY DATA M.D. IN-CL::"';"'ÄzIMUTH' : "T.V.D. ' ¡;Ús'-ëü-",TENïcUMI'SECTlO¡:" :....--Ní:ï:):· i' ·INCL. T 'AZIMUTH ., T::;¡:D-:!Ñis c"U;';TEiw CÜM:'SE¿Tïofll ........-,.-,.-.....-.. I ._._.__..____._..._...__._....~......._... .i ___.___._...:.__...........: . ... .______...,..__._...J ___._ ........ ..;....___..... ~ ..__............. .__ 2,499.45 21.380 191.580 2,418.93 -466.45 -116.72 480.82 3,060.01 22.110 197.370 2,940.03 -667.29 -164.49 687.23 2,593.73 21.100 192.320 2,506.81 -499.86 -123.79 514.94 3,153.81 21.750 197.750 3,027.04 -700.69 -175.06 722.21 2,686.02 20.930 192.150 2,592.96 -532.21 -130.80 548.01 3,246.25 21.510 197.610 3,112.97 -733.16 -185.40 756.23 2,780.56 21.460 192.330 2,681.10 -565.61 -138.05 582.16 3,338.71 21.250 197.590 3,199.07 -765.29 -195.60 789.88 2,873.13 22.230 193.080 2,767.02 -599.21 -145.63 616.59 3,431.58 21.510 190.510 3,285.56 -798.08 -203.79 823.68 2,966.97 22.270 195.750 2,853.88 -633.61 -154.47 652.11 Printed: 11/5/2003 10:46:29 AM RESERVOIR AND INTERVAL DATA .. -=~J~·:.~o-P-·.·.·,[" 'BASE_ _:.......-. 648 2 '850 Printed: 1/5/2003 0:46:29 AM RESERVOIR NAME 2P-422 ..... .- 2P-432 .. - -. .------.--.--. Fuel Water, Drill!~~_.__.___ ..--. ITEM UNITS gals. . bbls ZONE L_ MATERIALS / CONSUMPTION - .._U.SA~~.~-_· -[- -·oÑ--H~~~-~~·I:-"·...· :. . -.I:rEM -... .. ~__._~~~=. 920 16,200 .;Water, Potable . ·-.=.=:~.~.O _:. :~~~J_~____ -- I COMMENTS uÑiÿs'-'-"-T USAGE -..----. ..--. gals -r'- ___1_ ON HAND 13,980 ...---... _.. COMPANY __ . . . .. .___...___.__n ..._ 90nocoPhiUi!?~9<?mpany p!?yo~ Drillin~ !.~~ _.. Ba~.e!:.!!ughes Integ Baker HUQ~~.~..lnteq -- --.-..- D: . ............ ... _.J::'~;f.I~pNNEL D~n~.___.___ NO. HOURS ;i COMPANY - --- - -"Ü--" -..--.- . .--.-----.... _l ~p~~h Well Servic_e~ !':!? . Doyon Universal Service ! ii M-I-D~¡,!i~i~I~.~d~ - ---.='~.__ :: APC - Alaska Petroleum ... .. -.-----. 3 30 3 2 , I I .... . ..-.--...--.-----. . NO. ; HOURS .-. 4'!" --...--- 5 2 2 .-.--------.. - SERVICE ..- .- 24 HR SUMMARY: Pick up BHA #2, RIH 18. Perform FIT to to 2,039' ppg EMW ! ...n _ ___. . n_.. .__. . __ _.. Perform stripping drill, Test csg to 3500 psi, Drill out shoe track to 2,454', Drill to 2.474' & Drill to 3,552' --...-----.. SERVICE OPERATIONS SUMMARY ;~t~i~ H:~~_i:~~ i1R:U.LEr~~~;::~it~ië:;~~i:;~P._~t~r::RIH' 03:00 _~~~~_:" 1.75 I¡D~i~~___:·."'. ' SFTY :__~~Y~~A¢I'Ri9 & perf~~rn-:.~~~~~:~tn_·PPin~:~~~" kill dri~~iih'~li!"IQ~ë 04:45 .~~~~...: 1.00 . D~!.!:~~I" : DEOT _n~U_'3.':':~CI RIH to 2,317'! .f!i9..~__!~~t 9-5/8" C:~~~.!? 3~~_p~i f/3~.~! 05:45 O~:~~ j. 0.75 : DRIL_~X _;'" _ . pRLG .}~!:!.!3_~~C?: RIH & tag float c<?"_~r_.~_ 2.360', I?~~~_~_~.!..~~_o.~ t!.ack an~.c:.~ .Q?:~O 07:151..._ 0.7§__. n~.RILL p! ___~!...~~_ 'SURFAC. ~~~~.~_over to 9.6 ppg_~SND.Mud. . ..______. .~2:!_5_._ 07:30 ! 0:25 ___~.~)~L P ;DRL<?_ ~URFAC! Dril~ ?~~!,~~_~.ole for LOT ~o...¥.~~?~'. .......___. .. . 07:30 . 07:45 0.25 DRILL P II CIRC ! SURFAC: Circ. btm's up for LOT. 07:4·5TO~:~.9.. 0.75 DRILL ~._. FIT' '_~§~:~~~~l!,erform FiT-~ithn9:~_ppg. mud, 1046 P~!~_?.:~....95' TVD:'-_~~~ 08:30 . 08:~~ _ __ 0.25 DRILL P : SFTY _ PR0..o.__ ;.~eld Production hole ?~f~!y meeting with 1i"..~~ø_ p'ersona~.... 08:45 09:15 0.50 DRILL P CIRC, PROD 'Perform PWD baseline test. -------.-. ... . .. .. . . _ __._...______. .. __ ._n _ . ... . 09:15 00:00 14.75 DRILL P DRLG ! PROD Drill f/2,474' to 3,552' (3,398' TV D) ART = 8.8 hrs AST = 1 " nn;, VVU,-, " ! RPM 90, 510 GPM @ 2200 psi, TO 2I8K on. 4K off, UP 138K, DN 116K, : 126K, ECD's 10.4 to 10.7 ppg, Control drilling at 150'/hr to control ECD's, Pumping unweighted sweeps every 4 stands, No noticable mud losses, BGG +- 50 units. ....---.---.. - n' , ...._~ "-20K, ROT _____h_.. --r------ -.-.- .~~:........!___._._... . MA~~~.!:..."'.U..MP. 1 : Emsco .....---.- 2 Emsco -----.... - PUMP/HYDRAULIC DATA r-- ..-------.--.--..-.------.-------------,------------..-.- !STR.~~.~.!.i.~>..i. _~~N.ER (.1~>.._L-~..!~-1~ (g.p!,,> j~~~~~:..!~~i)j_.!~T~L Q_I KILL SPM i 12.000 I 6.000: 60 I 253.81 2,200: 507.62 .. ...------..-, --.,-----~_._..._.. ,-..---...---... - , ._.____~:OOO. I _.. 6:~0..Q! 60 ._. .2.~~.8!_L__,g!2~0 I 507.62 !_._ - -- PRESSURE -- WELL NAME 2P-432 JOB NUMBER! EVENT CODE 124 HRS PROG i ()º~._ -,-__L098.0 TMD I TVD I DFS -ª~§§?...:..9.. :.... 3,398.0 ; __?..:.99 REPT NO. 6 DATE 11/3/?_Q9_~ . Daily Drilling Report ConocoPhillips Alaska, Inc. . Page 2 of 2 ConocoPhillips Alaska Casing Report Page 1 of 2 Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Report #: Start: 2 10/22/2003 Spud Date: 11/1/2003 Report Date: 11/9/2003 End: -.". .--_. ......-..-- . ...---- ........-...- . .....-..-. . ,...--.---. ....-...-.---. ..... .....- ....... .....-.--.....-.----- ._~ . ..-..--. . General Information String Type: Intermediate Casing/Liner Hole TVD: 5,307.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 24.00 (hr) -.---.. . ._u·_··· . . .---.--.... ........- _._on.__ . .. Permanent Datum: KB (atdb) Hole Size: 8.500 (in) Hole TMD: 5,613.0 (ft) KB-Datum: 224.00 (ft) Water TMD: (ft) Str Wt on Slips: 120,296 (Ibs) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 23.52 (0) . Mud Lost: 208.0 (bbl) KB to Cutoff: 25.39 (ft) Days From Spud: 11.00 (days) ...--.---... ....'.---. -- . . .---.. .._~.__. -~-- ..---.-...... ..---- Casing Flange I Wellhead .-.. ... --... . --.-,.. --- . .____...... . _____._.._ - . "__o··__n _.._.. . _._ . ___ _... .. . ___.... ____._ ...~. ____... .. ._ _______.____. _ n_____.___ . . ._._. ___. __.___._... . _ ..______ _ ._. ..__...._. Manufacturer: FMC Hanger Model: Actual TMD Set: 5,602.33 (ft) Model: Gen V Packoff Model: Top Hub/Flange: (in) 15,000 (psi) BTM Hub/Flange: (in) 15,000 (psi) ...-"--. ..--. ..-.-- ..----. .....-...-.---. . .....--.--..---- ,--.----.. . ----. .--.-..-... Integral Casing Detail . ..___.m ..-..--.-.....---.. '-'---1'" .-.--....-..---. .-.-...---,.-.-.... '---"-' .--.-.--.....--... ....-,,----..-....-..-----...... ...----... ..-.----.-----....... Item i Size I Weight ¡ Grade i Drift ¡ Threads . JTS ¡ Length: Top :MU Torq.:THD, Manufacturer ¡ Model : (in.) ! (Iblft) I I (in) I : (It) . (ft) : (fHbf)· i i -·"-T··'" .......- .. -"--"-T'- .--:=i---..... ..-.---- ; Condo 'MaxOD! Min ID ! Compo Name I ; (in) : (in) : Casing Hanger 7.000 BTCM 1 1.58 25.39 Casing 7.000 26.00 L-80 6.151 BTC-MOD 135 5,493.92 26.97 Float Collar 7.000 BTCM 1 1.32 5,520.89 Casing 7.000 26.00 L-80 6.151 BTC-MOD 2 78.65 5,522.21 Float Shoe 7.000 1 1.47 5,600.86 5,602.33 -.--. . -.- -. .....-. -.--- . ..'..- .....-.. . ..--- Casing Hanger 6.276 7" 26# L-80 Ca Float Collar 6.276 7" 26# L-80 Ca Float Shoe .-.-.----. ......----... . ..--.-.... ...---.. .-- -.-.-.-... -.-- Non-Integral Casing Accessories ---.... ... ..--... ---.... .--'-". --..--. .--... -.--... .-..-- .-..-.-... .-.-.. ....--.--.... ___no ..... -----. . .. .----..'''... . ....-.-.-.-.........-.---1-........ - -.....-----...--.....-. . ----.-..-..........-...--....-.-........--- Accessory i Manufacturer ! Number ! Spacing 1___._.. .. .. . ._._._.._.....J.I:!~~ryª!_..._ .... _ .._..__._.....! How Fixed ; (ft) i Top (ft) ! Bottom (ft) : lWEATHERFoRD .._1. 29\ I 5,602.01 4,500.0 Overeollar WEATHERFORD 19 2,400.0 200.0 Floating ... -. ...-"" .---- ..-- .'.-.. .-.--. ...--- . .......--.-... -.......,....... ... ---.. .--.-- - ..-.- ....----.-.. ----.. Bowspring Centralizer Centering Guides Remarks ----.. ---.,.. ---.. -.- . .--- -."....... ---... ..--.. -.--- ...---.--. -- .--....... .--........... .--. -. --. ...-.-.- .. ..--. Rig & ran 7" Float shoe, 2 jts 7", 26#, L-80, BTCM csg, Float collar, 135 jts 7",26#, L-80, BTCM csg, FMC Gen 5 Casing hanger & landing joint, Placed Bow spring centralizers 1-15' above shoe on stop collar and 1-15' above float collar on stop collar, and 1 on every joint from shoe to joint # 28 for a total of 29 centralizers. Printed: 11/10/2003 7:15:21 AM GonocoPhillips Alaska Casing Report Page 2 of 2 Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Report #: Start: 2 10/22/2003 Spud Date: 11/1/2003 Report Date: 11/9/2003 End: ..--' -...-.----."...-....-- ._-------.. .""--"--'"' ..' ........--...... ""'" ..---... .....--.. ..-"'. .---...-.,..-...". ..-.----'''.,.. . -.--- Remarks .__.., - __.___n.. .__. __ .___.. u_... .__. -----.... . . ___ - - . . _.___... .... ..._ - __. _____m " ._............... ____.... Casing ran in hole fine with very little trouble, Had very poor pipe displacement while run in hole, Lost total of 208 bbls running pipe in hole, Attempted to eirc. casing several times on way in hole at 1,200', 2,440', 3,240', 4,050', Had at best 75% returns pumping at only 1.5 bpm, Had only 20% returns at 4,050', Landed casing with shoe at 5,602.33' and float collar at 5,520.89' . Printed: 11/10/2003 7:15:21 AM Printed: /10/2003 7:15:33 AM Test Data Thickening Time: Free Water: Fluid Loss: Fluid Loss Pressure: (%) (cc) OF) Temperature: Temperature: Temperature: OF) OF) OF) Compressive Strength 1: Compressive Strength 2: Temp (OF) ('F) Pressure (psi) (psi) Slurry Water .---- -- Slurry Data Fluid Type: Interval: Source: FLUSH 1,606.00 (ftJTo: 2,730.00 (ft Description CmtVol: Slurry Vol CW (bbl) (sk) Time Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield::'sk) Other Vol:30 0 Purpose: SPACER Mix Water: (gal) Foam Job: N 100 Stage No: - ..-.-----....... Type: Non-Disp. LS Density: 11.5 (ppg) Vise: 67 (s/qt) Bottom Hole Circulating Temperature: ("F) Displacement Fluid Type:Mud .. .... -.-. .. -.-. ..-. PVIYP: Density: 34 of3 Mud Data ......... ... ... .----... .. (cp)/34 (lb/100ft2) Gels 10 see: 15 (lb/100ft2) Bottom Hole Static Temperature: (OF) Volume: 214.00 1 11 Slurry No: 1 .5 (ppg) (bbl) Gels 10min: 18 Ib/1001(2) Meas. From Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 63 (gprn) Mud Circ Press: 350 (psi) Top Plug: Bottom Plug: 11/9/2003 Y Y Press Bumped: Press Held: Float Held; Type: Cement Volume Excess %: Casing 75.00 i .---- ----.-- ---..-.. i Start Mix Cmt: : Start Slurry Displ Start Displ End Pumping: End Pump Date: -- 05:00 05:45 06:55 10:00 Disp Bump Plug: Press Prior: Disp Avg Rate: Max Rate: 1.50 (bbl/min) 1.50 (bbl/min) N 200 (psi) (psi) (min) Y I i i Ann Flow After: Y Mixing Method: Batch Density Meas By: Densometer Returns: None Total Mud Lost: Cmt Vol to Surf: 335.00 (bbl) (bbl) Rot Time Start: : Rec Time Start:03:30 ----... Time End: : Time End: 09:30 -- RPM: SPM: 1 Stage No: Init Torque: Stroke Length: 1 1 't-Ibl) 5.0 of 1 1 Avg Torque: Drag Up: (It-Ibl) 1 75,000 (Ibs) Drag Down: .-.-...--- (ft-Ibl) 125,000 Ibs) - - Max Torque: Pipe Movement Cement Co: Intermediate Casing/Li Dowell Schlumberger .. u _.__ on Cern enter: Dennis Davis Pipe Movement: Reciprocating - -. _. Cmtd. Csg: i I Cmtd. Csg: Csg Type: sa TMD: sa Date: Cmtd. Csg: I I Cmtd. Plug Date: Plug Type: Drilled Out: Csg: ___ )liry. Hole Size: (in) TMD Set: 5,602 (ft) Date Set: 11/8/2003 Intermediate CasinglLi 7.000 (in.) Csg Type: Csg Size: sa TMD: sa Date: sa Type: 8.500 .__.+_ ~qlJeez~ 9p~~J-I_0!.~..... Hole Size: t ._..._...__~._.... $queeze Casing 'Hole Size: TMD Set: Date Set: __-1- -. __nE.[!Jg Hole Size: Top Set: BTM set: i t f Legal Well Name Common Well Name Event Name 2P-432 2P-432 ROT - DRILLING Cement Job Type Report # Start: Primary 2 10/22/2003 Spud Date Report Date End: 11/1 /2003 11 /9/2003 . Cementing Report ConocoPh ps Alaska . Page 1 of 3 . Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING . ConocoPhillips Alaska Cementing Report Page 2 of 3 Report #: Start: Spud Date: 11/1/2003 2 Report Date: 11/9/2003 10/22/2003 End: ..-- __.. .n."" ___. .. ..,on.. , Stage No: 1 Slurry No: 2 of 3 . ._. _n_____._ _.___.___ _ _._.....___... ._....._... .__.. ._..._. n_._ _n ___._.. _.... . _. .n.. Slurry Data Fluid Type: FLUSH Slurry Interval: 2,730.00 (ft)To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) ... .. ".0- __0__ ..._.....__..__._______.___._. ._ ........ Description: MUDPUSH XL Class: 4,500.00 (ft) Cmt Vol: (bbl) Density: 12.00 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) O1her Vol:40 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) ............. . ..... - - -. ... ... ... -. -.... .-...----,----...-..-....---.- -- Stage No: 1 Slurry No: 3 of 3 -...-.... - ..---. . ... Slurry Data Fluid Type: PRIMARY Slurry Interval: 4,500.00 (ft)To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) .. ...... ....... . - . . ... - - ..... ---.--- .. --.-.-.".......-..-.-.-...-...."..".-... ... ... . .. Description: LiteCRETE 5,602.00 (ft) Cmt Vol: 51.0 (bbl) Slurry Vol:130 (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 12.50 (ppg) Yield: 2.20 (ft3/sk) Water Vol: 24.1 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) ...- .. ..... -. .......-.-,.--..... .. ...-.. ....-,..-. .......-.- ................-.-.. ... ......---.-.-.... ... .n Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) .. ..-.-...-..-..-- -......... ._..... .._...'_..n Purpose: PRIMARY Mix Water: 7.79 (gal) Foam Job: N Pressure (psi) (psi) ...-.....--..----. - Stage No: 1 Slurry No: 3 of 3 - Additives . ....... ..---.-.----.----.----¡-----.---..--.. -..... ,- .. . ....-. . ... . . I" . .. .....-----.-,,---..-..---.. ..-.-.-.. - . . .. ..-.--..---.. . .. .... ........... ..... Trade Name . .' .Type ..._I...çOI'!C~ntfªtiº!:I...___............_.......l,J_n.í.ts... .. .. Liq!J.id..Ç-ºD.~..... I l!nit~___.__.__. D65 0.9C %BWOC C359 O.O~ %BWOC D47 D600G 0.2C G P S 1.5C G P S Printed: 11/10/2003 7:15:33 AM . . ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: 2P-432 Common Well Name: 2P-432 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2003 2 Report Date: 11/9/2003 10/22/2003 End: .. ......---.. . ......-. ......-. . . . ....-.---. Casing Test Shoe Test Liner Top Test . u.__.__m n.. ..___________.._ ..----.--.......-........ - ..--..---------..-....... ...--.----.-...--- ..-.-.--...-...... . - ..--.---..-------.-..- Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: . .. ------ - -.. --..-.---- - ..- -. . . .. .-. ._-,-".. . ... -.-- Log/Survey Evaluation Interpretation Summary . - ----"....-.....-.......... .... .. ..-- -...-....-.-.-... . . _ '''.'.n...____._.... .. -----.---.... . CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: ...__..__ n, ... .....----.-..-...--..., . Remarks ... . _____..__0... _. .. - . .-...-.. - --.... Turn over to Dowell, Pump 5 bbls CW100 @ 8.3 ppg, Test lines to 4000 psi, Continue pumping 25 more bbls CW100 at rate of 1.5 bpm @ 100 psi, followed by 40 bbls MudPUSH " Mixed at 12.0 ppg at rate of 1.5 bpm at 180 psi, Shut down, Drop btm plug, Pump 51 bbls (130 sxs) LiteCRETE cement mixed at 12.5 ppg wI .9%D65, .020%C359, .20%D47, 1.5%D600G at rate of 1.5 bpm at 200 psi, Shut down, Drop top plug, Displace cement w/1 0 bbls fresh water, followed by 204 bbls 11.5 ppg mud at rate of 1.5 bpm at 200 psi, Did not bump plug, Gained 3.9 bbls thru out displacement, C.I.P. @ 10:00 hrs. 11/9/03, Observe well- Mild flow. Printed: 11/10/2003 7:15:33 AM ConocoPhillips Alaska, Inc. Daily Drilling Report IJOB NUMBER I EVENTODCRODE 124 HRS PROG TMD I TVD I DFS I 5,613.0 I 5,307.0 I 11.00 FIELD NAME I OCS NO. AUTH MD IDAlL Y TANG Doyon 141 MELTWATER 6,094.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 11/9/2003 293238 BHA HRS SINCE INSP ILEAKOFF AFE 18.09 10030793 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 11/5/2003 5523.19 20.480 193.760 I 7.000 (in) @ 5,602.0 (ft) 3.500 (in) @ 6,094.0 (ft) 11/9/2003 DENSITV(ppg) I -'1"Ú5Ö··· ¡pp , . ---". i ECD: ;MiiD-DATAT'ï)AiLy-'C()ST': -.... ()n..__n ;. ëUr.Ù::OST; n.__. 0 .- n·.-.F_·.·y.-."-.·.-.·".·..·pyN..,. ..;'".·-._G_-..E.·.·._L..S.·...-."1' .W..· UH..·"·..TH.·...· p .1 "f:cïT...-.s_-o...L...'.i OIUWAT--'T'-%S~~dlMB:¡:-' ¡--"'PWpM ; -"-prIM" T CI r·...c~..·1..·H2s¡· LIME':-'ES 60 I 31/33 I 15/20 I 4.61 I 11 I I n_"¡"-¡Ú5.0· ''''1''--'- '9.01" I ""-ï .. .... r ..." r-..-n··l" --j-- I ...--. ..-.".,.... ."., " ... ....---. . ..-.......-.-----.---- .... ....._.. .___.___....__. ...._.......___n ...__... .._.._._. OPERATIONS SUMMARY .F.ROM! ·..ro...."L~~"~~~: ¡ ......cO~~:]~.~~~LË:"...-..su~_~_T~~~t.t~~~..1 ...."..n.~.:~~~~~__. '-"-'--'.:~~=:.'_.:.: . ....DËŠC:ÃI~~~~._·~.". . :...·"·..-=:n·.~ .n.....__...._".-.==~~". 00:00 03:30 3.50 CASE P RUNC PROD Finish Running 7", 26#, L-80, BTCM casing f/4,226' to 5,602' and land same, Stopped and eire, @ 5,287' only able to circ at 1 to 1.5 bpm with possible 20% returns at best, No Pipe displacement at all on last 10 joints, Lost total of 208 bbls mud running casing, Pipe ran in hole with no trouble. PROD Attempt to circ at rate of 1.5 bpm at 350 psi, 20% to trace retums, Lost 72 bbls while eire, Reciprocate pipe 10-15'. PULD PROD Lay down Franks fill up tool, Pick up Dowell cement head. CIRC PROD Attempt to circ at rate of 1.0 bpm at 250 psi, 20% to trace returns, Reciprocate pipe 10-15', Lost 48 bbls mud while circ. Batch mix cement. PUMP PROD Turn over to Dowell, Pump 5 bbls CW100 @ 8.3 ppg, Test lines to 4000 psi, Continue pumping 25 more bbls CW100 at rate of 1.5 bpm @ 100 psi, followed by 40 bbls MudPUSH II Mixed at 12.0 ppg at rate of 1.5 bpm at 180 psi, Shut down, Drop btm plug, Pump 51 bbls (130 sxs) UteCRETE cement mixed at 12.5 ppg w/.9%D65, .020%C359, .20%D47, 1.5%D600G at rate of 1.5 bpm at 200 psi, Shut down, Drop top plug, Displace cement w/1 0 bbls fresh water, followed by 204 bbls 11.5 ppg mud at rate of 1.5 bpm at 200 psi, Did not bump plug, Gained 3.9 bbls thru out displacement, C.I.P. @ 10:00 hrs. 11/9/03, Observe well- Mild flow, Reciprocated pipe until last 20 bbls of displacement. OTHR PROD Close Hydril and monitor well, Pressure built to 55 psi and slowly decreased to 44 psi, Bleed off pressure, Monitor well- Static. Rig down cement head & Landing joint, Change bails & elevators. Install 9-5/8" x 7' Pack off, Test same to 5000 psi for 10 min- OK Install test plug, Change top pipe rams to 3-1/2" x 6", Change btm pipe rams to 4", Change saver sub on top drive to HT-39 BOPE PROD Test all BOPE to 250 psi low & 5000 psi high, Hydril to 3500 high, BOPE test waived by AOGCC Lou Gramaldi., Pull test plug, Set wear bushing. Note: Total mud lost for the day= 413 bbls, Accum. total= 2427 bbls. . WELL NAM.E 2P-432 RIG NAME & NO. Dovon SUPERVISOR F. Herbert I M. Thornton CURRENT STATUS Finish Lavina down 5" drill Dipe. 24 HR FORECAST UD 5" DP P/U 4" DP & BHA, RIH & Drill JAR HRS OF SERVICE LITHOLOGY 03:30 04:30 CEMENTF CIRC 1.00 04:30 05:00 05:00 06:00 CEMENT F CEMENT F 0.50 1.00 06:00 10:15 CEMENTF 4.25 10:15 15:00 CEMENT F 4.75 15:00 16:00 16:00 17:00 17:00 19:00 CEMENT F CASE P WELCTL F PULD NUND NUND 1.00 1.00 2.00 19:00 00:00 WELCTL F 5.00 . Page 1 of 2 REPT NO. I DATE 12 11/9/2003 CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 2,344 370 AUTH. PROD PROD PROD ---....... . .... ----.-. .... 24 HR SUMMARY: RIH wI 7" csg to 5,602', Circ & Cmt csg, Close hydril on csg f/4 hrs, Set & test 9-5/8" x 7' packoff, Test BOPE. . ...-- ..---...-..--.. ......-... ... . .. ..-..-----...,.,-"'---. . . ..........._.,,-,... COMPANY n . _,__n ___.. ... ConocoPhillips Company Doyon Drilling Inc Baker Hughes Inteq SERYICE .--- ---...--... .._n_.__n_ .. .... . ..... ..-----.---- PERSONNEL DATA N'O" ::]:~~~~~ ~. . :C~~~~NY- .". . :~~".:~~=-~~::.:~~...:SERYIC':....~~::: :.~.... 3 Baker Hughes Inteq - D 31 Epoch Well Services Inc 3 Doyon Universal Service ..... ....- ! . __~(): . HO~~_~.._.. 2 4 5 Printed: 11/10/2003 7: 13:55 AM . . Page 2 of 2 ConocoPhillips Alaska, Inc. Daily Drilling Report 2P-432 DATE 11/9/2003 WELL NAME COMPANY M- Drilling Fluids PERSONNEL DATA SERVICE . _:"::~~~~-"-·ÑO..· . Œ~URS ::' ~·.:~~~:::~-ÕMPAN!~=~~---·l· -.. ·:~~:-SER.Y~~~-=-..-":~~~L__.~Õ:-=JHO~~~~ 2 APC - Alaska Petroleum 2 ~.._._-_.__.._..._._-_..__. ..._-..-... .. __....._n.. . ........---ì-. ITEM ._._..1. .... ......_.__. 'n .............~._.._.,....."._. __._n_.'.' ...___.. MATERIALS I CONSUMPTION ..~~~i~s~·~~.·:· . ........us-AGE··..... [:'~'~'N ~A~_~:·.:~~~I~·.·_~. IrE~.:_-_·::..·...·" ·r_::=~Ñ.rrS_..._.....i. gals 990 11 ,240 . Water. Potable . gals bbls 280 560 ...._,-,-_.. .....~ ...'-.-..-..-."..- _.._n.'_. . ..._.,.__..... Fuel Water, Drilling USAGE 4,180 ¡__.ON HAND 7,748 ._. RESERVOIR AND INTERVAL DATA ..__~...... ... ____ _.___._. ....... ......__._______. .n.. .._._.__.....~...... ,_._'_._._____. ........ _n. ._._____. _ _____._ .. .......__.____.. . ______... ..____.. .R.~.SERVOIR NAME ; . . n___._~ONE .! ___.!OP .......1.. BA~_,=_J _...... . . . ____......__. COMMENTS 2P-422 2P-432 303 2 800 .._-.- ---. -"..-.--.. .--.- . .---...... -----.... Printed: 11/10/2003 7:13:55 AM · PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: 2P-432 I Rig: Doyon 141 Date: 11/23/2003 Volume Input Volume/Stroke Pump Rate: Drilling Supervisor: Dear1 Gladden 1 Peter Wilson Pump used: #2 Mud Pump I· Strokes ~ 0.1010 Bbls/Strk ~ 5.0 Strk/min ... Type of Test: I Annulus Leak Off Test for Disposal Adequacy I ... I Pumping down I annulus. ¡... casing Test pressure Integrity Test Hole Size: 18-1/2" I· Casing Shoe Depth I Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 25.4 Ft 2,449 Ft-MD 2,372 Ft-TVD I 2,474 Ft-MD 2,395 Ft-TVD Strks psi Min psi Strks psi Min psi Casinq Size and Description: 19-5/8" 4O#/Ft L-80 BTC I· r 0 0 0 3500 0 0 0 450 Chanaes for Annular Adeauacv Test Pressure IntearitvTest 2 50 1 3500 2 200 0.25 350 Enter outer casing shoe t~ 18.1 in comments Mud Weight: 11.5 ppg 4 123 2 3500 4 390 0.5 310 Casing Description referen 9.6 casing string. Inner casing 00: 7.0 In. 6 287 3 3500 6 500 1 I Hole Size is that drilled bel 9 casing. 8 541 4 3500 8 620 1.5 Use estimated TOe for Ho 4,500 10 820 5 3480 10 450 2 Enter inner casing OD at right 7 Desired PIT EMW: 18.0 ppg 12 993 6 3480 12 400 2.5 290 Estimates for Test: 802 psi 0.2 bbls 14 1180 7 3480 14 400 3 290 ·1 1·[ 16 1380 8 3480 16 400 3.5 290 EMW = Leak-off Pressure + Mud Weight = 620 2372 + 11.5 PIT 15 Second 18 1611 9 3480 18 400 4 280 0.052 x TVD 0.052 x Shut-in Pressure, psi 20 1850 10 3480 20 400 4.5 280 EMW at 2449 Ft-MD (2372 Ft-TVD) = 16.5 350 22 2120 15 3480 22 410 5 280 4000 F. Lost 20 psi during test, held ~ 24 2400 20 3480 24 410 5.5 280 26 2700 25 3480 26 420 6 280 99.4% of test pressure. 3500 "~4::M.'~'jJ J~l.~. 28 2965 30 3480 28 440 6.5 280 30 3275 30 450 7 280 3000 31 3545 32 450 7.5 280 34 450 8 280 w 2500 36 450 8.5 280 a: 38 450 9 280 =» ~ 2000 9.5 w 10 a: c.. 1500 1000 500 j ::::; ~::::::::;:::::::::::::::::::::::::::::::::::: 0 0 1 2 3 4 5 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes oume Volume olume Vo ume ~CASING TEST _LEAK-OFF TEST 0 PIT Point Pumped Bled Back Pumped Bled Back 3.1 tsPls ~ 3.8 tsPIS 1.tI tsPls [vomments: .. RESERVOIR NAME .-.. --... --.. ..-.... 2P-422 .u ...... 2P-432 Printed: .- .-.. - ..... ..... .-. .... ..... - .--.. ._-.. ---- RESERVOIR AND INTERVAL DATA ... ..-----.. ..-- ..._..~. ----.. _n. I ....n... ..____._.... ..._._. .___.___..._..__.__.__________._ ZO~_E. L_.. TO~. ,.. ~~SE _om, ~ONl~EN!.S o 0 . 124/2003 7:26:46 AM --... Fuel Water, -- D.!~!in!i!... ....---. . ITEM ...- I -... .... UNITS _. ga~ bbls - -....- .. --. USAGE .~. . __h . ___ _ __... .u ..._. ___ MATERIALS I CONSUMPTION '...J ...... .. .. . .-....- ...... ........ ....... r" ON HAND i. ITEM i roo ...---. -.. ..:~. .u. . ._. '__'. _ -;_. , 8,210 ',Water, Potable I I --.. -- -. ---- ..-. ; 300 " ! .. -- ..... ......... -.... UNITS .~als.. L. ....... -.. USAGE -.. -.... ---. .- ....-.. ".-- ON HAND __ ... _··n__ ___ 11,376 .-... ....---- COMPANY i 1_· ._u.... ---...-...... .-. ,-.. ~o~~o~.!1~~lips.....fom~~_ny !.. poy~n I?...!:i_lling .I.!lc ... B~~er liugh~~.1 nteg _._ .~_aker _Hug.~~s I~!~q - _.~ Epo~h W_~II S~.l"\!ice.s_ Inc Do~~n .Y!1ive~al Se~ice ¡ - .---. ..-... . ..-. ..... ...-. .--- PERSONNEL DATA ... r-uNO:·-TH"ouRs'f-....· .-. '-"CÖ'MPANY - .!.._-. -.. ---- --. -¡t:...... .-.-.- - -... - --- 1_. .._. 2 ~_ .oo ~ ~-I. ~illin~LFlu.i.~_s __ _.__ I 31 I I: APC - Alaska Petroleum ..-. -.. --. - -- .. - .-- --- --. 1 1 , "Baker Oil Tools .n._ _ __.. ..__ __ .__ __ _. ? i ¡I F~C ç_~rp~!~tic:>':I. We~~h~_~ 2 L !i9ua~~oUotc~ 5 .' SERVICE i-' ! NO. ¡HOURS -- ..--.. -.. .. -.-- .-- ._..2 L 2i 1 I 1 , 1 I .J DESCRIPTION . .-- .--. -. .-... -.. ..-.. --.. ---.. --. .--... -----. Ann. to 3500 psi and chart for 30 min. Lost 70 psi. _ .. BI~ed press~!e?ff T~ø a_':Id sh~.~r R.P v.alve. ._. __ _. __ .. CM~_~ TN .l{D I~ndi~.g it :..~et !W~. __ _ _ .. .._. __. 'CMPL TN, NID BOPE -- ... - .. --.. . - -- .. -- -.. ..- - .u ICMPL TN,NIU Tree - WKM tree asssy on FMC 3.125" X 11" tbg head adapter. Test n I ada~ter ~9id to_.?O~~ p~ - ,"!~Id 1? min. T~st tr_ee ~?O ~~i I ~~Oq_K f~.r 10 ~in.: CMPL TN' R/U Hot Oil to 7" X 3.5" Ann. - Pump 80 bbls diesel- PR 1.8 bpm @ 1500 psi. !_. ._. J Put ~.~g ~ Ann in ~omr1.:l_l!ni~atio~ and._let..flui~uU-tuE..e _. ._ _ _ _ ._. I CMPL TN¡ Preform LOT on 9.625" X 7" Ann. - Pump 3.8 bbls, 11.0 ppg mud had leak off ¡ @ 620 psi for a 14.6 ppg EMW LOT, Pumped 120 bbls water to flush annulus, ... :!reeze pro.tect_with~? ~~I.s d~~se!: (18~8'Iv1D) ;ÇMPL.!.N'~MC R/U ~..Se! ~P'{_.w/l.~bri~tor_.. ._ ._. iCMPL TN!SeclJre Tree & Well Head - Clean Cellar area --. _ on _. _u._ _.. ... ._. ._ ! CMPL TN: Fin cleaning rock washer & pits ! .- -- -- 24 HR SUMMARY: .---...-. -_...._- SERVICE ·.~~el~é:1s~£!ig O~OO ,!1rs _~~/2~03'~_ to ."!10v~..to 2£,-4~4 on ___ .__. .._. __. ._ .... _.. .__ _ .__. .._. _ ._. n .__ _ __. Test tbg & Ann - NID BOPs - NIU tree & test same - Freeze protect well - Preform LOT on 9.625" X 7" .!'ater..flus~_and._~reez~ prot~ct w/.52 ~bls _~!.ese~:...- S~~ur~.well - R~I~as_~ Rip-_at O~:OO_~rs -- .-. - Ann. Pump .--. 120 _ i .. 06:30 : 07:00 -07:001 07':30 ..__ . un _. 07:30 ! 08:00 1 ! i 0.50 0.50 0.50 WELLSR P IWELLSR R -- -- - . ,WELLSR P -.- NUND NUND OTHR -.-n....--r--.----..--.. ...-- --, FROM: TO ¡HOURS ¡ --.. ".... .---.. r-.. --.... I 00:00 ! 00:45' 0.75 . i 01:15: 0.50 -. -I --- 02:00 0.75 03:30 ¡ 1.50 ..- 04:30 - . ... ..- 03:30 ; 04:30 00:45 01:15 02:00 -- 06:30 1- , ! - 2.00 .00 --. CMPL TN .- -. I~AS~P . ._ :CM':'LT~ A CMPL TN ~ -.. CMPL TN P .- FRZP iFRZP RURD NUND NUND ---.-.oo---.-.,...-.....-.. .._ "''-_'.. ......___. CODE 'TROUBLE' SUB CASE p' ;.... ---.. l'Má -- .-. . .-... ...._. ...._ ...n.. ..._ ..._ .___. OPERATIONS SUMMARY ';"-'PHASË "r-·"-··-·-"--- -- - ...---- -.-- j- ---.. ..-....- --.-. -.-... .-- -... ..-. 'CMPL TN'Test Csg - Test 7" X 3.5" JOB NUMBER 1 EVENT CODE .124 HRS PROG TMD TVD ; DFS 1 i I . .-'.. - .- --. ¡ .__9D.!l __. __ ___ ._.~_6.043.0 __~,7..10._º ,..__g5.Q.9 iFIELDNAME/OCSNO. !AUTHMD 'DAILY TANG ___.D.,,-y.9.n..:!.1. 1 ..__ __, I!1!=L TY'{ A TEB ._ ...:. . &.994.Q_ J_ _. _ 0 , ACCIDENTS LAST 24 HRS.? i DAILY INT WIO MUD ±32 ~_98Qº-~r!?__ .__ __._ r'- u. n_. _ ._.. __ .__~_ __ _ Q_ . DATE OF LAST SAFETY MEETING I DAIL Y TOTAL Move in and R/U on 2P -434 ; 11/23/2003 ' 69,802 -- - --; JAR HRS OF SERVICE 1 BHA HRS!;;IÑcE INSP-', ÚiÃKOF'F .-. --. 'lAFE --. ..-. .- , ! : i 10030793 LAsn¡uRvEY: DATE '-TMD -. .... INC ---. .-.. AZIM ·-!LA"ST·CÃSING--· ,-- -- oo fNEXT'CASING --. '.- _1Y~L?00L. .. ._.5,523..1.9_. __20·'H!..o .___. .1_~3.7!?.9 ~ 3.~QO (i~ @__.. 6.,g38.º.(ftL.; __._ (iQl.@ __. ----- .----. ___n. -.--.. _. .n_.. "r.-.. ....._.. ___. ...._.. .__.. .__._ ,.__.. ___. _..._.. _. _. 8.50 ; PP: 'ECD¡ MUD DATAl DAILY COST : 0 .---. "---, ..-..1.-..----..- _.._ _.._. _...... ..L.. .__ ....._. .___. ..__. . .__. _._......_.. ..L.... _'_'. _._ GELS; WUHTHP! FClT.SOL L' OIUWAT ! %SandJMBT! Ph/pM I PflMf ~~i:~_~!' ..=)_~.: ; _=- -1-.... ~.~.:_..~.=!.=. [~.-~ -- i .-~:: j" '-.- ~;."'=ï-- ~~_~~~!:f(~~) FV i PVNP --....1..-·-/-· -.- -.-. LITHOLOGY .--- ---- - SUPERVISOR D. GladQ~n I.P CURRENT STATUS ._.u, .__ __. _~ig Re.l~ased off gp 24 HR FORECAST 2P-432 . .- : ÄïG NAME & NO. V\IJ!so~_...l_ D<>.yon --. - CI ft)_ ëü;"·ëos-r1 ....-; "-ë~ "T --~... ..-. '--r-' -- o .-. ---- .-- ~~_S ~ . LIM~. ! 0 . _n _. __ n__ , CUM COST WI MUD i 4,141,223 -'ï AUTH. -.- -'. - - . !. .... - --_.._- LAST BOP PRES TEST i 1.111.6/20.93 REPT NO. I DATE ._L. _?EL. .J..!!23/200~ i CUM. TANG , 0 .-. _n ___. .__. n___ CUM INTANG WI MUD ..--- ES WELL NAME . . - ConocoPhillips Alaska, Inc. Daily Drilling Report Page 1 of 1 MEMORANDUM -- e State of Alaska TO: Alaska Oil and Gas Conservation Commission THRU: Jim Regg ~{¡a 3/ /0{04- P.I. Supervisor -( ( DATE: Tuesday, March 16,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2P-432 KUPARUK RIV U MELT 2P-432 FROM: John Crisp Petroleum Inspector Src: Inspector NON-CONFIDENTIAL API Well Numbe 50-103-20420-00-00 InspN mitJCr0403 I 5082403 Inspection Date: 3/1 4/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 2P-432 Type Inj. G TVD 5155 IA 80 3464 3418 3405 P.T. 2020910 TypeTest SPT Test psi 1288.75 OA 963 957 955 949 Interval Initial Test P/F Pass Tubing 2450 2450 2450 2450 Notes: No problems witnessed. Operator requested 3500 psi test. Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SALT WATER INJ. N=NOT INJECTING Type Test M=Anmùus Monitoring P=Standard Pressure Test R=Intemal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential T emprature Test Interval 1=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during WOIkover O=Other (describe in notes) Tuesday, March 16,2004 Page I of I J'i3'-I'053 J9SV1ô-- ) fiLj 'CQ3 ,Z¡2j- J"d-.- j1D' )3 LÞ n)~-I\ \ ~D3'- ¡5~ XS- JS3 ~.--cFt \ 01/27/04 Scbliumbel'gel' NO. 3100 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Date BL Color CD . Job# Log Description 2A-04 10709682 INJECTION PROFILE 12/27/03 1 2T -28 10709867 STATIC SURVEY 01/15/04 1 2A-04 10709691 RST 01/19/04 1 2K-01 10696828 LDL 01/14/04 1 1D-140 10696827 LDL 01/13/04 1 3H-03 10709688 PRODUCTION PROFILE 01/16/04 1 2P-447 10696819 SCMT 01/04/04 1 2P-434 10709667 USIT/CBL 12102/03 1 2P-432 10696818 PERF RECORD & SBHP 01/03/04 1 -... .,. I"\!.... __I:: I V' ¡:;'V . ~~~ "-." SIGNED:'~ \Iì....t i",":î-,,¡ \. \) ð'1 :t--, ¡1'" /\~ - . L~ ~ I -.. C, 1)004 0';'\" \.) .' L ,i\tS$.ka 011 & Gas ConS. CommiØOn Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. A,nmoæge DATE: ---\')~ ~ ,r"." ("~ . . Transmittal Form g)C)d -oq l r'__ BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 2P-432 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log J ,/933 T I blueline - MPR TVD Log 1 blueline - CCN-ORD Measured Depth Log I blueline - CCN-ORD TVD Log LAC Job#: 567206 Sent By: Glen Horel . C' Received B;~r:~\_'J-...\ iY-<-~( (Lf"~/V", Date: Jan 26, 2004 RECEIVED Date: JAn 2 7 2Q04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNI~I~ OR FAXING YOUR COpyfI . FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 "".. ...~ .. (' ~ß 'D \\\ y~ ----- II IIßIIPiSB-JOG-!OODWAI!tI:l ;;;;;;,-;:,,:;:;~:-;:;;:';;-i,:;;- - -'" ..... .., " .......'" ..... .., .." .....¡; ..'" -... ." .,-, ,..,. :~~~~=~;:;~~~;~'I;------~------ ,-._~.",."' .."·w",,,... _m :_"'~. 12/08/03 Scblumbepger NO. 3057 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD . :gw.. Œ,\ &>0-/4 J~-d=t 3B-01 r:. ' :J( INJECTION PROFILE 11/24/03 1 1 L-09 ,c IC -l ?J~i.' LEAK DETECTION LOG 11/26/03 1 1 C-119 '..J. ) '- í~~ INJECTION PROFILE 11/27/03 1 1 C-121 ~( 'y~~ r¡ -XI INJECTION PROFILE - 11/30/03 1 1D-110A 10709648 USIT - \)t· ~'(....é"'-;, \õ ,-..~ ÇL '-<"\ 1 \-()~-[)~ 10/31/03 1 U. 1D-140L 1 10709639 US IT \ 10/22/03 1 2P-432 ~ _ .....c. , SLIM SONIC LOGGING TOOL 11/21/03 1 \ 2P-432 10687658 UslT 11/16/03 1 .. nr:" 'I.. nIL. ""\ ~ '\1..-......'a,....1 y..... ...,.f . SIGNED:-~~ _A\_t, A :--~~\ '.... \ C ,-.... ',- ...... /,\ ---.. ""'J.=;L_, /v"- - , '- loO_~'C.{" DATE: DEC 12 2003 Alaska Oil & Gas Cons. CorrilTliseioo Anchorsge Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~~ ~'-~ Re: 2P-432 Update ;>O&-o'ì ,- Subject: Re: 2p..A32 Update" .. .....\ '.\'" . . ": ..~..(".. From: Thomas,.~:aµnder <tom_ mä:qp.4er@admin.state.akJils> Date: Mon, 24 Nd\i2003 15:20:04-0900,;'· rf~t:"'" yden, ·PhiIip~.~lip.Hayden@9~iiocop~~J~ips:·c'b~· e ....:: ' Thanks Philip. Not a problem on the cement change. One must adapt to what mother earth tells you as the well progresses. Glad this one is behind you. Tom Maunder, PE AOGCC Hayden, Philip wrote: Tom, For your information: we ran and cemented our 3 1/2" production liner over the weekend, ran the completion string and installed the tree. Presently we are drilling the surface hole on 2P-434. I would like to point out that we cemented the 3 1/2" liner with a 15.8 ppg slurry as per our original application for a Permit to Drill due to the high pressures we had encountered. I highlight this as previously I had indicated that we would use a light weight slurry due to the prognosed depleted reservoir pressure. If you have any questions please let me know. Philip 1 of 1 11/24/2003 3 :20 PM Re: 2P-432 Bond log of 7" Casing e Subject: Re: 2P-432 Bond log of 7" Casing Date: Wed, 19 Nov 200312:42:19 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> CC: "Jackson, Darron B." <darron.b.jackson@conocophillips.com> e éfO,) -0"\ \ Phillip and Darron, Your note is as we discussed when examining the log yesterday. I agree with the conclusion regarding isolation of the Cairn. There is "some" cement seen beyond the "spike", but the quality is less than across the Cairn. But, as you note, the event was minor and had been controlled with mud weights lower than ultimately in the well bore when the 7" was cemented. Your plan to continue to monitor the 7" x 9-5/8" annulus is appropriate. Good luck with the remainder of the wellbore. Tom Maunder, PE AOGCC "Hayden, Philip" wrote: > Tom, > > To summarise our review and discussion of the USIT bond log of the 7" casing run on 2P-432 we conclude that the Cairn interval in this well is sufficiently isolated from surface with the primary cement job. In addition we conclude that there is a very low chance of communication to surface from the gas spike recorded at 5193 ft MD. Given that this gas spike was a relatively minor event and that the 7" annulus pressure has remained at zero since running the casing ten days ago we feel that no remedial action is required at this time. We wíll, of course, be monitoring the well for any abnormal pressure developement should it occur and would propose a course of action at that time should it be necessary. > > Please let us know if this meets with your approval. > > Regards > > Phílíp I Ç'l1l1 M~lL!nd(:r <toDU~aundcr@8drDir.l:.?ia!Q.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 11/19/200312:42 PM Re: Update on 2P-432 operations e e Subject: Re: Update on 2p-432 operations Date: Thu, 13 Nov 2003 11 :22:29 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> CC: "Jackson, Darron B." <darron.b.jackson@conocophillips.com> dO~-a~ , Philip, et al: Your note is as we discussed yesterday. Given the hole situation from our discussions, it is probable that the bottom of the Cairn is isolated and you correctly state that the isolation concern is the top of the Cairn and the "spike", The forward plan as presently designed should maintain well integrity and well control while allowing the necessary evaluation. With regard to the location of the 3-1/2" seal bore, I have checked your updated permit application. Your documents stated that the 5" x 3-1/2" XO would be located above the Cairn. Neither the cover letter or the signed permit sheet acknowledged this, however 20 MC 25.450(a) allows the Commission discretion with regard to injection well construction where freshwater is not present. This is the case at Meltwater, so your plan to have the seal bore/XO located 302' md above the top of the Bermuda is acceptable. Please keep us informed of the progress on the well. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC "Hayden, Philip" wrote: > Tom, > > Further to our telephone conversation of yesterday, please see the attached file for an update on where we stand as of this morning and what we are planing for the completion of the well. > > At the moment we are preparing to pull out of hole with the 6 1/8" BHA and will run 5 1/2" liner tonight to cover the interval from the 7" shoe to the top of Bermuda where we are prognosed to be. This liner will have a lap of only 70 - 80 ft inside the 7" for two reasons: (1) We plan to run our bond log inside the 7" after running this 5 1/2" liner and would like to log as much of the 7" as possible, (2) After drilling our 4 3/4" hole through the reservoir we will run a 3 1/2" liner from TD to approximately 150 ft inside the 7" thus isolating the 5 1/2" "drilling liner". > > As per our discussion yesterday we feel that the main purpose of our bond log is the determination of the TOC and isolation of the gas bearing intervals behind the 7" casing. Running the bond log after running & cementing the 5 1/2" liner should achieve this aim while having the added benefit of reducing the time when we would have no pipe in hole. We will wait on the results of the bond log before proposing remedial measures if any. > > In addition I would like to draw your attention to our currently planned ''packer'' depth - i.e. where we will sting our completion string inside the PBR - 5452' MD. This will be located approximately 36' MD above the top of Cairn and 302' MD above the top of the Bermuda. As after completion the Cairn interval will be lying behind 3 casing strings it is unlikely that we will use that interval for injection or production in the future. However, this means that our principle target - Bermuda - will then be located 302' MD from our packer. Do you have any comments on this? > > If there are any questions or issues you would like to discuss please let me know. > > Regards > Philip > > «2P-43211-13-2003.ppt» > > ------------------------------------------------------------------------ > > Name: 2P-432 11-13-2003.ppt 2P-43211-13-2003.ppt Type: Microsoft PowerPoint Show (application/vnd.ms-powerpoint) Encoding: base64 Description: 2P-432 11-13-2003.ppt > > 1 of 2 11/13/2003 11 :22 AM TOC ?? e e 2P-432 11/13/03 16" @ 110' MD / TVD 9 5/8" @ 2449' MD / 2377' TVD Top Cairn @ 5190' TVD Bottom Cairn @ 5240' TVD 7" @ 5602' M D / 5297' TVD dO d---O ~ ( Top Bermuda @ 5754' MD 6 1/8" hole @ 5762' MD / 5446' TVD e e 2P-432 Planned Completion 16" @ 110' MD / TVD 9 5/8" @ 2449' MD / 2377' TVD TOC ?? ;Pd--O~ \ 3 }'2" Liner Top @ 5452' MD Top Cairn @ 5488' MD / 5190' TVD 5 }'2" Liner Top @ 5532' MD Bottom Cairn @ 5541' MD /5240' TVD 7" @ 5602' MD / 5297' TVD Top Bermuda @ 5754' MD 5 }'2" @ 5762' MD / 5446' TVD 3 }'2" @ TD Re: Update on 2P-432 e e Subject: Re: Update on 2P-432 Date: Mon, 10 Nov 200316:23:53 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> CC: "Jackson, Darron B." <darron.b.jackson@conocophillips.com>, John D Hartz <jack_hartz@admin.state.ak.us> ~ad--O~\ Philip, Yes, I knew that you were on the look out for gas. The encounter depth in this case is about 700' deeper. I suspect that interval below the Cairn is likely pretty well cemented. I think that the drillout will bear that out. As I said, that leaves the top of Cairn and the "spike" zone. With the heavier mud weight, pressures are likely overbalanced. Running the bond log now might give you time to think of what you might have to do to remedy cement placement. Unfortunately, that involves making holes in pipe which is not desirable with drilling deeper planned. Observation might provide the information needed, but a bond log across the interval cannot be discounted. Tom Maunder, PE AOGCC "Hayden, Philip" wrote: > Tom, > > Although we knew it was possible to encounter gas at any interval below the top of the C-BO we did expect it to be in the C-BO to C-37 intervals (2450 - 4270 ft TVD) based on the following two pieces of information available to us: (1) the gas kick encountered on 2P-441 in the C-37 interval and (2) Noise and temperature logs run on 2P-451 & 2P-431 that indicated fluid movement at both the C-37 & C-BO intervals. The depth of the gas show on 2P-432 was indeed unexpected but not unforeseen. > > We have discussed running a bond log before drilling out but feel this is premature as we are not yet sure if we may have to squeeze the shoe. We hope to glean some further information about the success of the cement job by drilling out and conducting the negative and FIT tests. Also, allowing ourselves time to observe the annulus for pressure, as you say, will provide further information on the success of cement placement. > > Philip > > -----Original Message----- > From: Tom Maunder {mailto:tom maunder@admin.state.ak.usl > Sent: Monday, November 10,20031:55 PM > To: Hayden, Philip > Cc: Jackson, Darron B.; John 0 Hartz > Subject: Re: Update on 2P-432 > > Philip and Darron, > >From the note and a discussion with Philip, the gas was encountered deeper than the earlier experience might have led you to expect. How much deeper was the spike encountered than you might have suspected? The drawing correctly illustrates the dilemma you face as to where the TOC might be. You have pumped sufficient cement to cover the intervals you have discussed if the job was successful. You did describe that the well has been "breathing" and the flow after cementing might be further breathing. It is good that no flow was seen after WOC. It is probable that cement was raised to the base of the Cairn leaving the question of how high did it get? > Has running a bond log been considered prior to drilling out?? Based on the problems encountered previously at Meltwater, your message and the drawing it would appear that the critical determination of isolation is the top of the Cairn and the gas spike. Observation for any annulus pressure while operations proceed should be performed to look for any potential problems. > > I look forward to your reply. > > Tom Maunder, PE > AOGCC > > "Hayden, Philip" wrote: > > > Tom, 1 of 3 11/13/2003 11 :25 AM Re: Update on 2P-432 20f3 e e » > > Further to our telephone conversation this morning, please find attached a rough schematic of the well as it stands today. » > > While drilling to 5193' MD /4911' TVD with 9.6 ppg no indications of any shallow pressure were encountered. Gas in the mud was consistently well below 100 units as measured by the mudloggers. While drilling at 5222' MD after the connection at 5193' MD, connection gas of 3400 units was detected at surface. We continued drilling to our planned casing top set contingency point while weighting up the mud to 10.8 ppg. This point was 5500' MD / 5200' TVD - prognosed to be 50' TVD above the Cairn but actually 10ft into the top of it although this was unknown at the time as the GR and RES logs had not penetrated the interval. At 10.8 ppg the gas was under control. The LWD suite indicated that the origin of the gas was a siltstone stringer well above the Cairn. » > > Although it had not been our intention to penetrate the Cairn before top setting, the presence of a charged interval so deep changed our minds as we wanted to be sure to have isolated any potential pressured interval with our 7" casing. The decision was taken to drill ahead to 50' TVD below Cairn to calibrate our prognosis and set the 7" at the correct depth. After drilling to 5613' MD / 5307' TVD gas units of 2840 were detected along with gas cut mud. Drilling was halted and the situation evaluated. The LWD logs indicated we had passed through the Cairn, top at 5190' TVD and bottom at 5240' TVD. At this point it was decided to set casing. The hole was stabilised over the next few days with 11.5 ppg mud. With this mud weight the gas in the system dropped back to below 100 units once more. Using the pressure sub in the drill string the fracture gradient was determined to be approximately 11.8 ppg at this point. » > > The drill string was pulled from the hole and the 7" run to 5602' MD. Due to the low fracture gradient returns while running casing were minimal. The cement job was pumped with a planned TOC at 4500' TVD but again returns were minimal. No pressure increase was observed during displacement due to the light weight of the slurry, 12.5 ppg. After displacement the well continued to flow slowly from the annulus and was shut in while WOC. After opening the well no flow was observed from the annulus and the pack off was run and tested. » > > The immediate plan ahead is as follows: > > Run in hole with drilling BHA > > Displace mud to 9.6 ppg > > Drill out shoe > > Flow check to determine if there is U-tubing from the annulus > > - If no U-tubing is observed an FIT to 11.5 is planned > > - If U-tubing is observed the shoe will be squeeze cemented » > > If you have any questions or would like to discuss any issue please let me know. » > > Regards » > > Philip > > «2P-43211-10-2003.ppt» » > > ------------------------------------------------------------------------ » » » » Name: 2P-432 11-10-2003.ppt 2P-43211-10-2003.ppt Type: Microsoft PowerPoint Show (application/vnd.ms-powerpoint) Encoding: base64 Description: 2P-432 11-10-2003.ppt r'· ... - - -- Tom Maunder <tom maundcr(âJDdmin.stFJte.é!k.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 11/13/2003 11 :25 AM RE: 2P-432 Top set casing . Subject: RE: 2P-432 Top set casing Date: Wed, 05 Nov 200317:06:49 -0900 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, We plan to meet the regulations on the TOC with respect to this interval. Our simulations so far also conclude that bringing the cement to this depth should not be a problem. I will keep you in formed. Philip -----Original Message----- From: Tom Maunder rmailto:tom maunder@admin.state.ak.usl Sent: Wednesday, November 05, 20034:44 PM To: Hayden, Philip Cc: Jackson, Darron B. Subject: Re: 2P-432 Top set casing Phil, After leaving the message with you, I talked to Darron and understand the situation out there. Setting the 7" is the prudent thing to do. As I discussed with Darron, I presume that you will be pumping sufficient cement on the 7" to assure that the "pressured interval" is isolated. Our regulations prescribe a TOC at least 500' above any pressured interval. Given the 500' tvd distance you mention, it doesn't seem that the cement job will need to be changed much if at all. Good luck. Tom Maunder, PE AOGCC "Hayden, Philip" wrote: > Tom, > > Just to keep you informed of what is going on on this well. 2P-432 was permitted with a surface casing and a tapered production casing string only. Due to having encountered a relatively pressured interval approximately 500 ft TVD above the top of the main Bermuda reservoir we have decided to run and cement a 7" production casing to the top of the reservoir. The purpose of this production casing will be to isolate this pressured interval from the relatively low pressured reservoir. Currently the mud weight in use is 10.8 ppg whereas the prognosed reservoir pressure is 7 ppg. Having run and cemented this production casing we will drill a 6 1/8" production hole, run and cement a 3 1/2" liner and run our planned 31/2" completion string. > > If you need any further information from me please let me know and I will be happy to oblige. > > Regards > > Philip 1 of 1 . ~o~"--o~ 1 11/5/20035:09 PM Re: 2P-432 Change in production casing cement design . Subject: Re: 2P-432 Change in production casing cement design Date: Thu, 23 Oct 2003 07:31 :01 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Hayden, Philip" <Philip.Hayden@conocophillips.com> . ;20d-O'\ \ Thanks for the notification. I agree with the rationale for changing the cement weight. I will place this note in the well file. Is 2P-432 going to be the first well in the new campaign?? When is expected spud?? Tom Maunder, PE AOGCC "Hayden, Philip" wrote: > Tom, > > After further evaluation we have decided to change our cement design for the production casing job for well 2P-432. Instead of the 15.8 ppg class G slurry as reported in our application for the permit to drill we will be using a 12.5 ppg, LiteCRETE slurry. The planned top of cement remains the same at 5055 ft MD. The reason for going with the lighter slurry is the predicted low reservoir pressure and the consequent lower fracture gradient. The 12.5 ppg slurry gives us a bigger margin for circulating in cement below the fracture gradient. > > If you would like more information on this please let me know. > > Regards > > Phílíp Tom Maunder <tom maunder(å1admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 10/23/2003 8: 15 AM - ~ ~~!Æ . / / / FRANK H. MURKOWSKI, GOVERNOR / ¡ / 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AI,ASKA ORAND GAS CONSERVATION COMMISSION Randy Thomas Phillips Alaska, Inc. Kuparuk Drilling Team Leader PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 2P-432 (Revised) Phillips Alaska, Inc. Permit No: 202-091 Sur. Loc. 948' FNL, 1894' FWL, Sec. 17, T8N, R7E, UM Btmho1e Loc. 2560' FSL, 1430' FWL, Sec. 17, T8N, R7E, UM Dear Mr. Thomas, Enclosed is the approved application for revised permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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 at 659-3607 (pager). Sincerely, I?i~..~~ ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this--1/day of September, 2003 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION , e á-Yõ PERMIT TO DRILL 20 MC 25.005 1 a. Type of Work: Drill [2] RedrillU 1b. Current Well Class: Exploratory U Development Oil U Multiple Zone 0 Re-entry 0 Stratigraphic Test 0 Service [2] Development Gas 0 Single Zone [2] 2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: ~ ') ConocoPhillips Alaska, Inc. Bond No. 59-52-180 2P-432 '~~\<;tJ:. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 6094' TVD: 5749' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 948' FNL, 1894' FWL, Sec. 17, T8N, R7E, UM L 32092 Meltwater Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2604' FNL, 1461' FWL, Sec. 17, T8N, R7E, UM ADL373112 11/1/2003 Total Depth: 9. Acres in Property: 14. Distance to 2560' FSL, 1430' FWL, Sec. 17, T8N, R7E, UM 5760 Nearest Property: 2560 at TD 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 443855 y- 5868930 Zone- 4 252' AMSL feet Well within Pool: 2P-431 , 18.56 16. Deviated wells: 17. Anticipated Pressure (see 20 AAC 25.035) Kickoff depth: 700 ft. Maximum Hole Angle: 22.19° Max. Downhole Pressure: 2564 psig I Max. Surface Pressure: 1951 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 16" 62.5# H-40 Weld 80 28' 28' 108' 108' 110 sx ArticCRETE (preinstalled) 12.25" 9.625" 40# L-80 BTC 2424 28' 28' 2452' 2377' 527 sx AS Lite & 225 sx LiteCRETE 8.5" 5.5" 15.5# L-80 BTCM 5327 28' 28' 5355 5065 467 sx Class G 8.5" 3.5" 9.3# L-80 EUE8RDM 739 5355' 5065 6094 5749 (Included above) 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Casing Length Size Cement Volume MD TVD Structural it Conductor ~...... Detailed Operations '\."rL. ..'Lr.... Intermediate ('/ ........ .. ..... LJ Production v(" ,.... n ;' ^'" Liner ~.... 'c..VUJ Perforation Depth MD (ft): Perforation Depth TVD (ft): ~~~ 20. Attachments: Filing Fee 0 BOP SketchLj Drilling programU Time v. Depth Plot U "'1;hallow Hazard Analysis U Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Philip Hayden 265-6481 Printed Name R. Thomas Title Kuparuk Drilling Team Leader Signature \ ~ ~ Phone '¿[7 ç bÖ So Date '=t f c( (OS P~ PhiliD Havden \ Commission Use Only Permit to Drill API Number: permitAP~va~/ tf ,? See cover letter Number: 2CJ;!.. --c::rJ/ 50- /C> '3 ~ ZO'/Zð -æ:> Date: ~ '/ '.J for other requirements Conditions of approval : Samples required DYes ßlNo Mud log fequi~d DYes ~ No Hydrogen sulfide measures DYes gNo Directional survey required ~Yes 0 No Other: "" ç~ ~ C,<t~([. t'\ -\- ~vv. \ \ ~ \D~, 3>500 f~ 'tI"\\~\~v",,\ ßO?~ /&J1 ,¿ ¿:A/~_ BY ORDER OF 7; '//¡ ð J Approved by: COMMISSIONER THE COMMISSION Date: ../ / / Form 10-401 Revised 3/2003 . ORIGINAl Submit in duplicate ConocJ'P'hillips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com September 2, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry Approval regarding Meltwater Injector 2P-432 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Sundry Approval for the previously permitted Meltwater oil pool injector, 2P-432, Permit Number: 202-091, API Number: 50-103-20420. The reason for this sundry approval application is the change in bottom hole location and update in well design as detailed in the attachments. The bottom hole location has moved approximately 404 ft at a heading of 281.7 degrees from the previously permitted one. Please find attached for the review of the Commission Form 10-403 and the updated information required by 20 ACC 25.005 for this well. The expected spud date is November 1, 2003. If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, ~~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader OR(Glr~;-\L e e 1. Type of Request: Abandon D Suspend D Operational shutdown D Perforate D Variance D;?D Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D er D Change approved program 0 Pull Tubing D Perforate New Pool D Re-enter Suspended W 2. Operator Name: 4. Current Well Class: 5. permi%NUmber: ConocoPhillips Alaska, Inc. Development D Exploratory D 202-091 3. Address: Stratigraphic D Service 0 67umber: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20420 7. KB Elevation (ft): 9. Well Name a%~er: 28' RKB Above Gl 2P-432 8. Property Designation: 10. Fiel:~~): ADL 32092 / ALK 373112 Ku uk River Field / Meltwater Oil Pool 11. PRESENT WELL CONDITION SU~ARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): P?eaSUred) Junk (measured): Casing Length Size MD TVD Burst Collapse Structural / Conductor / ~ Surface / ~, K '"-'0 \ "::>1..' \,) "">~\~~C Intermediate / .\0\ :1ê -..)-, ~ '\-c:::. \ rl"'- )'Ðt"''\ C '\ V'Q' Production / .... ,.,~ .....\ ~~~t." \. 'lL, ) '-\ L -: .-r--. '" \¡~ Liner / \ Jhð?kÎ ~4~') Perforation Depth MD (ft): Perforation Dept'n( (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Packers and SSSV Type: / Packers and SSSV MD (ft): 12. Attachments: Description Summary of proposal~[ 13. Well Class after proposed work: Detailed Operations Program D BOP Sk ch D Exploratory D Development D Service B 14. Estimated Date for 11~03 15. Well Status after proposed work: Commencing Operations: Oil D Gas D Plugged D Abandoned D 16. Verbal Approval: /ate: WAG 0 GINJD WINJD WDSPL D Commission Representative: 17: I hereby certify that the foregoing is.7 correct to the best of my knowledge. Contact Philic Havden 265-6481 Pnnted Name R. Thomas Title Kuparuk Drilling Team Leader Signature ~~ /\ \::.......... Phone 265-6830 Date "'1 ( è (?:) " -. y COMMISSION USE ONLY Conditions of approval: N Ify Commission so that a representative may witness Sundry Number: ~3 -.2? I Plug IntegrityD BOP Test D Mechanical Integrity Test D Location Clearance D Other: Subseq nt Form Required: BY ORDER OF Appr ed by: COMMISSIONER THE COMMISSION Date: STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Form 10-403 Revised 2/2003 OR\G\NAL SUBMIT IN DUPLICATE e A.~ation for Permit to Drill, Well 2P-432 Revision No.O Saved: 29-Aug-03 Permit It - Meltwater Well #2P-432 Application for Permit to Drill Document M(JximizE Well Valu~ Table of Contents 1. Well Name .............. ....... ........ ... .................. ...... ............ .................. ........ .............. ..... 2 Requirements of 20 AAC 25.005 (f). .................. .... ......... ..... ......... ... ...................... ............... ........... ....... 2 2. Location Sum mary .. ......... .......... ..................... .......... ............ .............. .......... ........... 2 Requirements of 20 AAC 25.005(c)(2) ....................... ........... .......... ................. ......... .......... ................... 2 Requirements of 20 AAC 25. 050(b )... ...... ................. ....... ........ .... .......... .... ......... ............ ..... ................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 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 ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) .................. ............ ........ ........ ...... .................... ........................... 4 7. Diverter System Information ...................................................................................5 Requirements of 20 AAC 25.005(c)(7) ......... ........... .... ......... ........... .... ................ ............. .... ....... ........... 5 8. Dri II i ng FI uid Program .. .... ........... ....... .......... .............. ................... ....... ......... ...... .... 6 Requirements of 20 AAC 25.005(c)(B) ... ................... .............. ........ .... ........................ ..... ........... ........... 6 Surface Hole Mud Program (extended bentonite) .................................................................................. 6 Production Hole Mud Program (LSND) .............. ......... ............. .................. .............. .......... .... ................ 6 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 1 O. Seismic Analysis ........ ............. .......... .............. .... ........ ................... ...................... .... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 7 12. Evidence of Bonding ............................................................................................... 7 2P-432 PERM/T /T.doc Page 1 of 8 Printed: 29-Aug-03 e A.tion for Permit to Drill, Well 2P-432 Revision No.O Saved: 29-Aug-03 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 7 13. Proposed Drilling Program .....................................................................................7 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments.. ................ ........ ................. ....... .... .............. ....... ......... ........... .............. 8 Attachment 1 Directional Plan (13 pages) .............................................................................................. 8 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 8 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 8 Attachment 4 Well Schematics (1 page) ................................................................................................8 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{bJ- For a well with multiple 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 2P-432. / 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 with 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 section lines. (8) the coordinates of the proposed loca/ion 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) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates / Northings: 5,868,930.21 Eastings: 443,854.52 948' FNL 1894' FWL Section 17 TaN R7E UM RKB Elevation 252' AMSL Pad Elevation 224' AMSL ,/ Location at Top of Productive Interval Bermuda Sand NGS Coordinates Northings: 5,867,277 2604' FNL, 1461' FWL, Section 17, T8N, R7E, UM ./ 5778 Eastings: 443,414 5457 5205 Location at Total De NGS Coordinates Northings: 5,867,162 2560' FSL 1430' FWL Section 17 T8N R7E UM Measured De th RKB: 6 094 Eastings: 443,383 Total Vertical De th RKB: 5 749 Total Vertical De th 55: 5 497 ./ ,/ and 2P-432 PERM/T /T.doc Page 2 of 8 Printed: 29-Aug-03 e A_lion for Permit to Drill, Well 2P-432 Revision No.O Saved: 29-Aug-03 (D) other information required by 20 MC 25.050(b)/ Requirements of 20 MC 25.050(b) If a well is to be intentionally deviateci the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent well bores within 200 feet of any portion of the proposed welç Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified maiç or (B) state that the applicant is the only affected owner, The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable/ An API 13 5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 2P-432. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) 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: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountereci criteria used to determine it, and maximum potential surface pressure based on a methane gradient,' The expected reservoir pressures in the Bermuda sands in the 2P-432 area vary from 0.33 to 0.46 psi/ft, / or 6.3 to 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from existing wells on the field together with reservoir model forecasts. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Bermuda sand formation is 1951 psi, calculated as follows: MPSP =(5573 ft)(0.46 - 0.11 psi/ft) =1951 psi V' (B) data on potential gas zones/ Due to the presence of high annular pressures on some of the Meltwater wells (2P-431, 451 & 438) there .I is the risk of encountering a pressured shallow zone. This interval may be encountered through the C-80 and C-37 formations. The original high pressures recorded in these annuli were of concern but as can be seen from the following table a series of annular bleeds together with an observed natural decline in pressures have reduced the potential maximum pressure considerably: .............-- Original 08/22/2003 Well Surface Fluid C-80 C-80 Equivalent Surface Fluid C-80 C-80 Equivalent Pressure Level Pressure Gradient (ppg) Pressure Level Pressure Gradient (ppg) 2P-431 1600 2387 1751 13.85 1260 1822 1473 11.66 2P-451 1380 2160 1541 12.23 940 2281 1074 8.53 2P-438 879 895 1245 9.83 820 682 1244 9.83 I 2P-432 PERM/T /T.doc Page 3 of 8 Printed: 29-Aug-03 e A.tion for Permit to Drill, Well 2P-432 Revision No.O Saved: 30-Aug-03 Using the latest annular pressures available the highest pressure that would be expected is approximately v 1480 psi at 2452 ft 1VD or 11.6 ppg EMW. Most of the previously drilled Meltwater wells had an m/LOT of approximately 16 ppg thus indicating that this pressured interval, should it exist, can be safely controlled with standard well control methods. Further annular bleeds are planned to take place before spud in order to reduce further the potential v maximum pressure that could be encountered in the C-80 and C-37 intervals. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone~ and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 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 ¡tem~ except for an Item already on file with the commission and identified in the application: (5) a descrí¡Jtion of the procedure for conducting formation Integrity tesfs; as required under 20 MC 25. 030(fJ' 2P-432 will be completed with 9 5/8" surface casing landed above the C-80 mudstone interval. The casing shoe will be drilled out and a leak off test will be performed in accordance with the "Leak Off Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following ¡tem~ except for an item already on file with the commission and Identified in the application: (6) a complete proposed CaS¡i7g and cementing program as required by 20 MC 25. 030, and a description of any slotted liner, pre- pelforated liner, or screen to be installed,' Casing and Cementing Program I See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MO/TVO MO/TVO 00 (in) (in) (tb/ft) Grade Connection (tV (ft) (ft) Cement Proaram 16 42 62.5 H-40 Welded 80 28 I 28 108 I 108 Cemented to surface with 110 sx ArticCRETE 9 5/8 12 V4 40 L-80 BTC 2424 28 I 28 2452/2377 Cement to ~~s \'-" to. Surface with Ç( 527 sx ASLite ",:;;/ <l: Lead, 225 sx LiteCRETE Tail 1" 5 Vz 8'/2 15.5 L-80 BTCM 5327 28 I 28 5355 I 5065 Cement Top planned @ 3% 8 Vz 9.3 L-80 EUE8RD 739 53551 5065 6094 I 5749 5055' MDI Mod 4787'1VD. Cemented wi 467 sx Class G 2P-432 PERMIT IT. doc Page 4 of 8 Printed: 30-Aug-03 e A.ation for Permit to Drill, Well 2P-432 Revision No.O Saved: 29-Aug-03 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fa/lowing items, 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 tl7ís requirement is waived by the commission under 20 MC 25.035{h){2); A 21 %", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 2P-432. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 2P-432 PERMIT IT.doc Page 5 of 8 Printed: 29-Aug-03 e A.tion for Permit to Drill, Well 2P-432 Revision No.O Saved: 30-Aug-03 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Pemlit 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 drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Suñace Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to 95/8" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.6 <9.2 <9.2* 9.6 Funnel Viscosity 250 250 150-200 55-65 (seconds) Yield Point 35-45 35-45 30-35 12-15 {eP pH 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate 6 6 4-6 4-6 (ee / 30 min)) Chlorides (mg/I) <600 <600 <600 <600 *9.6 ppg if hydrates are encountered Production Hole Mud Program (LSND) 95/8" Casin 7 Shoe to TD Initial Value Final Value Density (ppg) 9.6 9.6 Yield Point 22-28 10-15 {eP pH 9-9.5 9-9.5 API Filtrate 4-6 4 (ee / 30 min)) HTHP @ 15Cf (ee)) <12 <12 / Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Drill must be accompanied by each of the follow¡í1g item~ 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 goo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applicaäon for a Permit to Drill must be accompanied by each of the following ¡tem~ except for an Item already on file with the commission and identitìed in the application: {iO} for an exploratory or stratigraphic test well, a seismic refracäon or reflecäon analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 2P-432 PERMIT IT. doc Page 6 of 8 Printed: 30-Aug-03 e Aäation for Permit to Drill, Well 2P-432 .. Revision No.O Saved: 29-Aug-03 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 rifh or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 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 Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test (conductor has already been installed and cemented). 2. Spud and directionally drill 12 114" hole to casing point at 2452' MD /2377' 1VD as per directional plan. Run MWD tools as required for directional monitoring and LWD tools as required for data acquisition. 3. Run and cement 95/8",40# L-80, BTC casing to surface. Displace cement with mud. Perform top job if required. 4. Remove diverter system and install wellhead and test. Install and test 13 5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 5. PU 8 V2" bit and 6 114" drilling assembly, with MWD and LWD. RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 6. Drill out cement and 20' of new hole. Perform LOT or FIT to 18.0 ppg EMW, recording results. 7. Directionally drill to 5 V2" X 3 V2" casing point at 6094 MD / 5749' 1VD. 8. Run 5 V2", 15.5# L-80, BTC Mod x 3 V2", 9.3# L-80, EUE8RD Mod casing to TD. Pump cement and displace with water and mud. Note that the cross over and seal bore extension for the completion will be positioned 200' MD above the Cairn interval, if present, as this is an interval that may be produced later in the life of the field. 9. Make up completion string as required and RIH to depth. Locate seal bore extension, space out and land completion. Pressure test completion and production casing to 3500 psi for 30 minutes and record results. Shear RP shear valve in gas lift mandrel. 10. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV 11. Freeze protect well with diesel by pumping into tubing, taking returns from annulus and allowing to equalize. Carry out LOT and injection test on the outer annulus. Sweep the annulus with water and freeze protect.' ---.... 12. Set BPV and move rig off. 13. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in gas lift mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). 14. Run cement bond log and perforate. Rig down wire line unit. 2P-432 PERMIT IT.doc Page 7 of 8 Printed: 29-Aug-03 15. Attachments Attachment 1 Directional Plan (13 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematics (1 page) 2P-432 PERMIT IT. doc Page 8 of 8 Printed: 29-Aug-03 At the end of drilling operations, an application may be submitted to permit 2P-432 for annular disposal of fluids occurring as a result of future drilling operations on 2P pad. Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 2P Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 2P Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on the pad in accordance with a permit from the State of Alaska. 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.; 15. Freeze protect well and turn well over to production e A.atiOn for Permit to Drill, Well 2P-432 Revision No.O Saved: 29-Aug-03 -- e ConocoPhillips Alaska, Inc. - -_..-- .~ _._,,_._.._..._---_._---,_.~"......_~~--_..._-~--- Creoted by bmichoel For: P Hayden Dote plotted: 26-Aug-2003 Plot Reference is 2P-432 Version (/4.8_ Coordinates are in feet reference sial 1432. True Vertical Depths ore reference RKB (Doyon 141). ... .... INTEQ Structure: Drill Site 2P Well: 432 Field : Meltwater Location : North Slope, Alaska _________._.___._~____._._._.~_._______ _..~_~__._..~___m______~__"___ 0 350 700 1050 1400 1750 .---.., +- CD 2100 CD '+- '-" ...c 2450 +- Q. CD £::) 2800 0 Ü +- 3150 ~ CD > CD 35DD :J ~ l- I 385D V 42DO 4550 4900 5250 5600 595D RKB Elevation: 252' 194.48 AZIMUTH 1711' (TO TARGET) ***Plane of Proposal*** KOP 2.00 4.00 6.00 OLS: 2.00 deg per 100 It 8.00 10.00 12.00 14.00 Bose Permafrost 16.00 18.00 20.00 22.00 EOC Base Westsok 9 5/8 CSG C80 C50 C40 C37 TANGENT ANGLE 22.19 DEG T7 5 1/2 X 3 1/2 XO T4.1 (Tap Cairn) 2P-432 Top Berm Tgt 22 Jul 03 13 (Top Bermuda) T2 (Base Bermuda) \ C35 (Top Albian) ); ,,<> TO, Csg PI. 3 1/2 CSG 35D D 35D 700 1050 1400 1750 21DO 245D 28DD 3150 Vertical Section (feet) -> Azimuth 194.48 with reference 0.00 N, 0.00 E from slot #432 ~ ConocoPhillips 200 300 400 500 600 700 800 ----. +- Q) Q) "I- 900 '--'" ..r:: +- ~ 1000 0 (f) I 1100 V 1200 1300 1400 1500 1600 1700 1800 1900 2000 100 o 100 e e ConocoPhillips Alaska, Inc. Structure: Drill Site 2P Well : 432 Field : Meltwater Location : North Slope, Alaska ---~---_._~- ------_.._._..,._---------_.~-------_._,,-,-_._--_._-----'-- _..,,_._~--_.._-_._.- 800 <- West (feet) 500 400 300 200 o 100 100 700 600 SURFACE LOCATION: 948' FNL, 1894' FWL SEC. 17. T8N, R7E KOP CSG ~ ConocoPhillips Created by bmichoel For: P Hayden Dote plotted: 26-Aug-2003 Plot Reference is 2P-432 Version 14,B. Coordinates ore in feet reference slot 1432, True Vertical Depths ore reference RKB (Doyon 141). ..- .... INTEQ 194.48 AZIMUTH 1711' (TO TARGET) XO ***Plane of Proposa *** T3 (Top Bermuda) 2P-432 Top Berm Tg\ 22 Jul 03 2 (Bose Bermuda) C35 (Top Albian) TARGET LOCATION: 2604' FNL, 1461' FWL SEC. 17, TaN, R7E TO LOCATION: 2560' FSL, 1430' FWL SEC. 17, T8N, R7E ~ TRUE ConocoPhillips Alaska, Inc. ~ ConocoPhillips I Crected by bmíçhael For: P Hayden I Date plotted : 26-Aug-2003 Structure : Drill Site 2P Well : 432 I Plol Reference is 2P-432 Version #4.8. Field : Meltwater Location : North Slope, Alaska I I Coordínoles ore in feet reference slol #432. !True Vertical Depths ore reference RKB (Doyon 141). I lIiI. I f .... I INTEQ ==== PROF~LE COMMENT DATA ==== e ----- Point ----- MO Inc Oir TVO North East V. Sect Oeg/100 KOP 700.00 0.00 194.48 700.00 0.00 0.00 0.00 0.00 Base Permafrost 1357.76 13.16 194.48 1352.00 -72.79 -18.80 75.18 2.00 EOC 1809.41 22.19 194.48 1781.89 -205.40 -53.06 212.14 2.00 Base Westsak 1993.13 22.19 194.48 1952.00 -272.58 - 70.41 281.52 0.00 9 5/8 CSG 2452.12 22.19 194.48 2377.00 -440.41 -113.76 454.86 0.00 C80 2533.11 22.19 194.48 2452.00 -470.02 -121.41 485.45 0.00 C50 3129.26 22.19 194.48 3004.00 -688.00 -177.72 710.59 0.00 C40 3405.73 22.19 194.48 3260.00 -789.10 -203.83 815.00 0.00 e C37 3563.41 22.19 194.48 3406.00 -846.75 -218.73 874.54 0.00 T7 4645.54 22.19 194.48 4408.00 -1242.43 -320.94 1283.21 0.00 5 1/2 X 3 1/2 XO 5354.88 22.19 194.48 5064.81 -1501.80 -387.93 1551.09 0.00 T4.1 (Top Cairn) 5554.88 22.19 194.48 5250.00 -1574.93 -406.82 1626.63 0.00 13 (Top Bermuda) 5778.44 22.19 194.48 5457.00 -1656.67 -427.94 1711.05 0.00 T2 (Base Bermuda) 5903.71 22.19 194.48 5573.00 -1702.48 -439.77 1758.36 0.00 C35 (Top Albian) 5980.39 22.19 194.48 5644.00 -1730.52 -447.01 1787.32 0.00 TD, Csa pt. 6093.71 22.19 194.48 5748.93 -1771.95 -457.72 1830.12 0.00 ConocoPhillips Alaska, Inc. Hoyden Structure : Drill Site 2P Well : 432 ~ ConocoPhillips Date piottoo : 26-Aug-l003 Plot Reference ìs 2P-432 Version #4,ß, Field : Meltwater Location : North Slope, Coordiootas ore ín feet refflranca slot 6432_ Vertical Depths are reference RKB (Doyon UE NO H ~ \ 3~\0 350 10 20 300 o 40 310 50 60 290 70 280 80 270 90 260 100 250 110 240 120 210 150 200 160 190 180 Normal Plane Travelling Cylinder All depths shown are Measured depths on Reference Well Created by bmichael For: P Hoyden Dote plotted; 26-Aug-2003 Plot ReferenC<! is 2P-4-32 Vers,ofl #4,8, Coordinates ore in feet reference slôt #432_ Vertico! Depths ore reference RKB (Ooyoo 141). ConocoPhillips Alaska, Inc. Structure; Drill Site 2P Well; 432 Field; Meltwater <- West (feet) 180 160 140 120 100 80 60 40 20 ~ "" 1700 1500 1300 ~ 13 300 r 900 I I t 1100 I I I I ¿ 1300 I I I I I I ¡ 1500 I I I I I I I I j 1700 I I I I I I I I I I I /, 1900 I I I I & ',<> 1 -$- -$- -$- Location ; North Slope, o 20 700 1100 1300 -$- 900 ..' ConocoPhillips 40 120 140 60 80 100 160 80 60 e -$- - 40 20 0 20 40 60 U) 80 0 C ...... :r 100 ,--... -+. (i) (i) - 120 '--' I V 140 160 180 200 220 240 260 280 ConocoPhillips Alaska, Inc. Creote<::! by bmíchoel For: P Hoyden Dote plotted ; 26--Aug- 2003 Plot Reference ìs 2P-432 Version #4.8, Coordinctes ore Îf! feat rafen.'iOce slot 11432- Structure ; Drill Site 2P Well ; 432 "Þ''' ConocoPhillips VertIcal Depths ore RKB (Doyon INTEQ / ,1609 / I I j 2200 I I I + 2500 I I ¡ 2800 I I 13100 I I I of 3400 / I /3700 r / I J 4000 I I / r 4300 / I J 4600 ¡ I / . 4900 ¡ ¡ I 5200 1600 / / / (!¡ I 1900 / (!; 700 800 900 1000 200 ,300 " 1900 400 \ \ 500 -", \ ~ 600 700 \ \ 800 ~ 900 \, 2200 1000 \ if¡ \ 1100 0 1200 ,.-.., -+. (!) \ (!) - \ 1300 '--" ~ I V 1400 1500 1600 2500 1700 1800 1900 2000 2100 2200 Field ; Meltwater Location : North Slope, East (feet) - > 1600 1900 2200 2500 2800 e e ConocoPhillips Alaska, Inc. Drill Site 2P 432 slot #432 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-432 Version #4.B prop4523 Date printed Date created Last revised 26-Aug-2003 25-Feb-2001 25-Aug-2003 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.205,w150 26 57.506 Slot Grid coordinates are N 5868930.205, E 443854.510 Slot local coordinates are 946.92 S 1897.73 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e e ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,432 Your ref 2P-432 Version #4.B Meltwater,North Slope, Alaska Last revised : 25-Aug-2003 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S DegllOOft Sect 0.00 0.00 194.48 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 194.48 500.00 0.00 N 0.00 E 0.00 0.00 700.00 0.00 194.48 700.00 0.00 N 0.00 E 0.00 0.00 KOP 800.00 2.00 194.48 799.98 1. 69 S 0.44 W 2.00 1. 75 900.00 4.00 194.48 899.84 6.76 S 1. 75 W 2.00 6.98 1000.00 6.00 194.48 999.45 15.19 S 3.93 W 2.00 15.69 1100.00 8.00 194.48 1098.70 26.99 S 6.97 W 2.00 27.88 1200.00 10.00 194.48 1197.47 42.14 S 10.89 W 2.00 43.52 1300.00 12.00 194.48 1295.62 60.61 S 15.66 W 2.00 62.60 1357.76 13 .16 194.48 1352.00 72.79 S 18.80 W 2.00 75.18 Base Permafrost 1400.00 14.00 194.48 1393.06 82.39 S 21. 28 W 2.00 85.10 1500.00 16.00 194.48 1489.64 107.45 S 27.76 W 2.00 110.98 1600.00 18.00 194.48 1585.27 135.76 S 35.07 W 2.00 140.21 1700.00 20.00 194.48 1679.82 167.28 S 43.21 W 2.00 172.77 1800.00 22.00 194.48 1773.17 201. 97 S 52.17 W 2.00 208.60 1809.41 22.19 194.48 1781. 89 205.40 S 53.06 W 2.00 212.14 EOC 1993.13 22.19 194.48 1952.00 272 .58 S 70.41 W 0.00 281. 52 Base Westsak 2000.00 22.19 194.48 1958.36 275.09 S 71. 06 W 0.00 284.12 2452.12 22.19 194.48 2377.00 440.41 S 113.76 W 0.00 454.86 9 5/8" CSG 2500.00 22.19 194.48 2421. 34 457.91 S 118.29 W 0.00 472 . 94 2533.11 22.19 194.48 2452.00 470.02 S 121.41 W 0.00 485.45 C80 3000.00 22.19 194.48 2884.31 640.74 S 165.51 W 0.00 661. 77 3129.26 22.19 194.48 3004.00 688.00 S 177.72 W 0.00 710.59 C50 3405.73 22.19 194.48 3260.00 789.10 S 203.83 W 0.00 815.00 C40 3500.00 22.19 194.48 3347.29 823.56 S 212.74 W 0.00 850.60 3563.41 22.19 194.48 3406.00 846.75 S 218.73 W 0.00 874.54 C37 4000.00 22.19 194.48 3810.26 1006.39 S 259.96 W 0.00 1039.42 4500.00 22.19 194.48 4273.23 1189.21 S 307.19 W 0.00 1228.25 4645.54 22.19 194.48 4408.00 1242.43 S 320.94 W 0.00 1283.21 T7 5000.00 22.19 194.48 4736.21 1372.04 S 354.41 W 0.00 1417.07 5354.88 22.19 194.48 5064.81 1501.80 S 387.93 W 0.00 1551. 09 5 1/2" X 3 1/2" XO 5500.00 22.19 194.48 5199.18 1554.86 S 401.64 W 0.00 1605.90 5554.88 22.19 194.48 5250.00 1574.93 S 406.82 W 0.00 1626.63 T4.1 (Top Cairn) 5778.44 22.19 194.48 5457.00 1656.67 S 427.94 W 0.00 1711. 05 2P-432 Top Berm Tgt 22 Jul 03 5903.71 22.19 194.48 5573.00 1702.48 S 439.77 W 0.00 1758.36 T2 (Base Bermuda) 5980.39 22.19 194.48 5644.00 1730.52 S 447.01 W 0.00 1787.32 C35 (Top Albian) 6000.00 22.19 194.48 5662.16 1737.69 S 448.87 W 0.00 1794.73 6093.71 22.19 194.48 5748.93 1771.95 S 457.72 W 0.00 1830.12 TD, Csg Pt. All data is in feet unless otherwise stated. Coordinates from slot #432 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 1830.12 on azimuth 194.48 degrees from wellhead. Total Dogleg for wellpath is 22.19 degrees. Vertical section is from wellhead on azimuth 194.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ e e ConocoPhillips Alaska, Inc. Drill 8ite 2P,432 Meltwater,North 81ope, Alaska PROP08AL LI8TING Page 2 Your ref 2P-432 Version #4.B Last revised : 25-Aug-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 700.00 700.00 0.00 N 0.00 E KOP 1357.76 1352.00 72.79 8 18.80 W Base Permafrost 1809.41 1781. 89 205.40 8 53.06 W EOC 1993.13 1952.00 272.58 8 70.41 W Base Westsak 2452.12 2377.00 440.41 8 113.76 W 9 5/8" C8G 2533.11 2452.00 470.02 8 121. 41 W C80 3129.26 3004.00 688.00 8 177.72 W C50 3405.73 3260.00 789.10 8 203.83 W C40 3563.41 3406.00 846.75 8 218.73 W C37 4645.54 4408.00 1242.43 8 320.94 W T7 5354.88 5064.81 1501. 80 8 387.93 W 5 1/2" X 3 1/2" XO 5554.88 5250.00 1574.93 8 406.82 W T4.1 (Top Cairn) 5778.44 5457.00 1656.67 8 427.94 W 2P-432 Top Berm Tgt 22 Jul 03 5903.71 5573.00 1702.48 8 439.77 W T2 (Base Bermuda) 5980.39 5644.00 1730.52 8 447.01 W C35 (Top Albian) 6093.71 5748.93 1771. 95 8 457.72 W TD, Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE O.OOE 2452.12 6093.71 2377.00 5748.93 440.418 1771.958 113.76W 457.72W 9 5/8" C8G 3 1/2" C8G Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 2P-432 Top Berm Tgt 443414.000,5867277.000,999.00 5457.00 1656.678 427.94W 22-Feb-2001 e e ConocoPhillips Alaska, Inc. Drill Site 2P 432 slot #432 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 2P-432 Version #4.B prop4523 Date printed Date created Last revised 26-Aug-2003 25-Feb-200l 25-Aug-2003 Field is centred on 44l964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891. 466,999.00000, N Slot location is n70 3 9.205,w150 26 57.506 Slot Grid coordinates are N 5868930.205, E 443854.510 Slot local coordinates are 946.92 S 1897.73 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North e e ConocoPhillips Alaska, Inc. PROP08AL LI8TING Page 1 Drill Site 2P,432 Your ref 2P-432 Version #4.B Meltwater ,North Slope, Alaska Last revised , 25-Aug-2003 Measured Inclin Azimuth True Vert R E C TAN GULAR G RID C o 0 R D 8 G E 0 G RAP H I C Depth Degrees Degrees Depth C 0 0 R DIN ATE 8 Easting Northing C 0 0 RD"INAT E 5 0.00 0.00 194.48 0.00 O.OON o .OOE 443854.51 5868930.21 n70 3 09.21 w150 26 57.51 500.00 0.00 194.48 500.00 O.OON O.OOE 443854.51 5868930.21 n70 3 09.21 w150 26 57.51 700.00 0.00 194.48 700.00 O.OON o .OOE 443854.51 5868930.21 n70 3 09.21 w150 26 57.51 800.00 2.00 194.48 799.98 1. 695 0.44W 443854.06 5868928.52 n70 3 09.19 w150 26 57.52 900.00 4.00 194.48 899.84 6.768 1. 75W 443852.71 5868923.46 n70 3 09.14 w150 26 57.56 1000.00 6.00 194.48 999.45 15.195 3.93W 443850.47 5868915.04 n70 3 09.06 w150 26 57.62 1100.00 8.00 194.48 1098.70 26.995 6.97W 443847.33 5868903.27 n70 3 08.94 w150 26 57.71 1200.00 10.00 194.48 1197.47 42.145 10.89W 443843.31 5868888.15 n70 3 08.79 w150 26 57.82 1300.00 12.00 194.48 1295.62 60.618 15.66W 443838.39 5868869.72 n70 3 08.61 w150 26 57.96 1357.76 13.16 194.48 1352.00 72.798 18.80W 443835.15 5868857.57 n70 3 08.49 w150 26 58.05 1400.00 14.00 194.48 1393.06 82.395 21.28W 443832.60 5868847.99 n70 3 08.39 w150 26 58.12 1500.00 16.00 194.48 1489.64 107.455 27.76W 443825.94 5868822.98 n70 3 08.15 w150 26 58.31 1600.00 18.00 194.48 1585.27 135.768 35.07W 443818.41 5868794.73 n70 3 07.87 w150 26 58.52 1700.00 20.00 194.48 1679.82 167.288 43.21W 443810.03 5868763.28 n70 3 07.56 w150 26 58.75 1800.00 22.00 194.48 1773.17 201. 978 52.17W 443800.81 5868728.65 n70 3 07.22 w150 26 59.01 1809.41 22.19 194.48 1781.89 205.405 53.06W 443799.89 5868725.23 n70 07.18 w150 26 59.04 1993.13 22.19 194.48 1952.00 272.585 70.41W 443782.03 5868658.20 n70 06.52 w150 26 59.54 2000.00 22.19 194.48 1958.36 275.095 71.06W 443781.36 5868655.69 n70 06.50 w150 26 59.55 2452.12 22.19 194.48 2377.00 440.415 113.76W 443737.41 5868490.72 n70 04.87 w150 27 00.79 2500.00 22.19 194.48 2421. 34 457.915 118.29W 443732.75 5868473.25 n70 04.70 w150 27 00.92 2533.11 22.19 194.48 2452.00 470.025 121. 41W 443729.53 5868461.17 n70 04.58 w150 27 01. 01 3000.00 22.19 194.48 2884.31 640.745 165.51W 443684.14 5868290.81 n70 02.90 w150 27 02.28 3129.26 22.19 194.48 3004.00 688.005 177.72W 443671.57 5868243.64 n70 02.44 w150 27 02.63 3405.73 22.19 194.48 3260.00 789.105 203.83W 443644.69 5868142.76 n70 01.44 w150 27 03.38 3500.00 22.19 194.48 3347.29 823.568 212.74W 443635.52 5868108.37 n70 01.11 w150 27 03.64 3563.41 22.19 194.48 3406.00 846.755 218.73W 443629.36 5868085.23 n70 3 00.88 w150 27 03.81 4000.00 22.19 194.48 3810.26 1006.395 259.96W 443586.91 5867925.92 n70 2 59.31 w150 27 05.00 4500.00 22.19 194.48 4273.23 1189.215 307.19W 443538.30 5867743.48 n70 2 57.51 w150 27 06.36 4645.54 22.19 194.48 4408.00 1242.438 320.94W 443524.15 5867690.37 n70 2 56.99 w150 27 06.76 5000.00 22.19 194.48 4736.21 1372.045 354.41W 443489.68 5867561. 04 n70 2 55.71 w150 27 07.72 5354.88 22.19 194.48 5064.81 1501.805 387.93W 443455.18 5867431.55 n70 2 54.44 w150 27 08.69 5500.00 22.19 194.48 5199.18 1554.865 401.64W 443441. 07 5867378.60 n70 2 53.91 w150 27 09.08 5554.88 22.19 194.48 5250.00 1574.938 406.82W 443435.74 5867358.57 n70 2 53.72 w150 27 09.23 5778.44 22.19 194.48 5457.00 1656.675 427.94W 443414.00 5867277 . 00 n70 2 52.91 w150 27 09.84 5903.71 22.19 194.48 5573.00 1702.488 439.77W 443401. 82 5867231.29 n70 2 52.46 w150 27 10.18 5980.39 22.19 194.48 5644.00 1730.528 447.01W 443394.36 5867203.31 n70 2 52.19 w150 27 10.39 6000.00 22.19 194.48 5662.16 1737.698 448.87W 443392.46 5867196.16 n70 2 52.12 w150 27 10.45 6093.71 22.19 194.48 5748.93 1771.958 457.72W 443383.35 5867161.96 n70 2 51. 78 w150 27 10.70 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #432 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 1830.12 on azimuth 194.48 degrees from wellhead. Total Dogleg for wellpath is 22.19 degrees. Vertical section is from wellhead on azimuth 194.48 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ e e ConocoPhillips Alaska, Inc. Drill 5ite 2P,432 Meltwater,North Slope, Alaska PROP05AL LI5TING Page 2 Your ref 2P-432 Version #4.B Last revised : 25-Aug-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment - - - - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 700.00 700.00 O.OON O.OOE KOP 1357.76 1352.00 72.795 18.80W Base Permafrost 1809.41 1781.89 205.405 53.06W EOC 1993.13 1952.00 272.585 70.41W Base Westsak 2452.12 2377.00 440.415 113.76W 9 5/8' C5G 2533.11 2452.00 470.025 121. 41W C80 3129.26 3004.00 688.005 177.72W C50 3405.73 3260.00 789.105 203.83W C40 3563.41 3406.00 846.755 218.73W C37 4645.54 4408.00 1242.435 320.94W T7 5354.88 5064.81 1501.805 387.93W 5 1/2' X 3 1/2" XO 5554.88 5250.00 1574.935 406.82W T4.1 (Top Cairn) 5778.44 5457.00 1656.675 427.94W 2P-432 Top Berm Tgt 22 Jul 03 5903.71 5573.00 1702.485 439.77W T2 (Base Bermuda) 5980.39 5644.00 1730.525 447.01W C35 (Top Albian) 6093.71 5748.93 1771.955 457.72W TD, Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - -- - -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 2452.12 2377.00 O.OOE 6093.71 5748.93 440.415 1771. 955 113.76W 9 5/8" C5G 457.72W 3 1/2' CSG Targets associated with this wellpath ------------------------------------- ------------------------------------- Targe t name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - -- --- -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - -- 2P-432 Top Berm Tgt 443414.000,5867277.000,999.00 5457.00 1656.675 427.94W 22-Feb-2001 COßlPlllll: Field: I~cference Sile: I{cference Well: Reference Wellpalh: I.ker Hughes Incorporat. Anticollision Report ConocoPhillips Alaska, Inc. Meltwater 2P Pad 432 2P-432 Version#4.b .... ._......___..._n... _. ..__.__ -. ---...--.----.-- NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 25.00 ft Depth Range: 0.00 to 6093.71 ft Maximum Radius: 5280.00 ft Survey Program for Definitive Wellpath Date: 8/12/2003 Validated: No Planned From To Survey ft ft 0.00 6093.71 Planned: Version#4.b V25 Summary . . . . . . . . : <-~-_.::.:::",. . .... .. ,. Site">·,:,> 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad 2P Pad Meltwater North#1 Meltwater South #1 MWN#2 MWN#2 set Well¡i~th -------> ell """.,;, Wellpath .., 2P-406 Vers#2.A V2 Pia 2P-414 VerS#3a V1 Plan 2P-415 VO 2P-415A VO 2P-417 VO 2P-419 Vers#3.A V1 Pia 2P-420 VO 2P-422 V7 422A VO 2P-424 Vers#3.a V1 Pia 2P-427 VO 2P-429 VO 2P-431 V1 2P-434 Vers#9b V1 Plan 2P-438 VO 2P-441 VO 2P-443 Vers#3 V1 Plan: 2P-445 Vers#4 VO Plan: 2P-447 VerS#8b V2 Plan 2P-448 V2 2P-448A VO 2P-448PB1 VO 2P-449 Vers#6.b V1 Pia 2P-451 VO MWN#1 VO MWS#1 VO MWN#2 VO MWN#2A VO 406 414 415 415 417 419 420 422 422 424 427 429 431 434 438 441 443 445 447 448 448 448 449 451 MWN#1 MWS#1 MWN#2 MWN#2 Dale: 8/26/2003 Time: 16:17:59 I'age: Coo{ rdinale('Œ) I{derellce: Well: 432, True North Vertical (TVD) I{derellce: Doyon 141(0Id2) 252.0 Version: 7 Toolcode MWD+SAG Rë~~n~t ft 474.99 599.98 299.95 299.95 818.75 374.96 771.98 499.58 499.58 449.93 673.74 524.76 524.87 1000.75 424.99 1444.47 399.98 474.99 474.99 424.99 424.99 424.99 374.99 325.00 6084.29 4773.19 4891.67 ....... _._.. .... - _..__._._._..___ ...__n. _____ . Offset MD, ·ft: ;, 475.00 600.00 300.00 300.00 825.00 375.00 775.00 500.00 500.00 450.00 675.00 525.00 525.00 1000.00 425.00 1425.00 400.00 475.00 475.00 425.00 425.00 425.00 375.00 325.00 3850.00 .... .._...___n___ I)": Oracle Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Tool Name MWD + Sag correction Ctr-Ctr No-Go Distance Area ft; . ft 520.87 8.93 361.05 11.67 340.42 4.90 340.42 4.90 304.29 14.88 261.12 6.55 242.93 13.67 202.54 8.91 202.54 8.91 161.23 8.08 101.68 12.74 64.19 9.57 18.56 9.09 37.19 20.07 121.47 7.43 173.78 29.88 220.70 7.24 260.75 9.04 300.50 8.89 322.Q7 7.67 322.07 7.67 322.07 7.67 340.71 6.82 380.45 5.50 5264.43 82.93 Allowable Deviation ft 511.94 349.37 335.53 335.53 289.40 254.57 229.26 193.63 193.63 153.16 88.94 54.62 9.48 17.13 114.03 143.90 213.46 251.71 291.61 314.40 314.40 314.40 333.90 374.95 5181.49 5200.00 3423.39 113.69 3309.70 6775.00 2727.22 195.60 2531.62 ..... ...................... .:::..:.:..,:...... ............... ..... ... ......... ..... \V~~!1j~g:::' .. Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Pass: Major Risk e e MEL TW A TER - DRILLING HAZARDS SUMMARY 12 1,4" Open Hole & 9 5/8" Surface Casing Interval Event Risk L::evel Mitiaation Strateav! Continaencv Broach of conductor Low Monitor cellar continuouslv durina interval Gas Hydrates Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin Running sands & gravel Moderate Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Drill surface hole into shallow Low Do not exceed the surface hole TD as detailed pressured interval- C-80 in the individual well plans, ensure that all charged stands (in the derrick or in the hole) are accounted for at all times Hole swabbingfTight hole on Moderate Circulate hole clean prior to trip, proper hole trips filling (use of trip sheets), pumping out of hole as needed Stuck surface casing Low Clean the hole before running casing, pump hiah density hiah viscositv sweeos, wiDer trio Stuck pipe Low Keep hole clean, use high density high viscosity sweeps, keep pipe moving/rotating with pumps on whenever possible Lost circulation Low Keep hole clean. If losses occur - reduce pump rates and mud rheoloav, use LCM ¡/ ,/ 8 Iii' Open Hole & 5 1/2" X 3 Iii' Production Casing Interval Event Drill through a shallow pressured interval: C-80 to C-37 Insufficient or undetermined LOT Risk level Moderate Moderate High ECD / Tight hole on trips! Swabbing Moderate Differential sticking Moderate Barite sa Lost circulation Low High Miti ation Strate ! Contin enc Carry out well control drills. Kill fluid stored on location, contingency 7" casing string on location, hei htened awareness Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 18 MW e uivalent Condition mud & clean hole prior to trips. Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets Keep hole clean, periodic wiper trips, keep pipe movin /rotatin with um s on whenever ossible Good drillin ractices as documented in well Ian Pretreat mud before drilling reservoir section, keep hole clean - use PWD to monitor hole cleaning. If losses occur - reduce pump rates and mud rheolo , use LCM v Meltwater Drilling Hazards Summary Prepared by Philip Hayden 911/2003 Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 8/28/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 108 ft. MD < Base of Permafrost at 1,358 ft. MD (1,352 ft. TVD) < Top of Tail at 1 ,400 ft. MD < 95/8",40.0#, L-80 grade BTC, AB Modified in 12 1/4" OH TD at 2.452 ft. MD (2,377 ft. TVD) Mark of Schlumberger A 2P-432 CemCADE" Preliminary Job Design 9 5/8" Surface Preliminary Job Oesign based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 450% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 42' below base of permafrost.) Lead Slurrv (minimum pump time 207 min.) ArcticSet III Lite @ 10.7 ppg, -4.28 ft3/sk 0.7632 ft3/ft x (108') x 1.00 (no excess) = 0.3132 ft31ft x (1358' -108') x 5.50 (450% excess) = 0.3132 ft31ft x (1400' - 1358} x 1.45 (45% excess) = 82.4ft3 + 2153.3 ft3+ 19.1 ft = 2254.8 ft3 /4.28 ft3/sk = Round up to 527 sks 82.4 ft3 2153.3 ft3 19.1ft3 2254.8 ft3 526.8 sks Have 410 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv (minimum pump time 150 min.) LiteCRETE @ 12.0 ppg - 2.28 ft3/sk 0.3132 ft3/ft x (2452' -1400') x 1.45 (45% excess) = 0.4257 ft3/ft x 80' (Shoe Joint) = 477.8 ft3 + 34.1 ft3 = 511.9 ft3/ 2.28 ft3/sk = Round up to 225 sks 477.8 ft3 34.1 ft3 511.9 ft3 224.5 sks BHST = 59°F, Estimated BHCT = 75°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bb!) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 30 6.0 18.0 MudPUSH II 6 40 6.7 24.7 Drop Bottom Plug 4.0 28.7 Lead Slurry 7 402 57.4 86.1 Tail Slurry 5 91 18.2 104.3 Drop Top Plug 4.0 112.3 Water 5 20 4.0 116.3 XO to rig pumps 4.0 120.3 Displacement 7 145 20.7 141.0 Bump Plug 3 15 5.0 146.0 MUD REMOVAL Recommended Mud Properties: 9.6 ppg. Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-20, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 8/28/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 95/8",40.0#, L-80 grade STC, AS Modified at 2,452 ft. MD < 5 1/2", 15.5#, L-80 grade STC, AS Modified in 8 1/2" OH < Top ofTail at 5,055 ft. MD < X-over at 5,355 ft. MD < Top of Caim Fm. at 5,555 ft. MD < 31/2",9.3#, L-80 grade EUE, 8rd Modified in 8 1/2" OH TO at 6,094 ft. MD (5,749 ft. TVD) Mark of Schlumberger . 2P-432 CemCADE' Preliminary Job Design 51/2" x 31/2" Production Casing Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 300' above casing X-over. Tail Slurrv (minimum thickening time 133 min.) GasBLOK wI Class G + 053, 0600, 0135, 0800, 0047, 0065, per lab testing 3 @ 15.8 ppg, 1.17 ft Isk 0.2291 ft3/ft x 300' x 1.75 (75% excess) = 0.3272 ft31ft x (6094' - 5355') x 1.75 (75% excess) = 0.0488 ft31ft x 60' (Shoe Joint) = 120.3 ft3 + 423.2 ft3 + 2.9 ft3 = 546.4 ft3/1.17 ft3/sk = Round up to 467 sks 120.3 ft3 423.2 ft3 2.9 ft3 546.4 ft3 467 sks BHST = 146°F, Estimated BHCT = 124°F. (BHST calculated using a gradient of 2.~F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Yolume Cumulative Stage Time Time (min) (bb!) (min) CW100 5 10 2.0 2.0 Pressure test lines 10.0 12.0 CW100 5 40 8.0 20.0 Drop Bottom Plug 4.0 24.0 MudPUSH II 6 40 6.7 30.7 Tail Slurry 6 97 16.2 46.9 Drop Top Plug 4.0 50.9 Displacement 7 119 17.0 67.9 Bump Plug 2 14.2 7.1 75.0 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possib.le to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv? 23-25, Ty ? 37-40 Centralizers: Recommend 1 per joint on 5-1/2" section and 1-1/2 per joint on the 3-1/2 section to aid in mud removal. Meltwater 2P-432 In'-tor Proposed Completion Schematic 3-1/2" Completion String 30" x 16" 62.6# @ +1-108' MD (Insulated) Depths are based on Doyon 141 RKB Surface csg. 9 5/8" 40.0# L-80 BTC +1- 2452' MD 12377' TVD 5 %" 15.5# L-80 BTCM x 3 Yo" 9.3# L-80 EUE8RD Mod crossover at +1- 5355' MD I 5065' TVD Future Perforations Production csg 5 %" 15.5# L-80 BTCM x 3 %" 9.3# L-80 EUE8RD Mod +1- 6094' MD 15749' TVD e ~ Con 0 CO I:Qþs 3 %" FMC Gen 5 Tubing Hanger, 3 Yo" L-80 EUE8RD Mod pin down 3 %" 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3 %" 9.3# L-80 EUE8RD Mod Tubing to Surface 3 %" Camco 'DS' nipple wI 2.875" No-Go Profile. 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at +1- 500' MD 3 Yo" 9.3# L-80 EUE8RD Mod tubing to landing nipple 3 Yo" x 1" Camco 'KBG-2-9' mandrel wI shear valve, pinned for 3000 psi shear (casing to tubing differential), 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 Yo" Baker 'CMU' sliding sleeve wI 2.813" Camco DS profile, EUE8RD Mod box x pin. 3 Yo" x 6' L-80 EUE8RD Mod handling pup installed above 3 %" Camco 'D' nipple wI 2.75" No-Go profile. 3 Yo" x 16' L-80 EUE8RD Mod spacaeout pup installed above, 3 %" x 6' handling pup installed below 3 %" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3 Yo" L-80 EUE8RD Mod box up, 3 Yo" x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 W' BTCM x 3 Yo" EUE8RD Mod SBE set at +1- 200' MD above the top of the Bermuda interval (or 200' MD above the Cairn if present) 08/26/03 e ~ o -õ '" D;I u) I 150 28 OOW I 150 26 00 W 417 e;- ft 1-,/ §~ r"'. ...'~ .) _c ..............'" ...:...._...,;._....._-.,. "l !Jj -......,.....'1'0. --"""-"'---,..._..,_ J ',~." é' ~¡ 2P-420 ''''-'--.. <to - "-_._~"-->-...~. .. §, -".~_ ,f.? -'"'- --"""'" 8 ,_ .........--..:....__ JiJ ..;sf ,§',-~ ------- ¡q ~~ ~ ~~---8-~ ð 0 "-,,,-<¡r4p"""'·"'I".. ""-. 'off! ......, .N '~'''.'';~ ff -'~<.;: .# "'" . ~ B ~(.I:tJ .it -.".~..?y ~I vJ-~J.j,J.~:;i~' ........».~\,; .~.,.~,;a. "~-. . ~~.,.~;;, \~",. 0 . ,'. \~" .~ ~t iÿ.IC~ p:;J u Y '~$ ~ l 1 ~5v./ FJr ~qs,g ~,/ -;;. . .' (J·G ), ,ß z, ./ 3~'£i \ l(¡O(¡ y"......:J. l 4.... Il.,i j'-"''''"; C~t, / '~'c)^ .# ~J-', ' j \ /. '\~'- / '·'of!·1 ~ ° \ "Þ'J(ß ~.,:i7 'fJ è-' ,1 f-i .¡Llooh 2000 ~ \ j/'<>Î" <?, ,/ I' i?~OJ J\ \, .J."'- ../1'.":'''':'1 i 2-'" 'j '1 )o-~.-'/ (l "'q;, l ."'1., , j~ 60n,O i \ 'l!':!(f:J ",/,. 7 ¡ 1"''Ýi~ /v~"-- 'ft. 4oÇ\) /~ / / i5,.,.g;_4 22500 \\~ \\ 4~,00 /' >, 'vb /' -;"Oo[) It ¡ ·l {fl- \ \ , - " ~U0 '",1)\1 ~ SMú ,/,,>./ /' j \' \, ""ûoo 1 :1"-','\7 1 ~' I \ / / .1."'- 4$':;tì .3000 J \ N 5500 .¡' l ,r) \" j"'~' l 2P-44aA l' . .¡ ¡ ;r-J:.. \ I "Ucþ l! 5e,),,) 1 ~ \ ;I ! i " I, :sse:, ,/ ! '10(.'0 ~. . \ l' '/.~. 1-1 5500 1·_ J~¡OO ~ .\(;[;1:) \., / °00 - ~ ~ /'. ./ ;(. ! . \ ~'?fþ \. ~. ~\Y:f-''' . \\')"ß) \ \ ~ ~'~2 i ·\."Jq-p j ~Df)C' \ 1 . .\ j\~5N) \'\.., ~d3'.l 5",,0 \ ~\ ~ F;¡::'"f'.f\ \ ~ "·"V.. , i .. 2P-422Þ, ,000 I 2P-432 TVDss Ticks e \. , t:f-{J Feel , , , " 0 500 1,000 1,500 2,000 '\ '. '\ ,ODD N ~ 150 26 00 IN , o I 500 1 ,000 1 ,500 2,000 WELL PE:::RMIT CHECKLIST Field & Pool KUPARUK RIVER, MELTWATER OIL - 490140 PTD#: 202091 0 Administration Appr SFD Engineering Appr Date TEM 9/8/2003 ~1Ç'1 Geology Appr SFD Geologic Commissioner: /)aj 9/5/2003 Date 9/5/2003 Date Company CONOCOPHILLlPS ALASKA INC Initial ClasslType 1 P~mnitfee¡ attaçhed NA 2 Leasenumbe¡r .appropriate Yes 3 .U.nique¡ wellnarneand lJumb.er Yes 4 WellJQcated In.a.d.efinedpooL Yes 5 WellJQcated proper .distance. from driJling unitb.ound,ary. Yes 6 WellJQcated prope¡rdistançe from QtheJ wells. Yes 7Sutfiçientaçreage.available in.drilJilJg unit Yes 8 Jfdeviated, js weJlbQre¡ plç¡tjncJu.ded Yes 9 Qperator onl}! affeçted party. Yes 10 -0perator has appropriate 110nd inJQrce. Yes 11 Permit can be issued y,¡JtbQut co.nserva.tion order Yes 12 Permit can be issued y,¡JtbQut administratÌ\œapprovaJ Yes 13 .C.an perrnJt Þe apPJoved before J 5-day. waJt Yes 14 WellJQcated within area and.strç¡ta ,authorized byllJjection Order'# (puIlO# lncornmelJts>-(For. Yes 15AJI wells.within .1l4. mile.are¡a.of review idelJtified (For servjcewelJ On I}!) Yes 16 Pre-produced injector; duratiQn.of pre-production less than. 3 montbs. (For.service well onJy) N.o 17 ACMY finding 9f Con$i$tency.h,as be¡eÐ jssuedJorJhis pcoiect . . . NA 18 Gondu.ctor string. provided 19S.urface .cç¡sing.pJotects. alLknown. USDWs 20CMT vol adequ.ate. to circul,ateoÐ .cond.uctor. & SUJfq;g 21CMT voL adequ.ate. to tie-in JQng .string to surf csg 22 .CMTwill çoveraJl klJowÐ.pro.ductive bQri;?:on.s. 23 .Gasing designs adequate for C,.T~ B .&.p.ermafrost 24 AdequateJanj<ç¡ge.or re.seIYe pit 25 JfaJe-d(ill~ has a 10-403 fQr abandonment beelJ apPJoved 26 Mequate well bore. separatjoÐ proposed. 27 Jf d]verte¡r re¡quire¡d, does Jt meet reguJa.tions. 28 DJiUilJg fluid program schemç¡tic& equip Jistadequate. 29 BÜPEs, dO they meetreguJaJion 30 BÜPEpress ra.tilJg approp(iate;te¡st to.(puJ PSig in.comments>- 31 .C.hokemanifold compJies w/APLR~-53 (May 84>- 32 WQrk will oçc.U( withoutoperç¡tionshutdown. 33 Js presence. of H2S gas. probable. 34 MeçhanicaLCOlJdjtion of wells within ,6.0B ve¡rified (For. service well onM. Yes NA Yes No Yes Yes Yes NA Yes Yes Yes Yes Yes Yes Yes . . . NA Yes 35 Permit GaIJ be issued y,¡lo. hydr9ge¡n. sulfide¡ measures. 36 .D.ata.pre¡selJted on pote.ntial oveJpres.sure .zones. 37Seismic.analysJs. of sballow gas.zolJes. 38Seç¡bed wnditiolJ survey.(if off-shore) 39 . Contact narnelphoneJonA.leekly progress reports [e¡<plorç¡tory 9!1ly] Yes Yes NA NA NA Date: /0/1013 Engineering Commissioner: Date Public Commissioner , Date ~ ~~ '" .... Well Name: KUPARUK RIV U MELT 2P-432 SER I PEND GeoArea 890 Unit 11160 Waived: RevisiOIJ ofapprove.d.permiUo drill.priorJo spud. Program SER On/Off Shore On Well bore seg D Annular Disposal D · CO 456: . SpaCilJg unjts withjn the pooJ is.1 0 acres. .,6.1021. f\Jon.e e · M aquifers exempted 40 cm j 14..102 1b)(3) · ,6.nnul<3r disP9sal rn.ay be¡ reQue.sted.. · Big is.e.quippe.dwith steelpits. .No reser\lepjtplanlJed, Wa.steJo approved annulus or.disposal we¡lI, · Pro~imtty. analysis perfo(me.d.a!1d travelJngcyllnder.plot pn3paJe¡d. · MaxJmirn.e.xpectedJormationpre$suJe¡ ç¡tTD.B..7: EMW, MW plalJned 9..6, · Some.locali:z:ed .shallow pressure.s .have. beelJ se¡e!1olJ 3 y,¡ells, NearestwelJ (2P-4381 h.as C~B.O .EMW of 9.8. . · CalçuJaJed.MASP 1951 psi.. 3500 psiapproprtate, PPCo usualJyJests to.5000. psi.. - · There are IJQ wells withilJ 1/4 miles of 2P-432 ç¡Uhe. top oUhe. prod.uctive inter\laJ. . · Uf\JDER~RESBURED:. expected pressurein Be¡rmuda. reser\loir is 6.3 - 8.7 ppg EMW, · I:Hgb annula( pressures tn.2P43t 451 & 438.d.eIJQte SQme risk of shallow, bigh pres.sure, HighesJ. · expecte¡d. is 11.1 ppg. EMW.. Operç¡tor rates risk. as Jow to rnoderç¡te.. PotentiaL aÐd rnJti.gç¡t[on meaSUJes. aJe¡ · ad.dre$se.din the DriltingHa.zç¡rds Summary.. This application is for a revised bottom hole location for a previously approved permit to drill prior to spud. SFD · .. e -- ~1J~1JŒ (ffi~ ~~~~[{~ I ALASKA OIL AND GAS / CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Phillips Alaska, Inc. Kuparuk Drilling Team Leader PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 2P-432 Phillips Alaska, Inc. Permit No: 202-091 Sur. Loc. 948' FNL, 1894' FWL, Sec. 17, T8N, R7E, UM Btmhole Loc. 2478' FSL, 1826' FWL, Sec. 17, T8N, R7E, UM Dear Mr. Thomas, Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing conftrmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit 2P must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. · .. Permit No: 202-091 April 19, 2002 Page 2 of2 e e The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (M!) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test perfonned before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, b=l~ Chair BY ORDER OF THE COMMISSION DATED thisJ1t.(day of April, 2002 jjc/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. 1 a. Type of work: Drill l.:d Redrill 1b. Type of well. Exploratory U Stratigraphic Test U Development Oil U Re-entry DDeepen 0 Service [2] Development Gas 0 Single Zone [2] Multiple Zone 0 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB = 254 feet AMSL Kuparuk River Field 3. Address 6. Property Designation Meltwater Oil Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 373112 ALK 4998 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) 948' FNL, 1894' FWL, Sec. 17, T8N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2637' FSL, 1832' FWL, Sec. 17, T8N, R7E, UM 2P-432 #59-52-180 At total depth 9. Approximate sPu1ate Amount 2478' FSL, 1826' FWL, Sec. 17, T8N, R7E, UM April 24, 2002 $200,000 12. Distance to nearest property line 13. Distance to nearest well / 14. Number of acres in property 15. Proposed depth (MD and TVD) 2637' @ Target 2P-431, 17.9' @ 440' feet 2560 6205 ' MD I 5858 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (se~ MC 25.035 (e)(2» Kickoff depth: 700 MD Maximum hole angle 22 Maximum surface 2232 psig At total depth (TVD) 2846 psig 18. Casing program Setting Depth size 8oecifications Top Bottom Quantitv of Cement Hole Casinq Weiqht Grade Couolinq LenGth MD TVD MD TVD (include staoe data) 42" 16" 62.5# H-40 Weld 80' 30' 30' 110' 110' 9 cu yds High Early 9.875" 7.625" 29.7# L-80 BTCM 2393' 30' 30' 2423' 2351' 380 sx AS 3 Lite & 150 sx LiteCRETE 6.75" 5.5" 15.5# L-80 BTCM 5382' 30' 30' 5412' 5123' 280 sx Class G 6.75" 3.5" 9.3# L-80 EUE 8rd M 792' 5412' 5123' 6205' 5858' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface RECEIVED 0 APR 1 o 2002 Perforation depth: measured AlaakaOiI & Gas COlli. Commission Anchorage true vertical 20. Attachments Filing fee [2] Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program [2] Drilling fluid program [2]Time vs depth plot Defraction analysis DSeabed report 020 AAC 25.050 requirements [2] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge lJuestlons? c;iilTPat Rel/ly 265~ Signed ~ ~ Title: KuparukDrilling Team Leader Date 1.-( Ií~/'o L Rand Thomas ~, fl.1I~"n_nr~¡'n Commission Use Onlv Permit Number API number Approval date (( See cover letter Za2-"'O 9/ 50- A::J. '? - 2. 0 ý' 2..c q: I~ ,z..- for other requirements Conditions of approval Samples required DYes ~ No Mud log required DYes JðI No Hydrogen sulfide measures DYes ~ No Directional survey required ~ Yes 0 No Required working pressure for BOPE D2M; o 3M; 0 5M; 0 10M; 0 0 Other: 3000 ~\ ~'?~!.~ \-A.. \\~ c....<t.~~-\.a..'-.)~\\~ \.-o~ 411~ (02- Approved by r a. ItA. f)l . '^ ,1' fL .by order of , Commissioner the commission Date {) 0 e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 'rJ ~I\- t.J I )ft; /0 '2- ~/{'l-O~ Form 10-401 Rev. 12/1/85. ORIGINAL Submit in triplicate e AP.ion for Permit to Drill, Well 2P-432 Saved: 10-Apr-02 Permit It - Meltwater 2P-432 Application for Permit to Drill Document Mo)xir'l'lizE W~II I/olu~ Table of Contents 1. Well Name................. ...... ................... ................ ......... ................. ................... .......... 3 Requirements of 20 AAC 25.005 (f). .......... ....... ..................... ......... ........................................................ 3 2. Location Su m mary .......... ........ ................ ................... ... ....... ..... .................. ............. 3 Requirements of 20 AAC 25.005(c)(2) ............................. ......................................................... ............. 3 Requirements of 20 AAC 25. 050(b).............. .......................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 4 Requirements of 20 AAC 25. 005( c)(3) ......... ............................................. ............................................. 4 4. Drilling Hazards Information ................................................................................... 4 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 4 5. Procedure for Conducting Formation Integrity Tests........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................4 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25. 005( c)(6) ................................................................................................... 4 7. Diverter System Information ...................................................................................5 Requirements of 20 AAC 25. 005( c)(7) ............. ..................................................... ......................... ........ 5 8. Dri II i.ng FI u id Prog ram ....... ............... ............. ..... ....... ......... ...... .................. ............. 5 Requirements of 20 AAC 25. 005( c)(B) .. ................................................................................................. 5 9. Abnormally Pressured Formation Information ......................................................6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 1 O. Seism ic Analysis..... ................ .............. ........................................................... ........ 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bonding ...............................................................................................6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 ORIGINAL 432 PERMIT IT TEMPLATE.dot Page 1 of 7 Printed: 10-Apr-02 e APWion for Permit to Drill, Well 2P-432 Saved: 10-Apr-02 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attach ments ................................................ .......................... ........ ...... ..................... 7 Attachment 1 AOGCC Form 10-401 (Front of permit package) ............................................................ 7 Attachment 2 Directional Plan................................................... ...... ...................................................... 7 Attachment 3 Drilling Hazards Summary................ ...................... ...... .................. ................................. 7 Attachment 4 Well Schematic...................................... ........... ................................................. .............. 7 Attachment 5 Cement Details.............................................................................................. .................. 7 ORIGINAL 432 PERMIT IT TEMPLATE.dot Page 2 of 7 Printed: 1 D-Apr-02 e A.tion for Permit to Drill, Well 2P-432 Saved: 10-Apr-02 1. Well Name Requirements of 20 AAC 25.005 (f) Each well mIJst be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branche0 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 2P-432. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill mlJst be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's 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 section lines. (8) the coordinates of'the proposed location of'the well at the surface, ret'erenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmo::'fJheric Administration; (C) the proposed depth of the well at the top of eal..iJ objective formation and at totai depth,' Location at Surface NGS Coordinates Northings: 5868930.21 I 948' FNL, 1894' FWL, Sec 17, T8N R7E, UM I RKB Elevation: 254 ft AMSL Eastings: 443854.51 Pad Elevation: 224 ft AMSL Location at Top of 2637' FSL, 1832' FWL, Sec 17, T8N, R7E, UM Productive Interval (Bermuda Formation) NGS Coordinates Measured Depth (RKB feet): 5779' Northings: 5867235.36 Eastings: 443784.96 True Vertical Depth (55 feet): 5210 ' True Vertical Depth (RKB feet): 5464 ' Location at Total Depth I 2478'FSL, 1826' FWL Sec 17, T8N R7E, UM NGS Coordinates Measured Depth (RKB feet): 6205' Northings: 5867076.58 Eastings: 443778.44 True Vertical Depth (55 feet): 5604 ' True Vertical Depth (RKB feet): 5858 ' and (D) other information required by 20 AAC Z'i050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a PermIt to Drill (Form 10"40.1) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent we/lbores w;t!¡in 200 feet of any portion of the proposed we/f,' Please see Attachment 2: Directional Plan and (2) for all wells wIthin 200 feet of the proposed we/lbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public record0 and show that each named operator has been furnished a copy of'the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. ORIGINAL 432 PERMIT IT TEMPLATE.dot Page 3 of 7 Printed: 10-Apr-02 e AP.ion for Permit to Drill, Well 2P-432 Saved: 10-Apr-02 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application tor a Permit to Dlill must be accompanied by each of the follow/ilg Items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPt:) as required by 20 AAC 25:035, 20 AAC 25.036, or 20 AAC 25:03;; as applicable,' Please refer to Nordic 3 BOP Schematic currently on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Pelmit to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identifled in the application: (4) information on drillÙ7g hazards, including (A) the maximum downhole pres::,"Ure that may be encountered, CrIteria used to determine i0 and maximum potential surface pressure based 017 a methane gradient; The expected,)eservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.51 psi/ft, or 8.5 to 9.7 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing operations on the nearby exploration wells, Meltwater North #1 and Meltwater North #2/2A, and on development wells. The maximum potential surface pressure (MPSP) based on the the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Bermuda formation is: MPSP as a function of reservoir pressure =(5580 ft 1VD)(0.51 - 0.11 psi/ft) = 2232 psi/' / Assuming a LOT / FIT of 16.2 ppg based on open hole results from the closest offset well, 2P-441, MPSP as a function of LOT / FIT at the surface shoe (2351' 1VD) =(16.2* .052*2351')-(2351 *0.11) =1722 psi. /' Therefore, the MPSP may be based on the reservoir pressure calculation of 2232 psi. (B) data Oil potential gas zOlles~' The Cairn interval is expected from 5512' MD - 5571' MD. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity tor differential sticking/ Please see Attachment 3: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application tor a Pem7it to Dri!1 must be accompanied by eac/! of the following ¡tems~ except f..r¡r an Item already on flle with the commission and identified in the application: (5) a desCliption or the procedure for conducting tormation integrity' tests, as required under 20 AAC 25. 030(t},' A formation integrity test will be performed after drilling out below surface in accordance with the Phillips Alaska LOT / FIT procedure, currently on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of tile following items, except for an item already 017 file with the commission and Identifled in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted line/~ pre- perforated lìne¡~ or screen to be instal/eel;' ORiGINAL 432 PERMIT IT TEMPLA TE.dot Page 4 of 7 Printed: 10-Apr-02 e AP.ion for Permit to Drill, Well 2P-432 Saved: 10-Apr-02 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Iblft) Grade Connection (tV (ft) (ft) Cement Proaram 30 X 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 9 cy High Insulated Early 7 5/8 9 7/8 29.7 L-80 BTC AB 2393 30 / 30 2423 / 2351 380 sx 10.7 MOD ppg AS3 Lead, 150 sx 12 ppg LiteCrete Tail Planned Top of Cement: SURFACE 51/2 6 3/4 15.5 L-80 BTC AB 5382 30 / 30 5412/5123 280 sx 15.8 MOD ppg Class 'G' 31/2 63/4 9.3 L-80 8RND 792 5412/ 5123 6205 / 5858 Planned Top of MOD Cement: 4912' MD /' ./' 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following ¡tem~ except for an Item already on file with the commission and identifÎed in the application: (7) a diagram and description of the diverter system as required by 20 MC 25.03~ unless this reqUliement is waived by the commission under 20 AAC 2.5:035(11)(2); Please refer Nordic 3 Diverter Schematic currently on file with the Commission. 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 fallowing Item~ except far an Item alœady on flle with the commission and identifled in the application: (8) a drilling fluid program, ¡i¡eluding a dlilgram and descripú'on of the drilling flUId system, as required by 20 AAC 25.o:n· Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be built and maintained to the following specifications: Spud to 97/8" Drill Out to Top Bermuda Surface Casing Top Bermuda To Well TD Initial Value Final Value Initial Value Final Value Initial Value Final Value / Density (ppg) 9.6 9.6 9.6 9.6 9.6 9.6 Funnel Viscosity 150-200 150-200 50 65 50 65 (seconds) , Yield Point 35-45 27-40 10 25 10 25 (cP) Plastic Viscostiy 8-15 11-22 8-18 8-18 8-18 8-18 Obl100 sf) 10 second Gel 10-30 10-25 3 9 3 9 Strenath Obl100 sf) 10 minute Gel 25 55 4 8 4 8 Stren.ath (Ibl100 sf) PH 8-9 8-9 8-9 8-9 9-9.5 9-9.5 ORIGINAL 432 PERMIT IT TEMPLA TE.dot Page 5 of 7 Printed: 10-Apr-02 e AP.ion for Permit to Drill, Well 2P-432 Saved: 10-Apr-02 I API Filtrate(cc) <15 <15 <6 <6 <6 <6 Please refer to Nordic 3 Fluid System Components currently on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on file wIth the commission and Identified in the application: (9) for an exploratory or stratigraphic test wel{ a tabulation :,-etting out the depths of predicted abnormally gea-pressured strata as required by 20 AAC 25.033{f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application far a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on f¡le wIth the commission and Identified in the application: (10) for an explorator¡ or stratigraphic test wellr a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory of stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application far a Permit to Drill must be accompanied by each of the tollowing items, except for an item already on file wIth the commission and identified in the application: (11) far a well dnlled tram an offshore platfofln moMe bottom-founded structure, jad-up rig, or floating dnlling vesselr an analysis of seabed conditions as required by 20 MC 25. 061 (b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the follmving item.~ except for all item already on file with the commission and Identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a PermIt to Drill must be accompanied by each of the followlÍ7g Items, except for an Item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4: Well Schematic: 1. Excavate cellar¡ install cellar box¡ set and cement 16" x 30" insulated conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Nordic 3. Install diverter & function test same. ./ // 3. Spud and directionally drill 9 7/S" hole to 7 5/S" surface casing point (+/- 2423 MD') according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. 4. Run and cement 7 5/S" 29.7# L-SO BTC AB MOD casing to surface using ArcticSet 3 lead slurry and LiteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to ensure cement reaches the surface. Displace cement with mud. ORIGINAL 432 PERMIT IT TEMPLA TE.dot Page 6 of 7 Printed: 10-Apr-02 It AP8ion for Permit to Drill, Well 2P-432 Saved: 10-Apr-02 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. / 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results. / 7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 18.0 ppg EMW. / / 8. Directionally drill 6 3/4" hole to well total depth (+/- 6205' MD) according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. Circulate and condition hole. POOH. 9. Run open hole e-line or drill pipe conveyed logs as needed. 10. Run and cement 5 1/2" 15.5# L-80 BTC AB MOD x 3 1/29.3# L-80 8RND MOD tapered production ,/ casing string with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' MD above the planned top perforation. / 11. Run and land 3 1/2" 9.3#, L-80, 8RND MOD tubing. Displace well to completion brine. 12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 13. Freeze protect well. Set BPV. Release rig and turn well over to production. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. * Cement bond log will be run prior to perforating injectors. 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 eac!¡ of the following item::,~ 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 authorìzi!tion under 20 AAC 25.080 for an annular disposal operation in the well,,' Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P pad or hauled to a Class II disposal well. All cuttings to be disposed of will be either disposed of down the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for disposal down an approved disposal well. At the end of drilling operations, a request will be submitted for this well to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 AOGCC Form 10-401 (Front of permit package) Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Cement Details ORIGINAL 432 PERMIT IT TEMPLA TE.dot Page 7 of 7 Printed: 10-Apr-02 0 300 600 900 1200 1500 1800 ,-.., 2100 +- Q) Q) '+- '-"" 2400 .r:: +- 0... Q) 2700 0 0 3000 Ü +- I..... Q) > 3300 Q) :::¡ I..... 3600 l- I V 3900 4200 4500 4800 5100 5400 5700 6000 - e Phillips Alaska, Inc. RKB Elevation: 254' KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 It 8.00 10.00 12.00 Base Permafrost 14.00 16.00 18.00 20.00 EOC Base Westsak 7 5/8 CSG C80 C50 C40 C37 MW(Y) Midpt TGT RYSD 26 MAR 02 T2 lBase Bermuda) 300 600 900 1200 1500 1800 2100 2400 Structure: Drill Site 2P Well : 432 Field : Meltwater Location : North Slape, 181.91 AZIMUTH 1720' (TO TARGET) ***Plane of Proposal*** TANGENT ANGLE 21.96 DEG ./ T7 5 1/2 X 3 1/2 XO T4.1 (Tap Cairn) 13.1 (Base Cairn) 13 (Top Bermuda) Bermuda Mdpt TGT C35 (Top Albion) Vertical Section (feet) -> Azimuth 181.91 with reference 0.00 N, 0.00 E from slot #432 ORIGI¡VAL Created by bmichoel For: P Reilly Dote plotted; l-Apr-2002 Plot Reference is 2P-432 Version 112. Coordinates ore in feet reference slot 1432. Vertical Depths ore reference RKB (Nordic liiiig ......... -- TNTEQ 200 100 100 0 100 200 300 400 500 600 700 ,,-..., 800 +- Q) Q) '+- '-'" 900 ..c +- ::¡ 0 1000 tf) I V 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 e Phillips Alaska, Inc. Structure: Drill Site 2P Well : 432 Field: Meltwater Location : North Slope, East (teet) -> 100 200 300 400 KOP SURFACE LOCATION: 948' FNL. 1894' FWL SEC. 17, T8N. R7E Base Permafrost EOC Base Westsak e Created by bmichoel For: P Reilly Dote plotted: 1-Apr-2002 Plot Reference is 2P-432 Version #2. Coordinates ore in feet reference slot #432. Vertical Depths ore reference RKB (Nordic ~. ~ TNTEt) j L7 5/8 CSG C80 181.91 AZIMUTH 1720' (TO TARGET) ***Plone of Proposal*** ~ J*l C50 TRUE C40 C37 T7 5 1/2 X 3 1/2 XO T4.1 (Top Cairn) D.l (Bose Cairn) TARGET LOCATION: 2613' FSL, 1831' FWL SEC. 17. T8N, R7E D (Top Bermuda) Bermuda Mdpt TGT T2 (Bose Bermuda) C35 (Top Albian) j L TO, Csg PI. TO LOCATION: 2478' FSL. 1826' FWL SEC. 17, T8N, R7E ORIGINAL Phillips Alaska, Inc. Created by bmichael Structure: Drill Site 2P Well : 432 Date plotted: 1-Apr-2002 Plot Reference is 2P-432 Version #2. Field : Meltwater Location : North Slope, Alaska Coordinates orc in feet reference slot #432. Vertical Depths ore reference RK8 (Nordic !ll!!iltII ....... - J1'>IïF.Q ==== PROF~LE COMMENT DATA ==.== ----- Point ----- MD Inc Dir TVD No rt h East V. Sect Deg/100 e KOP 700.00 0.00 181.91 700.00 0.00 0.00 0.00 0.00 Bose Permafrost 1359.82 13.20 181.91 1354.00 -75.61 -2.53 75.65 2.00 <::> EOC 1797.76 21.96 181.91 1771.09 -207.65 -6.94 207.76 2.00 ::0 -- Bose Westsak 1994.97 21.96 181.91 1954.00 -281.34 -9.40 281.50 0.00 ~ 7 5/8 CSG 2423.29 21.96 181.91 2351.26 -441.39 -14.75 441.64 0.00 -- ~ C80 2523.29 21.96 181.91 2444.00 -478.76 -15.99 479.02 0.00 ~ C50 3123.84 21.96 181.91 3001.00 -703.17 -23.49 703.56 0.00 r-- C40 3405.25 21.96 181.91 3262.00 -808.32 -27.00 808.77 0.00 C37 3588.54 21.96 181.91 3432.00 -876.81 -29.29 877.30 0.00 4772.40 21.96 181.91 4530.00 -1319.19 -44.07 1319.93 0.00 e 5 1/2 X 3 1/2 XO 5412.04 21.96 181.91 5123.25 -1558.21 -52.05 1559.07 0.00 14.1 (Top Cairn) 5512.04 21.96 181.91 5216.00 -1595.57 -53.30 1596.46 0.00 13.1 (Bose Cairn) 5571.34 21.96 181.91 5271.00 -1617.73 -54.04 1618.63 0.00 (Top Bermuda) 5779.43 21.96 181.91 5464.00 -1695.49 -56.64 1696.44 0.00 Bermuda Mdpt TGT 5841.97 21.96 181.91 5522.00 -1718.86 -57.42 1719.82 0.00 (Bose Bermuda) 5904.50 21.96 181.91 5580.00 -1742.23 -58.20 1743.20 0.00 C35 (Top Albion) 5995.07 21.96 181.91 5664.00 -1776.07 -59.33 1777.06 0.00 e e Created by bmichoel For: P Reilly Dote plotted: 1 -Apr-2002 Plot Reference is 2P-432 Version H2. Coordinates ore in feet reference slot #432. True Vertical Depths ore reference RKB (Nordit:: III). n[¡~ Þ~.6==< ........... Phillips Alaska, Inc. Field: Meltwater Location : North Slope, Alaska Structure: Drill Site 2P Well : 432 !NT!!:Q '.1500 TRUE NORTH ~ -<=:r c=J 350 0 10 340 210 @ ~~ 20 250 330 30 320 40 310 50 300 60 70 280 80 270 90 260 100 1 10 240 " 1100/ . / ,/1500 (1/2 ~6 ~ ~o " 1500 1,30 220.1500 140 210 15'0 ~ 200 160 I!J, $ 1 90 1 80/ 1 70 @@ ~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ORIGINAL Created by bmichae! For: P Reilly Date plotted: l-Apr- 2002 Plat Reference is 2P-432 Version #2. Coordinates ore in feet reference slot #432. rue Vertical Depths are reference RKB (Nordic lliliillîi aalÏm··· ~tiüGiEs JNTKQ e e Phillips Alaska, Inc. ~~--- <PHILLlPSr I t . '\: Structure: Drill Site 2P Well : 432 Field : Meltwater Location: North Slope, <- West (feet) ~."7MOO " 700 0 20 40 60 80 100 120 140 160 80 "' N ..,. 60 ,;. 700 40 ~300 @300 e " 500 " 500 20 180 160 140 120 100 80 60 40 20 ~ <:& ~ " 900 " 900 '" 130cJ G0. '\Y " 700 " 500 /_300 ~300 ! '0 ~300 ! @300 " 500 " 500 ¡, 700 " 700 .; 700 (f¡ ¡ 900 " 900 11100 " 1100 J 1300 & f 1300 (f¡ i!J '" 900 " 500 ~300 % 500 " .300 " 700 "'B7OO .. 900 I ~300 I I 700 20 ~ 1100 I I " 900 40 I I I I 900 ~ 1300 60 I I UJ I 80 0 I I C -+ I ,;. 1100 ::r I I 100 ,......., I ....... I CD " 1500 1100 CD I -+ I 120 '-../ I I I I V I 140 I I I I 160 I I ~ I ~ 1700 180 I I I I 200 I 1300 I I I I 220 I I I I 240 I I I ,1 260 I I I @ 280 ORIGINAL C-~-~-~t-;d---by--¡;-~¡;-h~-~T . Date plotted: e Location For: P Reilly 1-Apr-2002 Phillips Alaska, Well: 432 Plot Reference is 2P-432 Version H2. Coordinates ore in feet reference slat #432. Varticol Depths ore reference RKB (Nordic III). llliïl!! -=- INT":f) 700 600 Ø> ,Ø>.@'Ø ,,' r90?~ ~~ {600 /" 1 6ÖO ~. (!; ¡2200 !5ì <!i / ilsf'tPoO . 2200/ . / j / ! ¡ 250p (j) , f1J "f34~\J0 " 2500 .f , ¡ 3700 fC [!J 500 400 300 . ,,~1900 f 1600 :1 : " 1.13ØO I¡ ¡ ~ ¡ ¡ .i/ Ii 1 900 ¡¡~'l/!lfIJJ !,! l /' ,,1900 4' " 19rib ¡, If " /~ 7ÆfID i #200 / ! ! ! II " 2200 ~~w!ò Structure: Drill Site 2P Field : Meltwater 200 100 0 East (feet) -> 100 200 400 Ii I' ¡! 2200;.~ 1600 If Ii II Ii 2500>1 /, Ii Ii 'i 2800~ t 1900 , i 31001> ! ,1 jl " * 3400 !I jI ;1 1+ 3700 it il II !I 2200.;. 4000 I I i I i' . , , ~ 4300 . , ! I , ¡I i + 4600 , m, , , * 4900 , , , , + 5200 , , , ~ 5500 , , , I . 5800 m 300 e In 500 600 1000 200 700 800 900 ~ ~<?®~ .'" 190!y', '",1~ 300 <?® ' " '",1900 ~ 400 , 1600.J " ~ 500 ,,1900, 1600 , .~< '.. 600 2200 ~ 700 ?", \ ~ 800 \ \ \ \ \ 900 , , ~ \ , < , , 1000 \ \ ~ (/) 1100 0 s:: -+ " 1900 ~ :::r 1200 .......... -+. CD CD -+ 1300 '-" I V 1400 1500 . 2500 1600 1700 " 2200 2800 1800 % 1900 2000 :. 2800 2100 'ê 2200 ORIGINAL e e Phillips Alaska, Inc. Drill Site 2P 432 slot #432 Meltwater North Slope I Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License 2P-432 Version #2 prop4523 Date printed Date created Last revised l-Apr-2002 25-Feb-200l 27-Mar-2002 Field is centred 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.20S,w150 26 57.506 Slot Grid coordinates are N 5868930.205, E 443854.510 Slot local coordinates are 946.92 S 1897.73 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIG/^lAL e e Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P.432 Your ref 2P-432 Version #2 Meltwater,North Slope, Alaska Last revised , 27-Mar-2002 Measured Inclin. Azimuth True Vert R E C TANGULA R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R DIN ATE S Deg/l00ft Sect 0.00 0.00 181. 91 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 181. 91 500.00 0.00 N 0.00 E 0.00 0.00 700.00 0.00 181. 91 700.00 0.00 N 0.00 E 0.00 0.00 KOP 800.00 2.00 181. 91 799.98 1. 74 S 0.06 w 2.00 1. 75 900.00 4.00 181. 91 899.84 6.97 S 0.23 w 2.00 6.98 1000.00 6.00 181. 91 999.45 15.68 S 0.52 W "/2.00 15.69 1100.00 8.00 181. 91 1098.70 27.86 S 0.93 W 2.00 27.88 1200.00 10.00 181. 91 1197.47 43.50 S 1.45 W 2.00 43.52 1300.00 12.00 181. 91 1295.62 62.57 S 2.09 w 2.00 62.60 1359.82 13 .20 181.91 1354.00 75.61 S 2.53 W 2.00 75.65 Base Permafros t 1400.00 14.00 181. 91 1393.06 85.05 S 2.84 w 2.00 85.10 1500.00 16.00 181. 91 1489.64 110.92 S 3.71 W 2.00 110.98 1600.00 18.00 181. 91 1585.27 140.13 S 4.68 W 2.00 140.21 1700.00 20.00 181.91 1679.82 172.67 S 5.77 W 2.00 172.77 1797.76 21. 96 181. 91 1771.09 207.65 S 6.94 W 2.00 207.76 EOC 1994.97 21.96 181. 91 1954.00 281. 34 S 9.40 W 0.00 281. 50 Base Westsak 2000.00 21. 96 181.91 1958.66 283.22 S 9.46 w 0.00 283.38 2423.29 21. 96 181.91 2351.26 441. 3 9 S 14.75 W 0.00 441. 64 7 5/8" CSG 2500.00 21. 96 181.91 2422.40 470.06 S 15.70 W 0.00 470.32 2523.29 21. 96 181.91 2444.00 478.76 S 15.99 w 0.00 479.02 C80 3000.00 21. 96 181. 91 2886.14 656.89 S 21. 94 w 0.00 657.26 3123.84 21. 96 181. 91 3001. 00 703.17 S 23.49 w 0.00 703.56 C50 3405.25 21. 96 181.91 3262.00 808.32 S 27.00 W 0.00 808 . 77 C40 3500.00 21. 96 181. 91 3349.88 843.73 S 28.19 W 0.00 844.20 3588.54 21. 96 181. 91 3432.00 876.81 S 29.29 w 0.00 877.30 C37 4000.00 21. 96 181. 91 3813.62 1030.57 S 34.43 w 0.00 1031.14 4500.00 21. 96 181. 91 4277.36 1217.40 S 40.67 W 0.00 1218.08 4772.40 21. 96 181. 91 4530.00 1319.19 S 44.07 W 0.00 1319.93 T7 5000.00 21. 96 181. 91 4741.09 1404.24 S 46.91 w 0.00 1405.02 5412.04 21.96 181. 91 5123.25 1558.21 S 52.05 W 0.00 1559.07 5 1/2 X 3 1/2 XO 5500.00 21. 96 181. 91 5204.83 1591.07 S 53.15 w 0.00 1591. 96 5512.04 21. 96 181. 91 5216.00 1595.57 S 53.30 W 0.00 1596.46 T4.1 (Top Cairn) 5571.34 21.96 181. 91 5271.00 1617.73 S 54.04 W 0.00 1618.63 T3.1 (Base Cairn) 5779.43 21. 96 181. 91 5464.00 1695.49 S 56.64 W 0.00 1696.44 T3 (Top Bermuda) 5841. 97 21. 96 181. 91 5522.00 1718.86 S 57.42 W 0.00 1719.82 MW(Y) Midpt TGT RVSD 26 MAR 02 5904.50 21. 96 181.91 5580.00 1742.23 S 58.20 w 0.00 1743.20 T2 (Base Bermuda) 5995.07 21. 96 181. 91 5664.00 1776.07 S 59.33 W 0.00 1777.06 C35 (Top Albian) 6000.00 21. 96 181.91 5668.57 1777.91 S 59.39 W 0.00 1778.90 6204.50 21. 96 181. 91 5858.24 1854.33 S 61. 95 w 0.00 1855.36 TD, Csg Pt. All data is in feet unless otherwise stated. Coordinates from slot #432 and TVD from RKB (Nordic III) (254.00 Ft above mean sea level). Bottom hole distance is 1855.36 on azimuth 181.91 degrees from wellhead. Total Dogleg for wellpath is 21.96 degrees. Vertical section is from wellhead on azimuth 181.91 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL e e Phillips Alaska, Inc. Drill Site 2P, 432 Meltwater,North Slope, Alaska PROP05AL LI5TING Page 2 Your ref 2P-432 Version #2 Last revised : 27-Mar-2002 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 700.00 700.00 0.00 N 0.00 E KOP 1359.82 1354.00 75.61 5 2.53 W Base Permafrost 1797.76 1771.09 207.65 5 6.94 W EOC 1994.97 1954.00 281. 34 5 9.40 W Base Westsak 2423.29 2351.26 441.39 5 14.75 W 7 5/8" C5G 2523.29 2444.00 478.76 5 15.99 W C80 3123.84 3001. 00 703.17 5 23.49 W C50 3405.25 3262.00 808.32 5 27.00 W C40 3588.54 3432.00 876.81 5 29.29 W C37 4772.40 4530.00 1319.19 5 44.07 W T7 5412.04 5123.25 1558.21 5 52.05 W 5 1/2 X 3 1/2 XO 5512.04 5216.00 1595.57 5 53.30 W T4.1 (Top Cairn) 5571.34 5271. 00 1617.73 5 54.04 W T3.1 (Base Cairn) 5779.43 5464.00 1695.49 5 56.64 W T3 (Top Bermuda) 5841.97 5522.00 1718.86 5 57.42 W MW(Y) Midpt TGT RV5D 26 MAR 02 5904.50 5580.00 1742.23 5 58.20 W T2 (Base Bermuda) 5995.07 5664.00 1776.07 5 59.33 W C35 (Top Albian) 6204.50 5858.24 1854.33 5 61. 95 W TD, Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 6204.50 5858.24 O.OOE 2423.29 2351.26 1854.335 441.395 61.95W 3 1/2" C5G 14.75W 7 5/8" C5G Targets associated with this wellpath ------------------------------------- --- - ---- - - - - - - - - - -- - - ------- - - - - - - - -- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(Y) Midpt TGT RV5D 443784.000,5867212.000,999.00 5522.00 1718.865 57.42W 22-Feb-2001 ORIGINAL e e Phillips Alaska, Inc. Drill Site 2P 432 slot *432 Meltwater North Slope, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License 2p-432 Version #2 prop4523 Date printed Date created Last revised 1-Apr-2002 25-Feb-2001 27-Mar-2002 Field is centred 441964.235,5869891. 466.999.00000. N Structure is centred on 441964.235,5869891.466,999.0000Q,N Slot location is n70 3 9.20S,w150 26 57.506 Slot Grid coordinates are N 5868930.205, E 443854.510 Slot local coordinates are 946.92 S 1897.73 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL e e Phillips Alaska, Inc. PROP05AL LI5TING Page 1 Drill Site 2P,432 Your ref 2P-432 Version #2 Mel twater, North Slope, Alaska Last revised : 27-Mar-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID C o 0 R D 5 G E o G RAP H I C Depth Degrees Degrees Depth C 0 0 RDINATE5 Eas t ing Northing C 0 o R DIN A T E 5 0.00 0.00 181. 91 0.00 O.OON o .OOE 443854.51 5868930.21 n70 09.21 w1S0 26 57.51 500.00 0.00 181. 91 500.00 O.OON o .OOE 443854.51 5868930.21 n70 09.21 w150 26 57.51 700.00 0.00 181.91 700.00 O.OON o .OOE 443854.51 5868930.21 n70 09.21 w150 26 57.51 800.00 2.00 181.91 799.98 1. 745 0.06W 443854.44 5868928.46 n70 09.19 w150 26 57.51 900.00 4.00 181.91 899.84 6.975 0.23W 443854.22 5868923.23 n70 09.14 w150 26 57.51 1000.00 6.00 181. 91 999.45 15.685 0.52W 443853.87 5868914.53 n70 09.05 w1S0 26 57.52 1100.00 8.00 181.91 1098.70 27.865 0.93W 443853.37 5868902.35 n70 08.93 w150 26 57.53 1200.00 10.00 181.91 1197.47 43.505 1. 45W 443852.73 5868886.72 n70 08.78 w150 26 57.55 1300.00 12.00 181.91 1295.62 62.575 2.09W 443851.94 5868867.66 n70 08.59 w150 26 57.57 1359.82 13 .20 181.91 1354.00 75.615 2.53W 443851.41 5868854.63 n70 08.46 w150 26 57.58 1400.00 14 .00 181. 91 1393.06 85.055 2.84W 443851. 02 5868845.19 n70 08.37 w150 26 57.59 1500.00 16.00 181. 91 1489.64 110.925 3.71W 443849.96 5868819.33 n70 08.11 w150 26 57.61 1600.00 18.00 181. 91 1585.27 140.135 4.68W 443848.76 5868790.12 n70 07.83 w150 26 57.64 1700.00 20.00 181. 91 1679.82 172.675 5.77W 443847.43 5868757.60 n70 07.51 w150 26 57.67 1797.76 21. 96 181. 91 1771.09 207.655 6.94W 443845.99 5868722.64 n70 07.16 w150 26 57.71 1994.97 21. 96 181. 91 1954.00 281. 345 9.40W 443842.97 5868648.97 n70 3 06.44 wISO 26 57.78 2000.00 21. 96 181. 91 1958.66 283.225 9.46W 443842.89 5868647.09 n70 3 06.42 w1S0 26 57.78 2423.29 21. 96 181. 91 2351.26 441. 395 14.75W 443836.40 5868488.98 n70 3 04.86 w150 26 57.93 2500.00 21. 96 181. 91 2422.40 470.065 15.70w 443835.23 5868460.33 n70 3 04.58 w150 26 57.96 2523.29 21. 96 181.91 2444.00 478.765 15.99W 443834.87 5868451.63 n70 3 04.50 w150 26 57.97 3000.00 21. 96 181. 91 2886.14 656.895 21. 94W 443827.56 5868273.56 n70 02.74 wIS0 26 58.14 3123.84 21. 96 181.91 3001. 00 703.175 23.49W 443825.67 5868227.30 n70 02.29 wIS0 26 58.19 3405.25 21. 96 181.91 3262.00 808.325 27.00W 443821.35 5868122.19 n70 01.26 w150 26 58.29 3500.00 21. 96 181.91 3349.88 843.735 28.19W 443819.90 5868086.80 n70 00.91 w150 26 58.32 3588.54 21. 96 181. 91 3432.00 876.815 29.29W 443818.54 5868053.72 n70 00.58 w150 26 58.36 4000.00 21.96 181. 91 3813.62 1030.575 34.43W 443812.23 5867900.03 n70 2 59.07 w150 26 58.50 4500.00 21. 96 181.91 4277.36 1217.405 40.67W 443804.57 5867713.27 n70 2 57.23 w150 26 58.69 4772.40 21. 96 181. 91 4530.00 1319.195 44.07W 443800.39 5867611.52 n70 2 56.23 w150 26 58.78 5000.00 21. 96 181. 91 4741.09 1404.245 46.91W 443796.91 5867526.50 n70 2 55.39 w1S0 26 58.87 5412.04 21. 96 181. 91 5123.25 1558.215 52.0SW 443790.59 5867372.59 n70 2 53.88 w150 26 59.02 5500.00 21. 96 181. 91 5204.83 1591. 075 53.15W 443789.24 5867339.74 n70 2 53.56 wIS0 26 59.05 5512.04 21. 96 181.91 5216.00 1595.575 53.3 ow 443789.06 5867335.24 n70 2 53.51 w150 26 59.05 5571.34 21. 96 181.91 5271.00 1617.735 54.04W 443788.15 5867313.09 n70 2 53.29 w150 26 59.07 5779.43 21. 96 181. 91 5464.00 1695.495 56.64W 443784.96 5867235.36 n70 2 52.53 w150 26 59.15 5841.97 21. 96 181. 91 5522.00 1718.865 57 .42W 443784.00 5867212.00 n70 2 52.30 w1S0 26 59.17 5904.50 21. 96 181. 91 5580.00 1742.235 58.20W 443783.04 5867188.64 n70 52.07 w150 26 59.19 5995.07 21. 96 181. 91 5664.00 1776.075 59.33W 443781. 65 5867154.81 n70 51. 74 w150 26 59.23 6000.00 21. 96 181. 91 5668.57 1777.915 59.39W 443781. 58 5867152.97 n70 51. 72 w150 26 59.23 6204.50 21. 96 181.91 5858.24 1854.335 61. 95W 443778.44 5867076.58 n70 50.97 w150 26 59.30 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot *432 and TVD from RKB (Nordic III) (254.00 Ft above mean sea level). Bottom hole distance is 1855.36 on azimuth 181.91 degrees from wellhead. Total Dogleg for wellpath is 21.96 degrees. Vertical section is from wellhead on azimuth 181.91 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes IWEQ ORIGINAL e e Phillips Alaska, Inc. Drill Site 2P. 432 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 2P-432 Version #2 Last revised : 27-Mar-20Q2 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 700.00 700.00 O.OON o .OOE KOP 1359.82 1354.00 75.61S 2.53W Base Perrnafrost 1797.76 1771.09 207.65S 6.94W Eoe 1994.97 1954.00 281. 34S 9.40W Base Westsak 2423.29 2351.26 441.39S 14.75W 7 5/8" eSG 2523.29 2444.00 478.76S 15.99W e80 3123.84 3001. 00 703.17S 23.49W e50 3405.25 3262.00 808.32S 27.00W e40 3588.54 3432.00 876.81S 29.29W e37 4772.40 4530.00 1319.19S 44.07W T7 5412.04 5123.25 1558.21S 52.05W 5 1/2 X 3 1/2 XO 5512.04 5216.00 1595.57S 53 .3 OW T4.1 (Top Cairn) 5571.34 5271.00 1617.73S 54.04W T3.1 (Base Cairn) 5779.43 5464.00 1695.49S 56.64W T3 (Top Bermuda) 5841.97 5522.00 1718.86S 57.42W MW(Y) Midpt TGT RVSD 26 MAR 02 5904.50 5580.00 1742.23S 58.20W T2 (Base Bermuda) 5995.07 5664.00 1776.07S 59.33W e35 (Top Albian) 6204.50 5858.24 1854.33S 61. 95W TD, Csg Pt. Casing positions in string 'A' - - - - - ------ - - - - - -------- - - - - -- ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 6204.50 5858.24 O.OOE 2423.29 2351.26 1854.33S 441. 39S 61. 95W 3 1/2' eSG 14.75W 7 5/8" eSG Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MWIY) Midpt TGT RVSD 443784.000,5867212.000,999.00 5522.00 1718.86S 57.42W 22-Feb-2001 ORIGI¡VAL e Phillips Alaska, Inc. Drill Site 2P 432 slot #432 Meltwater North Slope, Alaska e by Baker Hughes INTEQ SUM MAR Y C LEA RAN C ERE P 0 R T Your ref 2P-432 Version #2 Our ref prop4523 License Date printed 1-Apr-2002 Date created 25-Feb-2001 Last revised 27-Mar-2002 Field is centred on 441964.235,5869891.466.999.00000.N Stru;cture is centred on 441964.235,5869891.466,999. OOOOO,N Slot location is n70 3 9.205,w150 26 57.506 Slot Grid coordinates are N 5868930.205, E 443854.510 Slot local coordinates are 946.92 S 1897.73 E Reference North is True North Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance Sperry Sun MWD 4052-7593'MDl1/13/2), ,448A,Dril 20-Feb-2002 319.7 Sperry Sun MWD 0-755 'MDI12/23/01).. 448,Drill S 20-Feb-2002 319.7 MWD <0-2040'>, ,448.Drill Site 2P 28-Dec-2001 319.7 Sperry Sun MWD 848-8663 'MDI1/7 /2) ,,448, Drill S 20-Feb-2002 319.7 MWD <0 - 6008 '>..417 ,Drill Site 2P 25-May-2001 300.0 MWD <0-6860' >, ,420, Drill Site 2P 14-Jan-2002 240.1 MWD <3660 - 1l075'>,,415,Drill Site 2P 2-Dec-2001 339.7 MWD <5552 - 9038' >" 415A, Drill Site 2P 17-Dec-2001 339.7 MWD <0-8853 '>, ,422, Drill Site 2P Il-Mar-2002 199.7 MWD <0-8974'>, ,429,Drill Site 2P 27-Feb-2002 60.1 MWD <0-9224' >" 438. Drill Site 2P 4-Jun-2001 120.1 MWD <0-5950'>, ,45l,Drill Site 2P ll-Mar-2002 379.7 MWD <0 - 8848' >Depth Shifted" 422A, Drill Site 5-Mar-2002 199.7 MWD <0 - 7>, ,431,Drill Site 2P 1-Apr-2002 17.9 MWD <0 - 7327'>,,441,Drill Site 2P 1-Apr-2002 175.6 PMSS <0-6122 '>, ,MWN#1,Meltwater North #1 26-Feb-2001 4812.2 PMSS <0-6300'>"MWN#2,Meltwater North #2 26-Feb-2001 3106.9 PMSS <2212-7349'>, ,MWN#2A.Me1twater North #2 26-Feb-2001 2476.2 PMSS <0-8935 I >, , MWSouth1 ,Meltwater South #1 6-Mar-2001 45148.8 ORIGI¡VAL M.D. 20.0 20.0 20.0 20.0 0.0 180.0 240.0 240.0 320.0 80.0 100,0 240.0 320.0 440.0 962.5 6204.5 4940.0 4680.0 6204.5 Diverging from M.D. 20.0 20.0 20.0 20.0 712.5 180.0 240.0 240.0 320.0 80.0 100.0 240.0 320.0 440.0 962.5 6204.5 4940.0 4680.0 6204.5 e e Phillips Alaska, Inc. Drill Site 2P 432 slot #432 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref Our ref License 2P-432 Version #2 prop4523 Date printed Date created Last revised l-Apr-2002 25-Feb-200l 27-Mar-20Q2 Field is centred on 441964.235.5869891.466,999.00000, N Structure is centred 441964.235,5869891.466,999.00000,N Slot location is n7D 3 9.205,w150 26 57.506 Slot Grid coordinates are N 5868930.205, E 443854.510 Slot local coordinates are 946.92 S 1897.73 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORJG¡J~AL e e Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P, 432 Your ref 2P-432 Version n Meltwater,North Slope, Alaska Last revised , 27-Mar-2002 Measured Inclin. Az imu th True Vert R E C TANGU LA R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C 0 0 R DIN A T E S Sect Major Minor Vert. Azi. 0.00 0.00 181. 91 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 500.00 0.00 181. 91 500.00 0.00 N 0.00 E 0.00 1.31 1. 31 0.75 N/A 700.00 0.00 181. 91 700.00 0.00 N 0.00 E 0.00 1.83 1. 83 1.05 N/A 800.00 2.00 181. 91 799.98 1. 74 S 0.06 w 1. 75 2.09 2.09 1.20 N/A 900.00 4.00 181. 91 899.84 6.97 S 0.23 w 6.98 2.38 2.35 1.35 1.91 1000.00 6.00 181. 91 999.45 15.68 S 0.52 W 15.69 2.71 2.62 1.50 1.91 1100.00 8.00 181. 91 1098.70 27.86 S 0.93 W 27.88 3.12 2.89 1.65 1.91 1200.00 10.00 181.91 1197.47 43.50 S 1.45 W 43.52 3.62 3.18 1.81 1.91 1300.00 12.00 181.91 1295.62 62.57 S 2.09 W 62.60 4.24 3.47 1.97 1.91 1359.82 13 .20 181.91 1354.00 75.61 S 2.53 W 75.65 4.69 3.66 2.06 1.91 1400.00 14.00 181. 91 1393.06 85.05 S 2.84 w 85.10 4.99 3.79 2.13 1.91 1500.00 16.00 181. 91 1489.64 110.92 S 3.71 W 110.98 5.86 4.11 2.29 1.91 1600.00 18.00 181. 91 1585.27 140.13 S 4.68 W 140.21 6.85 4.46 2.47 1.91 1700.00 20.00 181. 91 1679.82 172.67 S 5.77 W 172.77 7.98 4.82 2.65 1.91 1797.76 21. 96 181.91 1771.09 207.65 S 6.94 W 207.76 9.19 5.20 2.84 1.91 1994.97 21. 96 181. 91 1954.00 281. 34 S 9.40 W 281. 50 11.70 5.98 3.24 1.91 2000.00 21. 96 181. 91 1958.66 283.22 S 9.46 W 283.38 11.77 6.00 3.25 1.91 2423.29 21. 96 181.91 2351.26 441.39 S 14.75 W 441. 64 17.28 7.74 4.14 1.91 2500.00 21. 96 181. 91 2422.40 470.06 S 15.70 W 470.32 18.28 8.06 4.30 1.91 2523.29 21. 96 181. 91 2444.00 478.76 S 15.99 W 479.02 18.58 8.16 4.35 1.91 3000.00 21.96 181. 91 2886.14 656.89 S 21. 94 W 657.26 24.86 10.18 5.38 1.91 3123.84 21. 96 181. 91 3001.00 703.17 S 23.49 W 703.56 26.50 10.71 5.65 1.91 3405.25 21. 96 181. 91 3262.00 808.32 S 27.00 W 808.77 30.23 11.92 6.27 1.91 3500.00 21. 96 181. 91 3349.88 843.73 S 28.19 w 844.20 31.48 12.32 6.47 1.91 3588.54 21.96 181. 91 3432.00 876.81 S 29.29 W 877.30 32.65 12.71 6.67 1.91 4000.00 21. 96 181. 91 3813.62 1030.57 S 34.43 w 1031.14 38.11 14.48 7.57 1.91 4500.00 21. 96 181.91 4277.36 1217.40 S 40.67 W 1218.08 44.75 16.66 8.68 1.91 4772.40 21. 96 181. 91 4530.00 1319.19 S 44.07 W 1319.93 48.37 17.84 9.29 1.91 5000.00 21.96 181.91 4741.09 1404.24 S 46.91 W 1405.02 51. 39 18.84 9.79 1.91 5412.04 21. 96 181. 91 5123.25 1558.21 S 52.05 W 1559.07 56.87 20.64 10.71 1.91 5500.00 21. 96 181. 91 5204.83 1591.07 S 53.15 W 1591. 96 58.04 21. 02 10.90 1.91 5512.04 21. 96 181. 91 5216.00 1595.57 S 53.30 w 1596.46 58.20 21. 07 10.93 1.91 5571.34 21. 96 181. 91 5271.00 1617.73 S 54.04 W 1618.63 58.98 21.33 11.06 1.91 5779.43 21. 96 181. 91 5464.00 1695.49 S 56.64 W 1696.44 61. 75 22.24 11.53 1.91 5841.97 21. 96 181. 91 5522.00 1718.86 S 57.42 W 1719.82 62.58 22.51 11.67 1.91 5904.50 21. 96 181. 91 5580.00 1742.23 S 58.20 W 1743.20 63.41 22.79 11.81 1.91 5995.07 21. 96 181.91 5664.00 1776.07 S 59.33 W 1777.06 64.62 23.18 12.01 1.91 6000.00 21. 96 181. 91 5668.57 1777.91 S 59.39 W 1778.90 64.68 23.21 12.02 1. 91 6204.50 21. 96 181. 91 5858.24 1854.33 S 61. 95 W 1855.36 67.40 24.10 12.47 1.91 All data is in feet unless otherwise stated. Coordinates from slot #432 and TVD from RKB (Nordic III) (254.00 Ft above mean sea level). Bottom hole distance is 1855.36 on azimuth 181.91 degrees from wellhead. Vertical section is from wellhead on azimuth 181.91 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ OHI '\~ 11\ 1 "L " f ~ ¡ .J u llvA e e Phillips Alaska, Inc. Drill Site 2P ,432 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 2P-432 Version #2 Last revised : 27-Mar-2002 P05ITION UNCERTAINTY 5UMMARY ------------------------------ ------------------------------ Depth From To Survey Too 1 Error Model position Uncertainty Major Minor Vert. ---------------------------------------------------------------------------------------------------- 6205 ARCO (H.A) Mag) User specified 67.40 24.10 12.47 1. Ellipse dimensions are half axis . 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 700.00 700.00 0.00 N 0.00 E KOP 1359.82 1354.00 75.61 5 2.53 W Base Permafrost 1797.76 1771. 09 207.65 5 6.94 W EOC 1994.97 1954.00 281. 34 5 9.40 W Base Westsak 2423.29 2351.26 441.39 5 14.75 W 7 5/8" C5G 2523.29 2444.00 478.76 5 15.99 W C80 3123.84 3001.00 703.17 5 23.49 W C50 3405.25 3262.00 808.32 5 27.00 W C40 3588.54 3432.00 876.81 5 29.29 W C37 4772.40 4530.00 1319.19 5 44.07 W T7 5412.04 5123.25 1558.21 5 52.05 W 5 1/2 X 3 1/2 XO 5512.04 5216.00 1595.57 5 53.30 W T4.1 (Top Cairn) 5571.34 5271.00 1617.73 5 54.04 W T3.1 (Base Cairn) 5779.43 5464.00 1695.49 5 56.64 W T3 (Top Bermuda) 5841. 97 5522.00 1718.86 5 57.42 W MW(Y) Midpt TGT RVSD 26 MAR 02 5904.50 5580.00 1742.23 5 58.20 W T2 (Base Bermuda) 5995.07 5664.00 1776.07 5 59.33 W C35 (Top Albian) 6204.50 5858.24 1854.33 5 61. 95 W TD, Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Cas ing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 6204.50 5858.24 O.OOE 2423.29 2351.26 1854.335 441.395 61. 95W 3 1/2" C5G 14.75W 7 5/8" C5G Targets associated with this wellpath ------------------------------------- -- - ------ - - - - - - - - - - - - - -- - - - - - - - - - - - -- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(Y) Midpt TGT RV5D 443784.000,5867212.000,999.00 5522.00 1718.865 57.42W 22-Feb-2001 ORIGIiVAL e e 2P-432 DrillinQ Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) Surface Casina Interval Event Risk Level Mitiaation Strateav Tight hole / Packoff problems Moderate Revised BHA design, good hole cleaning practices, new surface mud desiqn - LSNO. Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Careful well planning and surveying, adherence to anti-collision policy Gravel and sand sloughing Low Elevated mud viscosity from spud; Hi dens sweeps. Shakerrrrough Cuttings Low Controlled ROP System Overflow Permafrost Hydrates Low Controlled drilling, reduced pump rates, higher mud weights, cold mix water and mud, lower viscosities, and lecithin additions as needed. Shoe Fracture/Lost Returns Low Reduced pump rates, and lightweight tail cement during cement job Production Casina Interval Interval Risks Event Risk Level Mitigation Strategy Gas kick in the C37 interval. Moderate Kick drills, careful monitorinq of pit levels. Lost Circulation High Good drilling practices. LCM, InstanSEAL as needed. Stay within ECO hardlines High ECO and swabbing if High Pumping and rotating out on all trips to reduce swab higher MW is required and barite sag potential. Keep hole mud system as clean as possible. Bring pumps on slowly. RIH slowly to avoid surqe. Tight hole / Packott problems Moderate Revised BHA design, good hole cleaning practices ORIGIJVAL 2P-432 Drilling Hazards Summary. doc prepared by Pat Reilly 04/10/02 Page 1 of 1 Meltwater 2P-a Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String 16" 62.6# @ +1-110' MD Port Collar 1000' MD Depths are based on Doyon 141 RKB Surface csg. 7-5/8" 29.7# L-80 BTCM +1- 2423' MD 12351' TVD 12' Pup (Critical) Intermediate csg. 5-1/2" 15.5# L-80 BTCM run CSR to surface +1- 5412' MD 15123 TVD Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD TD to CSR +1- 6204' MD I 5858' TVD PHltllPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Cameo 'DS' nipple wI 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +1- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Cameo 'KBG-2-9' mandrel wI DCK-3 shear valve and bottom latch (Max. OD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Cameo No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 3-1/2" Camco 'D' nipple wI 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" OD x 4" ID 17' Seal Bore Extension CSR set at +1- 100' MD above the top of the Bermuda (OR 100' MD ABOVE THE TOP OF THE CAIRN IF THE CAIRN IS PRESENT) ORIGINAL PJR,4/10/02 Rig: Nordic 3 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 4/5/2002 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com < TOC at Surface Pre\ñous Csg. < 16", 62.6#, H-40 grade Welded Connection at 120 ft. MD < Base of Permafrost at 1,360 ft. MD (1,354 ft. lVD) < Top of Tail at 1,380 ft. MD < 75/8",29.7#, L-80 grade BTC, AB Modified in 9 718" OH TO at 2,423 ft. MD (2,351 ft. lVD) Mark of Schlumberger . . 2 P-432 Cell'. ¿t~ðY:-''''Ÿe{,')ý1I·..rð.·,,~Wfl;JÒ~'él3Y9·'''''-'''' .::. , 0] s/8"Surface . . ... . Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Svstems (Volumes are based on 450% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 20' below base of permafrost.) Lead Slurrv (minimum pump time 173 min.) AS Lite @ 10.7 pp~, Class G + 50%0124,9%044,0.4%046,30%053, 1.5%S1, 1.5%079 - 4.28 ft Isk 0.9513 fe/ft x (120') x 1.00 (no excess) = 0.2148 fe/ft x (1360' - 120') x 5.50 (450% excess) = 0.2148 fe/ft x (1380' - 1360') x 1.45 (45% excess) = 114.2 fe + 1464.9 ft3 + 6.2 fe = 1585.3 fe I 4.28 ft%k = Round up to 380 sks 114.2 fe 1464.9 fe 6.2 fe 1585.3 ft3 370.4 sks Have 280 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv (minimum pump time 125 min.) LiteCRETE @ 12.0 ppg - 2.40 fe/sk 0.2148 fe/ft x (2423' -1380') x 1.45 (45% excess) = 0.2578 fe/ft x 80' (Shoe Joint) = 324.9 fe + 20.6 fe = 345.5 fel 2.40 fe/sk = Round up to 150 sks 324.9 fe 20.6 fe 345.5 fe 144 sks BHST = 54°F, Estimated BHCT = 80°F. (BHST calculated using a gradient of 2.2°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 6 40 6.7 6.7 Orop Bottom Plug 3.0 9.7 MudPUSH XL 6 40 6.7 16.4 Lead Slurry 6 290 48.3 64.7 Tail Slurry 6 64 10.7 75.4 Orop Top Plug 3.0 78.4 Oisplacement 6 88 14.7 93.1 Bump Plug 3 20 6.7 99.8 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv'" 17-20, Ty'" 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Rig: Nordic 3 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 4/5/2002 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Pre-.10us Csg. < 75/8",29.7#, L-80 grade BTC, AB Modified at 2,423 ft. MD < 51/2", 15.5#, L-80 grade BTC, AB Modified in 6 3/4" OH < Top of Tail at 4,912 ft. MD < X-o\A3rat 5,412 ft. MD < Top of Bermuda Fm. at 5,779 ft. MD < 31/2", 9.3#, L-80 grade EUE, 8re1 Modified in 6 3/4" OH 1D at 6,205 ft. MD (5,858 ft. lVD) Mark of Schlumberger 2 P-432 Cell .<A··DE* 13r...¡I;:,T¡¡¡;:(iiit.......·Iii¡¡~I,a.I"';;.;O,"',"""J...1i!:IIit~ ' I", I .."''-'III.'....I~ u..... J'""""'OO~... .~v""".~. t" :: 5 1/2" x 3 1/2'" Production Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Svstems (Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing X-over. Tail Slurrv (minimum thickening time 136 min.) GasBLOK wi Class G + D53, D600, D135, D800, D047, D065, per lab testing @ 15.8 ppg, 1.2 ft3/sk 0.0835 fe/ft x 500' x 1.75 (75% excess) = 0.1817 fe/ft x (6205' - 5412') x 1.75 (75% excess) = 0.0488 fe/ft x 90' (Shoe Joint) = 73.1 fe + 252.2 fe + 4.4 fe = 329.7 fel 1.2 felsk = Round up to 280 sks 73.1 ft3 252.2 fe 4.4 fe 329.7 fe 274.8 sks BHST = 131°F, Estimated BHCT = 112°F. (BHST calculated using a gradient of 2.2°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bb ) (min) CW100 5 50 10.0 10.0 MudPUSH XL 5 40 8.0 18.0 Tail Slurry 5 60 12.0 30.0 Drop Top Plug 3.0 33.0 Displacement 5 75 15.0 48.0 Slow Rate 4 50 12.5 60.5 Bump Plug 3 10 3.3 63.8 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* XL, Pv"" 19-22, T y "" 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. OR/GI/VAL PHILLI. Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY e Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 April 1 0, 2002 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 2P-432 Surface Location: Target Location: Bottom Hole Location: 948'FNL, 1894' FWL,Sec. 17,T8N,R7E 2637'FSL, 1832' FWL,Sec. 17, T8N, R7E 2478'FSL, 1826' FWL, Sec. 17,T8N, R7E Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development injector KRU 2P-432. The well will be drilled and completed using Nordic 3. Please utilize documents on file for this rig. Logs anticipated to be run on this well include real time Gamma Ray in the surface hole and real time GR/Res, Den/Neutron in the production hole. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2P, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Steve Moothart, Geologist 265-6965 If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048. Sincerely, K~~ Randy Thomas Kuparuk Drilling Team Leader RECEIVED APR 1 0 ¡I AlllkaÐitIGasCons. Commis..~( AndIorage ORIGINAL PHIL.L.IPS AL.ASKA, INC. PAl PAYABLES P.O.Bpx 102776 AnchÖrage, AK 99510-2776 73-426/839 CHECK NUMBER 2051 12610 0997579 STATE OF ALASKA AOGCC 333 W. 7TH AVENUE, SUITE 100 MARCH 08, 2002 PAY TO THE ... VOID AFTER 90 DAYS ... . ."..... EXACTLY********** 100 DOLLARS AND 00 CENTS $******** 100.00 BANK =ONB. - ~~ BANK ONE, NA - 0710 9~içago, I L Pa~able throu!;r. ,.,""" ",,' . """ 00""'''' ¿¿:: e TRACE NUMBER: 205112610 ,QP"~3¡;L 11'205. . 2 b .011' 1:08 :ì gO L.. 2 b 21: o g g 7 5 7 9 III Rl:CE/~D API? 1 0 ~Q7.GasI'-^oo- ~~ e -- -- TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LEITER WELL NAME~.(k 2P'" 0/3 L CHECK 1 CHECK WHAT APPLIES STANDARD LEITER ADD~NS(OPTION~ "CLUE" DEVELOPMENT MULTI LATERAL The permit is for a new wellbore segment of existing weD ~ Permit No, API No. . (If api number last two (2) Production should continue to be reported as a function .of digits are between 60-69) the original API number stated above. DEVELOPMENT P~OT HOLE (PH) In accordance with 20 AAC 25.005(f), aU records, data and REDRlLL logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70180) from records, data and logs acquired for well (name on permit). EXPLORATION ANNULAR DISPOSAL Annular disposal has not been requested. . . L-JNO INJECTION WELL AN~AL Annular Disposal of drilling wastes will not be approved. . . V INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . REDRlLL THIS WELL DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS ¿YES + SPACING EXCEPTION Enclosed Is the approved application for permit to, drill the above referenced well. The permit is approved . subJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY FIELD & POOL 7'C?o/c.¡Ö ADMINISTRATION 1. Permit fee attached. . . . . . . .. .......... 2. Lease number appropriate. . . . . . .. .......... 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided . . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations . . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to 3 ¿'I(,') Cì psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued wlo hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . R .I~TJl 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . ~ 34. Contact namelphone for weekly progress reports [exploratory on/ ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. GEOLOGY: ENGINEERING: UIC/Annular: COMMISSIO :~ :::/SJl'-l1 \<¡;g~~04j'-lIÚ "z... C"¡MH .. ',~,,"~ ""...........-..--> APPR /~"9= 4!L- ~ ENGINEERING APPR Dr T~ \¡..]c;k- 4 I" "J L. ~ 't({~ GEOLOGY APPR DATE f/!L ~Z- -- G:\geology\templates\checklist. doc PROGRAM: Exp GEOL AREA Dev ?,YO N N N N N N N N N N , ¡(PIt Q I( O. N <ØI j ~ N.o,,k ! -¥-tr Air It- t ' N cf (7 ç"s. Pv¡Jpr oruL.. N N N N MSP :: 2-2"52. ~~/, N N yæ Y N Y Y 'TBR- ' Redrll Serv UNIT# Well bore seg ///bÒ {7,,,/ j e (/'10 \ . . k' CS-i "l -:. ?""C;OO p r..:.. Comments/Instructions: Ann. disposal para req ON/OFF SHORE e e 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 fìnding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . **** REEL HEADER **** LDWG 04/01/26 AWS 01 **** TAPE HEADER **** LDWG 04/01/26 01 *** LIS COMMENT RECORD *** . 8ð d -0°1 \. RECEIVED J/\H 2 7 2004 AJaskaOiI&GasCons,CommiIaIon AncMtage )d-.- ')37 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER MELTWATER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 G. SUTING D. GLADDEN MWD RUN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 12.250 8.500 6.125 4.750 2P-432 501032042000 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 26-JAN-04 MWD RUN 2 2 E. AGUIRRE D. GLADDEN MWD RUN 17 8N 7E 252.00 224.00 CASING SIZE (IN) 9.625 7.000 5.500 MWD RUN MWD RUN DRILLERS DEPTH (FT) 2449.0 5602.0 5762.0 6043.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR '"\~-~~Ù\w T~LIVERY FROM THE WELL SITE. 4IIÞ SURFACE LOCATION: LAT: N 70 DEG 03' 9.205" LONG: W150 DEG 26' 57.506" LOG MEASURED FROM D.F. AT 252.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized Multiple Propagation Resistivity (MPR) and Gamma Ray services from 108 - 2454 feet MD (108 - 2377 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 Drill Collar Pressure (DCP) and MPR Resistivity services from 2454 - 5613 feet MD (2377 - 5307 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) Depth of 9 5/8" Casing Shoe - Logger: 2447 feet MD (2370 TVD) Depth of 9 5/8" Casing Shoe - Driller: 2449 feet MD (2372 TVD) (2) The interval from 5450 to 5500 feet MD (5155 - 5202 TVD) was logged up to 13.5 hours after being drilled due to well control problems. (3) The interval from 5613 to 6043 feet MD (5307 - 5710 TVD) was drilled without LWD tools in the hole. No logging was performed. (4) Depth of 7" Casing Shoe - Driller: 5602 feet MD (5297 TVD) (5) Depth of 5 1/2" Casing Shoe - Driller: 5760 feet MD (5422 TVD) (6) The interval from 5545 to 5613 feet MD (5244 - 5307 TVD) was not logged due to sensor-bit offset at the end of MWD run 2. $ Tape Subfile: 1 88 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 294.0 STOP DEPTH 5613.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ . DATA SOURCE TOOL CODE . BIT RUN NO 1 2 MERGE TOP 294.0 2407.0 MERGE BASE 2407.0 5613.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. Neutron and Density tools were only used on Run 2 and therefore contain null data above 2407' MD. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 2p432_5.xtf 150 ConocoPhillips Alaska, Inc. 2P-432 Kuparuk River 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 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 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 . 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: 560 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 294.000000 5613.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 610 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: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 1 .2500 START DEPTH 294.0 STOP DEPTH 2407.0 # 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: 01-NOV-03 MSB 18655 8.25 MPR MEMORY 2454.0 294.0 2407.0 o .0 22.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY TOOL NUMBER DAS 7158 MPR 8028 SRIG 58017 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 108.0 # BOREHOLE CON~ONS 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): # LS. 8.85 .0 .0 150 .0 .000 .000 .000 .000 78.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1 (MWD Run 1). GR/MPR. 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) 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) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 2p432.xtf 150 ConocoPhi11ips Alaska, I 2P-432 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH TCDM GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS RPTH TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 GRAM RPD RPM RPS RPX RAD RACSLM RAS RACSHM ROPS RPTHM TCDM * 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: 0.250000 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 = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 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 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 445 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 294.000000 2407.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 544 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!! ! !! !!!!!! ! ! !!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 3 log header data for each bit run in separate files. 2 .2500 START DEPTH STOP DEPTH MWD $ . 2407.0 5613.0 # 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: # 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: . 05-NOV-03 MSB 18655 6.75 TC MEMORY 5613.0 2407.0 5613.0 o 20.0 23.5 TOOL NUMBER DHA 99020 CCN 71630 ORD 12103 MPR 6245 SRIG 92230 8.500 2449.0 LSND 9.60 .0 .0 150 .0 .000 .000 .000 .000 112.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1 (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 -------------------------------- WDFN LCC CN WN FN COUN STAT 2p432.xtf 150 ConocoPhillips Alaska, I 2P-432 Kuparuk River 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 GAP I 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 .,. , '\... 16 . DEGF 1 TCDM MWD Total Data Records: 917 Tape File start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2407.000000 5613.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1027 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/01/26 01 **** REEL TRAILER **** LDWG 04/01/26 AWS 01 Tape Sub file: 5 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes 4 ------- 4 . 64
