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201-069
2025-0715_Location_Clear_KRU_2P-417_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: Location Clearance Petroleum Inspector KRU 2P-417 ConocoPhillips Alaska LLC. PTD 2010690; Sundry 324-147 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-417 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 5 feet 5 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 13:57:01 -08'00' 2025-0715_Location_Clear_KRU_2P-417_ksj Page 2 of 2 Location Clearance Inspection – KRU 2P-417 (PTD 2010690) 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: 225' 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' 9.625" L-80 2381' 7" L-80 5289' 4.5" L-80 5989' 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 Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: 51 bbls 15.8 ppg Class G Cement Surface-2108' Cement cap 15.8 ppg cement observed at surface Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 3700-4950' 5412-5465' ABANDONED 5495-5515' MD and 5482-5502' TVD (below cement plug) Gas-Oil Ratio:Choke Size: 16 gal Cement on top of CBIP @5465' Per 20 AAC 25.283 (i)(2) attach electronic information 2108-2440' 25 bbl 15.8 ppg Cement 26# 6002' Surface 5289' 62.5# 40# 108' Surface 5302' SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 42" 12.25" 9 cu yds High Early Surface 380 sx AS3 Lite, 190 sx LiteCRETE 12.6# Surface 5302' 2382'Surface Surface CASING WT. PER FT.GRADE 5/13/2001 CEMENTING RECORD 5869000 1455' MD/ 1455' TVD SETTING DEPTH TVD 5869010 TOP HOLE SIZE AMOUNT PULLED 444211 444340 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 Kuparuk River Field/ Meltwater Oil Pool - Abandoned BOTTOM 50-103-20375-00-00 KRU 2P-417 ADL0373112 878' FNL, 2187' FWL, Sec. 17, T8N, R7E, UM 863' FNL, 2899' FEL, Sec. 17, T8N, R7E, UM ALK 4998 4/27/2001 6008' MD/ 5995' TVD Surface/ Surface P.O. Box 100360, Anchorage, AK 99510-0360 444147 5868998 875' FNL, 2251' FWL, Sec. 17, T8N, R7E, UM 9. Ref Elevations: KB: 27.5' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 3/22/2025 201-069/ 324-147/ 324-711 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above8.5" TUBING RECORD 420 sx Class G8.5" 5305'4.5" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 10:28 am, Apr 08, 2025 Abandoned 3/22/2025 JSB RBDMS JSB 041125 xGVTL 7/30/2025 DSR-4/17/25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1455' 1455' 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: 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. 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 N/A - Abandoned INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Authorized Title: 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. 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 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 am the author of this document Location: Date: 2025.04.08 09:45:59-08'00' Foxit PDF Editor Version: 13.1.6 g Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 5,412.0 2P-417 3/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FINAL P&A - AOGCC Rep Sully Sullivan witnessed and approved 2P-417 3/21/2025 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: AOGCC Rep Sully Sullivan witnessed and approved the TOC and Marker Plate. 3/21/2025 pproven NOTE: Final depth is 5' 5" below tundra. NES welder welded the Marker Plate to the well stub. 3/21/2025 pproven NOTE: CUT AND REMOVE WELL STUB (COMPLETE REMOVED 8.5' OF WELL) 3/20/2025 pproven NOTE: PREP- CONTINUED EXCAVATION TO 10', TD 14' (IN PROGRESS). 3/17/2025 pproven NOTE: CUT & REMOVED WELL HEAD (COMPLETE 66" (5'-6")' BELOW THE 8' TO TUNDRA MARK) 3/15/2025 pproven 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 42.7 107.5 107.5 62.50 H-40 WELDED SURFACE 9 5/8 8.83 42.7 2,381.7 2,380.3 40.00 L-80 BTC-ABM PRODUCTION 7"x4.5" @ 5325" 7 6.28 2,434.0 6,002.2 5,989.6 26.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 42.6 Set Depth … 2,102.1 Set Depth … 2,102.0 String Max No… 4 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 2,097.2 2,097.0 2.06 Shoe - Mule 4.500 4 1/2" 12.6 ppf, L-80 IBT Tubing Mule Shoe 3.958 Top (ftKB) 2,650.0 Set Depth … 5,305.4 Set Depth … 5,292.8 String Max No… 4 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 3,603.0 3,590.7 3.49 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 4,573.0 4,560.4 0.50 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,127.8 5,115.2 0.43 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,179.0 5,166.4 0.35 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,230.1 5,217.5 0.35 SLEEVE 5.625 SLIDING SLEEVE w/NO GO CAMCO PROFILE BAKER CMU 3.810 5,256.8 5,244.2 0.35 NIPPLE 5.000 NIPPLE w/NO GO PROFILE CAMCO DB-6 3.750 5,302.6 5,290.0 0.28 LOCATOR 5.125 BAKER LOCATOR BAKER 3.875 5,303.4 5,290.8 0.28 SEAL 4.000 BAKER 80-40 SEAL ASSY BAKER 80-40 3.875 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) 42.7 42.6 0.20 MARKER PLATE 30" Marker plate 1/4" thick 3/21/2025 0.000 2,434.0 2,432.0 8.73 CUT MSC on rig 2/25/2025 6.200 2,440.0 2,437.9 8.77 CIBP Set CIBP on rig 2/25/2025 0.000 2,650.0 2,645.5 8.59 CUT WELLTEC MECHANICAL TBG CUT AT 2650' RKB 4/3/2024 3.958 5,200.0 5,187.4 0.35 TUBING PUNCH 3' TUBING PUNCH, 2", 7 GRAM, 18 0.61" HOLES OWEN 3/25/2024 3.958 5,465.0 5,452.4 0.26 PLUG Set TTS CIBP 10/7/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 2P- 417 12/14/2001 6.0 IPERF 3.38" HSD Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,495.0 5,515.0 1 FRAC 12/14/2001 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 42.7 2,382.0 42.7 2,380.5 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 10Drag up (lbs): 20Time started reciprocating: 02:00Time stopped reciprocating: 06:31Cement Found Between Shoe and Collar (Y/N): NCement found on liner tool (Y/N): NAnnular flow after cement job (Y/N): N 5,412.0 5,465.0 5,399.4 5,452.4 Cement Plug Dump bailed cement with Slickline on top of CIBP 12/17/2023 3,700.0 4,950.0 3,687.6 4,937.4 Intermediate String 1 Cement PUMPED 51 BBLS OF 15.8 PPG CLSS G CEMENT FOR INTERMEDIATE BALANCED PLUG. 3/30/2024 2,108.0 2,440.0 2,107.9 2,437.9 Cement Plug 07:23 - Cement Wet - Pump 22 bbls of 10# spacer @ 3 bpm, 240 psi Drop 6" ball. Pump 25bbls of 15.8# Cement @ 3.5 bpm, 630 psi. Drop 6" ball. Pump 6 bbls 10# tail @ 3 bpm, 285 psi Displace w/ 22.8 bbls 10# NaCl @3 BPM , 325 PSI. Shut down pump no flow. 3/1/2025 42.7 2,108.0 42.7 2,107.9 Cement Cap 15.8# cement observed at surface 3/3/2025 2P-417, 4/7/2025 1:36:49 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 5325"; 2,434.0-6,002.2 IPERF; 5,495.0-5,515.0 FRAC; 5,495.0 PLUG; 5,465.0 Cement Plug; 5,412.0 ftKB TUBING PUNCH; 5,200.0 GAS LIFT; 5,179.0 GAS LIFT; 5,127.8 GAS LIFT; 4,573.0 Intermediate String 1 Cement; 3,700.0 ftKB GAS LIFT; 3,603.0 CUT; 2,650.0 CIBP; 2,440.0 CUT; 2,434.0 SURFACE; 42.7-2,381.7 Cement Plug; 2,108.0 ftKB Cement Casing; 42.7 ftKB CONDUCTOR; 42.7-107.5 MARKER PLATE; 42.6 Cement Cap; 42.7 ftKB KUP PROD KB-Grd (ft) 37.20 RR Date 5/15/2001 Other Elev… 2P-417 ... TD Act Btm (ftKB) 6,008.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037500 Wellbore Status PROD Max Angle & MD Incl (°) 8.79 MD (ftKB) 2,442.68 WELLNAME WELLBORE2P-417 Annotation Last WO: End DateH2S (ppm) 40 Date 11/2/2014 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 5,412.0 2P-417 3/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FINAL P&A - AOGCC Rep Sully Sullivan witnessed and approved 2P-417 3/21/2025 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: AOGCC Rep Sully Sullivan witnessed and approved the TOC and Marker Plate. 3/21/2025 pproven NOTE: Final depth is 5' 5" below tundra. NES welder welded the Marker Plate to the well stub. 3/21/2025 pproven NOTE: CUT AND REMOVE WELL STUB (COMPLETE REMOVED 8.5' OF WELL) 3/20/2025 pproven NOTE: PREP- CONTINUED EXCAVATION TO 10', TD 14' (IN PROGRESS). 3/17/2025 pproven NOTE: CUT & REMOVED WELL HEAD (COMPLETE 66" (5'-6")' BELOW THE 8' TO TUNDRA MARK) 3/15/2025 pproven 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 42.7 107.5 107.5 62.50 H-40 WELDED SURFACE 9 5/8 8.83 42.7 2,381.7 2,380.3 40.00 L-80 BTC-ABM PRODUCTION 7"x4.5" @ 5325" 7 6.28 2,434.0 6,002.2 5,989.6 26.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 42.6 Set Depth … 2,102.1 Set Depth … 2,102.0 String Max No… 4 1/2 Tubing Description Tubing – Kill String Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 2,097.2 2,097.0 2.06 Shoe - Mule 4.500 4 1/2" 12.6 ppf, L-80 IBT Tubing Mule Shoe 3.958 Top (ftKB) 2,650.0 Set Depth … 5,305.4 Set Depth … 5,292.8 String Max No… 4 1/2 Tubing Description Tubing – Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 3,603.0 3,590.7 3.49 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 4,573.0 4,560.4 0.50 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,127.8 5,115.2 0.43 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,179.0 5,166.4 0.35 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,230.1 5,217.5 0.35 SLEEVE 5.625 SLIDING SLEEVE w/NO GO CAMCO PROFILE BAKER CMU 3.810 5,256.8 5,244.2 0.35 NIPPLE 5.000 NIPPLE w/NO GO PROFILE CAMCO DB-6 3.750 5,302.6 5,290.0 0.28 LOCATOR 5.125 BAKER LOCATOR BAKER 3.875 5,303.4 5,290.8 0.28 SEAL 4.000 BAKER 80-40 SEAL ASSY BAKER 80-40 3.875 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) 42.7 42.6 0.20 MARKER PLATE 30" Marker plate 1/4" thick 3/21/2025 0.000 2,434.0 2,432.0 8.73 CUT MSC on rig 2/25/2025 6.200 2,440.0 2,437.9 8.77 CIBP Set CIBP on rig 2/25/2025 0.000 2,650.0 2,645.5 8.59 CUT WELLTEC MECHANICAL TBG CUT AT 2650' RKB 4/3/2024 3.958 5,200.0 5,187.4 0.35 TUBING PUNCH 3' TUBING PUNCH, 2", 7 GRAM, 18 0.61" HOLES OWEN 3/25/2024 3.958 5,465.0 5,452.4 0.26 PLUG Set TTS CIBP 10/7/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 2P- 417 12/14/2001 6.0 IPERF 3.38" HSD Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,495.0 5,515.0 1 FRAC 12/14/2001 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 42.7 2,382.0 42.7 2,380.5 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 10Drag up (lbs): 20Time started reciprocating: 02:00Time stopped reciprocating: 06:31Cement Found Between Shoe and Collar (Y/N): NCement found on liner tool (Y/N): NAnnular flow after cement job (Y/N): N 5,412.0 5,465.0 5,399.4 5,452.4 Cement Plug Dump bailed cement with Slickline on top of CIBP 12/17/2023 3,700.0 4,950.0 3,687.6 4,937.4 Intermediate String 1 Cement PUMPED 51 BBLS OF 15.8 PPG CLSS G CEMENT FOR INTERMEDIATE BALANCED PLUG. 3/30/2024 2,108.0 2,440.0 2,107.9 2,437.9 Cement Plug 07:23 - Cement Wet - Pump 22 bbls of 10# spacer @ 3 bpm, 240 psi Drop 6" ball. Pump 25bbls of 15.8# Cement @ 3.5 bpm, 630 psi. Drop 6" ball. Pump 6 bbls 10# tail @ 3 bpm, 285 psi Displace w/ 22.8 bbls 10# NaCl @3 BPM , 325 PSI. Shut down pump no flow. 3/1/2025 42.7 2,108.0 42.7 2,107.9 Cement Cap 15.8# cement observed at surface 3/3/2025 2P-417, 4/7/2025 1:36:49 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 5325"; 2,434.0-6,002.2 IPERF; 5,495.0-5,515.0 FRAC; 5,495.0 PLUG; 5,465.0 Cement Plug; 5,412.0 ftKB TUBING PUNCH; 5,200.0 GAS LIFT; 5,179.0 GAS LIFT; 5,127.8 GAS LIFT; 4,573.0 Intermediate String 1 Cement; 3,700.0 ftKB GAS LIFT; 3,603.0 CUT; 2,650.0 CIBP; 2,440.0 CUT; 2,434.0 SURFACE; 42.7-2,381.7 Cement Plug; 2,108.0 ftKB Cement Casing; 42.7 ftKB CONDUCTOR; 42.7-107.5 MARKER PLATE; 42.6 Cement Cap; 42.7 ftKB KUP PROD KB-Grd (ft) 37.20 RR Date 5/15/2001 Other Elev… 2P-417 ... TD Act Btm (ftKB) 6,008.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037500 Wellbore Status PROD Max Angle & MD Incl (°) 8.79 MD (ftKB) 2,442.68 WELLNAME WELLBORE2P-417 Annotation Last WO: End DateH2S (ppm) 40 Date 11/2/2014 Comment SSSV: NIPPLE Page 1/6 2P-417 Report Printed: 4/7/2025 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) 2/24/2025 06:00 2/24/2025 08:00 2.00 MIRU, MOVE RURD P Complete setting transition mats, pull off well and stage on pad 0.0 0.0 2/24/2025 08:00 2/24/2025 11:00 3.00 MIRU, MOVE CLEN P Clean up around 419, level out snow around 417, pick up rig mats and spot around 417 // scrape pad down unable to prep well due to being so close to rig while on 419 0.0 0.0 2/24/2025 11:00 2/24/2025 14:00 3.00 MIRU, MOVE RURD P Spot rig over well and save out // construct cellar berming // Work rig accept checklist 0.0 0.0 2/24/2025 14:00 2/24/2025 16:00 2.00 MIRU, WELCTL RURD P Rig accepted 14:00 // Take on 9.8 brine, rig up circulating lines in cellar and to tiger tank 0.0 0.0 2/24/2025 16:00 2/24/2025 16:30 0.50 MIRU, WELCTL SFTY P PJSM w/ rig crew on well kill. 0.0 0.0 2/24/2025 16:30 2/24/2025 17:00 0.50 MIRU, WELCTL PRTS P Flood lines. PT circ manifold & hardline T/ 3000 PSI. 0.0 0.0 2/24/2025 17:00 2/24/2025 18:15 1.25 MIRU, WELCTL CIRC P Kill well w/ 31 Bbls hot deep clean followed by144 Bbls 9.8# NaCl @ 4 BPM. FCP=680 PSI. Clean 9.8# seen 151 total pumped. 0.0 0.0 2/24/2025 18:15 2/24/2025 18:30 0.25 MIRU, WELCTL RURD P B/D circ manifold & hardline. 0.0 0.0 2/24/2025 18:30 2/24/2025 19:15 0.75 MIRU, WELCTL OWFF P OWFF, 30 Min no flow. Bleed OA F/ 140 PSI. 0.0 0.0 2/24/2025 19:15 2/24/2025 21:15 2.00 MIRU, WHDBOP NUND P N/D tree & adaptor spool. Hang tree in cellar. Function ULDS & LLDS. Inspect hanger neck threads. 0.0 0.0 2/24/2025 21:15 2/24/2025 21:30 0.25 MIRU, WHDBOP MPSP P Install HP BPV & test dart. 0.0 0.0 2/24/2025 21:30 2/25/2025 00:00 2.50 MIRU, WHDBOP NUND P N/U BOP. Install flow riser. R/U trip hose. Grease manual & HCR valves. 0.0 0.0 2/25/2025 00:00 2/25/2025 01:00 1.00 MIRU, WHDBOP RURD P R/U testing equipment, Fill stack w/ fresh water. Shell test BOP. LDS leaking. Applied additional torque, healed up leak. 0.0 0.0 2/25/2025 01:00 2/25/2025 11:00 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested UVBR's, w/ 3 1/2" & 4 1/2" test joints. Test annular w/ 3 1/2" & 7" test joints. Test LPR w/ 7" test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 1/2" & 4 ½” EUE 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=2950 PSI, after closure=1600 PSI, 200 PSI attained =23 sec, full recovery attained =128 sec. UVBR's= 5 sec, LVBR’s= 4.5 sec. Annular= 24 sec. Simulated blinds= 4.5 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =1920 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Brian Bixby. 0.0 0.0 2/25/2025 11:00 2/25/2025 11:45 0.75 MIRU, WHDBOP CLEN P Clean floor and rig down test equipment 0.0 0.0 2/25/2025 11:45 2/25/2025 12:15 0.50 MIRU, WHDBOP MPSP P Pull test dart & BPV. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 3/5/2025 Page 2/6 2P-417 Report Printed: 4/7/2025 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) 2/25/2025 12:15 2/25/2025 13:30 1.25 COMPZN, CSGRCY PULL P Pickup landing jt, set down 10 K and BOLDS // Pull hanger to floor 60K up wt 2,650.0 2,650.0 2/25/2025 13:30 2/25/2025 14:00 0.50 COMPZN, CSGRCY CIRC P Circulate SxS 6bpm @ 170 psi 2,620.0 2,620.0 2/25/2025 14:00 2/25/2025 18:15 4.25 COMPZN, CSGRCY PULL P Pull and lay down xx jts 4.5" IBT tubing, 81 Full joints & 5.82' Cut jt. 2,620.0 0.0 2/25/2025 18:15 2/25/2025 19:00 0.75 COMPZN, CSGRCY CLEN P Clean & clear RF. 0.0 0.0 2/25/2025 19:00 2/25/2025 19:45 0.75 COMPZN, CSGRCY RURD P Load tools for upcoming BHA's. Change out handling equipment to DP. 0.0 0.0 2/25/2025 19:45 2/25/2025 20:00 0.25 COMPZN, CSGRCY BHAH P M/U BHA #1 CIBP T/ 9' 0.0 9.0 2/25/2025 20:00 2/25/2025 21:45 1.75 COMPZN, CSGRCY TRIP P RIH F/ 9' T/ 2419'. PUW=65K, SOW=65K. Drop 5/8" setting ball. 9.0 2,419.0 2/25/2025 21:45 2/25/2025 22:30 0.75 COMPZN, CSGRCY MPSP P K/U RIH T/ 2442'. Pressure up T/ 1200 PSI hold for 2 Min. Continue pressure up saw initial shear @ 1700 PSI, pressure up T/ 2500 PSI hold for 5 Min. Pressure up T/ 3800 PSI for 5 Min. P/U to neutral weight 65K shear off plug. P/U 5'. RIH tag plug top @ 2440'. 2,419.0 2,442.0 2/25/2025 22:30 2/25/2025 23:45 1.25 COMPZN, CSGRCY TRIP P B/D TD. POOH F/ 2440' T/ 9'. 2,442.0 9.0 2/25/2025 23:45 2/26/2025 00:00 0.25 COMPZN, CSGRCY BHAH P L/D BHA #1. 9.0 0.0 2/26/2025 00:00 2/26/2025 00:15 0.25 COMPZN, CSGRCY CLEN P Clean & clear RF. 0.0 0.0 2/26/2025 00:15 2/26/2025 00:30 0.25 COMPZN, CSGRCY BHAH P M/U BHA #2 MSC T/ 12'. 0.0 12.0 2/26/2025 00:30 2/26/2025 03:00 2.50 COMPZN, CSGRCY TRIP P RIH F/ 12' T/ 2422' PUW=65K, SOW=63 12.0 2,422.0 2/26/2025 03:00 2/26/2025 03:45 0.75 COMPZN, CSGRCY CIRC P P/U working single. Kelly up. RIH tag CIBP @ 2440'. P/U T/ 2430'. Wash in @ 1 BPM, 115 PSI. Confirm no collar @ cut depth. 2,422.0 2,434.0 2/26/2025 03:45 2/26/2025 04:00 0.25 COMPZN, CSGRCY CUTP P Cut 7" CSG @ 2434'. Rot @ 100 RPM, 1.2K Free Tq. Circ @ 2.5 BPM, 815 PSI. ROT=65K. 1.5-2.8K Tq. fell back T/ 1.2K. No PSI wrap around to OA 2,434.0 2,434.0 2/26/2025 04:00 2/26/2025 04:30 0.50 COMPZN, CSGRCY CIRC P P/U T/ 2418'. Close UPR. Pump 1 Bbls down kill 350 PSI bled T/ 0 PSI when pump shut down. No movement at OA. Open UPR. P/U T/ 2870'. Circ 1 BPM, 115 PSI was down & locate collar @ 2406'. 2,434.0 2,419.0 2/26/2025 04:30 2/26/2025 05:00 0.50 COMPZN, CSGRCY PULD P L/D single. Rack back stand. M/U working single T/ 2350' 2,419.0 2,350.0 2/26/2025 05:00 2/26/2025 05:30 0.50 COMPZN, CSGRCY CUTP P Cut 7" CSG @ 2350'. Rot @ 100 RPM, 1.1K Free Tq. Circ @ 2.5 BPM, 835 PSI. ROT=65K. 1.5-3.2K Tq. fell back T/ 1.2K. 45 PSI wrap around to OA 2,350.0 2,350.0 2/26/2025 05:30 2/26/2025 06:30 1.00 COMPZN, CSGRCY CIRC P Attempt to circulate down IA up OA // Pressure up 300 psi on IA through cut no wrap around on OA shut down pump // Blow down kill line prep for TOOH 2,350.0 2,350.0 2/26/2025 06:30 2/26/2025 07:00 0.50 COMPZN, CSGRCY TRIP P TOOH T/ 1772' 2,350.0 1,772.0 2/26/2025 07:00 2/26/2025 07:30 0.50 COMPZN, CSGRCY CPBO P Make up TD, Locate collar @ 1,781' // Cut Tubing @ 1,800' // Observe 60 psi on OA gauge, no change on OA pressure 1,772.0 1,800.0 Rig: NORDIC 3 RIG RELEASE DATE 3/5/2025 Page 3/6 2P-417 Report Printed: 4/7/2025 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) 2/26/2025 07:30 2/26/2025 08:00 0.50 COMPZN, CSGRCY CIRC P Line up to circulate down drill pipe up OA through cut, no circulation, Observe bleed off @ 400 psi 1,800.0 1,800.0 2/26/2025 08:00 2/26/2025 09:30 1.50 COMPZN, CSGRCY TRIP P Trip out of hole to 1261' // Abnormal fill , stop for flow check found OA pressure had climbed to 360 psi 1,800.0 1,261.0 2/26/2025 09:30 2/26/2025 12:00 2.50 COMPZN, CSGRCY CIRC P Line up pump down IA taking returns up OA to open top tank, confirm circulation // Pump 70 bbls deep clean followed by 9.8# NaCl // Circulate @ 3 bpm @ 270 psi 1,261.0 1,261.0 2/26/2025 12:00 2/26/2025 12:30 0.50 COMPZN, CSGRCY OWFF P Shut down pump blow down tiger line // OWFF // Still showing signs of pressure 1,261.0 1,261.0 2/26/2025 12:30 2/26/2025 16:15 3.75 COMPZN, CSGRCY CIRC P Circulate SxS down drill pipe up IA 1.5 bpm @ 167 psi // Still showing pressure circulate B/U down drill pipe up IA, line up circulate down DP and IA taking returns up OA 2 bpm @ 62 psi 3 bpm @ 86 psi // 1,261.0 1,261.0 2/26/2025 16:15 2/26/2025 16:45 0.50 COMPZN, CSGRCY OWFF P Flow check 30 min no flow 1,261.0 1,261.0 2/26/2025 16:45 2/26/2025 19:00 2.25 COMPZN, CSGRCY TRIP P TOOH F/ 1261' T/ 12' 1,261.0 12.0 2/26/2025 19:00 2/26/2025 19:15 0.25 COMPZN, CSGRCY BHAH P L/ D BHA #2 12.0 0.0 2/26/2025 19:15 2/26/2025 19:45 0.50 COMPZN, CSGRCY CLEN P Clean & clear RF & pipe shed. 0.0 0.0 2/26/2025 19:45 2/26/2025 20:45 1.00 COMPZN, CSGRCY RURD P M/U pack off pulling tool. BOLDS. Pull 11" x 7" pack off. L/D pack off & pulling tool. 0.0 0.0 2/26/2025 20:45 2/26/2025 21:15 0.50 COMPZN, CSGRCY RURD P M/U landing joint. T/ hanger. K/U 0.0 1,800.0 2/26/2025 21:15 2/26/2025 21:30 0.25 COMPZN, CSGRCY PULL P Pull hanger T/ RF. Clean PUW=70K. 1,800.0 1,765.0 2/26/2025 21:30 2/26/2025 22:30 1.00 COMPZN, CSGRCY CIRC P Circ STS @ 2 BPM, 55 PSI through poor boy. Over Boarding contaminated fluid at surface. 1,765.0 1,765.0 2/26/2025 22:30 2/26/2025 23:00 0.50 COMPZN, CSGRCY OWFF P OWFF - out of balance on CSG side. L/D landing joint & hanger. 1,765.0 1,765.0 2/26/2025 23:00 2/26/2025 23:30 0.50 COMPZN, CSGRCY CIRC P Circ STB @ 6 BPM, 65 PSI. 1,765.0 1,765.0 2/26/2025 23:30 2/27/2025 00:00 0.50 COMPZN, CSGRCY PULL P OWFF. L/D landing joint & hanger. B/D TD. 1,765.0 1,765.0 2/27/2025 00:00 2/27/2025 00:15 0.25 COMPZN, CSGRCY PULL P L/D 7" CSG F/ 1765' T/ 1645', PUW=70K. - Well out of ballanc on CSG side. 1,765.0 1,645.0 2/27/2025 00:15 2/27/2025 01:00 0.75 COMPZN, CSGRCY CIRC P K/U circ STS @ 7 BPM, 65 PSI. B/D TD. 1,645.0 1,645.0 2/27/2025 01:00 2/27/2025 02:00 1.00 COMPZN, CSGRCY PULL P L/D 7" CSG F/ 1645' T/ 1007', PUW=65K. - Well out of ballanc on CSG side. 1,645.0 1,007.0 2/27/2025 02:00 2/27/2025 02:30 0.50 COMPZN, CSGRCY CIRC P K/U circ STS @ 7 BPM, 65 PSI. B/D TD. 1,007.0 1,007.0 2/27/2025 02:30 2/27/2025 02:45 0.25 COMPZN, CSGRCY PULL P L/D 7" CSG F/ 1007' T/ 727', PUW=49K. - Well out of ballanc on CSG side. 1,007.0 727.0 2/27/2025 02:45 2/27/2025 03:30 0.75 COMPZN, CSGRCY CIRC P K/U circ STS @ 7 BPM, 65 PSI. B/D TD. 727.0 727.0 2/27/2025 03:30 2/27/2025 03:45 0.25 COMPZN, CSGRCY PULL P L/D 7" CSG F/ 727', T/ 568' PUW=43K. - Well out oif ballance on CSG side. 727.0 568.0 Rig: NORDIC 3 RIG RELEASE DATE 3/5/2025 Page 4/6 2P-417 Report Printed: 4/7/2025 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) 2/27/2025 03:45 2/27/2025 05:00 1.25 COMPZN, CSGRCY CIRC P K/U circ STS @ 7 BPM 60 PSI. B/D TD. Fluid continued to U-tube out of pipe. Gas break out getting worse in stack. Gas breaking out in tubing. R/U TIW & head pin. Circ STS @ 5 BPM, 568.0 568.0 2/27/2025 05:00 2/27/2025 06:00 1.00 COMPZN, CSGRCY OWFF P OWFF 568.0 568.0 2/27/2025 06:00 2/27/2025 07:00 1.00 COMPZN, CSGRCY CIRC P Reverse circulate to sweep gas from pipe // No gain while circulating // 3 bpm @ 64 psi 568.0 568.0 2/27/2025 07:00 2/27/2025 08:00 1.00 COMPZN, CSGRCY OWFF P Still showing signs of gas migration from swap out from lower cuts 568.0 568.0 2/27/2025 08:00 2/27/2025 09:00 1.00 COMPZN, CSGRCY CIRC P Weight up to 10# // Circulate top of hole ~568' to 10# NaCl // 2 bpm @ 67 psi // No fluid gain while circulating 568.0 568.0 2/27/2025 09:00 2/27/2025 09:45 0.75 COMPZN, CSGRCY OWFF P No gain, still seeing gas break out // Prep to trip in hole 568.0 568.0 2/27/2025 09:45 2/27/2025 11:00 1.25 COMPZN, CSGRCY TRIP P Make up XO, TIH with DP to 1780' // Confirm pipe displacement 568.0 1,780.0 2/27/2025 11:00 2/27/2025 12:45 1.75 COMPZN, CSGRCY CIRC P Circulate well to 10# // Circulate SxS 1.5 times // Circulate 3 bpm @ 150 psi 1,780.0 1,780.0 2/27/2025 12:45 2/27/2025 13:15 0.50 COMPZN, CSGRCY OWFF P OWFF, no flow observed 1,780.0 1,780.0 2/27/2025 13:15 2/27/2025 14:45 1.50 COMPZN, CSGRCY TRIP P Blow down stand pipe // Trip out of hole with drill pipe to top of casing 1,780.0 680.0 2/27/2025 14:45 2/27/2025 16:30 1.75 COMPZN, CSGRCY PULL P Pull and lay down 42 jts total 7" BTC casing and 19.58' cut joint 680.0 0.0 2/27/2025 16:30 2/27/2025 17:30 1.00 COMPZN, CSGRCY CLEN P Clean and clear rig floor // Rig down GBR tongs prep for TIH w/ fishing spear 0.0 0.0 2/27/2025 17:30 2/27/2025 20:00 2.50 COMPZN, CSGRCY BHAH P Crew change out. M/U BHA #3 7" spear & 6 ea. 6-1/8" collars w/ jars and bumper sub T/ 230', SOW=45K. 0.0 230.0 2/27/2025 20:00 2/27/2025 21:30 1.50 COMPZN, CSGRCY TRIP P RIH F/ 230' T/ 1745'. PUW=69K, SOW=69K. 230.0 1,745.0 2/27/2025 21:30 2/27/2025 21:45 0.25 COMPZN, CSGRCY FISH P RIH saw spear engage fish @ 1796'. No-go @ 1807'. Set down 30K. P/U pipe free @ 90K. P/U T/ 1773', PUW 85K, dragging T/ 95K. 1,745.0 1,773.0 2/27/2025 21:45 2/27/2025 23:15 1.50 COMPZN, CSGRCY CIRC P Circ BU @ 2.5-4 BPM, 90-215 PSI. Over board contaminated fluid. P/U T/ 1742'. PUW=78K. 1,773.0 1,742.0 2/27/2025 23:15 2/27/2025 23:45 0.50 COMPZN, CSGRCY PULD P Rack back stand, B/D TD. L/D single T/ 1711'. 1,742.0 1,711.0 2/27/2025 23:45 2/28/2025 00:00 0.25 COMPZN, CSGRCY OWFF P OWFF - 1,711.0 1,711.0 2/28/2025 00:00 2/28/2025 01:00 1.00 COMPZN, CSGRCY CIRC P Circ STS @ 5 BPM, 515 PSI. 1,711.0 1,711.0 2/28/2025 01:00 2/28/2025 01:15 0.25 COMPZN, CSGRCY OWFF P R/D B/D circ hose. OWFF - no flow 1,711.0 1,711.0 2/28/2025 01:15 2/28/2025 03:00 1.75 COMPZN, CSGRCY TRIP P POOH F/ 1711' T/ 230'. PUW=78K. 1,711.0 230.0 2/28/2025 03:00 2/28/2025 04:15 1.25 COMPZN, CSGRCY BHAH P Rack back DC's, L/D BHA #3. Release spear F/ 7" 230.0 0.0 2/28/2025 04:15 2/28/2025 04:30 0.25 COMPZN, CSGRCY RURD P R/U GBR CSG equipment. 0.0 0.0 2/28/2025 04:30 2/28/2025 04:45 0.25 COMPZN, CSGRCY SFTY P PJSM on laying down 7" CSG 0.0 0.0 2/28/2025 04:45 2/28/2025 05:30 0.75 COMPZN, CSGRCY PULL P L/D 7" CSG fish, 20.40' cut, 12 full joints, 25.54' cut. 0.0 0.0 2/28/2025 05:30 2/28/2025 06:30 1.00 COMPZN, CSGRCY BHAH P Pick up fishing BHA 7" casing spear 0.0 230.0 Rig: NORDIC 3 RIG RELEASE DATE 3/5/2025 Page 5/6 2P-417 Report Printed: 4/7/2025 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) 2/28/2025 06:30 2/28/2025 08:30 2.00 COMPZN, CSGRCY TRIP P Trip in hole to top of fish // Fully locate 2357' 230.0 2,357.0 2/28/2025 08:30 2/28/2025 08:45 0.25 COMPZN, CSGRCY FISH P Pull on fish 150K fish moving up hole 2,357.0 2,299.0 2/28/2025 08:45 2/28/2025 10:00 1.25 COMPZN, CSGRCY CIRC P Circulate S x S 2,299.0 2,299.0 2/28/2025 10:00 2/28/2025 13:00 3.00 COMPZN, CSGRCY PULD P TOOH laying down drill pipe 2,299.0 230.0 2/28/2025 13:00 2/28/2025 14:15 1.25 COMPZN, CSGRCY BHAH P Lay down BHA and fish 12.18' cut, 1 full joints & 30.11' cut. 230.0 0.0 2/28/2025 14:15 2/28/2025 15:30 1.25 COMPZN, CSGRCY TRIP P Trip in remainder of pipe to lay down drill pipe 0.0 1,208.0 2/28/2025 15:30 2/28/2025 16:30 1.00 COMPZN, CSGRCY CLEN P Load out all Yellow jacket tools 1,208.0 1,208.0 2/28/2025 16:30 2/28/2025 18:00 1.50 COMPZN, CSGRCY PRTS P Run in test plug on string // Precautionary test due to usage while U -tubing. UVBR's, HCR Kill, CMV #2, #5, #6 & 3 1/2"FOSV, 250/2500 1,208.0 1,238.0 2/28/2025 18:00 2/28/2025 18:30 0.50 COMPZN, CSGRCY RURD P R/D, B/D testing equipment. 1,238.0 1,238.0 2/28/2025 18:30 2/28/2025 19:00 0.50 COMPZN, CSGRCY MPSP P Pull test plug 1,238.0 1,208.0 2/28/2025 19:00 2/28/2025 19:30 0.50 COMPZN, CSGRCY CIRC P Circ STS @ 5 BPM, 305 PSI. 1,208.0 1,208.0 2/28/2025 19:30 2/28/2025 19:45 0.25 COMPZN, CSGRCY RURD P B/D, RD circ equipment. 1,208.0 1,208.0 2/28/2025 19:45 2/28/2025 21:30 1.75 COMPZN, CSGRCY PULD P L/D 3 1/2" DP T/ surface. 1,208.0 0.0 2/28/2025 21:30 2/28/2025 22:00 0.50 COMPZN, CSGRCY CLEN P Clean & clear RF & pipe shed 0.0 0.0 2/28/2025 22:00 2/28/2025 22:30 0.50 COMPZN, CSGRCY RURD P R/U TBG handling equipment. 0.0 0.0 2/28/2025 22:30 3/1/2025 00:00 1.50 COMPZN, CSGRCY PULD P Drift string in pipe shed w/ 3.74" drift. 0.0 0.0 3/1/2025 00:00 3/1/2025 01:45 1.75 COMPZN, CSGRCY RURD P Replace bad joints w/ spares from outside. Kick out bad joints. 0.0 0.0 3/1/2025 01:45 3/1/2025 05:00 3.25 COMPZN, CSGRCY PUTB P Crew change out. RIH w/ 4 1/2", 12.6#, L-80, IBT cement string w/ mule shoe T/ 2381', PUW=91K, SOW=67K. 0.0 2,380.0 3/1/2025 05:00 3/1/2025 06:00 1.00 COMPZN, CSGRCY WASH P Wash in hole F/ 2382' T/ 2430' @ 4 BPM, 58 PSI. 2,380.0 2,430.0 3/1/2025 06:00 3/1/2025 07:00 1.00 COMPZN, CSGRCY CMNT P Rig up HES cementers 2,430.0 2,430.0 3/1/2025 07:00 3/1/2025 07:30 0.50 COMPZN, CSGRCY CMNT P PT lines 3500 psi // Batch up cement // Cement wet @ 07:23 2,430.0 2,430.0 3/1/2025 07:30 3/1/2025 08:45 1.25 COMPZN, CSGRCY CMNT P 07:23 - Cement Wet 08:03- Pump 10# spacer 3 bpm @ 240 psi 22 bbls 08:10- Shut down pump drop 5" ball 08:11- Pump 15.8# Cement 25bbls @ 3.5 bpm @ 630 psi 08:18- Shut down pump drop 6" ball 08:20- Pump 10# tail 6 bbls @ 3.5 bpm @ 260 psi 08:22- Displace w/ 22.8 bbls 10# NaCl shut down pump no flow 08:45- Head pin rigged down ready to pull out of balanced plug 2,430.0 2,430.0 3/1/2025 08:45 3/1/2025 09:30 0.75 COMPZN, CSGRCY TRIP P TOOH @ 20 FPM T/ 1810' Cement in place @ 09:30 Hrs. 2,430.0 1,810.0 3/1/2025 09:30 3/1/2025 10:00 0.50 COMPZN, CSGRCY CIRC P Circulate SxS @ 3.5 bpm @ 65 psi // Dump spacer to cuttings tank 1,810.0 1,810.0 Rig: NORDIC 3 RIG RELEASE DATE 3/5/2025 Page 6/6 2P-417 Report Printed: 4/7/2025 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) 3/1/2025 10:00 3/2/2025 00:00 14.00 COMPZN, CSGRCY WOC P Wait on cement 500 psi compressive strength 1,810.0 1,810.0 3/2/2025 00:00 3/2/2025 18:30 18.50 COMPZN, CSGRCY WOC P Wait on cold cement sample to get hard 1,810.0 1,810.0 3/2/2025 18:30 3/2/2025 20:30 2.00 COMPZN, CSGRCY WASH P Wash in hole @ 4 BMP, 45 PSI F/ 1810' T/ 2108'. Tag TOC w/ 15 SOW. Tag witnessed by Sully Sullivan. P/U 2105' 1,810.0 2,105.0 3/2/2025 20:30 3/2/2025 21:00 0.50 COMPZN, CSGRCY CIRC P Circ STS @ 6 BPM, 50 PSI. Over boarding green cement. 2,105.0 2,105.0 3/2/2025 21:00 3/2/2025 22:00 1.00 COMPZN, CSGRCY HOSO P L/D joints #67 - #65. M/U 7.82' space up pup & joint #65. M/U landing joint T/ hanger. M/U hanger to string. RIH & land hanger w/ BTM of mule shoe @ 2102.14'. RILDS. 2,105.0 2,102.1 3/2/2025 22:00 3/2/2025 22:30 0.50 COMPZN, CSGRCY RURD P R/U testing equipment. Flood lines. 2,102.1 2,102.1 3/2/2025 22:30 3/2/2025 23:30 1.00 COMPZN, CSGRCY PRTS P PT balance plug T/ 1000 PSI for 10 MIn. PT balance plug T/ 1500 PSI for 30 Min. Test witnessed by AOGCC rep Sully Sullivan. 2,102.1 2,102.1 3/2/2025 23:30 3/3/2025 00:00 0.50 COMPZN, CSGRCY RURD P B/D, R/D testing equipment. 2,102.1 2,102.1 3/3/2025 00:00 3/3/2025 01:00 1.00 COMPZN, WHDBOP WWWH P P/U jetting tool. Jet BOP stack. L/D jetting tool. B/D TD. 2,102.1 2,102.1 3/3/2025 01:00 3/3/2025 11:00 10.00 COMPZN, WHDBOP OTHR P Perform BWM. Identified bad annular element. 2,102.1 2,102.1 3/3/2025 11:00 3/3/2025 13:00 2.00 COMPZN, WHDBOP NUND P Nipple down BOPs 2,102.1 0.0 3/3/2025 13:00 3/3/2025 15:00 2.00 COMPZN, PLUG NUND P Nipple up production tree for cementing 0.0 0.0 3/3/2025 15:00 3/3/2025 17:00 2.00 COMPZN, PLUG RURD P Rig up halliburton cement // PT lines 3500 psi good test 0.0 0.0 3/3/2025 17:00 3/3/2025 19:00 2.00 COMPZN, PLUG CMNT P Cement well to surface // Pump 20 bbls lead fresh water // Pump 189 bbls 15.8# cement // 15.8 observed at surface // flush and blow down lines 0.0 0.0 3/3/2025 19:00 3/3/2025 21:00 2.00 COMPZN, PLUG RURD P Rig down cement crew and cellar lines // Secure tree 0.0 0.0 3/3/2025 21:00 3/4/2025 00:00 3.00 COMPZN, PLUG RURD P Misc rig down // Prep to pull off the well // Pull off well and stage on pad // clean around well and prep to mob rig to 2V 0.0 0.0 3/4/2025 00:00 3/5/2025 00:00 24.00 MIRU, MOVE MOB P Mob F/ 2P T/ 2N. Hold for fueler F/ 14:00-15:00. Mob T/ 2L. Hold for crew change out F/ 17:45 T/ 19:30. Mob towards 2M 0.0 0.0 3/5/2025 00:00 3/5/2025 05:00 5.00 MIRU, MOVE MOB P Mob T/ 2M. Hold for field change out F/ 5:00 T/ 7:30. Mob T/ 4 corners. Hold for Alpine change out bus F/10:00 T/ 10:30. Mob T/ 2B. Hold for Alpine change out bus & Santos emergency vehicle F/12:30 T/ 13:30. Mob T/ 2V. 0.0 0.0 3/5/2025 05:00 3/5/2025 17:30 12.50 MIRU, MOVE MOB P Cont. rig move from 2M to 2V. Arrive at 2V @ 17:30. Rig Release from 2P-417. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 3/5/2025 DTTMSTART JOBTYP SUMMARYOPS 3/19/2024 CHANGE WELL TYPE (SECURE) T DDT TO 0 PSI (IN PROGRESS) 3/20/2024 CHANGE WELL TYPE (SECURE) T DDT TO 0 PSI (IN PROGRESS). 3/20/2024 CHANGE WELL TYPE SET 4.5" SLIPSTOP CATCHER @ 2314' RKB, PULL STA 1 DUMMY VLV @ 2219' RKB & REPLACE W/ 2000# CASING SOV, PULL 4.5" SLIPSTOP CATCHER @ 2314' RKB. READY FOR TUBING PUNCH. 3/21/2024 CHANGE WELL TYPE (SECURE) T DDT TO 0 PSI (IN PROGRESS) 3/22/2024 CHANGE WELL TYPE (SECURE) T DDT TO 0 PSI (IN PROGRESS) 3/23/2024 CHANGE WELL TYPE (SECURE) T DDT TO 0 PSI (PASS) BLEED IA TO 0 PSI (COMPLETE) OA DDT TO 0 PSI (IN PROGRESS) 3/24/2024 CHANGE WELL TYPE (SECURE) OA DDT TO 0 PSI (IN PROGRESS) 3/25/2024 CHANGE WELL TYPE SHOOT TUBING PUNCH FROM 5200'-5203', CCL-TS=6.7', CCL STOP DEPTH=5193.3', LOG CORRELATED TO TUBING TALLY DATED 5/15/2001, PRE-SHOT T/IA=1100/0, POST SHOT T/IA=450/250, WELL LEFT S/I. JOB IS READY FOR CEMENTING 3/25/2024 CHANGE WELL TYPE (SECURE) BLEED OA FOR BUR (COMPLETE) 3/25/2024 CHANGE WELL TYPE RIG UP LRS PUMP UNIT TO TBG, PUMP 15 BBLS DOWN TBG @ 2 BPM, 1000 PSI PUMP PRESSURE THROUGH PERFERATIONS AND UP IA TO TANK, U TUBE. JOB COMPLETE, RIG DOWN 3/30/2024 CHANGE WELL TYPE PUMPED INTERMEDIATE BALANCED CEMENT PLUG. PUMPED 51 BBLS OF 15.8 PPG CEMENT AND DISPLACED IT WITH 56 BBLS OF 9.8 PPG BRINE PLACING THE TOC AT ~3700' RKB IN THE TUBING AND IA. READY FOR FREEZE PROTECT. 4/1/2024 CHANGE WELL TYPE SHEARED SOV. CIRCULATED 80 BBLS OF DIESEL FREEZE PROTECT. 4/2/2024 CHANGE WELL TYPE ****AOGCC WITNESSED **** TAG TOP OF CEMENT @ 3580' RKB. PERFORMED PASSING CMIT TO 1500 PSI. READY FOR E-LINE. 4/3/2024 CHANGE WELL TYPE CUT 4.5" TUBING WITH WELLTEC MECHANICAL CUTTER AT 2650' RKB. TATTLETALE SHOWED BLADE EXTENSION TO 4.77" AND CCL SHIFT SEEN ON LOG AFTER CUTTING (TBG WAS IN TENSION). JOB COMPLETE, READY FOR RIG 2/24/2025 RECOMPLETION Pull off well stage on pad. Move mats. Pull over well. MIRU auxiliary equipment. Complete acceptance checklist. Take 9.8 PPG NaCl. Build heated deep clean pill. R/U circ manifold. PT cir manifold & hard line. Kill well w/ 31 Bbls heated deep clean pill followed by 141 Bbls 9.8#. Clean returns back to surface. B/D hard line. OWFF - 30 min no flow. R/D circ equipment. N/D tree & adaptor spool. Function LDS, inspect hanger neck threads. Install HP BPV & test dart. N/U BOP. 2/25/2025 RECOMPLETION Perform initial BOPE test 250/2500, rig down test equipment. Pull test dart & BPV, M/U landing jt, BOLDS, pull hanger to floor 60K up wt, Circulate SxS. L/D 4 1/2" IBT string 81 full joints & 5,28' cut joint. M/U BHA #1 CIBP. RIH & set @ 2440', shear off & tag to confirm set. POOH, L/D BHA #1. 2/26/2025 RECOMPLETION M/U BHA #2 MSC. RIH tag CIBP @ 2440'. Confirm no collar at cut depth. Cut 7" CSG @ 2434'. No PSI wrap around on OA. Close UPR pump 1 Bbls into formation 350 PSI, bleed to 0 PSI no wrap around to OA. P/U locate collar @ 2406'. Cut 7" CSG @ 2350'. Attempt to circ no movement at OA. P/U locate collar @ 1781'. Cut 7" CSG @ 1800'. Attempt to circ, no movement at OA. POOH T/ 1261'. Abnormal hole fill. OA showing 360 PSI. Circ out OA. Circ out inside 7". Re Circ OA. OWFF. POOH F/ 1261' T/ 12'. L/D BHA #2 MSC. M/U pack off pulling tool. BOLDS. Pull 11" x 7" pack off. M/U hanger. Pull hanger T/ RF. Circ STS through poor boy. OWFF- out of balance pump STB @ 6 BPM, OWFF. 2/27/2025 RECOMPLETION L/D 7" CSG F/ 1765’ out of balance U-tube up CSG side @ 1645’, 1007’, 727’. 568’ Correct hole fill at each interval. Circ STS @ 7 BPM each time. At 568’ after pumping STS fluid and gas continued to exhaust from CSG. Gas breaking out in stack worsening. Circ additional STS. OWFF, Reverse circ BU out CSG. Circ in 10.0 PPG mud cap @ 568'. OWFF. RIH on DP T/ 1780'. Circ 10.0 PPG NaCl around. OWFF. POOH, rack back DP & L/D 7" CSG total of 42 joints & 19.58' cut joint. M/U BHA #3 spear. RIH engage CSG stub T/ 1806'. P/U pipe free @ 90K. Circ 2x BU. OWFF. 2/28/2025 RECOMPLETION Circ STS. OWFF. POOH F/ 1717', L/D BHA #3 & 7" CSG, 20.40' cut, 12 full joints & 25.54' cut. pick up fishing BHA# 4 7" spear, TIH no-go on fish @ 2357', pull fish free 150k, circulate SxS. LDDP F/ 2357', L/D BHA #4 & 7" CSG 12.18' cut, 1 full joints & 30.11' cut. RIH w/ DP out of derrick T/ 1208'. Set test plug. Put a precautionary test due to usage while U-tubing, test UVBR's, HRC Kill, CMV #2, #5, #6 & 3 1/2" IF TIW. Pull test plug. Circ STS @ 5 BPM to sweep DP. LDDP F/ 1208'. Drift string in shed w/ 3.74" drift. 3/1/2025 RECOMPLETION Replace bad joints with spares from outside. RIH w/ 4 1/2" IBT cement string T/ 2380', Wash in hole @ 4 BPM T/ 2430'. R/U HES cement. PT lines. Pump 25 Bbls surface shoe job as per plan. Pull to safety @ 1810'. Cement in place @ 09:30 Hrs. Circ out spacer. WOC. 2P-417 Final Plug and Abandon Summary of Operations 3/2/2025 RECOMPLETION WOC wait for sample to harden up. Wash in hole @ 4 BMP, 45 PSI F/ 1810' T/ 2108'. Tag TOC @ 2108' w/ 15 SOW. Circ STS @ 6 BPM, 50 PSI. Over boarding green cement. Space out. RIH & land hanger w/ BTM of mule shoe @ 2102.14'. RILDS. PT cement plug T/ 1500 PSI for 30 Min - Pass. Witnessed by AOGCC rep Sully Sullivan. 3/3/2025 RECOMPLETION Jet BOP stack. Perform BWM. change out blinds, upper pipe rams and annular, nipple down BOPs, nipple up Production tree, rig up HES cementers and PT lines 3500 PSI, pump 20 Bbls lead fresh water followed by 189 Bbls 15.8# cement, flush and blow down lines, rig down HES and secure tree, Misc rig down for pull off well and clean around well, prep for move to 2V 3/4/2025 RECOMPLETION Mob F/ 2P T/ 2N. Hold for fueler. Mob T/ 2L. Hold for crew change out. Mob towards 2M 3/5/2025 RECOMPLETION Mob T/ 2M. Hold for field change out. Continue rig move to 2V. Arrive at 2V Pad @ 17:30. Release rig. 3/10/2025 CHANGE WELL TYPE (P&A) PREP FOR P&A DDT AND TOC VERIFIACTION. CLEARED CELLAR OF FLUIDS AND GRAVEL (2YD). ***NEXT STEP: IA/OA DDT. VALVE REMOVAL.*** 3/11/2025 CHANGE WELL TYPE (P&A) T X IA X OA DDT (COMPLETE), PULL WELLHEAD VALVES (COMPLETE), PULL TREE (COMPLETE) ***NEXT STEP : MOB NES -CUT REMOVE WELLHEAD.**** 3/15/2025 CHANGE WELL TYPE (P&A) CUT AND REMOVED WELL HEAD (COMPLETE 66" (5'-6")' BELOW THE 8' TO TUNDRA MARK) CUT AND REMOVE THE CELLAR (IN PROGRESS) ****NEXT STEP : CUT REMOVE CELLAR. BEGIN EXCAVATION TO 14' TD FOR SHORE CAN INSTALL.**** 3/16/2025 CHANGE WELL TYPE (P&A) PREP- CUT- REMOVE STEEL & CORRUGATED CELLAR (COMPLETE). BEGIN EXCAVATION, TD 14' (IN PROGRESS). ****NEXT STEP- CONTINUE EXCAVATION UNTIL 14' TD, THEN SET & BACKFILL AROUND SHORE (ADDITIONAL 6'-6" OF WELL STUB NEEDS REMOVED TO MEET 4' BELOW OG.)**** 3/17/2025 CHANGE WELL TYPE (P&A) PREP- CONTINUED EXCAVATION TO 10', TD 14' (IN PROGRESS). ****NEXT STEP- CONTINUE EXCAVATION UNTIL 14' TD, THEN SET & BACKFILL AROUND SHORE (ADDITIONAL 6'-6" OF WELL STUB NEEDS REMOVED TO MEET 4' BELOW OG.)**** 3/18/2025 CHANGE WELL TYPE (P&A) PREP- EXCAVATED TO 14' TD. SET 8' D x 16' H SHORE CAN. BACKFILLED AROUND SHORE CAN, INSTALLED TEMPORARY HAND RAIL. (COMPLETE) ****NEXT STEP: CUT & REMOVE MINIMUM OF 6' 6" MORE OF WELL STUB, PREPARE FOR WELL MARKER PLATE AND AOGCC VIEWING.**** 3/19/2025 CHANGE WELL TYPE (P&A) PREP - IN PROGRESS, CLEARED RESIDUAL CEMENT FROM INSULATED JACKET. JOB POST PONED DUE TO PHASE 2 CONDITIONS. ****NEXT STEPS: POST STORM CLEAN OUT, CUT/REMOVE ADDITIONAL 6' 6"+ OF WELL STUB TO MEET 4' BELOW OG REQUIREMENTS.***** 3/20/2025 CHANGE WELL TYPE (P&A) CUT AND REMOVE WELL STUB (COMPLETE REMOVED 8.5' OF WELL) 3/21/2025 CHANGE WELL TYPE (P&A) AOGCC REP SULLY SULLIVAN WITNESSED THE TOC AND MARKER PLATE (5' 5" BELOW TUNDRA) WELDED THE MARKER PLATE TO THE WELL STUB (COMPLETE) 3/22/2025 CHANGE WELL TYPE (P&A) REMOVE "SHORING CAN" AND BACKFILL (COMPLETE) 2P-417 Well Final P&A Schematic Conductor: 16" Conductor 107.5' KB Production Casing Cement: 90 bbls of 15.8# Class G Cement Calculated TOC @ 2,854' KB 3 5 4 Production Casing: 7" x 4.5" @ 5,325' KB, 26# x 12.6#, L- 80 BTC Set @ 6,002.2’ KB Bermuda Peforations: @ 5,495' – 5,515' KB (20') Surface Casing: 9-5/8", 40#, L-80 BTC-ABM Set @ 2,381.7' KB (2380' TVD) Production Tubing: 4 ½”, 12.6# L-80 IBT Set @ 5,305.4' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D'ĞŶsdƵďŝŶŐ,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϰϰϬ͘ϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬEŽ 'ŽĂŵĐŽWƌŽĨŝůĞ ϱ͕ϮϯϬ͘ϭΖ ϰ ĂŵĐŽͲϲEŝƉƉůĞǁͬEŽ'Ž WƌŽĨŝůĞ ϱ͕Ϯϱϲ͘ϵΖ ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϱ͕ϯϬϮ͘ϲϬ ϲ ĂŬĞƌϴϬͲϰϬ^ĞĂůƐƐĞŵďůLJ ϱ͕ϯϬϯ͘ϰΖ Plug #1 – Reservoir TOC ±5412' RKB C80 @ 2490' KB C80 @ 2490' KB Plug #2 – Intermediate TOC ±3700' RKB BOC @ ±4950' RKB Plug #3 – Surface Shoe TOC 2108' RKB (2108' TVD) BOC @ ±2440' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2108' RKB 2 1 2025-0321_Surface_Abandon_KRU_2P-417_ss Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3-23-2025 P. I. Supervisor FROM: Sully Sullivan SUBJECT: Surface Abandonment Petroleum Inspector KRU 2P-417 ConocoPhillips Alaska Inc PTD 2010690; Sundry 324-147 3-21-2025: I traveled to Kuparuk River Unit 2P-417 to witness the surface abandonment. Once on location I met with Conoco representative Brennen Green. I looked over and collected paperwork, inspected the marker plate, took measurements of the pad and top of casing to confirm cutoff depth. The top of the cut casing is 5 ft 5 inches below original tundra level (see drawing). I inspected and confirmed all well spaces have cement to surface, and it is hard. The marker plate information is accurate, and plate has the correct dimensions. I gave the okay for the plate to be installed and after installation I inspected the complete weld and found no gaps or overhangs. I gave the okay to proceed and returned to Deadhorse. Attachments: Photos (6) 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.24 14:44:19 -08'00' 2025-0321_Surface_Abandon_KRU_2P-417_ss Page 2 of 4 Surface Abandonment – KRU 2P-417 (PTD 2010690) Photos by AOGCC Inspector S. Sullvan 3-21-2025 2025-0321_Surface_Abandon_KRU_2P-417_ss Page 3 of 4 2025-0321_Surface_Abandon_KRU_2P-417_ss Page 4 of 4 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: 23.8 ft Total Depth: 6008 ft Lease No.: ADL0373112 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 107 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 2,382 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7"x4-1/2" O.D. Shoe@ 6,002 Feet Csg Cut@ 2,434 Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 4-1/2 O.D. Tail@ 5,305 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 2,440 ft 2,111 ft 10.0 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing IA 1680 1610 1580 OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: This report reflects the plug tag and MIT of KRU 2P-417 for the intermdiate cement plug. Well has 10 ppg NaCl brine above the plug. They washed down to 2100 ft MD with 10k lbs down weight, picked up and washed down again to 2109 ft MD. Picked up a third time and tagged three more times with 15k lbs down weight for a final tag of 2111 ft MD. Witnessed a passing MIT and gave okay to continue with abandonment procedure. March 2, 2025 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-417 ConocoPhillips Alaska Inc. PTD 2010690; Sundry 324-711 none Test Data: P Casing Removal: Kevin Barr Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0302_Plug_Verification_KRU_2P-417_ss 9 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 99 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.09 16:27:46 -08'00' 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): 6008'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. W ell 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 1/23/2025 4-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2353' 5495-5515' 5976' 5482-5502' 7" x 4-1/2" Perforation Depth TVD (ft): 107' 2382' 5989'6002' 16" 9-5/8" 79' 5305' MD 107' 2380' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 201-069 P.O. Box 100360, Anchorage, AK 99510 50-103-20375-00-00 Kuparuk River Field Meltwater Oil Pool-Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5303' MD and 5291' TVD N/A Shane Germann 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: Shane.Germann@conocophillips.com (907) 263-4597 Senior CTD/RWO Engineer KRU 2P-417 5995' 3700' 3688' 3700', 5412', 5465' 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): 986 psi 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: 2024.12.19 06:52:22-09'00' Foxit PDF Editor Version: 13.0.0 By Grace Christianson at 8:35 am, Dec 19, 2024 324-711 X DSR-12/20/24 X X SFD 12/26/2024 10-407 X June 30, 2025 BOP test to 2500 psig Annular preventer test to 2500 psig See attached "Conditions of Approval" VTL 12/27/2024MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.31 10:16:55 -09'00'12/31/24 RBDMS JSB 010925 KRU 2P-4ϭϳ 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. 2P-417 Plug and Abandonment Background & Objective 2P-417 was a producer that has been shut in since September 2021. This well was suspended with a CIBP and cement and is currently waiting for AOGCC witness of a tag and test (as of 3/5/2024). The steps to P&A this well include three more cement plugs: an intermediate plug across the tubing, a plug across the surface casing shoe after the tubing and production casing has been pulled, and then a final plug to surface. Well Data Meltwater Formation: x Reservoir pressure 2/3/2020 = 2348 RKB @ 5482’ TVD x MASP = 1800 psi C-80 Formation: x OAP = 394 psi (9/17/23) (fluid packed with diesel) x MASP = 986 psi Last tag 5528’ RKB on 2/15/21 Max deviation = 8 deg at 2442’ KB Intermediate Plug – Wireline & Pumping Prepared by: Katherine O’Connor Estimated Start Date: 3-1-24 (Completed – SJG 12/18/24) Procedure 1.Punch tubing at ±5,200’ RKB 2. Pump the following schedule taking returns up the IA: a. ±50 bbls surfactant wash b. ±200 bbls 9.8 brine c. ±51 bbls cement d. ±56 bbls 9.8 brine displacement 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 3700’ MD RIH and tag TOC and perform pressure test to 1500 psi (AOGCC Witnessed) Cut tubing at ±2,650’ RKB Well Name Previous plug tag depth (RKB)PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-417 3580' Pass 4/2/2024 50 psi 0 psi 440 psi 4/3/2024 Production Casing Cement: 90 bbls of 15.8# Class G Cement Calculated TOC @ 2,854' KB 2P-417 Well Suspension Schematic Conductor: 16" Conductor 107.5' KB 3 5 4 Production Casing: 7" x 4.5" @ 5,325' KB, 26# x 12.6#, L- 80 BTC Set @ 6,002.2’ KB Bermuda Peforations: @ 5,495' – 5,515' KB (20') Surface Casing: 9-5/8", 40#, L-80 BTC-ABM Set @ 2,381.7' KB (2380' TVD) Production Tubing: 4 ½”, 12.6# L-80 IBT Set @ 5,305.4' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D'ĞŶsdƵďŝŶŐ,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂŵĐŽͲϲEŝƉƉůĞ ϰϴϱ͘ϲΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬEŽ 'ŽĂŵĐŽWƌŽĨŝůĞ ϱ͕ϮϯϬ͘ϭΖ ϰ ĂŵĐŽͲϲEŝƉƉůĞǁͬEŽ'Ž WƌŽĨŝůĞ ϱ͕Ϯϱϲ͘ϵΖ ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϱ͕ϯϬϮ͘ϲϬ ϲ ĂŬĞƌϴϬͲϰϬ^ĞĂůƐƐĞŵďůLJ ϱ͕ϯϬϯ͘ϰΖ Plug #1 – Reservoir TOC ±5412' RKB C80 @ 2490' KB C80 @ 2490' KB Plug #2 – Intermediate TOC ±3580' RKB BOC @ ±4950' RKB Surface Casing Plugs – Rig Date: 3-5-2024 Prepared by: Sydney Long Estimated Start Date: 5-6-2024 1-23-202 MIRU 1. MIRU on 2P-417. (No BPV due to abandonment of all perforations.) 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 18 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’ inside the surface casing shoe based on space out of MD above target TOC and space out with 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 2P-417 Surface Shoe Cement Schematic Conductor: 16" Conductor 107.5' KB Production Casing Cement: 90 bbls of 15.8# Class G Cement Calculated TOC @ 2,854' KB 3 5 4 Production Casing: 7" x 4.5" @ 5,325' KB, 26# x 12.6#, L- 80 BTC Set @ 6,002.2’ KB Bermuda Peforations: @ 5,495' – 5,515' KB (20') Surface Casing: 9-5/8", 40#, L-80 BTC-ABM Set @ 2,381.7' KB (2380' TVD) Production Tubing: 4 ½”, 12.6# L-80 IBT Set @ 5,305.4' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D'ĞŶsdƵďŝŶŐ,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϰϴϬ͘ϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬEŽ 'ŽĂŵĐŽWƌŽĨŝůĞ ϱ͕ϮϯϬ͘ϭΖ ϰ ĂŵĐŽͲϲEŝƉƉůĞǁͬEŽ'Ž WƌŽĨŝůĞ ϱ͕Ϯϱϲ͘ϵΖ ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϱ͕ϯϬϮ͘ϲϬ ϲ ĂŬĞƌϴϬͲϰϬ^ĞĂůƐƐĞŵďůLJ ϱ͕ϯϬϯ͘ϰΖ Plug #1 – Reservoir TOC ±5412' RKB C80 @ 2490' KB C80 @ 2490' KB Plug #2 – Intermediate TOC ±3580' RKB BOC @ ±4950' RKB Plug #3 – Surface Shoe TOC 2230' RKB (2230' TVD) BOC @ ±2480' RKB Base of 7” Casing 150'-200' BCPWF50$ 2 1 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 2432 2482 Open Hole 8.5 0.060898 3.0 Displacement of Prod Casing Stub Included in BBL/FT calc 2382 2432 Open Hole 8.5 0.070187 3.5 2230 2382 Surface Casing 8.83 0.075742 11.5 18.0 Total Volume of Plug Surface Casing 23 2230 Surface Casing 8.83 0.066454 146.7 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-417 c. PTD #: 201-069 d. API #: 50-103-20375-00-00 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 2P-417 Well Final P&A Schematic Conductor: 16" Conductor 107.5' KB Production Casing Cement: 90 bbls of 15.8# Class G Cement Calculated TOC @ 2,854' KB 3 5 4 Production Casing: 7" x 4.5" @ 5,325' KB, 26# x 12.6#, L- 80 BTC Set @ 6,002.2’ KB Bermuda Peforations: @ 5,495' – 5,515' KB (20') Surface Casing: 9-5/8", 40#, L-80 BTC-ABM Set @ 2,381.7' KB (2380' TVD) Production Tubing: 4 ½”, 12.6# L-80 IBT Set @ 5,305.4' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D'ĞŶsdƵďŝŶŐ,ĂŶŐĞƌ Ϯϱ͘ϲΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϮϰϴϬ͘ϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬEŽ 'ŽĂŵĐŽWƌŽĨŝůĞ ϱ͕ϮϯϬ͘ϭΖ ϰ ĂŵĐŽͲϲEŝƉƉůĞǁͬEŽ'Ž WƌŽĨŝůĞ ϱ͕Ϯϱϲ͘ϵΖ ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϱ͕ϯϬϮ͘ϲϬ ϲ ĂŬĞƌϴϬͲϰϬ^ĞĂůƐƐĞŵďůLJ ϱ͕ϯϬϯ͘ϰΖ Plug #1 – Reservoir TOC ±5412' RKB C80 @ 2490' KB C80 @ 2490' KB Plug #2 – Intermediate TOC ±3580' RKB BOC @ ±4950' RKB Plug #3 – Surface Shoe TOC 2230' RKB (2230' TVD) BOC @ ±2480' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2230' RKB 2 1 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 5,412.0 2P-417 3/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Tbg Cut 2P-417 4/3/2024 bworthi1 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 28.5 107.5 107.5 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 2,381.7 2,380.3 40.00 L-80 BTC-ABM PRODUCTION 7"x4.5" @ 5325" 7 6.28 26.4 6,002.2 5,989.5 26.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 5,305.4 Set Depth … 5,292.8 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 25.6 25.6 0.12 HANGER 8.000 FMC GEN V TUBING HANGER 4.500 485.6 485.5 0.52 NIPPLE 5.570 CAMCO DB-6 NIPPLE CAMCO DB-6 3.875 2,219.9 2,219.5 4.76 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 3,603.0 3,590.7 3.49 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 4,573.0 4,560.4 0.50 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,127.8 5,115.2 0.43 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,179.0 5,166.4 0.35 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,230.1 5,217.5 0.35 SLEEVE 5.625 BAKER CMU SLIDING SLEEVE w/NO GO CAMCO PROFILE BAKER CMU 3.810 5,256.9 5,244.2 0.35 NIPPLE 5.000 CAMCO DB-6 NIPPLE w/NO GO PROFILE CAMCO DB-6 3.750 5,302.6 5,290.0 0.28 LOCATOR 5.125 BAKER LOCATOR BAKER 3.875 5,303.4 5,290.8 0.28 SEAL 4.000 BAKER 80-40 SEAL ASSY BAKER 80-40 3.875 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) 2,650.0 2,645.5 8.59 CUT WELLTEC MECHANICAL TBG CUT AT 2650' RKB 4/3/2024 3.958 5,200.0 5,187.4 0.35 TUBING PUNCH 3' TUBING PUNCH, 2", 7 GRAM, 18 0.61" HOLES OWEN 3/25/2024 3.958 5,465.0 5,452.4 0.26 PLUG Set TTS CIBP 10/7/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,219.9 2,219.5 4.76 1 GAS LIFT SOV BK 1 0.0 3/20/2024 Shear ed 3/30/2 4 0.000 3,603.0 3,590.7 3.49 2 GAS LIFT DMY BK 1 0.0 8/15/2001 0.000 4,573.0 4,560.4 0.50 3 GAS LIFT DMY BK 1 0.0 12/12/2001 0.000 5,127.8 5,115.2 0.43 4 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 5,179.0 5,166.4 0.35 5 GAS LIFT DMY BK 1 0.0 2/19/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 2P- 417 12/14/2001 6.0 IPERF 3.38" HSD Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,495.0 5,515.0 1 FRAC 12/14/2001 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,412.0 5,465.0 5,399.4 5,452.4 Cement Plug Dump bailed cement with Slickline on top of CIBP 12/17/2023 3,700.0 4,950.0 3,687.6 4,937.4 Intermediate String 1 Cement PUMPED 51 BBLS OF 15.8 PPG CLSS G CEMENT FOR INTERMEDIATE BALANCED PLUG. 3/30/2024 2P-417, 4/4/2024 9:08:58 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 5325"; 26.4-6,002.2 FLOAT SHOE; 6,000.4-6,002.2 FLOAT COLLAR; 5,906.3- 5,907.8 FRAC; 5,495.0 IPERF; 5,495.0-5,515.0 PLUG; 5,465.0 Cement Plug; 5,412.0 ftKB CSR; 5,305.4-5,324.8 SEAL; 5,303.4 LOCATOR; 5,302.6 NIPPLE; 5,256.9 SLEEVE; 5,230.1 TUBING PUNCH; 5,200.0 GAS LIFT; 5,179.0 GAS LIFT; 5,127.8 GAS LIFT; 4,573.0 Intermediate String 1 Cement; 3,700.0 ftKB GAS LIFT; 3,603.0 CUT; 2,650.0 SURFACE; 28.8-2,381.7 FLOAT SHOE; 2,380.0-2,381.7 FLOAT COLLAR; 2,302.9- 2,304.6 GAS LIFT; 2,219.9 NIPPLE; 485.6 CONDUCTOR; 28.5-107.5 HANGER; 28.8-30.9 HANGER; 26.4-27.7 HANGER; 25.6 KUP PROD KB-Grd (ft) RR Date 5/15/2001 Other Elev… 2P-417 ... TD Act Btm (ftKB) 6,008.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037500 Wellbore Status PROD Max Angle & MD Incl (°) 8.79 MD (ftKB) 2,442.68 WELLNAME WELLBORE2P-417 Annotation Last WO: End DateH2S (ppm) 40 Date 11/2/2014 Comment SSSV: NIPPLE ϮWͲϰϭϳϭϱĂůĐƵůĂƚĞĚWdKΛϮϴϱϰ͛Z<^^ŚŽĞΛϮϯϴϮ͛Z</WΛϮϰϴϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϮϯϬ͛Z<WƵƚΛϮϰϯϮ͛Z<ϴϬdŽƉΛϮϰϵϬ͛Z<ϴϬĂƐĞΛϯϰϯϬ͛Z< 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6008'feet 5412', 5465'feet true vertical 5995' feet 5399', 5452' feet Effective Depth measured 5412'feet 5303'feet true vertical 5399' feet 5291' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 5305' MD 5293' TVD Packers and SSSV (type, measured and true vertical depth) 5303' MD N/A 5291' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Meltwater Oil Pool-Suspended 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker 80-40 Seal Assembly SSSV: None Dusty Freeborn dusty.freeborn@conocophillips.com (907) 265-6218Staff Project Engineer 5495-5515' 5482-5502' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 107' ~ ~~ Suspended ~~ ~ measured TVD 7" x 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-069 50-103-20375-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0373112 Kuparuk River Field/ Meltwater Oil Pool KRU 2P-417 Plugs Junk measured Length Production Liner Casing 5989'6002' 107'Conductor Surface Intermediate 16" 9-5/8" 2382' 2380' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:04 pm, Oct 17, 2024 Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU =Well Integrity and Intervention, E=Dusty.Freeborn@ conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2024.10.16 14:59:15-08'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 5,412.0 2P-417 3/17/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Tbg Cut 2P-417 4/3/2024 bworthi1 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 28.5 107.5 107.5 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 2,381.7 2,380.3 40.00 L-80 BTC-ABM PRODUCTION 7"x4.5" @ 5325" 7 6.28 26.4 6,002.2 5,989.5 26.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth 5,305.4 Set Depth 5,292.8 String Max No 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 25.6 25.6 0.12 HANGER 8.000 FMC GEN V TUBING HANGER 4.500 485.6 485.5 0.52 NIPPLE 5.570 CAMCO DB-6 NIPPLE CAMCO DB-6 3.875 2,219.9 2,219.5 4.76 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 3,603.0 3,590.7 3.49 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 4,573.0 4,560.4 0.50 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,127.8 5,115.2 0.43 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,179.0 5,166.4 0.35 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,230.1 5,217.5 0.35 SLEEVE 5.625 BAKER CMU SLIDING SLEEVE w/NO GO CAMCO PROFILE BAKER CMU 3.810 5,256.9 5,244.2 0.35 NIPPLE 5.000 CAMCO DB-6 NIPPLE w/NO GO PROFILE CAMCO DB-6 3.750 5,302.6 5,290.0 0.28 LOCATOR 5.125 BAKER LOCATOR BAKER 3.875 5,303.4 5,290.8 0.28 SEAL 4.000 BAKER 80-40 SEAL ASSY BAKER 80-40 3.875 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) 2,650.0 2,645.5 8.59 CUT WELLTEC MECHANICAL TBG CUT AT 2650' RKB 4/3/2024 3.958 5,200.0 5,187.4 0.35 TUBING PUNCH 3' TUBING PUNCH, 2", 7 GRAM, 18 0.61" HOLES OWEN 3/25/2024 3.958 5,465.0 5,452.4 0.26 PLUG Set TTS CIBP 10/7/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,219.9 2,219.5 4.76 1 GAS LIFT SOV BK 1 0.0 3/20/2024 Shear ed 3/30/2 4 0.000 3,603.0 3,590.7 3.49 2 GAS LIFT DMY BK 1 0.0 8/15/2001 0.000 4,573.0 4,560.4 0.50 3 GAS LIFT DMY BK 1 0.0 12/12/2001 0.000 5,127.8 5,115.2 0.43 4 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 5,179.0 5,166.4 0.35 5 GAS LIFT DMY BK 1 0.0 2/19/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 2P- 417 12/14/2001 6.0 IPERF 3.38" HSD Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,495.0 5,515.0 1 FRAC 12/14/2001 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,412.0 5,465.0 5,399.4 5,452.4 Cement Plug Dump bailed cement with Slickline on top of CIBP 12/17/2023 3,700.0 4,950.0 3,687.6 4,937.4 Intermediate String 1 Cement PUMPED 51 BBLS OF 15.8 PPG CLSS G CEMENT FOR INTERMEDIATE BALANCED PLUG. 3/30/2024 2P-417, 9/25/2024 11:50:16 AM M D (ft KB ) -1,175.5 -1,167.7 -1,110.2 -1,077.4 -1,018.4 -927.8 -893.0 0.0 26.2 28.5 30.8 75.1 107.9 499.3 2,219.8 2,232.3 2,304.5 2,381.6 2,430.1 2,650.9 3,603.0 3,615.5 4,448.2 4,573.2 4,585.6 5,120.7 5,134.2 5,172.2 5,185.4 5,192.3 5,203.1 5,230.0 5,256.9 5,264.8 5,296.6 5,303.5 5,305.4 5,325.5 5,334.3 5,412.1 5,423.9 5,466.9 5,515.1 5,527.9 5,549.9 5,907.8 6,002.3 Vertical schematic (actual) T-7 (final) T-4.1 (fi T-4.2 (fi T-3 (final) T-3.1 (fi T-2 (final) FLOAT SHOE; 6,000.4-6,002.2; 1.74; 3- 12; 4.500; 3.958 CASING; 5,907.8-6,000.4; 92.67; 3-11; 4.500; 3.958 FLOAT COLLAR; 5,906.3-5,907.8; 1.44; 3-10; 4.500; 3.958 CASING; 5,334.5-5,906.3; 571.84; 3-9; 4.500; 3.958 IPERF; 5,495.0-5,515.0; 12/14/2001 CASING XO THREAD; 5,331.4-5,334.5; 3.12; 3-8; 4.500; 3.958 CASING PUP; 5,325.6-5,331.4; 5.75; 3- 7; 4.500; 3.958 XO Reducing; 5,324.8-5,325.6; 0.83; 3- 6; 7.000; 3.958 CSR; 5,305.4-5,324.8; 19.37; 3-5; 6.250; 4.750 CASING XO THREAD; 5,304.4-5,305.4; 1.04; 3-4; 7.000; 6.276 SEAL; 5,303.4-5,305.4; 2.00; 1-35; 4.000; 3.875 LOCATOR; 5,302.6-5,303.4; 0.80; 1-34; 5.125; 3.875 CASING PUP; 5,296.2-5,304.4; 8.20; 3- 3; 7.000; 6.276 TUBING PUP; 5,296.5-5,302.6; 6.10; 1- 33; 4.500; 3.958 TUBING; 5,264.8-5,296.5; 31.74; 1-32; 4.500; 3.958 TUBING PUP; 5,258.4-5,264.8; 6.41; 1- 31; 4.500; 3.958 NIPPLE; 5,256.9-5,258.4; 1.51; 1-30; 5.000; 3.750 TUBING PUP; 5,234.7-5,256.8; 22.17; 1-29; 4.500; 3.958 SLEEVE; 5,230.1-5,234.7; 4.57; 1-28; 5.625; 3.810 TUBING PUP; 5,224.0-5,230.1; 6.10; 1- 27; 4.500; 3.958 TUBING; 5,192.2-5,224.0; 31.83; 1-26; 4.500; 3.958 TUBING PUP; 5,185.5-5,192.2; 6.70; 1-25; 4.500; 3.958 GAS LIFT; 5,179.0-5,185.5; 6.50; 1-24; 5.984; 3.938 TUBING PUP; 5,172.2-5,179.0; 6.80; 1-23; 4.500; 3.958 TUBING; 5,140.4-5,172.2; 31.76; 1-22; 4.500; 3.958 TUBING PUP; 5,134.3-5,140.4; 6.10; 1- 21; 4.500; 3.958 GAS LIFT; 5,127.8-5,134.3; 6.50; 1-20; 5.984; 3.938 TUBING PUP; 5,120.9-5,127.8; 6.96; 1-19; 4.500; 3.958 TUBING; 4,585.6-5,120.9; 535.28; 1-18; 4.500; 3.958 TUBING PUP; 4,579.5-4,585.6; 6.08; 1- 17; 4.500; 3.958 GAS LIFT; 4,573.0-4,579.5; 6.50; 1-16; 5.984; 3.938 TUBING PUP; 4,566.2-4,573.0; 6.85; 1- 15; 4.500; 3.958 TUBING; 3,615.6-4,566.2; 950.55; 1-14; 4.500; 3.958 TUBING PUP; 3,609.5-3,615.6; 6.14; 1-13; 4.500; 3.958 GAS LIFT; 3,603.0-3,609.5; 6.50; 1-12; 5.984; 3.938 TUBING PUP; 3,596.1-3,603.0; 6.89; 1- 11; 4.500; 3.958 TUBING; 2,232.4-3,596.1; 1,363.67; 1-10; 4.500; 3.958 PROD CASING; 27.7-5,296.2; 5,268.52; 3-2; 7.000; 6.276 FLOAT SHOE; 2,380.0-2,381.7; 1.75; 2-5; 9.625; 8.835 SURFACE; 2,304.6-2,380.0; 75.36; 2-4; 9.625; 8.835 FLOAT COLLAR; 2,302.9-2,304.6; 1.65; 2-3; 9.625; 8.835 TUBING PUP; 2,226.3-2,232.4; 6.06; 1-9; 4.500; 3.958 GAS LIFT; 2,219.9-2,226.3; 6.47; 1-8; 5.984; 3.938 TUBING PUP; 2,213.0-2,219.9; 6.85; 1- 7; 4.500; 3.958 TUBING; 499.2-2,213.0; 1,713.80; 1-6; 4.500; 3.958 SURFACE; 30.9-2,302.9; 2,272.01; 2-2; 9.625; 8.835 NIPPLE; 485.6-499.2; 13.63; 1-5; 5.570; 3.875 TUBING; 75.0-485.6; 410.61; 1-4; 4.500; 3.958 CONDUCTOR; 28.5-107.5; 79.00; 1-1; 16.000; 15.062 TUBING PUP; 57.5-75.0; 17.48; 1-3; 4.500; 3.958 TUBING; 26.2-57.5; 31.32; 1-2; 4.500; 3.958 HANGER; 28.8-30.9; 2.14; 2-1; 12.000; 8.835 HANGER; 26.4-27.7; 1.25; 3-1; 10.000; 7.000 HANGER; 25.6-26.2; 0.60; 1-1; 8.000; 4.500 KUP PROD KB-Grd (ft) RR Date 5/15/2001 Other Elev 2P-417 ... TD Act Btm (ftKB) 6,008.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037500 Wellbore Status PROD Max Angle & MD Incl (°) 8.79 MD (ftKB) 2,442.68 WELLNAME WELLBORE2P-417 Annotation Last WO: End DateH2S (ppm) 40 Date 11/2/2014 Comment SSSV: NIPPLE Reviewed By: P.I. Suprv Comm ________ :ZϭϭͬϮϳͬϮϬϮϰ /ŶƐƉĞĐƚEŽ͗ƐƵƐϮϰϭϬϬϭϭϯϯϰϱϯ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϵͬϯϬͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗ƌŝĂŶŝdžďLJ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨLJŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϯͬϭϳͬϮϬϮϰ η ϯϮϯͲϰϬϱ dƵďŝŶŐ͗Ϭ /͗Ϭ K͗ϱϴϬ KƉĞƌĂƚŽƌ͗ŽŶŽĐŽWŚŝůůŝƉƐůĂƐŬĂ͕/ŶĐ͘ KƉĞƌĂƚŽƌZĞƉ͗DĂƚƚDŝůůĞƌ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϵͬϮϳͬϮϬϮϰ dLJƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗/ŶŝƚŝĂů tĞůůEĂŵĞ͗<hWZh<Z/shD >dϮWͲϰϭϳ WĞƌŵŝƚEƵŵďĞƌ͗ϮϬϭϬϲϵϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ 'ŽŽĚ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ 'ŽŽĚ ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ 'ŽŽĚ ŽŵŵĞŶƚƐ >ŽĐĂƚŝŽŶǀĞƌŝĨŝĞĚďLJƵƐŝŶŐWĂĚDĂƉ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ WŚŽƚŽĂƚƚĂĐŚĞĚ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗^ƵŶĚƌLJ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ tĞĚŶĞƐĚĂLJ͕EŽǀĞŵďĞƌϮϳ͕ϮϬϮϰ 9 9 9 9 2024-0930_Suspend_KRU_2P-417_photos_bb Page 1 of 1 Suspended Well Inspection – KRU 2P-417 PTD 2010690 AOGCC Inspection Rpt # susBDB241001133453 Photos by AOGCC Inspector B. Bixby 9/30/2024 ORIGINATED TRANSMITTAL DATE: 6/26/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4744 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Meltwater PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4744 2P-417 501032037500 Tubing Punch 25-Mar-2024 RECIPIENTS Conoco Phillips 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 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 201-069 T39056 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 15:17:48 -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 0 201-069 T38913 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 14:54:46 -08'00' 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:6008 ft MD Lease No.:ADL 373112 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 107 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 2382 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:7" x 4 1/2"O.D. Shoe@ 6002 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:4 1/2"O.D. Tail@ 5305 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 5000 ft 3580 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1730 1645 1624 IA 1723 1645 1623 OA 460 458 458 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Ryan Moore Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Travel to Kuparuk 2P-417 to witness tag and test of the intermediate balanced cement plug. I met with Conoco representative Ryan Moore and received all appropriate documentation. The wireline unit utilized a digital depth recorder that was correlated to RKB. The tool string had a 300 lb. weight bar and flapper bailer. They tagged before and after the MIT. Both tags were at 3580 ft. The cement samples of both runs were packed semi-hard cement. Aprdil 2, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-417 ConocoPhillips Alaska Inc. PTD 2010690; Sundry 324-147 Well Schematic Test Data: P Casing Removal: rev. 3-24-2022 2024-0402_Plug_Verification_KRU_2P-417_ss Plug Verification – KRU 2P-417 (PTD 2010690) Well Schematic 4/2/2024 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 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: 225' 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' 9.625" L-80 2381' 7" L-80 5289' 4.5" L-80 5989' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above8.5" TUBING RECORD 420 sx Class G8.5" 5305'4.5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 3/17/2024 50-103-20375-00-00 KRU 2P-417 ADL0373112 878' FNL, 2187' FWL, Sec. 17, T8N, R7E, UM 863' FNL, 2899' FEL, Sec. 17, T8N, R7E, UM ALK 4998 4/27/2001 6008' MD/ 5995' TVD 5412' MD/ 5399' TVD P.O. Box 100360, Anchorage, AK 99510-0360 444147 5868998 875' FNL, 2251' FWL, Sec. 17, T8N, R7E, UM 9. Ref Elevations: KB: 27.5' CASING WT. PER FT.GRADE 5/13/2001 CEMENTING RECORD 5869000 1455' MD/ 1455' TVD SETTING DEPTH TVD 5869010 TOP HOLE SIZE AMOUNT PULLED 444211 444340 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 Kuparuk River Field/ Meltwater- Suspended BOTTOM SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 42" 12.25" 9 cu yds High Early Surface 380 sx AS3 Lite, 190 sx LiteCRETE 12.6# Surface 5302' 2382'Surface Surface 26# 6002' Surface 5289' 62.5# 40# 108' Surface 5302' SUSPENDED 5495-5515' MD and 5482-5502' TVD Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: 5412-5465' 16 gal Cement on top of CBIP @5465' Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 14. Permit to Drill Number / Sundry: 201-069/ 323-405 By James Brooks at 8:30 am, Mar 20, 2024 Suspended 3/17/2024 JSB RBDMS JSB 040424 xGDSR-4/23/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1455' 1455' 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 Authorized Title: 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. 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 N/A - Suspended N/A - Suspended INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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=USReason: I am the author of this document Location:Date: 2024.03.19 15:03:07-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB Tag TOC 5,421.0 2P-417 12/17/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled vlv, circ out, set DMY vlv 2P-417 2/19/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/19/2010 ninam 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 28.5 107.5 107.5 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 2,381.7 2,380.3 40.00 L-80 BTC-ABM PRODUCTION 7"x4.5" @ 5325" 7 6.28 26.4 6,002.2 5,989.5 26.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth … 5,305.4 Set Depth … 5,292.8 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 25.6 25.6 0.12 HANGER 8.000 FMC GEN V TUBING HANGER 4.500 485.6 485.5 0.52 NIPPLE 5.570 CAMCO DB-6 NIPPLE CAMCO DB-6 3.875 2,219.9 2,219.5 4.76 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 3,603.0 3,590.7 3.49 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 4,573.0 4,560.4 0.50 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,127.8 5,115.2 0.43 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,179.0 5,166.4 0.35 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,230.1 5,217.5 0.35 SLEEVE 5.625 BAKER CMU SLIDING SLEEVE w/NO GO CAMCO PROFILE BAKER CMU 3.810 5,256.9 5,244.2 0.35 NIPPLE 5.000 CAMCO DB-6 NIPPLE w/NO GO PROFILE CAMCO DB-6 3.750 5,302.6 5,290.0 0.28 LOCATOR 5.125 BAKER LOCATOR BAKER 3.875 5,303.4 5,290.8 0.28 SEAL 4.000 BAKER 80-40 SEAL ASSY BAKER 80-40 3.875 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) 5,465.0 5,452.4 0.26 PLUG Set TTS CIBP 10/7/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,219.9 2,219.5 4.76 1 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 3,603.0 3,590.7 3.49 2 GAS LIFT DMY BK 1 0.0 8/15/2001 0.000 4,573.0 4,560.4 0.50 3 GAS LIFT DMY BK 1 0.0 12/12/2001 0.000 5,127.8 5,115.2 0.43 4 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 5,179.0 5,166.4 0.35 5 GAS LIFT DMY BK 1 0.0 2/19/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 2P- 417 12/14/2001 6.0 IPERF 3.38" HSD Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,495.0 5,515.0 1 FRAC 12/14/2001 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 5,412.0 5,465.0 5,399.4 5,452.4 Cement Plug Dump bailed cement with Slickline on top of CIBP 12/17/2023 2P-417, 3/18/2024 4:25:34 PM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 5325"; 26.4-6,002.2 IPERF; 5,495.0-5,515.0 FRAC; 5,495.0 PLUG; 5,465.0 Cement Plug; 5,412.0 ftKB GAS LIFT; 5,179.0 GAS LIFT; 5,127.8 GAS LIFT; 4,573.0 GAS LIFT; 3,603.0 SURFACE; 28.8-2,381.7 GAS LIFT; 2,219.9 NIPPLE; 485.6 CONDUCTOR; 28.5-107.5 KUP PROD KB-Grd (ft) RR Date 5/15/2001 Other Elev… 2P-417 ... TD Act Btm (ftKB) 6,008.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037500 Wellbore Status PROD Max Angle & MD Incl (°) 8.79 MD (ftKB) 2,442.68 WELLNAME WELLBORE2P-417 Annotation Last WO: End DateH2S (ppm) 40 Date 11/2/2014 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 10/4/2023 CHANGE WELL TYPE DRIFT & TAG BTM & 5529' SLM. BRUSH & FLUSH TBG DOWN TO 5500' RKB. DRIFT DUMMY CIBP DOWN TO 5500' RKB, READY TO LOAD WELL WITH INHIBITED SEAWATER. 10/5/2023 CHANGE WELL TYPE LOAD WELL W/ 55 BBLS OF INHIBITED SEAWATER. FREEZE PROTECT W/ 30 BBLS DIESEL. READY FOR RELAY & CIBP. 10/6/2023 CHANGE WELL TYPE SET 3.50" TTS CIBP MID ELEMENT @ 5465 RKB. MIT-T TO 2500 PSI PASSED. READY FOR SLICKLINE TO DUMP BAIL CEMENT. 10/7/2023 CHANGE WELL TYPE DUMP BAIL APPROX ~4 GAL OF CEMENT ON TOP OF CIBP @ 5465' RKB, JOB IN PROGRESS 10/8/2023 CHANGE WELL TYPE DUMP BAIL APPROX ~ 12 GAL OF CEMENT ON TOP OF CIBP @ 5465' RKB, JOB IN PROGRESS 12/17/2023 CHANGE WELL TYPE DRIFT 3.77" CENT TO DB-6 NIP @ 5256' RKB FOR 19' CF. TAG TOC @ 5421' RKB, EST 44' OF CEMENT ON CIBP @ 5465' RKB. READY FOR SW TAG TOC & MIT-T. 2/17/2024 CHANGE WELL TYPE BRUSH TBG DOWN TO TOC @ 5421' RKB, SET CATCHER ON TOC @ 5421' RKB, PULL 1" GLV FROM STA 5 @ 5179' RKB, JOB IN PROGRESS 2/18/2024 CHANGE WELL TYPE CIRC OUT 198 BBLS CISW, FOLLOWED BY 68 BBLS LEPD, PERFORM CMIT TxIA TO 2500 PSI (FAILED) JOB IN PROGRESS 2/18/2024 CHANGE WELL TYPE CIRC OUT PUMPED 197 BBLS SEAWATER AND 68 BBLS DSL FOR FP INTO TBG TAKING RETURNS UP IA TO OT. UTUBED TBG/IA CMIT-TXIA FAILED @ TBG/IA 2450/2475 PSI. PUMPED 2.2 BBLS INTO TBG/IA TO ACHIEVE MAX APPLIED PRESSURE OF TBG/IA - 2500/2540 PSI. 1ST 15 MIN, TBG/IA LOST 25/40 PSI. 2ND 15 MIN, TBG/IA LOST 15/10 PSI. 3RD 15 MIN, TBG/IA LOST 10/15 PSI. BLED BACK .8 BBLS 2/19/2024 CHANGE WELL TYPE CMITxIA TO 2500 PSI (PASSED) SET 1" DUMMY VALVE IN STA 5 @ 5179' RKB, PERFORM MITT TO 2500 PSI (PASSED), PULLED 4.5" CATCHER FROM TOC @ 5421' RKB 2/28/2024 CHANGE WELL TYPE (SUSPEND WELL) FT LDS/GN'S, T POT (PASS) T PPPOT (PASS) IC POT (PASS) IC PPPOT (PASS) 3/17/2024 CHANGE WELL TYPE STATE WITNESS (AUSTIN MCLEOD) TAG TOC @ 5412' RKB (GOOD SAMPLE), STATE WITNESS MITT TO 2010 PSI (PASSED). READY FOR NEXT STEPS. 2P-417 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:NA Rig Elevation:NA Total Depth:6008 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A: Conductor:16"O.D. Shoe@ 107 Feet Csg Cut@ NA Feet Surface:9-5/8"O.D. Shoe@ 2382 Feet Csg Cut@ NA Feet Intermediate:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production:7"x4-1/2"O.D. Shoe@ 6002 Feet Csg Cut@ NA Feet Liner:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing:4-1/2"O.D. Tail@ 5305 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 5465 ft 5412 ft 8.6/6.9 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2010 1980 1970 IA 1480 1480 1470 OA 300 300 300 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to KRU 2P to witness the tag and pressure test of the bottom, zone isolating cement plug that had been dumped bailed on 12/17/2023 on top of a cast iron bridge plug (CIBP) inside the wells 4-1/2 inch production string. CIBP was set at 5465 ft MD putting it 30 ft above the top perforation. They ran in the hole with generic 2-1/2 inch slickline bailer string and tagged at 5412 ft MD (max inclination on well 8°) with multiple jars down. At surface we found cement in the bailer. Then achieved a passing mechanical integrity test of the plug/production string. No issues with this inspection. March 17, 2024 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-417 ConocoPhillips Alaska, Inc. PTD 2010690; Sundry 323-405 none Test Data: P Casing Removal: Brent Rogers Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0317_Plug_Verification_KRU_2P-417_am 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): 6008' 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 (907) 263-3718 Well Interventions Engineer KRU 2P-417 5995' 5465' 5452' 1800 psi 5465' N/A 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5303' MD and 5291' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 201-069 P.O. Box 100360, Anchorage, AK 99510 50-103-20375-00-00 Kuparuk River Field Meltwater Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst 5305' MD 107' 2380' 107' 2382' 5989'6002' 16" 9-5/8" 79' 2353' 5495-5515' 5976' 5482-5502' 7" x 4-1/2" Perforation Depth TVD (ft): 3/1/2024 4-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 3:13 pm, Mar 06, 2024 324-147 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: 2024.03.05 15:02:57-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor DSR-3/6/24 X BOP test to 2500 psig; Annular preventer test to 2500 psig. A variance to 20 AAC 25.112(a)(1)(A) is granted. Cement is not required from 100' below the base of the C-80 to 100' above the top of the C-80. The variance is granted to allow an equally effective plug which includes the placement of a cement plug from ~50' MD below the surface casing shoe in the open hole to 150' MD into the surface casing. (20 AAC 25.112(i)) A variance to the cement logging required in Other Order 196 is granted. Cement logging is not required. AOGCC inspection required after cutoff and before remedial cementing X X SFD 3/21/2024 10-407 VTL 3/25/2024 (X-Over at 5302' MD) SFD JLC 3/22/2024 Est. TOC @ ~3,820' MD SFD Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB Tag TOC 5,421.0 2P-417 12/17/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled vlv, circ out, set DMY vlv 2P-417 2/19/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/19/2010 ninam 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 28.5 107.5 107.5 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 2,381.7 2,380.3 40.00 L-80 BTC-ABM PRODUCTION 7"x4.5" @ 5325" 7 6.28 26.4 6,002.2 5,989.5 26.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth 5,305.4 Set Depth 5,292.8 String Max No 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 25.6 25.6 0.12 HANGER 8.000 FMC GEN V TUBING HANGER 4.500 485.6 485.5 0.52 NIPPLE 5.570 CAMCO DB-6 NIPPLE CAMCO DB-6 3.875 2,219.9 2,219.5 4.76 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 3,603.0 3,590.7 3.49 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 4,573.0 4,560.4 0.50 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,127.8 5,115.2 0.43 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,179.0 5,166.4 0.35 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,230.1 5,217.5 0.35 SLEEVE 5.625 BAKER CMU SLIDING SLEEVE w/NO GO CAMCO PROFILE BAKER CMU 3.810 5,256.9 5,244.2 0.35 NIPPLE 5.000 CAMCO DB-6 NIPPLE w/NO GO PROFILE CAMCO DB-6 3.750 5,302.6 5,290.0 0.28 LOCATOR 5.125 BAKER LOCATOR BAKER 3.875 5,303.4 5,290.8 0.28 SEAL 4.000 BAKER 80-40 SEAL ASSY BAKER 80-40 3.875 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) 5,421.0 5,408.4 0.23 OTHER Dump bail cement on bridge plug. 10/8/2023 0.000 5,465.0 5,452.4 0.26 PLUG Set TTS CIBP 10/7/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,219.9 2,219.5 4.76 1 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 3,603.0 3,590.7 3.49 2 GAS LIFT DMY BK 1 0.0 8/15/2001 0.000 4,573.0 4,560.4 0.50 3 GAS LIFT DMY BK 1 0.0 12/12/2001 0.000 5,127.8 5,115.2 0.43 4 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 5,179.0 5,166.4 0.35 5 GAS LIFT DMY BK 1 0.0 2/19/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 2P- 417 12/14/2001 6.0 IPERF 3.38" HSD Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,495.0 5,515.0 1 FRAC 12/14/2001 0.0 0.00 0.00 2P-417, 2/20/2024 7:11:34 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 5325"; 26.4-6,002.2 IPERF; 5,495.0-5,515.0 FRAC; 5,495.0 PLUG; 5,465.0 OTHER; 5,421.0 GAS LIFT; 5,179.0 GAS LIFT; 5,127.8 GAS LIFT; 4,573.0 GAS LIFT; 3,603.0 SURFACE; 28.8-2,381.7 GAS LIFT; 2,219.9 NIPPLE; 485.6 CONDUCTOR; 28.5-107.5 KUP PROD KB-Grd (ft) RR Date 5/15/2001 Other Elev 2P-417 ... TD Act Btm (ftKB) 6,008.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037500 Wellbore Status PROD Max Angle & MD Incl (°) 8.79 MD (ftKB) 2,442.68 WELLNAME WELLBORE2P-417 Annotation Last WO: End DateH2S (ppm) 40 Date 11/2/2014 Comment 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: ___________________ 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): 6008' 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 (907) 263-3718 Well Interventions Engineer KRU 2P-417 5995' 5465' 5452' 1800 psi 5465' N/A 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 5303' MD and 5291' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 201-069 P.O. Box 100360, Anchorage, AK 99510 50-103-20375-00-00 Kuparuk River Field Meltwater Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst 5305' MD 107' 2380' 107' 2382' 5989'6002' 16" 9-5/8" 79' 2353' 5495-5515' 5976' 5482-5502' 7" x 4-1/2" Perforation Depth TVD (ft): 3/1/2024 4-1/2" Packer: Baker 80-40 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-090 By Kayla Junke at 2:35 pm, Feb 15, 2024 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: 2024.02.15 11:57:49-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor DSR-2/15/24SFD 2/21/2024 Abandon Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB Tag TOC 5,421.0 2P-417 12/17/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag TOC 2P-417 12/17/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/19/2010 ninam 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 28.5 107.5 107.5 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 2,381.7 2,380.3 40.00 L-80 BTC-ABM PRODUCTION 7"x4.5" @ 5325" 7 6.28 26.4 6,002.2 5,989.5 26.00 L-80 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.6 Set Depth 5,305.4 Set Depth 5,292.8 String Max No 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 25.6 25.6 0.12 HANGER 8.000 FMC GEN V TUBING HANGER 4.500 485.6 485.5 0.52 NIPPLE 5.570 CAMCO DB-6 NIPPLE CAMCO DB-6 3.875 2,219.9 2,219.5 4.76 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 3,603.0 3,590.7 3.49 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 4,573.0 4,560.4 0.50 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,127.8 5,115.2 0.43 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,179.0 5,166.4 0.35 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,230.1 5,217.5 0.35 SLEEVE 5.625 BAKER CMU SLIDING SLEEVE w/NO GO CAMCO PROFILE BAKER CMU 3.810 5,256.9 5,244.2 0.35 NIPPLE 5.000 CAMCO DB-6 NIPPLE w/NO GO PROFILE CAMCO DB-6 3.750 5,302.6 5,290.0 0.28 LOCATOR 5.125 BAKER LOCATOR BAKER 3.875 5,303.4 5,290.8 0.28 SEAL 4.000 BAKER 80-40 SEAL ASSY BAKER 80-40 3.875 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) 5,421.0 5,408.4 0.23 OTHER Dump bail cement on bridge plug. 10/8/2023 0.000 5,465.0 5,452.4 0.26 PLUG Set TTS CIBP 10/7/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,219.9 2,219.5 4.76 1 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 3,603.0 3,590.7 3.49 2 GAS LIFT DMY BK 1 0.0 8/15/2001 0.000 4,573.0 4,560.4 0.50 3 GAS LIFT DMY BK 1 0.0 12/12/2001 0.000 5,127.8 5,115.2 0.43 4 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 5,179.0 5,166.4 0.35 5 GAS LIFT DMY BK 1 0.0 2/4/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 2P- 417 12/14/2001 6.0 IPERF 3.38" HSD Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,495.0 5,515.0 1 FRAC 12/14/2001 0.0 0.00 0.00 2P-417, 2/9/2024 9:49:12 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 5325"; 26.4-6,002.2 FRAC; 5,495.0 IPERF; 5,495.0-5,515.0 PLUG; 5,465.0 OTHER; 5,421.0 GAS LIFT; 5,179.0 GAS LIFT; 5,127.8 GAS LIFT; 4,573.0 GAS LIFT; 3,603.0 SURFACE; 28.8-2,381.7 GAS LIFT; 2,219.9 NIPPLE; 485.6 CONDUCTOR; 28.5-107.5 KUP PROD KB-Grd (ft) RR Date 5/15/2001 Other Elev 2P-417 ... TD Act Btm (ftKB) 6,008.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032037500 Wellbore Status PROD Max Angle & MD Incl (°) 8.79 MD (ftKB) 2,442.68 WELLNAME WELLBORE2P-417 Annotation Last WO: End DateH2S (ppm) 40 Date 11/2/2014 Comment SSSV: NIPPLE 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. You don't often get email from katherine.oconnor@conocophillips.com. Learn why this is important From:Davies, Stephen F (OGC) To:O"Connor, Katherine Cc:Loepp, Victoria T (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]RE: KRU 2P-415A (Permit 201-226; Sundry 324-144) - Question Date:Monday, March 18, 2024 1:17:37 PM Thank you, Katherine. The erroneous calculated cement top of 5,782 MD is based on 62-1/2 barrels of cement, 6-3/4 hole diameter, 30% hole washout, and a production casing string consisting of only 5-1/2 pipe (forgetting that a significant portion of that production casing string actually consists of 3-1/2 pipe). Could you please check the calculated TOCs on schematic drawings that accompany all future Sundry Applications? Thanks for your help, Steve Davies AOGCC From: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Sent: Monday, March 18, 2024 12:54 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 2P-415A (Permit 201-226; Sundry 324-144) - Question Hi Steve I just pulled the drilling record, and confirmed there was 62.5 bbls of cement pumped. Using that and the 6-3/4 hole size, I calculate TOC outside the casing being ~7000 KB depending on how many digits I carry through in my calcs. So unsure how whomever made the schematic got to 5782 KB. Thanks Katherine Katherine OConnor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, March 18, 2024 12:09 PM To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: KRU 2P-415A (Permit 201-226; Sundry 324-144) - Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Katherine, Im reviewing CPAIs revised Sundry Application for KRU 2P-415A. This is a minor point, but to ensure that AOGCCs well records are accurate could you please confirm the calculated top of cement for the 5.5 x 3.5 production casing string that is shown on the wellbore schematic drawing as 5,782 MD? Cheers and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field & Processed 20ͲNovͲ23 0 1 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field & Processed 21ͲNovͲ23 0 1 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field & Processed 7ͲJanͲ23 0 1 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 72PͲ415A 50Ͳ103Ͳ20383Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 7ͲOctͲ23 0 1 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲOctͲ23 0 1 10 2VͲ05 50Ͳ029Ͳ21051Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 19ͲJulͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 1C-22 PTD:202-222 T38179 2.1D-38 PTD: 200-077 T38180 3. 1J-107 PTD: 207-107 T38181 4. 1L-03A PTD: 199-037 T38182 5. 2L-313 PTD: 198-219 T38183 6. 2M-24 PTD: 192-050 T38184 7. 2P-415A PTD: 201-226 T38185 8. 2P-417 PTD: 201-069 T38186 9. 2P-420 PTD: 201-182 T38187 10. 2V-05 PTD: 183-176 T38188 12/1/2023 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:25:47 -09'00' 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): 6008'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 (907) 263-3718 Well Interventions Engineer KRU 2P-417 5995' 6008' 5995' None N/A 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 AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 2303' MD and 5291' TVD 486' MD and 485' TVD Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 201-069 P.O. Box 100360, Anchorage, AK 99510 50-103-20375-00-00 Kuparuk River Field Meltwater Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY N/A -Suspended TVD Burst 5305' MD 107' 2380' 107' 2382' 5989'6002' 16' 9-5/8" 79' 2353' 5495-5515' 5976' 5482-5502' 7" x 4-1/2" Perforation Depth TVD (ft): 8/3/2023 4-1/2" Packer: Baker 80-40 Seal Assembly SSSV: Camco DB-6 Nipple Perforation Depth MD (ft): L-80 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 3:56 pm, Jul 18, 2023 323-405 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: 2023.07.18 12:59:00-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor December 31, 2024 X DSR-7/19/23MDG 7/24/2023 X 10-407 VTL 7/26/2023GCW 07/26/2023JLC 7/26/2023 07/26/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.26 19:45:26 -06'00' RBDMS JSB 072823 2P-417 Suspension Date Wrien: 11 July 2023 Execu on Date: August 3, 2023 Prepared by: Katherine O’Connor Background & Objecve KRU 2P-417 was a producer that has been shut in since October 2021. 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 2/3/2020 = 2348 RKB @ 5482’ TVD MASP = 1800 psi Last tag 5528’ RKB on 2/15/21 Procedure Wireline & Pumping 1. Fluid pack tubing and IA with corrosion inhibited seawater and freeze protect 2. Set CIBP @ ±5,465’ RKB (must be set within 50’ of the top of perforations) 3. Perform CMIT-TxIA to 2500 psi, record results 4. Perform MIT-T to 2500 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. 5435’ 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 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled DH Choke 2P-417 2/16/2021 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/19/2010 ninam 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 28.5 107.5 107.5 62.50 H-40 WELDED SURFACE 9 5/8 8.83 28.8 2,381.7 2,380.3 40.00 L-80 BTC-ABM PRODUCTION 7"x4.5" @ 5325" 7 6.28 26.4 6,002.2 5,989.5 26.00 L-80 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.6 Set Depth … 5,305.4 Set Depth … 5,292.8 String Ma… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 25.6 25.6 0.12 HANGER 8.000 FMC GEN V TUBING HANGER 4.500 485.6 485.5 0.52 NIPPLE 5.570 CAMCO DB-6 NIPPLE CAMCO DB-6 3.875 2,219.9 2,219.5 4.76 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 3,603.0 3,590.7 3.49 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 4,573.0 4,560.4 0.50 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,127.8 5,115.2 0.43 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,179.0 5,166.4 0.35 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 5,230.1 5,217.5 0.35 SLEEVE 5.625 BAKER CMU SLIDING SLEEVE w/NO GO CAMCO PROFILE BAKER CMU 3.810 5,256.9 5,244.2 0.35 NIPPLE 5.000 CAMCO DB-6 NIPPLE w/NO GO PROFILE CAMCO DB-6 3.750 5,302.6 5,290.0 0.28 LOCATOR 5.125 BAKER LOCATOR BAKER 3.875 5,303.4 5,290.8 0.28 SEAL 4.000 BAKER 80-40 SEAL ASSY BAKER 80-40 3.875 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,219.9 2,219.5 4.76 1 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 3,603.0 3,590.7 3.49 2 GAS LIFT DMY BK 1 0.0 8/15/2001 0.000 4,573.0 4,560.4 0.50 3 GAS LIFT DMY BK 1 0.0 12/12/2001 0.000 5,127.8 5,115.2 0.43 4 GAS LIFT DMY BK 1 0.0 5/15/2001 0.000 5,179.0 5,166.4 0.35 5 GAS LIFT DMY BK 1 0.0 2/4/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 2P- 417 12/14/2001 6.0 IPERF 3.38" HSD Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,495.0 5,515.0 1 FRAC 12/14/2001 0.0 0.00 0.00 IPERF; 5,495.0-5,515.0 FRAC; 5,495.0 GAS LIFT; 5,179.0 GAS LIFT; 5,127.8 GAS LIFT; 4,573.0 GAS LIFT; 3,603.0 SURFACE; 28.8-2,381.7 GAS LIFT; 2,219.9 NIPPLE; 485.6 CONDUCTOR; 28.5-107.5 E FROM: Sandra D. Lemke, ATO -704 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Core Photo well list DATE: 11/15/2019 North Slooe. Alaska ConocoPhillips TRANSMITTAL RECEIVEC.ao "09 NOV 15 2019 1 ys AOGCC TO: Meredith Guhl AOGCC 222 W. 71h Ave., Suite 100 Anchorage, Alaska 99501 Transmitted: M 2P-417 Care photos 3 1 4 4 5 94- 3S-16 Core Phctos 31444, )q Atlas 1 Core photos 3 1 4 4 3 5 CD2 -24 Core Photos 3 1 4 4 2 iy Cirque 3 Corr photos -T.O*u7- 12 Meltwater North 1 UV WL photos—T2_5(9(o0 P Shark Tooth 1 Core photos — '12-411449 2X 1004025835 Meftwater-N-1,pdf-'_25/9(,0 I-1004278632_3S-16.pdf 3 1 4 4 4 1D04282603_flendezvous-A.pof 3 1 4 4 6 Transmittal instructions: please promptly sign, scan, and e-mail to CC: Receipt: V t V Date: Alaska/IT-GGRE I C ocoPhil s Alaska I Office: 907 265 6947 Mobile 907 440.4512 • STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMMI ON r V APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved R -ogram r Suspend r Rug Fbrforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re - enter Susp. Well r Stimulate r Alter casing r Other:Cement shoe - P" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Developrnent Fj . Exploratory r 201 -069 • 3. Address: 6. A+ Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20375 - 00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Na e a • N ' ber: where ownership or landownership changes: Spacing Exception Required? Yes r No F • 2P-417 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0373112 - Kuparuk • i - r - Id / Itwater Oil Pool - 11. PRESENT WELL CONDITION ' , r Amy A Total depth MD (ft): Total Depth TVD (ft): Effective Depth Mo (ft): Effective Depth TVD (ft): Plugs,' eas ,,,): Junk (measured): 6008 - 5995 Casing • Length Size MD // T � )/D" Burst Collapse CONDUCTOR 79 16 108' W1'Q8' 1640 630 • SURFACE 2353 12 2382' t 2380' 5750 3090 PRODUCTION 5976 10 60 \ : 5990' 7240 5410 - . S e j Perforation Depth MD (ft): Perforation Depth TVD (ft): , Tubing Size: Tubing Grade: Tubing MD (ft): 5495 - 5515 5482 - 550 4.5 L - 80 5305 Packers and SSSV Type: P - ck - and - # ; C -ft) and TVD (ft) I VED PACKER = BAKER 80 -40 SEAL ASSY ' ' r' ER D 4 1% 1 3, TVD = 5291 SSSV = CAMCO "DB -6" NIPPLE M r = ' r D = 486 AUG 1 7 AOGCC 12. Attachments: Description Summary of Propos w\ � 7� ■ 13. ' Class after proposed work: Detailed Operations Program r BOP e h 1 � •loratory r Development ri - Service r 14. Estimated Date for Commencing Operations / ell St us after proposed work: 9/15/2012 ` \ Oil P Gas r WDSPL r Suspended r 16. Verbal Approval: Date' . NJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true a' . correct to the best of my knowledge. Contact: MJ Loveland /Martin Walters Printed Name Marti ' Walters Title: WI Proj Supervisor / , � r j' Phone: 659 -7043 Date: 8/15/12 Signature /7/4/ - G, l.�(.-'fS J Commission Use Only > (Z. / Sundry Number: Conditions of approval: Not Commission so that a representative may witness -- / • i Plug Integrity r BO.'' Test r Mechanical Integrity Test r Location Clearance r e' / > ' iL Other: Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ` / r j! �' V Form 10 -403 0S ' 161 Submit in Duplicate i <1; 2 Cb • • Iry • • ConocoPh i l ps Alaska P.O. BOX 100360 RECEN ED ANCHORAGE, ALASKA 99510 -0360 AUG 17 ?n,) August 15, 2012 AOGC Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2P -417, PTD 201 -069 surface casing cement shoe. Please call MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, 4 Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures • • ConocoPhillips Alaska, Inc. Kuparuk Well 2P-417 (PTD 201 -069) SUNDRY NOTICE 10 -403 REQUEST 08/15/12 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Meltwater well 2P -417 (201 -069). A surface casing cement shoe was not pumped at the time of original completion in 2001. The cement shoe is required to isolate the surface casing by production casing annulus (OA), from downhole formations above the producing zone. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for at minimum 1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 48 hrs on cement 4. MITOA to 1800 psi. 5. Submit 10 -404 to AOGCC. NSK Problem Well Supervisor 8/15/2012 KUP • 2P-417 • ConocoPhillips Awns Well Attributes Max Angle & MD TD AkI ka ItK Wel!bore API /UWI Field Name Well Status Inc' (°) MD (ftKB) Act Btm (ftKB) ,,,.„,, 501032037500 MELTWATER PROD 8,79 2,442.68 6,008.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date " "" SSSV: NIPPLE 30 10/28/2011 Last WO: 5/15/2001 Well Gonad - 21417, 1/30/2012 1011 42 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: ELMD 5,510.0 1/2/2009 Rev Reason: WELL REVIEW osborl 1/30/2012 -- Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (T... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 20 CONDUCTOR 16 15.062 28.5 107.5 107.5 62.50 H - 40 WELDED ea. I Nor y : Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.697 28.8 2,381.7 2,380.3 40.00 L-80 BTC -ABM Casing Description String 0... String ID ... Top (ftKB) Set Depth (T... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 26.4 6,002.2 5,989.5 26.00 L - BTC • 7 "x4.5" @ 5325" Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd Ate" TUBING 41/2 3.958 26.1 5,305.4 5,292.8 12.60 L -80 IBT ill Completion Details Top Depth II CONDUCTOR. (TVD) D) Top Inc! lncl No'... 28 -108 Top (ftKB) (RKB) (°) Item Description Comment ID ('n) 26.1 26.1 0.12 HANGER FMC GEN V TUBING HANGER 4.500 NIPPLE, 486 485.6 485.5 0.52 NIPPLE CAMCO DB-6 NIPPLE 3.875 5,230.1 5,217.5 0.35 SLEEVE BAKER CMU SLIDING SLEEVE w/NO GO CAMCO PROFILE 2.813 5256.9 5,244.2 0.35 NIPPLE CAMCO DB -6 NIPPLE w/NO GO PROFILE 3.750 . 4 5,302.6 5,290.0 0.14 LOCATOR BAKER LOCATOR 2.985 GAS LIFT. 5,303.4 5,290.8 0.14 SEAL BAKER 80-40 SEAL ASSY 2 .985 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (.h.. Type Comment 5,495.0 5,515.0 5,482.4 5,502.4 BERMUDA, 12/14/2001 6.0 IPERF 3.38" HSD 2P-417 Stimulations & Treatments ,,,,, V ? , o, A F iiiN v SURFACE, Bottom 29 -2,382 Min Top Max Btm Top Depth Depth Depth Depth (TVD) (ND) (ftKB) (MB) (RKB) (ftKB) Type Date Comment lit 5,495.0 5,515.0 5,482.4 5,502.4 FRAC 12/14/2001 BERMUDA FRAC, 213,000# 16/20 CARBOLITE, 12 PPA ON PERFS GAS LIFT, 3,503 _ Notes: General & Safety End Date Annotation 1 1/19/2010 NOTE: VIEW SCHEMATIC w /Alaska SChematic9.0 GAS LIFT, _ IC 4,573 11111111111111111 • GAS , , 28 5,1 T, GAS ,179 IIIFM 5,1 T, 1 • SLEEVE, 5,230 NIPPLE, 5,257 S MR MI LOCATOR. 5,303 I SEAL, 5,303 Mandrel Details Top Depth Top Port 4' (ND) Inci OD Valve Latch Size TRO Run Stn Top MKS) (TM) ('1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,219.9 2,219.5 4.76 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/15/2001 2 3,603.0 3,590.8 3.61 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/15/2001 3 4,573.0 4,560. 0.29 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 12/12/2001 IPERF, 5,4955,515 ' - _ - - 4 5,127.8 5,115.2 0.35 CAMCO KBG2 5 5,179.0 5,166.4 0.35 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/152001 FRAC. 5,495 1 GAS LIFT OV BK 0.250 0.0 1/4/2010 PRODUCTION 7"1,45" e 5325 ", 26.6,002 TD, 8.008 • . III 'Nov' RECEIVED • • SEP 24 2012 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 21, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. requests to withdraw the 10 -403 Sundry requests for OA cement shoes on the following wells: ,.2P -417 (PTD 201 -069 2P -438 (PTD 201 -082) 2P -441 (PTD 202 -017) This work has been cancelled and will not be completed until further study has been done at which time the appropriate Sundry requests will be filed. Please call Martin Walters or me at 659 -7043 if you have any questions. Sincerely, /17/ cli - e --(41 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures • • Page 1 of 1 ~~-o~y Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] _ Sent: Wednesday, December 30, 2009 9:26 AM ~~l•Q ~Z~~'~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L DOA) Cc: NSK Problem Well Supv Subject: 2P-417 (PTD 201-069) Report of failed TIFL Attachments: 2P-417 schematic.pdf Tom, Jim, Guy Kuparuk producer 2P-417 (PTD 201-069) failed a diagnostic TIFL. The TIO prior to the test was 290/460/530. A leaking OV is suspected. Slickline will troubleshoot the leak and repair if possible. '~-"` Attached is a schematic and a 90 day TIO plot. v, Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~~~ ~ ~ ~za tc 12/31 /2009 KRU 2 P-417 PTD 201-069 12-30-2009 TIO Pressures • • ,,~ , _. ~ KUP Well Attributes ~~noc~Philli~s ~ ~~`; '~ _ ~ ~w Im aauuwl IF la creme 2P-417 ___ - - - - ax Angle & MD TD I-- - _ - WeI1S[atus ProNlnj Type Incl(f '.7D (ftKB) -t 3tm (ftKB) ~Pann ~ ~ R.79 ~ 2.442.68 ~ 6008.0 i_ C -.-___ __.___ omment H25 (ppm) Date Annotation End Date KBGrd (R) Rig Release Date _' 1 WeIlCofig 2. 41 ~ - :.'_AM S -- - SSV; NIPPLE _. 22 7/12008 Last WO: 5/15/2001 d Date E . - $ n mat'w - ~ - _ A - oration Depth (RKB) Entl Date A nnotation n -- _ _ _ L ast iag'. ELMD 5 ,510.0 122009 Rev Reason: TAG FILL _ - _ - . C asing Strings _ _ _ ~ _ _ T __ St ing OD Stang ID T ng Set Depth ' Set Depth (ND) Strang Wt S[ C sing Dascnption (n) 11^) Top (RKB) (ftKB) (RKB) (IbaRt) 6 de String Top Thrtl C ONDUCTOR 16 15.062 27.5 107.5 107.5 62.50 H-40 WELD S URFACE 95/8 8.697 27.5 2,382.0 2,380.5 40.00 L-80 BTC-ABM y!- P RODUCTION 7 6.151 27.5 5,302.0 5,289.4 26.00 L-80 BTC-ABM ~ ~ L INER 4 12 3.958 5,302.0 6 002.0 5,989.4 12.60 L 80 IBT 3NDUCroR, k° Tubing Strmgs _ _ -- 108 _ Str ID St OD 9 9 bet D pth Set Depth (ND) Sty rag Wr St ~ IftNB) (ftKB) (lbsltt) G d g String ToP Thrd ' Tub ig De pt on ( I ( ) - ~ Top (ftHB) 1 _ _ 0 0 5 30 i.01 5 790.4 12.60 L 80 _ -. IBS , _ - -~ Othef In HOIe I ( AI Jewel TUbirj ~ __ Run & Retrievable, Fish~etc.l - - _ Top Depth T NIPPLE, 485 ~ ~ T ( KBI op (RKB) ~ ) Top Inc! (°) Description Comment Run Date ID in ( ) 485.0 484.9 0.53 NIPPLE CAMCO'DB-6' NIPPLE 5202001 3.675 2,220.0 2,219.7 4.76 GAS LIFT CAMCOlKBG-2/1/DMV/BK/// Comment: STA 1 5/152001 3.938 3,603.0 3,590.8 3.61 GAS LIFT CAMCO/KBG-2/1/DMYBK7//Comment: STA2 5/152001 3.938 Gras LIFT, 4,573.0 4,560.4 0.29 GAS LIFT CAMCO/KBG-2!1/DMY/BK///Comment: STA3 12/12/2001 3.938 2'220 ~ 5,128.0 5,115.4 0.35 GAS LIFT CAMCO/KBG-2/1/DMYBK//l Comment: STA4 5!152001 3.938 ~ 5,179,0 5,166.4 0.35 GAS LIFT CAMCO/KBG-2/1/OVBK/.313//Comment: STA5 7/25/2008 3.938 t 5,230.0 5,217.4 0.35 SLEEVE BAKER CMU w/3.81" CAMCO NO GO Profile 5202001 5,257.0 5,244.4 0.35 NIPPLE CAMCO DB-6 w/NO GO profile 5202001 3.750 SURF23 2 9 5,303.0 5,290.4 0.14 SEAL BAKER 90-47 CSG SEAL ASSEMBLY 5/20/2001 3.875 ~< 5,305.0 5,292.4 0.14 TTL L . 5202001 3.875 -.~___ Perforations . - -- _ _-- _._ -_ - - ------- _- I._ _. _. ___-_.._- Shot GAS LIFT 3.603 RKB Top (ND) etm (ND) (RKB) (RKB) Dens sh... Comment Zone Date ( Type ~ , ) Top (ftKB) Btm ( 5,495.0 5,515.0 5,482.4 5.502.4 BERMUDA, 12/142001 6.0 IPERF 3.38" HSD ~ , 2P-417 _-. ~ Stimulations & Treatments - __ - _ __ -- - ' Bottom GAS LIFT. Mln Top Max Btm Top Depth Depth 4573 ~ ~ Depth Depth (rvD) (ND) ~ (RKB) (RKB) (RKB) (ftKB) Type Date Comment . 495.0 5,515.0 5,482.4 5,502.4 FRAC 12/142001 BERMUDA FRAC, 213,000# 16/20 CARBOLITE, 12 5 , PPA ON PERFS OAS LIEF. 5,128 GAS LIFT, 5,179 1. -:'~ SLEEVE. 5,230 ~ m~~~ NIPPLE, 5,257 _~ PRODUCTION, 5,302 ~ ~ ~ SEAL 5,303 ~ = -_ TTL, 5,305 IPERF, 5,495-5,515 ) _ FRAC. 5,495 T ~ t ' ! J LINER, 6,002 ~ ~ I _ TD. 6,008 g. D~II~IfIII~~~f~~ 1 ,^ e Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 3F-05 12115003 1E-22 12115008 3F-12 12115008 1 D-136 12115008 3F-06 AZED-00003 3J-02 12115008 2N-332 12096514 2N-323 AZED-00008 2N-342 12096514 2N-302 AZED-00007 2P-417 AZED-00012 2V-03 12115000 1 R-13 AYS4-00019 1 B-02 AYS4-00020 Please sign and return one copy of this tr. /`1 ~ ~ - l~ ~, - NO. 5035 ! j -x'! ; //((~~ ~ „ ~. ~<<^, Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk log Description Date BL Color CD PRODUCTION PROFILE ~-,„~ - ; Y. ~ ~ 1 ~y Cc ~ C r~ r-,~ 12/20/08 1 INJECTION PROFILE ~.(~,. j ~; ,~. _,_'_) ~. ~ "~ C_. _~ 12/24/08 1 1 INJECTION PROFILE , -~_. '~ k, :,-_ R~---~- ~ j-~ x 12/25/08 1 1 INJECTION PROFILE ,_ ', ~~ .~ ., ", _ ~l,'~,`~ 12/26/08 1 1 PRODUCTION PROFILE ~,°"~-- c;~.~-I`-' ~ L L.~ 12/27!08 1 1 INJECTION PROFILE ~ ,_ ~ ~~ r _ / („-:~ /- .-L Ll ~•~ 12/29/08 1 1 SBHP SURVEY , =,^,v _ - -:~_C -',J ;_~~~ _~ 12/30/08 1 1 SBHP SURVEY ~-" ->- -- ~. '~! j ~= ~f-C f~/~ " 12/30/08 1 1 SBHP SURVEY ;)'~"=1- ~- (~"-.<; ~ ~/~-(,j 12/30/08 1 1 SBHP SURVEY T .~ - ~ % ~ _ ,-) l ._. ~ ~.- . ' _>'. i C.. 12/30/08 1 1 SBHP SURVEY , (-' ~;',,.t'' -'_`)/._/C. ''~- 01/02/09 1 1 INJECTION PROFILE j~= % ' -- ~ ~-;+_ - 12/17!08 1 1 INJECTION PROFILE `~- ~ 1<'. x__ -- - }C.~:";~!. 01/03/09 1 1 INJECTION PROFILE ;J:j;~? j"~~ ~", .._.~-~- ~ ~"~ `(;:>;~' 01/04/09 1 1 ~nsmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 01 /08/09 • L~ 2P-417 (PTD 2010690) Report of failed TIFL Page 1 of 1 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, July 12, 2008 6:49 PM I `~~ To: Maunder., Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2P-417 (PTD 2010690) Report of failed TIFL Attachments: 2P-417 schematic.pdf; 2P-417 90 day TIO plot.jpg Tom, Jim Kuparuk MI gas lifted producer 2P-417 (PTD 2010690) failed a TIFL on 07/09/08 and was added to the weekly SCP report. The TIO prior to the TIFL was 890/875/225. lead king Orifice GLV is suspected. Slickline will troubleshoot the leak and repair if possible. There is a pressure event on the trend plot that is due to the casing valve on the well being shut in and the ~ pressure gauge reading the lift gas header pressure. The down swing on the trend correlates with the header being depressured to change out a valve. Attached is a 90 day TIO plot and schematic. «2P-417 schematic.pdf» «2P-417 90 day TIO plot.jpg» '~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. ~~~~ ~~{~ 2~~~ Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/5/2008 KRU 2P-417 PTD 201-069 Tll/O Plot - 2P~17 3000 2500 2000 a 1500 1000 -_ i.,` 500 (1 ~-++++ 11-Apr-O$ 24-Apr-08 07-May-08 20-May-08 02-Jun-08 15-Jury-08 28-Jun-08 C1ate 200 150 • a E as 100 0 s V 50 0 • -~ -~~ ~ar~t~~oPhilli~s A~a~k~, r~~. 2P-417 _ - _ API: 501032037500 ruslNG ~ SSSV Type: Nipple (0-5303, OD:4.500, ID:3.958) ~ ---- Annular Fluid: ' J ~ Reference Lo i 1 Last Ta 5506' SLM Last Ta Date: 12/23/2007 Casing String -ALL STRINGS Descri lion Size I SURFACE (28-2382, OD:9.625, W t40.00) 'RODUCTION (28-5302, OD:7.000, wt:2s.oo> Gas Lift 3ndrel/Dummy Valve 3 (4573-4574, OD:5.984) Gas Lift 3ndrel/Dummy Valve 4 (51285129, OD:5.984) Gas Lift MandrelNalve 5 (51795180, SLEEVE (52305231, OD:4.500) KRU 2P-417 SOD _ -~ Angle @ TS: ~ deg @ 15!2001 J Angle @ TD: 1 deg @ 6008 Last W/O: Rev Reason: TAG FILL ;f Lo Date: Last U date: 1/4/2008 TD: 6008 ftK8 Hole Angle:_ 9 de~c @ 2443 Tnn Rnttnm TVf) Wt (:rorin Thrua.i CONDUCTOR 16.000 28 108 107 62.50 H-40 WELD SURFACE 9.625 28 2382 2381 40.00 L-80 BTC-ABM PRODUCTION 7.000 28 5302 5289 26.00 L-80 BTC-ABM `Y ~ F'KUU LINtK ~4.5UU ~ 5;iU1 I bUU'L_ I 5yay I lL.tiU I L-tSU I It31 "~ - Tubing Strln TUBING _ ,- Sizes _ -- To Bottom i TVD Wt _ Grade Thread I ~t .,i)0 0 5303 '~ ,~~i0 ~ 12 r;0 L_-80 IET Perforations Summary Interval TVD - -- Zone Status Ft SPF Date i ype Comment - 5~195 5515 5482 - 5502 20 6 12/1-t,~001 IF ERF 3 38" HSD Stimulations Interval & Treatments Date T e Comment _ 5495 - 5515 12/14/2001 FRAC BERMU DA FRAC, 213,000# 16/20 CARBOLITE, 12 P PA ON PERFS Gas Lift Mandrels/Valves ~ St MD TVD Man Mfr Man Type V Mfr V Type V DD Latch _ Port TR© Date Run Vlv Cmnt 1 2220 2220 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 5/15/2001 -_ 2 3603 3591 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 5/15/2001 -=~ 3 4573 4560 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 12/12/2001 ~ ~ 4 5128 5115 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 5/15/2001 ~ ~ 5 5179 5166 - CAMCO KBG-2 CAMCO OV 1.0 BK 0.313 - 0 12/16/2001 _ -_ Other {plugs, equip etc.) -JEWELRY Ue th TVD T e Descri lion ID 485 485 NIP CAMCO'DB-6'NIPPLE 3.875 5230 5217 SLEEVE BAKER CMU wl3.81" CAMCO NO GO Profile 3.813 5257 5244 NIP CAMCO DB-6 w/NO GO rofile 3.750 5303 5290 SEAL BAKER 90-47 CSG SEAL ASSEMBLY 3.875 5305 5292 TTL 3.875 ~,. NIP (5257-5258, _ ~FN~ - i --- SEAL S (5303-5305, OD:4.000) FRAC (5495-5515) Perf (5495-5515) j-- IL-~~ e Conoc;pí,illips A~aska e I i! ,).C: c'>Uình JU'L- 'Hi <;..;l L'vW P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 '9, f':1. Anchorage June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 . "'.""" i.. JiU'"j""" íì""\ ¡)v~,,~¡¡c.¡..Þ 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, Royfill404B, 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 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. Sincerely, ç<.-~~,",-J, d~ C::>6/ ~ {) /ð6 Attachment ¿-)D [-ó to9 e e ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement um ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 5/19/2006 · Conoc~illips Alaska ~.~.!:: ~"'j1- jJ t\1 :1 .~t : -.\ 'J j ml &. G¡¡S Cans. Anchj)T!.1ge P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 06, 2006 dvr~ ðlt9 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 '/Î'~' . ~;;-fi' :,~V&' ;:¡f'J1,;~,'L! r¡? hi t, 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. ConocoPhillips Problem Well Supervisor Attachment . . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Vol. of cement Final top of Cement top urn ed cement off date bbls ft Corrosion inhibitor/ sealant date 5/19/2006 Phillips Alaska Inc. • • Meltwater 2P-417 Well ''`~ ~ ~ ~ ~ (~~ File HOU-011005 ~,/ `V`' !/ 4. CMS-300TH PERMEABILITY AND POROSITY DETERMINATION Summary After completion of electrical properties, capillary pressure and NMR experiments, the samples were cleaned and dried. Permeability and porosity data were measured using Core Laboratories' CMS-300T"" instrument, and the CMS pore volume was used to calculate porosity and water saturations. Procedure 1. The core plugs were placed in a Soxhlet distillation apparatus and cleaned using hot refluxing Toluene and Methanol. They were then dried in a conventional oven at 220°F, and cooled in a humidity-free environment. 2. Grain volume was determined for each sample by placing it into a stainless steel matrix cup. Helium was injected from reference cells of known volume and pressure using a Core Laboratories' AutoPorosimeter. Grain volume (g/cc) was calculated using Boyle's law of gas expansion. Grain density was calculated by dividing sample dry weight by grain volume. 3. The samples were loaded into Core Laboratories' CMS-300T"" for determination of permeability and porosity, with an initial (standard) confining pressure of 800 psi, and a subsequent test confining pressure of 1850 psi (for electrical properties). Helium was injected into the sample from reference cells of known volume and pressure. A direct pore volume was determined using Boyle's law of gas expansion, and then pressure was vented at a known rate and unsteady-state Klinkenberg permeability determined by pressure decay. Bulk volume was determined by summation of the pore volume and grain volume, and then porosity was calculated by dividing .pore volume by bulk volume. ~.-~ M ~~~~~~ JAN ~ 2 2004 Alaska Oil & Gas Cons. Commission Anchorage Core Laboratories PERMEABILITY TO AIR vs POROSITY After Final Cleaning CMS-300 Method - 800 psi ncp Phillips Alaska Inc. Well :Meltwater 2P-417 1000 Location: Alaska File: HOU-011005 100 E i Q O ~' 10 `~ m U_ 1 0.0 5.0 10.0 15.0 20.0 25.0 30.0 35.0 40.0 Porosity, %Bv Core Laboratories CMS-300 CONVENTIONAL PLUG ANALYSIS After Final Cleaning Phillips Alaska Inc. Well :Meltwater 2P-417 Location: Alaska File: HOU-011005 Sample Depth Reservoir Pore Porosity Permeabili b(He) Beta Alpha Grain Number Net Overburden Volume Klinkenber Kair Density feet si cm3 % and si ft -1 microns cm3 8S 5441.50 800 12.046 20.3 8.908 10.41 9.20 1.09E+09 3.14E+01 2.59 8S 5441.50 1000 12.000 20.2 8.833 10.33 9.29 1.11E+09 3.17E+01 2.59 16S 5447.65 800 12.940 22.6 79.52 84.63 3.14 7.57E+07 1.94E+01 2.66 16S 5447.65 1000 12.910 22.5 79.18 84.31 3.17 7.57E+07 1.94E+01 2.66 19S 5448.55 800 13.909 23.3 87.16 92.52 2.99 5.82E+07 1.64E+01 2.66 19S 5448.55 1000 ~ 13.852 23.2 86.84 92.17 2.98 5.87E+07 1.65E+01 2.66 52S 5500.75 800 13.425 22.8 20.93 23.53 6.47 3.36E+08 2.27E+01 2.67 52S 5500.75 1000 13.370 22.7 20.77 23.35 6.49 3.38E+08 2.26E+01 2.67 74S 5509.45 800 11.077 19.2 2.354 2.872 13.06 2.66E+10 2.01E+02 2.59 74S 5509.75 1000 11.011 19.1 2.311 2.818 13.01 - 2.89E+10 2.15E+02 2.59 89S 5513.90 800 13.088 22.7 22.96 25.49 5.73 3.59E+08 2.66E+01 2.66 89S 5513.90 1000 12.995 22.6 22.81 25.32 5.72 3.66E+08 2.69E+01 2.66 97S 5536.65 800 11.724 20.7 4.947 5.895 10.87 3.47E+09 5.52E+01 2.65 97S 5536.65 1000 11.631 20.5 4.876 5.811 10.88 3.60E+09 5.65E+01 2.65 100S 5544.65 800 11.380 19.6 2.300 2.901 15.52 2.96E+10 2.18E+02 2.67 100S 5544.65 1000 11.312 19.5 2.283 2.879 15.51 2.98E+10 2.19E+02 2.67 Core Laboratories r e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFichc\CvrPgs _Illserts\Microfilm _ Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2010690 MD 6008 C Well NamelNo. KUPARUK RIV U MELT 2P-417 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20375-00-00 TVD 5995 Completion Date 12/13/2001 Completion Status 1-01L 47 47 Current Status 1-01L 5953 Open 7/16/2002 5953 Open 7/16/2002 5953 Open 6/27/2002 -------- -~ UIC N 47 ---- -- Well Cores/Samples Information: Name c...core Chips 'e'Cíttings Interval Start Stop 5429 5547 93 5993 Sample Set Number Comments ~ Sent Received --"--- i I -- J 1059 1059 -,-- - -.- ADDITIONAL INFORMATION (bN Chips Received? G) N yfV Well Cored? Analysis Received? (yyN ~/N Daily History Received? Formation Tops Comments: ~ ~ ~H'fr~ ~ À' 3 - ~þ t À. ~ ~~ ~ ~~ ~ --~-:r~M,¡~- ~- h-. ~~ M~-.k.,- Compliance Reviewed By: - ~ Date: ¥<..O J ~~- vI ~~ s ~~ (...- 'ß ~ r~t.lu.~~ ~~") Uf/ J tWI, l-. l~ )'67 g - >-~ ~ ") p ~ ytð ~ ~ ~~ '- ) ~i"\'-) À~ ~ ( .;t .) ~ ;. -- )--1 L(,J f fK A-v'r"î t~J.u.l.\:~ '""- IL~ l.ù~ I ^"':>8).. -j"f7C f¡?' X Ñt;.t..1 i'v-- ~ D {¡V1\ ~'" } ^ ~ ^lH~ \ ~ ,>8 Á - :> '9, r ~ ¿""lu-/ UJ lU.- ~ f~J~À-Ò~~( DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2010690 Well Name/No. KUPARUK RIV U MELT 2P-417 Operator CONOCOPHILLlPS ALASKA INC jp~¿ À) ~ ~1 API No. 50-103-20375-00-00 MD 6008-- TVD 5995 / Completion Date 12/13/2001 ,-/ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional su~~~ ~=~~- y~- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) --~~ Logl Electr Data Digital Dataset Log Log Run Interval OH 1 Type Med/Frmt Number Name Scale Media No Start Stop CH Received C~m!':1~_- .. . -. --- -. t..Kog -.---- 2 FINAL 1850 6000 Case 6/1/2001 1850-6000 Color Print' ~g 2 FINAL 5100 5800 Case 6/1/2001 5100-5800 Color Print ~ -é- ^-. FINAL 93 5994 Open 61712001 93-5994 BL, Sepia ~ S- À.. FINAL 93 5994 Open 617/2001 93-5994 BL, Sepia I ~ ~ 2.. FINAL 93 5994 Open 617/2001 93-5994 BL, Sepia i-€~ C ....'. ..'.'.--.,..'."'.,', - 1 93 5994 Open 6/27/2002 RWD - MPRlNEU/DEN/GR [ ~ ;Neutron -- 25 Blu 1 93 5994 Open 6/27/2002 1-- - ~ JflduttiÒri/f{ésistivity 25 Blu 1 93 5994 Open 6/27/2002 -t159 ...ßâmrri~RâY - 25 Blu 1 93 5994 Open 6/27/2002 ft:õ9 25 Blu 1 93 5994 Open 6/27/2002 ~g ~~~~tA~ -_.-- 25 Blu 1 93 5994 Open 6/27/2002 /-~ I~g ~~~r~~~. 25 Blu 1 93 5994 Open 6/27/2002 I Log G¡:¡01maJRay . 25 Blu 1 93 5994 Open 6/27/2002 G.og 1)$n~íty: . 25 Blu 1 93 5994 Open 6/27/2002 ~ ~".... .'. êOg ~rnrt)~R-~Y 25' Blu 1 93 5994 Open 6/27/2002 (llg .->fr.".. ".......ôW..'."'..'.'..... C.'.t..iO......n........I.R.,.........e..~.....S...IS.....'...,t.",iV..,....itY....... . 25 Blu 1 93 5994 Open 6/27/2002 1\C).Ðf\o-} {ED C I:{ >t{~ 1 ÐS04 ~ensitY'...>,» .. 1 1834 5970 Open 1/25/2002 U::og +va GRI DEN/ NEU oS 1.. FINAL 93 5994 Open 617/2001 93-5994 BL, Sepia ~ vrVD GRI RES/ DEN/ NEU 5 FINAL 93 5994 Open 617/2001 93-5994 BL, Sepia 4.o-g 4 GRI RES 5 FINAL 93 5994 Open 617/2001 93-5994 BL, Sepia fg GR/ RES/ DEN/ NEU 5 FINAL 93 5994 Open 617/2001 93-5994 BL, Sepia ,g ~ GRI RES 5 FINAL 93 5994 Open 617/2001 93-5994 BL, s~~~a ---- RE: 2P-4?2A Annular Disposal Application 10 J - C>la~ ~I Subject: RE: 2P-422A Annular Disposal Application Date: Wed, 22 Oct 2003 09:11 :28 -0800 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> To: "Tom Maunder" <tom_maunder@admin.state.ak.us> Tom, Here are the recalculated pump in pressures with some comments for the wells in question. (Did you want them in an excel spreadsheet ?) 2P-417: 14.3 ppg 2P-422: 15.2 ppg (unchanged as the difference between the correct and incorrect TVDs was so small) ~: 17.2 ppg. This "new calculated" pump in pressure is greater than the original FIT of 16.2 ppg. This is attributed to the fact that an intermediate casing string was run on this well due to a well control problem. This resulted in a shoe (and cement) approximately 1500 ft TVD higher than any of the other wells drilled on Meltwater. We conclude that the formations exposed on the other wells, including our candidate well 2P-422, are isolated in the case of 2P-441. Regards Philip -----Original Message----- From: Tom Maunder rmailto:tom maunder@admin.state.ak.usl Sent: Wednesday, October 22,20038:11 AM To: Hayden, Philip Subject: Re: 2P-422A Annular Disposal Application Philip, With regard to the "new calculated" pump in pressures for 2P-417, 2P-422 and 2P-441, would you please provide them?? Thanks, Tom Maunder "Hayden, Philip" wrote: > Tom, > > In response to your comments: >./ > For the pump in test for well 2P-420 I must apologise for not having > made sure that the sheet had been correctly filled in. Your calculation > of 14.2 ppg EMW had been previously confirmed by us but the sheet had > not been corrected. / > / J v > For wells 2P-417, 2P-422 and 2P-441 the incorrect TVD was used for > calculating the EMW for injection at the shoe. This had been noted by us > and the corrected EMW for injection at the shoe had been determined and > found to be, in all cases, lower than the original injection pressure at > the initial leak off or formation integrity test. We did not amend these > files before sending them on to you as they are part of the official 1 of 3 r to( .)\> po<:--\. C>~ \- \-. '\ "> ~ \) ~ C-I.V \> \ ~ cc... +\ C>('. '- ~ þ., !>. -.:::, \>~. ~~ \((:c.c~ ~ Õ ~ -\ ,,~ r - V", \ ~ '~~'~ ~(:. è)?- '--\~ \ . 17 Ç>- '-\ ~ \ . d ~- '--\ 'ð(:' ~~-L.\d'ì , a"-~dO ~-?- L~ \ ""~ \<.t ~\ ~ ~« , \ ~ ~ ~ txr;. \ L Ù { '.....~\()~, D«-Cê. '" c:., \'\>\C) \;)<! ~ ~ þ... . r ~ .-.c... ~ "\-" ~ \,,~ \' \). 1~ ~,,\- ~o ~h~ "< ~C\\\~~ w(Q~ \ O~) "'-'>ú-'( CJ.~'f C;P(:C-\\ \,)c- \.1..)0\ ç., \~~ , Ær2~ t t>/ ~ I,}Ì) 10/22/2003 9:59 Ar RE: 2P-4?2A Annular Disposal Application (' > files. This would have lead to two different sets of data for these > wells and we felt this could be potentially more confusing. On the other > hand we recognise now that we should have brought this to your attention > in our initial correspondence. We will be sure to do so in the future. > > For well 2P-431 we have been unable to locate any record of a pump in > test after the initial leak off test was performed. We do know that this > annulus has been freeze protected and also that methanol has been pumped > down it to remove a hydrate plug but accurate pressure information is > lacking. However, due to its location, between wells 429 and 441 we are > confident that its behaviour with respect to a pump in test is similar > to these wells. > > I hope this note adequately addresses your comments and questions. If > there is anything else please let me know. > > Regards > > Philip > > -----Original Message----- > From: Tom Maunder lmailto:tom maunderæD.admin.state.ak.usl > Sent: Monday, October 20, 2003 9:07 AM ' > To: Hayden, Philip > Subject: Re: 2P-422A Annular Disposal Application > > Phil, > Here are my further comments/questions on the 2P-422A application. I > look > forward to your reply. > Thanks. > Tom Maunder, PE > AOGCC > > On the 2P-420 pump in test, the calculation has not been done. TVDs > have > not been entered. Using the 550 psi maximum pressure and the shoe tvd, >1 > calculate 14.2 EMW. The EMW of the sustained pump in pressure would be > slightly lower. > > On the pump in test of 2P-417, the calculation does not use the tvd of > the > rathole at the surface casing shoe. Using 2430' tvd, the EMW calculates > to > 14.2 which is in agreement with the calculation for 2P-420. > > Tom Maunder wrote: > > > Hi Phil, > > Welcome back. I was looking at the application and I have a couple of > > questions. Please note that I am not finished with my review of the > > packet. This first note will allow you to capture my eddress. 2of3 I( 10/22/2003 9:59 AI RE: 2P-422A Annular Disposal Application ~ ~ \ » > > My questions/comments are: » > > On the pump in plot for 2P-422ST dated 4/22/02, the TVD used in the > > calculation is not the same as done on the initialleakoff dated > > 2/20/02. Why the difference?? » > > The TVDs on 2P-441 also are different. In particular the pump in TVD > is > > listed as the mid point between the top of cement and surface shoe. > All > > EMWs should be referenced to the surface shoe. » > > There is no pump in test for 2P-431. » > > You have made the appropriate tvd change on 2P-429. » > > Tom Maunder, PE > > AOGCC 3 of 3 10/22/20039:59 AI d DI-O(o9 ALD' 1 d . h d if 2002 ( nnu ar lsposa urzng t e secon quarter 0 h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume V olume Volume Quarter Protect Total Total Date Date Volumes CD2-15 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2002 June 2002 CD2-48, CD2-46 ID-II 32102 100 0 32202 235 0 32437 May 2002 June 2002 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 IC-IS 4176 100 0 4276 379 0 4655 June 2002 June 2002 1 C-l 04 ~ 1 ~ 1 A rfi h' hD' lA h . E . dd' h d 2002 l { ota 0 urnes znto nnu l or W lC lsposa ut orzzatlon xplre urzng t e secon quarter Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus IJ -09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 11-10 IC-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 lC-133, lC-121, lC- 123, lC-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- 2001 15 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 IC-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 lC-127, lC-117, lC- 111, lC-123 ALD' L d. h fi 12002 ~ÙJ-C C 9 nnu ar lsposa unng t e lrst quarter 0 h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly #1, 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 IC-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 2001 2002 CD2-IS 10346 100 0 10446 371 0 10817 March March CD2-50 2002 2002 CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-4S 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-4ISA 4843 100 0 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 2002 2002 CD2-26 0 0 0 0 380 0 380 -- -- Freeze protect only for CD2-26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only ( J'¡ L \l¡ 1 A rfi h' hD' LA h . E . dd. h fi. 2002 ota 0 urnes lnto nnu l or W lC lsposa ut Orlzatlon xplre urzng t e lrst quarter Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus ID-32 23162 100 0 337 23599 Open, Freeze Protected January February 10-39 2001 2001 IJ -03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 11-09, 11-14, 11-10 ( <301-01.0'1 J# PHILLIPS ALASKA, INC. 2-P 417 MELTWATER NORTH SLOPE BOROUGH, ALASKA ( \ FINAL WELL REPORT (May 12, 2001) John Morris - Sr. Logging Geologist Andrew Buchanan - Sr. Logging Geologist ~ EPOCH RECEiVED { JAN 3 0 2D02 Alaska Oil & Gas Cons. Commission Anchorage TABLE OF CONTENTS \ PHilliPS ALASKA, INC. 2-P 417 MEl TWATER NORTH SLOPE BOROUGH, ALASKA WELL INFORMATION ..... ........... ..... ........ ...... ..... ...... ..... ........ ....... ..... ..... ... ...... ... ......... ... 3 DRILLING AND GEOLOGICAL DISCUSSION ."...".""."..""........"..."..."".".."......."o." 5 \ LITHOLOGY AN D COMMENTS .. ..... ........o.. o..o...o.o.o.o.o.o.o..o. ..o..o.o.o. o....o.o..o. o.......o..o.o..o.o.. o..o. o.o.o.o.o.o.o. o.o.o.o.o. .........6 DAILY ACTIVITY SUMMARY .......................................................................................24 SURVEY INFORMATION .o.o....o.. .o.o.o.o. o.o.o.... .... ...o..o. ..o. ... ...... .........o... ....o...o... ....... ............ ...o.o... .....26 DAILY MU D PROPERTI ES.o...o..o...o.o.o.o..o..o..o.o.o.o.o..o.o...o.o.o..o.o.o.......o.o...o. o...o.o.o..o.. o..o.o.o..o.o..o.o....o..o....o. ................28 BIT RECORD.. ........ ....... ......... ........... .......... ..... .......... .... ....... ........ ....... ........ ............. ...29 DAILY REPORTS o.o...o.... o.o.o....o...o......o....o............. .... o.............. .......... ................ .o.. APPENDIX A LOGS ... ......................... ....... ... .... ... .... .... ... ........ ......... ......... ........ .......... ...... APPENDIX B REC;ErVED Jt'N 3 () ZOO? Alaska Oil & Gas COilS. Commission Anchorage ( [;I EPOCH 2 a W Phillips Alaska, Inc. Meltwater 2-P 417 , WELL INFORMATION Company: Phillips Alaska, Inc Well: 2-P 417 Field: Meltwater Region: North Slope Borough Location: Sec. 17, T.8N, R7E UM Coordinates: 877' FNL 2252'FWL Elevation: Ground Level: 225.0' AMSL Drill Floor: 255.0' AMSL County, State: North Slope, Alaska API Index: 50-103-20375 I \ Spud Date: 04/27/01 @ 2245 hrs Total Depth: 5993.0' Contractor: Doyon Drilling, Inc. Company Representative: Dearl Gladden Ray Springer Rigrrype: Doyon #141 Top drive Triple Epoch Logging Unit: MLOA3 Epoch Personal: John Morris Andrew Buchanan Company Geologist: Dave Shafer Jeff Haris Casing Data: Surface: 9 5/8" Main hole: 7 5/8" ( rlole size: 12 %" to 2430' 8 'ÿ2" to 5993' U EPOCH 3 ( .v1ud Type: Logged Interval: Electric Logging Co: Logs Run: ( ( s ~ Phillips Alaska, Inc. Meltwater 2-P 417 Baroid 93' to 5993' Baker-Hughes Inteq Surface hole Main hole E-line Directional-Gamma-Resistivity Directional-Gamma-Resistivity-Neutron-Density Dipole sonic-MDT/RFT Pressure-FMI-Platform Express U EPO(~H 4 = ~ Phillips Alaska, Inc. Meltwater 2-P 417 \ DRilliNG AND GEOLOGICAL DISCUSSION Epoch Well Logging arrived on location April 27, 2001 and proceeded to rig up before spud. The well was spudded on April 27, 2001 at 2245hrs. The well was drilled according to the well plan to casing point at 2430'. The lithology over this interval consisted of sand and conglomerate to 900' where tuffaceous clay and siltstone become predominant. From 1400' to casing point at 2400' the lithology consists of interbedded silts and clays with occasional coaly/carbonaceous material layers and thick sand and conglomerate units. The 9 5/8" casing hit a bridge and could not be run all the way to bottom so a joint was laid down and casing was set at 2382'. The 8 %" main hole was drilled according to the well plan to a depth of 5262' with no problems. At this point a planed wiper trip was preformed and found that the shales of the upper hole were caving. It became necessary to Kelly up and wash and ream out to casing. At that point it became necessary to pick up a hole opener to clean out the sloughing zone. This required several trips through the interval from the shoe to 3100'. After two days the hole opener was laid down and bottom hole assembly was picked up to resume drilling. The lithology over this interval consisted of interbedded clay, silt and tuffaceous ash with occasional carbonaceous shale zones, rare sand intervals and occasional coaly/carbonaceous material beds. The well continued to drill to core point at 5429' with no problems through very similar lithology. ( 'he Bottom hole assembly was laid down and the core assembly was picked up to cut two 60' core. (he core interval consists of very fine to occasional coarse, angular to occasional subround poorly sorted sand with poor intergranular porosity. The fluorescence shows good hydrocarbon saturation with a slow moderate to strong, very slow streaming cut. Once the cores were laid down the drilling assembly was picked up to drill ahead to total depth. Total depth 5993' md, 5980.4' TVO was reached on May 12, 2001 at 0530 hrs. ( ~ EPOCH 5 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 , LITHOLOGY AND COMMENTS 120 CONGLOMERATE = TRANSLUCENT WHITE, DARK GRAY TO BLACK, GREEN, FINE UPPER TO PEBBLE AND POSSIBLY COBBLE SIZE GRAINS; UNCONSOLIDATED; OCCASIONAL CLAY MATRIX IN PART; VERY POORLY SORTED; LOW SPHERICITY; SUBROUND TO SUBANGULAR; COMPOSED OF 20% TRANSLUCENT QUARTZ; 300/0 CHERT; 300/0 META-LITHIC FRAGMENTS, 100/0 QUARTZITE, 5% CARBONATES; 5% TUFF; NO VISIBLE OIL INDICATORS. 175 SAND = LIGHT GRAY TO GRAYISH BROWN; FINE LOWER TO COARSE UPPER; VERY POORLY SORTED; ANGULAR TO ROUND; LOW TO MODERATE SHPERICITY; UNCONSOLIDATED; COMMON CLAY MATRIX; INFER GRAIN SUPPORTED; COMPOSED OF 300/0 CLEAR AND TRANSLUCENT QUARTZ GRAINS, 400/0 LIGHT AND DARK CHERT, 30% LITHIC FRAGMENTS; INFER GOOD INTERGRANULAR POROSITY; NO VISIBLE OIL INDICATORS. ( 245 CONGLOMERATE = TRANSLUCENT WHITE, DARK GRAY TO BLACK, GREEN, FINE UPPER TO PEBBLE AND POSSIBLY COBBLE SIZE GRAINS; UNCONSOLIDATED; OCCASIONAL CLAY MATRIX IN PART; VERY POORLY SORTED; LOW; SPHERICITY; SUBROUND TO SUBANGULAR; COMPOSED OF 20% TRANSLUCENT QUARTZ; 300,10 CHERT; 30% META-LITHIC FRAGMENTS, 10°,10 QUARTZITE, 10°,10 WELDED TUFF, OCCASIONAL SILICIFIED LIMESTONES, TRACE SILICIFIED OOLITIC SANDSTONE AND CRINOID STEM; NO VISIBLE OIL INDICATORS. 310 SAND = LIGHT GRAY TO GRAYISH BROWN; FINE LOWER TO COARSE UPPER; VERY POORLY SORTED; ANGULAR TO ROUND; LOW TO MODERATE SHPERICITY; UNCONSOLIDATED; COMMON CLAY MATRIX; INFER GRAIN SUPPORTED; COMPOSED OF 30% CLEAR AND TRANSLUCENT QUARTZ GRAINS, 40% LIGHT AND DARK CHERT, 30% LITHIC FRAGMENTS; INFER GOOD INTERGRANULAR POROSITY; NO VISIBLE OIL INDICATORS. 365 CONGLOMERATE = TRANSLUCENT WHITE, DARK GRAY TO BLACK, GREEN, FINE UPPER TO PEBBLE AND POSSIBLY COBBLE SIZE GRAINS; UNCONSOLIDATED; OCCASIONAL CLAY MATRIX IN PART; VERY POORLY SORTED; LOW SPHERICITY; SUBROUND TO SUBANGULAR; COMPOSED OF 20% TRANSLUCENT QUARTZ; 30% CHERT; 30°,10 META-LITHIC FRAGMENTS, 10% QUARTZITE, 10% WELDED TUFF; OCCASIONAL VISIBLE GLASS SHARDS IN TUFFACEOUS CLAY MATRIX; NO VISIBLE OIL INDICATORS. 430 CLAYfTUFFACEOUS CLAY = LIGHT GRAY TO GRAYISH WHITE; VERY SOFT; PASTEY TO CLOTTY; COMMON VISIBLE GLASS SHARDS; COMMONLY OCCURS AS MATRIX IN SANDS AND CONGLOMERATE. ( (J EPOCH 6 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 (~60 SAND = LIGHT GRAY TO GRAYISH BROWN; FINE LOWER TO COARSE UPPER; VERY POORLY SORTED; ANGULAR TO ROUND; LOW TO MODERATE SHPERICITY; UNCONSOLIDATED; COMMON CLAY MATRIX; INFER GRAIN SUPPORTED; COMPOSED OF 30% CLEAR AND TRANSLUCENT QUARTZ GRAINS, 40°1<> LIGHT AND DARK CHERT, 30% LITHIC FRAGMENTS; INFER GOOD INTERGRANULAR POROSITY; NO VISIBLE OIL INDICATORS. 515 CONGLOMERATE = TRANSLUCENT WHITE, DARK GRAY TO BLACK, GREEN, FINE UPPER TO PEBBLE AND POSSIBLY COBBLE SIZE GRAINS; UNCONSOLIDATED; OCCASIONAL CLAY MATRIX IN PART; VERY POORLY SORTED; LOW SPHERICITY; SUBROUND TO SUBANGULAR; COMPOSED OF 20% TRANSLUCENT QUARTZ; 300/0 CHERT; 30°1<> META-LITHIC FRAGMENTS, 10% QUARTZITE, 10% WELDED TUFF; OCCASIONAL VISIBLE GLASS SHARDS IN TUFFACEOUS CLAY MATRIX; NO VISIBLE OIL INDICATORS. 580 CLAYITUFFACEOUS CLAY = LIGHT GRAY TO GRAYISH WHITE; VERY SOFT; PASTEY TO CLOTTY; COMMON VISIBLE GLASS SHARDS; COMMONLY OCCURS AS MATRIX IN SANDS AND CONGLOMERATE. ( 610 SILTSTONE = LIGHT GRAY TO TAN; SOFT; QUARTZOSE AND TUFFACEOUS IN PART; IRREGULAR TO BLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; GRITTY TEXTURE; COMMONLY CLAYEY; OCCURS AS DESCRETE LAMINAE AND AS MATRIX IN PART; OCCASIONALLY GRADING TO VERY FINE SANDSTONE; POORLY CEMENTED; NO OIL SHOWS. 655 CLA YITUFFACEOUS CLAY = LIGHT GRAY TO GRAYISH WHITE; VERY SOFT; RUNNY TO THICK; STICKY; MODERATL Y TO VERY SOLUBLE; DOMINANTLY APPEARS AS AMORPHOUS LUMPS; DRIES TO DULL, MATTE LUSTER; SILGHTL Y SILTY TEXTURE; NON TO LOCALLY MODERATLY CALCAREOUS; COM SAND GRAINS EMBEDDED IN LUMPS; SCATTERED TO COM CARBONACEOUS MATTER; LOCALLY SIL TV, GRADING IN PART TO SILTSTONE; NO OIL INDICATORS. 705 CONGLOMERATE = MULTICOLORED, COM TRANSLUCENT WHITE, LIGHT TO DARK GRAY, BLACK, MODERATLY BROWN, OCCASIONAL MEDIUM GREENISH GRAY; CLASTS RANGE FROM FINE TO PEBBLE SIZE; ANGULAR TO WELL ROUNDED; POORLY SORTED; COMPOSED OF 30% QUARTZ, 20% CHERT, 500/0 LITHICS; SCATTERED CARBONACEOUS MATTER; CLAY MATRIX IS INFERRED; NO OIL INDICATORS. 750 SILTSTONE = LIGHT GRAY; SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; 1 TO 2 MM CUTTINGS WITH IRREGULAR HABIT; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, GRAINY TEXTURE; NON CALCAREOUS; ARGILLACEOUS, GRADING TO AND INTERBEDDED WITH CLAYSTONE; SCATTERED TO COM CARBONACEOUS SPECKS AND STREAKS; SCATTERED MICRO FINE MICA; NO OIL INDICATORS. ( n EPOCH 7 e ~ Phillips Alaska, Inc. Meltwater 2-P 417 ("'95 TUFFACEOUS CLAYSTONE = LIGHT GRAY; VERY SOFT TO OCCASIONAL SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR CUTTINGS WITH ROUNDED EDGES; MATTE, EARTHY LUSTER; SILGHTL Y GRITTY TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SCATTERED BLEBS ASH FALL TUFF; SCATTERED TO COM CARBONACEOUS MATTER; LOCALLY MODERATL Y TO VERY SIL TV, GRADING TO SILTSTONE IN PART; NO OIL INDICATORS. 840 COAL = BLACK TO DUSKY YELSH BROWN; SOFT TO FIRM; CRUMBLY TO MODERATL Y BRITTLE; SILGHTL Y SHINY LUSTER; MODERATL Y ROUGH SURFACE TEXTURE; OCCASIONAL WOODY STREAKS; OCCASIONAL FINE CLAYSTONE LAMINATIONS; NO OIL. 870 CONGLOMERATE = MULTICOLORED; COM TRANSLUCENT WHITE, CLEAR, LIGHT TO DARK GRAY, OCCASIONAL MODERATL Y BROWN OR LIGHT GREENISH GRAY; CLASTS RANGE FROM FINE TO PEBBLE FRAGMENTS; ANGULAR TO WEll ROUNDED, DOMINANTLY SUBANGULAR TO SUB ROUND; POORLY SORTED; COMPOSED OF 40% QUARTZ, 30% CHERT, 30% LITHICS; FEW GRAINS WITH CLAY STICKING TO SURFS; APPEARS TOTALLY DISAGGREGATED IN SPLS; NO ACID REACTION; NO Oil INDICATORS. 925 SilTSTONE = liGHT GRAY; SOFT TO SllGHTL Y FRIM; MUSHY TO CRUMBLY; DULL LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON CALCAREOUS; APPEARS AS AMORPHOUS LUMPS; ARGilLACEOUS, GRADING TO CLAYSTONE; COMMON CARBONACEOUS SPECKS; SCATTERED MICRO FINE MICA FLAKES; NO OIL. ( 965 TUFFACEOUS CLAYSTONE = liGHT GRAY TO PALE YELLOWISH BROWN; VERY SOFT TO SOFT; MUSHY TO CRUMBLY, OCCASIONAL SILGHTL Y BRITTLE; SMALL IRREGULAR AND SUBBlOCKY CUTTINGS; MATTE, EARTHY LUSTER; SMOOTH TO MODERATL Y GRITTY TEXTURE; NON TO LOCALLY VERY CALCAREOUS; COMMON ASHY APPEARANCE; SCATTERED TO COM CARBONACEOUS MATTER; OCCASIONAL FIRM TO HARD AND VERY CALCAREOUS, GRADING TO LIMESTONE; OCCASIONAL VERY Sll TV, GRADING IN PART TO SilTSTONE; NO Oil INDICATORS. 1025 SAND = MULTICOLORED, DOMINANTLY TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, OCCASIONAL liGHT GREENISH GRAY; CLASTS RANGE FROM VERY FINE TO COARSE, DOMINANTLY VERY FINE TO FINE; SUBANG TO SUBRND; POORLY SORTED; COMPOSED OF 600/0 QUARTZ, 40% LITHICS; APPEARS AS LOOSE GRAINS IN SAMPLEES; APPARENTLY OCCURS AS THIN INTERBEDS WITH CLA YSTONE/SIL TSTONE; NO OIL INDICATORS. 1075 SILTSTONE = LIGHT GRAY; SOFT TO SllGHTl Y FRIM; MUSHY TO CRUMBLY; DULL LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON CALCAREOUS; APPEARS AS AMORPHOUS LUMPS; ARGILLACEOUS, GRADING TO CLAYSTONE; COMMON CARBONACEOUS SPECKS; SCATTERED MICRO FINE MICA FLAKES; NO OIL. ( (1 EPOCH 8 œ W Phillips Alaska, Inc. Meltwater 2-P 417 {" '115 TUFFACEOUS CLAYSTONE = LIGHT GRAY TO PALE YELLOWISH BROWN; VERY SOFT TO SOFT; MUSHY TO CRUMBLY, OCCASIONAL SILGHTL Y BRITTLE; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE, EARTHY LUSTER; SMOOTH TO MODERATL V GRITTY TEXTURE; NON TO LOCALLY VERY CALCAREOUS; COMMON ASHY APPEARANCE; SCATTERED TO COM CARBONACEOUS MATTER. 1155 SILTSTONE = LIGHT GRA V, OCCASIONAL WITH SILGHTL V BROWNISH HUES; VERY SOFT TO SILGHTL Y FIRM; DOMINANTLY MUSHY TO CRUMBLY, OCCASIONAL SILGHTL Y BRITTLE; SMALL IRREGULAR SHAPED CUTTINGS; DULL LUSTER WITH SCATTERED SPARKLES; GRITTY, GRAINY TEX; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; COMMON BLACK PINPOINT SPECKS; SCATTERED MICRO MICA; OCCASIONAL VERY ARGIL, GRADING TO AND INTERBEDDED WITH CLAYSTONE; NO OIL INDICATORS. 1205 TUFFACEOUS CLAYSTONE = LIGHT GRAY TO PALE YELLOWISH BROWN; VERY SOFT TO SOFT; MUSHY TO CRUMBLY, OCCASIONAL SILGHTL Y BRITTLE; IRREGULAR AND SUBBLOCKY CUTTINGS HABIT; MATTE LUSTER; MODERATL Y GRAINY TEXTURE; NON TO OCCASIONAL MODERATLY CALCAREOUS; COM ASHY APPEARANCE; TRACE SHELL FRAGMENTS; SCATTERED CARBONACEOUS MATTER; LOCALLY SILTY, GRADES IN PART TO SILTSTONE; NO OIL. 1255 SILTSTONE = LIGHT GRAY, OCCASIONAL WITH SILGHTL Y BROWNISH HUES; VERY SOFT TO SILGHTL Y FIRM; DOMINANTLY MUSHY TO CRUMBLY, OCCASIONAL SILGHTL Y BRITTLE; SMALL IRREGULAR SHAPED CUTTINGS; DULL LUSTER WITH SCATTERED SPARKLES; GRITTY, GRAINY TEX; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; COMMON BLACK PINPOINT SPECKS; SCATTERED MICRO MICA; OCCASIONAL VERY ARGIL; RARE SHELL FRAGMENTS; INTERBEDDED WITH CLAYSTONE; NO OIL INDICATORS. 1305 TUFFACEOUS CLAYSTONE = LIGHT GRAY TO PALE YELLOWISH BROWN; VERY SOFT TO SOFT; MUSHY TO CRUMBLY, OCCASIONAL SILGHTL Y BRITTLE; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE, EARTHY LUSTER; SMOOTH TO MODERATL V GRITTY TEXTURE; NON TO LOCALLY VERY CALCAREOUS; COMMON ASHY APPEARANCE; SCATTERED TO COM CARBONACEOUS MATTER. 1345 COAL = BLACK TO DUSKY BROWN; FIRM; BRITTLE; SMALL HACKL Y AND TABULAR CUTTINGS; SILGHTL Y SHINY LUSTER; MODERATL Y ROUGH SURFACE TEXTURE; SCATTERED LAMS OF CLAYSTONE; OCCASIONAL APPEARS WOODY; RARE GAS BUBBLES ON FRACTURE SURFACES; NO OIL INDICATORS. ( n EPOCH 9 Sf ~ Phillips Alaska, Inc. Meltwater 2-P 417 ( '380 SAND = MULTICOLORED, DOMINANTLY TRANSLUCENT WHITE, LIGHT TO MEDIUM GRAY, OCCASIONAL LIGHT GREENISH GRAY; CLASTS RANGE FROM VERY FINE TO COARSE, DOMINANTLY VERY FINE TO FINE; SUBANG TO SUBRND; POORLY SORTED; COMPOSED OF 60% QUARTZ, 400/0 LITHICS; APPEARS AS LOOSE GRAINS IN SAMPLEES; APPARENTLY OCCURS AS THIN INTERBEDS WITH CLAYSTONE/SILTSTONE; NO OIL INDICATORS. 1430 CONGLOMERATE = MULTICOLORED; COM TRANSLUCENT WHITE, CLEAR, LIGHT TO DARK GRAY, OCCASIONAL MODERATL Y BROWN OR LIGHT GREENISH GRAY; CLASTS RANGE FROM FINE TO PEBBLE FRAGMENTS; ANGULAR TO WELL ROUNDED, DOMINANTLY SUBANGULAR TO SUB ROUND; POORLY SORTED; COMPOSED OF 40%) QUARTZ, 30% CHERT, 300/0 LITHICS; FEW GRAINS WITH CLAY STICKING TO SURFS; APPEARS TOTALLY DISAGGREGATED IN SPLS; TRACE HYDRATES IN PART; TRACE IRON SILTSTONE IN PART; NO OIL INDICATORS. 1505 SILTSTONE = LIGHT GRAY, OCCASIONAL WITH SILGHTL Y BROWNISH HUES; VERY SOFT TO SILGHTL Y FIRM; DOMINANTLY MUSHY TO CRUMBLY, OCCASIONAL SILGHTL Y BRITTLE; SMALL IRREGULAR SHAPED CUTTINGS; DULL LUSTER WITH SCATTERED SPARKLES; GRITTY, GRAINY TEX; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; COMMON BLACK PINPOINT SPECKS; SCATTERED MICRO MICA; OCCASIONAL VERY ARGIL; RARE SHELL FRAGMENTS; INTERBEDDED WITH CLAYSTONE; NO OIL INDICATORS. ( ~555 CLAYSTONEITUFFACEOUS CLAYSTONE = LIGHT GRAY TO PALE YELLOWISH BROWN AND REDISH BROWN; VERY SOFT TO SOFT; MUSHY TO OCCASIONALLY CRUMBLY; IRREGULAR TO MASSIVE CUTTINGS; IRREGULAR TO OCCASIONAL PLATY FRACTURE; MATTE TO DULL EARTHY LUSTER; SMOOTH TO OCCASIONAL GRITTY TEXTURE; SLIGHTLY CALCAREOUS; INTERBED WITH SILTSTONE IN PART; COMMON CARBONACEOUS MATERIAL. 1610 CONGLOMERATE = MULTICOLORED; COM TRANSLUCENT WHITE, CLEAR, LIGHT TO DARK GRAY, OCCASIONAL MODERATLY BROWN OR LIGHT GREENISH GRAY; CLASTS RANGE FROM FINE TO PEBBLE FRAGMENTS; ANGULAR TO WELL ROUNDED, DOMINANTLY SUBANGULAR TO SUB ROUND; POORLY SORTED; COMPOSED OF 40% QUARTZ AND QUARTZITE, 30% CHERT, 30% LITHIC FRAGMENTS, COMMONLY OBSERVED GRAINS WITH CLAY STICKING TO SURFS; APPEARS DISAGGREGATED IN PART; TRACE HYDRATES IN PART; TRACE IRON SILTSTONE IN PART; NO OIL INDICATORS. 1675 SANDSTONE = LIGHT GRAY TO SALT AND PEPPER TO GRAY GREEN; FIRM TO HARD; VERY FINE LOWER TO LOWER MEDIUM WITH OCCASIONAL MEDIUM TO COARSE; SUBROUND TO PREDOMINANTLY SUBANGULAR; MODERATE SPHERICITY; MODERA TL Y TO GOOD SORTING; SILICEOUS CEMENT; COMMONLY APPEAR WELDED AND OCCASIONAL RECRYSTALIZED; QUARTZITE IN PART; OCCASIONAL CLORITIZED; ESTIMATE VERY POOR TO OCCASIONAL FAIR INTERGRAINULAR POROSITY; NO VISIBLE OIL INDICATORS. (' ~ EPOCH 10 a ~ Phillips Alaska, Inc. Meltwater 2-P 417 'i '735 CONGLOMERATE = MULTICOLORED; PREDOMINANTLY PEBBLE SIZE WITH ~ OCCASIONAL COARSE SAND; PREDOMINANTLY WELL ROUNDED; LOW SPHERICITY; MODERATELY SORTED; 20°/Ó QUARTZ, 30& CHERT, 100/0 QUARTZITE; 40°/Ó LITHIC FRAGMENTS; NO VISIBLE MATRIX; DISSAGERATED; NO VISIBLE OIL SHOWS. 1775 SILTSTONE - LIGHT GRAY TO WHITISH GRAY AND SALT AND PEPPER; SOFT TO FIRM; PREDOMINANTLY QUARTZOSE; MASSIVE CUTTINGS; IRREGULAR TO BLOCKY FRACTURE; VERY CLAYEY IN PART; GRITTY TEXTURE; GRADING TO VERY FINE SANDSTONE; ( 1810 CLAYSTONE = LIGHT GRAY, PALE YELSH BROWN, OCCASIONAL LIGHT GREENISH GRAY; SOFT; MUSHY TO CRUMBLY; SMALL IRREGULAR, SUBBLOCKY AND SUBTABULAR CUTTINGS WITH ROUNDED EDGES; MATTE, EARTHY LUSTER; MODERATL Y GRITTY TEX; NON TO LOCALLY MODERATL Y CALCAREOUS; LOCALLY SILTY, GRADING TO AND INTERBEDDED WITH SILTSTONE; COM CARBONACEOUS MATTER; OCCASIONAL THIN COAL SEAMS; TRACE MODERATL Y BRI LIGHT YELLOW SPL FL; NO CUT; NO OTHER OIL INDICATORS. 1865 SILTSTONE = LIGHT GRAY, OCCASIONAL WITH SILGHTL Y BROWNISH HUES; SOFT TO OCCASIONAL SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SANDY IN PART; OCCASIONAL GRADES TO VERY FINE SANDSTONE; INTERBEDDED WITH CLAYSTONE; TRACE MODERATL Y BRI LIGHT YELLOW SPL FL; NO CUT OR OTHER OIL INDICATORS. 1920 SANDSTONE = LIGHT GRAY TO WHITE, COMMON SALT AND PEPPER APPEARANCE; CRUMBLY; CLASTS RANGE FROM SILT TO VERY FINE UPPER; SUBROUNDED; MODERATL Y WELL SORTED; DOMINANTLY QUARTZ WITH COMMON LITHICS; ESTIMATED POOR POR AND PERM; CLAY MATRIX; NON TO SILGHTL Y CALCAREOUS; NO APPARENT OIL. 1960 CLAYSTONE = LIGHT GRAY, PALE YELSH BROWN, LIGHT GREENISH GRAY; VERY SOFT TO SOFT; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBPLATY CUTTINGS; MATTE LUSTER; SILGHTL Y GRITTY TEXTURE; NON TO LOCALLY MODERATL Y CALCAREOUS; SILTY IN PART, GRADING TO AND INTERBEDDED WITH SILTSTONE; SCATTERED TO COM BLACK PINPOINT SPECKS; NO OIL INDICATORS. 201 0 SILTSTONE = LIGHT GRAY, OCCASIONAL WITH SILGHTL Y BROWNISH HUES; SOFT TO OCCASIONAL SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SANDY IN PART; OCCASIONAL GRADES TO VERY FINE SANDSTONE; INTERBEDDED WITH CLAYSTONE; NO APPARENT OIL INDICATORS. ( [:I EPOC:H 11 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 f "'060 SANDSTONE = LIGHT GRAY TO WHITE, COMMON SALT AND PEPPER APPEARANCE; CRUMBLY; CLASTS RANGE FROM SILT TO VERY FINE UPPER; SUBROUNDED; MODERA TL Y WELL SORTED; DOMINANTLY QUARTZ WITH COMMON LlTHICS; ESTIMATED POOR POR AND PERM; CLAY MATRIX; NON TO SILGHTL Y CALCAREOUS; NO APPARENT OIL INDICATORS. 2105 SANDSTONE = LIGHT GRAY TO WHITE; MODERATL Y FIRM; CRUMBLY; CLASTS RANGE FROM VERY FINE LOWER TO FINE UPPER; SUBANGULAR TO SUBROUND; MODERATL Y WELL SORTED; COMPOSED OF QUARTZ WITH COMMON LITHICS; CLAY MATRIX; MATRIX SUPPORTED; NON TO SILGHTL Y CALCAREOUS; ESTIMATED POOR POR AND PERM; NO OIL INDICATORS. 2150 CLAYSTONE = LIGHT GRAY, PALE YELSH BROWN, LIGHT GREENISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBPLATY CUTTINGS; MATTE LUSTER; SILGHTL Y GRITTY TEXTURE; NON TO LOCALLY MODERATL Y CALCAREOUS; SILTY IN PART, GRADING TO AND INTERBEDDED WITH SILTSTONE; SCATTERED TO COM BLACK PINPOINT SPECKS; TRACE ASH FALL TUFF; NO OIL INDICATORS. ( 2200 SILTSTONE = LIGHT GRAY, PALE YELSH BROWN, LIGHT BROWNISH GRAY; SOFT TO OCCASIONAL SILGHTL Y FIRM; CRUMBLY TO RARELY SILGHTL Y BRITTLE; DULL LUSTER; GRITTY, ABRASIVE TEXTURE; NON TO lOCALLY SILGHTL Y CALCAREOUS; ARGilLACEOUS, GRADING IN PART TO CLAYSTONE; lOCALLY SANDY, GRADING IN PART TO VERY FINE GRAIN SANDSTONE; SCATTERED MICRO FINE MICA; SCATTERED TO COM BLACK PINPOINT SPECKS; NO OIL INDICATORS. 2255 SANDSTONE = LIGHT GRAY TO SLIGHTLY BROWNISH GRAY; SOFT TO FIRM; VERY FINE LOWER TO FINE UPPER; PREDOMINANTLY SUBROUND TO ANGULAR; MODERATELY TO WELL SORTED; MODERATE SPHERICITY; GRAIN AND MATRIX SUPPORTED; COMPOSED OF PREDOMINANTLY QUARTZ WITH LITHICS; SILTY CLAYEY MATRIX; GRADES TO SILTSTONE IN PART; POROSITY COMMONLY INFILLED WITH MATRIX; ESTIMATED VERY POOR TO POOR INTERGRAN- ULAR POROSITY; NO SHOWS. 2315 CLAYSTONE = LIGHT GRAY, PALE YELSH BROWN, LIGHT GREENISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBPLATY CUTTINGS; MATTE LUSTER; SILGHTL Y GRITTY TEXTURE; NON TO LOCALLY MODERA TL Y CALCAREOUS; SILTY IN PART, GRADING TO AND INTERBEDDED WITH SILTSTONE; SCATTERED TO COM BLACK PINPOINT SPECKS; TRACE ASH FALL TUFF; NO OIL INDICATORS. 2365 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; TO FIRM; CRUMBLY; DULL TO EARTHY LUSTER; GRITTY TEXTURE; SLIGHTLY CALCAREOUS IN PART; ARGILLACEOUS TO VERY ARGILLACEOUS; INTERBEDDED WITH AND OCCASIONALLY GRADING TO CLAYSTONE; SANDY TO VERY SANDY IN PART; COMMONLY GRADING TO VERY FINE SANDSTONE; RARELY WELL CEMENTED; NO VISIBLE OIL SHOWS. ( fJ EPOCH 12 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 , "'425 ( CLAYSTONE = LIGHT GRAY WITH OCCASIONAL PALE YELLOWISH BROWN HUES; SOFT; CRUMBLY TO OCCASIONAL MODERATL Y FIRM; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE, EARTHY LUSTER; SMOOTH TO MODERATLY GRITTY TEXTURE; NON TO LOCALLY MODERA TL Y CALCAREOUS; LOCALLY SILTY, GRADING IN PART TO SILTSTONE; SCATTERED CARBONACEOUS SPECKS; SCATTERED ASHY ZONES; NO OIL INDICATORS. 2470 CONGLOMERATE = (TRACE AMOUNTS) TRANSLUCENT WHITE, CLEAR, BLACK; GRANULE AND PEBBLE FRAGMENTS; ANGULAR PIECES OF WELL ROUNDED GRAINS; POORLY SORTED; LOOSE IN SAMPLEE; QUARTZ WITH COMMON IGNEOUS AND META LITHICS; OCCASIONAL THIN COATING OF CLAY ON SOME GRAINS; NO OIL INDICATORS. 251 0 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SCATTERED CARBONACEOUS SPECKS; SCATTERED MICRO FINE MICA; INTERBEDDED AND GRADING TO CLAYSTONE IN PART; SCATTERED ASH FALL TUFF BLEBS; NO OIL INDICATORS. 2560 ASH FALL TUFF = LIGHT GRAY TO WHITE; VERY SOFT TO RARELY MODERATL Y HARD; VARIABLE AMORPHOUS TO RARELY PLATY CUTTINGS; DOMINANTLY EARTHY LUSTER, RARELY SILGHTL Y RESINOUS; APPEARS AS BLEBS IN CLAYSTONE AND AS FREE IRREGULAR TO PLATY CUTTINGS IN SPLS; MODERATL Y BRIGHT LIGHT YELLOW MINERAL FLUORESCENCE; NO OIL INDICATORS. 2605 CLAYSTONE = LIGHT GRAY WITH OCCASIONAL PALE YELSH BROWN HUES; SOFT; CRUMBLY TO OCCASIONAL MODERATL Y FIRM; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE, EARTHY LUSTER; SMOOTH TO MODERATLY GRITTY TEXTURE; NON TO LOCALLY MODERATL Y CALCAREOUS; LOCALLY SILTY, GRADING IN PART TO SILTSTONE; SCATTERED CARBONACEOUS SPECKS; SCATTERED ASHY ZONES; NO OIL INDICATORS. 2650 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SCATTERED CARBONACEOUS SPECKS; SCATTERED MICRO FINE MICA; INTERBEDDED AND GRADING TO CLAYSTONE IN PART; SCATTERED ASH FALL TUFF BLEBS; NO OIL INDICATORS. 2700 ASH FALL TUFF = LIGHT GRAY TO WHITE; VERY SOFT TO RARELY MODERATL Y HARD; HABIT IS AMORPHOUS TO RARELY PLATY CUTTINGS; DOMINANTLY EARTHY LUSTER, RARELY SILGHTL Y RESINOUS; APPEARS AS BLEBS IN CLAYSTONE AND AS FREE IRREGULAR TO PLATY CUTTINGS IN SPLS; MODERATL Y BRIGHT LIGHT YELLOW MINERAL FLUORESCENCE; NO OIL INDICATORS. ( ~ EPOCH 13 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 ~- "745 CLAYSTONE = MEDIUM DARK GRAY TO BROWNISH GRAY; SOFT TO MODERATL Y FIRM; CRUMBLY TO OCCASIONAL SILGHTL Y BRITTLE; SMALL IRREGULAR, SUBBLOCKY AND SUBTABULAR CUTTINGS; EARTHY TO OCCASIONAL SILGHTL Y SHINY LUSTER; SMOOTH TO MODERATL Y GRITTY TEXTURE; NON CALCAREOUS; LOCALLY COMMON TUFFACEOUS STREAKS AND BLEBS; OCCASIONAL THINLY INTERBEDD WITH ASH FALL TUFF; LOCALLY SIL TV, RARELY GRADES TO SILTSTONE; NO OIL INDICATORS. 2800 TUFFACEOUS ASH = WHITE TO LIGHT GRAY WITH OCCASIONAL MEDIUM GRAY; VERY SOFT TO OCCASIONAL FIRM; PREDOMINANTLY AMORPHOUS TO MASSIVE CUTTINGS HABIT; EARTHY TO OCCASIONAL SPARKL Y LUSTER; APPEARS AS BLEBS IN OCCASIONAL YELLOW MINERAL FLUORESCENCE. 2835 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTLY FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SCATTERED CARBONACEOUS SPECKS; SCATTERED MICRO FINE MICA; INTERBEDDED AND GRADING TO CLAYSTONE IN PART; SCATTERED ASH FALL TUFF BLEBS; NO OIL INDICATORS. 2885 CLAYSTONE = MEDIUM GRAY TO BROWNISH GRAY; PREDOMINANTLY SOFT TO FIRM; CRUMBLY TO MUSHY, RARE BRITTLE; IRREGULAR TO SUBBLOCKY CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; SMOOTH TO OCCASIONAL GRITTY TEXTURE; OCCASIONAL SIL TV AND TUFFACEOUS ASH LAMINAE. 2930 TUFFACEOUS ASH = WHITE TO LIGHT GRAY WITH OCCASIONAL MEDIUM GRAY; VERY SOFT TO OCCASIONAL FIRM; PREDOMINANTLY AMORPHOUS TO MASSIVE CUTTINGS HABIT; EARTHY TO OCCASIONAL SPARKL Y LUSTER; APPEARS AS BLEBS IN OCCASIONAL YELLOW MINERAL FLUORESCENCE; RARE VISIBLE GLASS SHARDS. 2970 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO STIFF; CRUMBLY TO OCCASIONAL BRITTLE; IRREGULAR TO BLOCKY CUTTINGS HABIT; PLANAR TO IRREGULAR FRACTURE; GRITTY, ABRASIVE TEXTURE; MATTE TO SPARKL Y LUSTER; TRACE MICROMICACEOUS; TRACE CARBONACEOUS MATERIAL; VERY CLAYEY IN PART; NO VISIBLE OIL INDICATORS. 3015 TUFFACEOUS ASH = WHITE TO LIGHT GRAY WITH OCCASIONAL MEDIUM GRAY; VERY SOFT TO OCCASIONAL FIRM; PREDOMINANTLY AMORPHOUS TO MASSIVE CUTTINGS HABIT; EARTHY TO OCCASIONAL SPARKL Y LUSTER; APPEARS AS BLEBS IN OCCASIONAL YELLOW MINERAL FLUORESCENCE; RARE VISIBLE GLASS SHARDS. 3055 CLAYSTONE/CARBONACEOUS CLAYSTONE = MEDIUM TO DARK BROWNISH GRAY; VERY SOFT TO STIFF; MUSHY TO PASTEY AND OCCASIONALLY CRUMBLY; SUBBLOCKY TO MASSIVE CUTTINGS; IRREGULAR TO BLOCKY FRACTURE; DULL EARTHY TO RESINOUS LUSTER; COMMON CARBONACEOUS MATERIAL; SLIGHTLY SIL TV IN PART. (' n EPOC:H 14 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 ~ "'\ 1 00 TUFFACEOUS ASH = WHITE TO LIGHT GRAY WITH OCCASIONAL VERY PALE GREEN; VERY SOFT TO OCCASIONAL FIRM; PREDOMINANTLY AMORPHOUS TO MASSIVE CUTTINGS HABIT; BRITTLE TO BLOCKY FRACTURE; DULL EARTHY TO RESINOUS SPARKL Y LUSTER; APPEARS AS BLEBS AND ON CLAYS CUTTINGS AND AS DESCRETE LAMINAE; OCCASIONAL YELLOW MINERAL FLUORESCENCE; RARE VISIBLE GLASS SHARDS. 3150 CLAYSTONE/CARBONACEOUS CLAYSTONE = MEDIUM TO DARK BROWNISH GRAY; VERY SOFT TO STIFF; MUSHY TO PASTEY AND OCCASIONALLY CRUMBLY; SUB BLOCKY TO MASSIVE CUTTINGS; IRREGULAR TO BLOCKY FRACTURE; DULL EARTHY TO RESINOUS LUSTER; COMMON CARBONACEOUS MATERIAL; SLIGHTLY SIL TV IN PART. 3195 TUFFACEOUS ASH = WHITE TO LIGHT GRAY WITH OCCASIONAL VERY PALE GREEN; VERY SOFT TO OCCASIONAL FIRM; PREDOMINANTLY AMORPHOUS TO MASSIVE CUTTINGS HABIT; BRITTLE TO BLOCKY FRACTURE; DULL EARTHY TO RESINOUS SPARKL Y LUSTER; APPEARS AS BLEBS AND ON CLAYS CUTTINGS AND AS DESCRETE LAMINAE; OCCASIONAL YELLOW MINERAL FLUORESCENCE; RARE VISIBLE GLASS SHARDS. 3245 CLAYSTONE = MEDIUM GRAY TO BROWNISH GRAY; PREDOMINANTLY SOFT TO FIRM; CRUMBLY TO MUSHY, RARE BRITTLE; IRREGULAR TO SUBBLOCKY CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; SMOOTH TO OCCASIONAL GRITTY TEXTURE; OCCASIONAL SIL TV AND TUFFACEOUS ASH LAMINAE. ( 3305 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO STIFF; CRUMBLY TO OCCASIONAL BRITTLE; IRREGULAR TO BLOCKY CUTTINGS HABIT; PLANAR TO IRREGULAR FRACTURE; GRITTY, ABRASIVE TEXTURE; MATTE TO SPARKL Y LUSTER; TRACE MICROMICACEOUS; COMMON CARBONACEOUS MATERIAL; VERY CLAYEY; NO VISIBLE OIL INDICATORS. 3350 CLAYSTONE/CARBONACEOUS CLAYSTONE = MEDIUM TO DARK BROWNISH GRAY; VERY SOFT TO STIFF; MUSHY TO PASTEY AND OCCASIONALLY CRUMBLY; SUBBLOCKY TO MASSIVE CUTTINGS; IRREGULAR TO BLOCKY FRACTURE; DULL EARTHY TO RESINOUS LUSTER; COMMON CARBONACEOUS MATERIAL; SLIGHTLY SILTY IN PART. 3395 TUFFACEOUS ASH = WHITE TO LIGHT GRAY WITH OCCASIONAL VERY PALE GREEN; VERY SOFT TO OCCASIONAL FIRM; PREDOMINANTLY AMORPHOUS TO MASSIVE CUTTINGS HABIT; BRITTLE TO BLOCKY FRACTURE; DULL EARTHY TO SUB- VITREOUS LUSTER; APPEARS AS BLEBS AND ON CLAYS CUTTINGS AND AS DESCRETE LAMINAE; OCCASIONAL YELLOW MINERAL FLUORESCENCE; RARE VISIBLE GLASS SHARDS; DECREASING CONTENT WITH DEPTH. ( ~ EPOCH 15 = ~ Phillips Alaska, Inc. Meltwater 2-P 417 , ",450 CLAYSTONE = MEDIUM BROWNISH GRAY WITH SILGHTL Y OLIVE HUES; SOFT TO \ SILGHTL Y FIRM; CRUMBLY TO OCCASIONAL MODERA TL Y BRITTLE; EARTHY LUSTER; MODERATL Y GRITTY TEXTURE; SMALL BLOCKY AND TABULAR CUTTINGS; NON CALCAREOUS; SCATTERED BLEBS OF ASH FALL TUFF; OCCASIONAL CARBONACEOUS LAMS; RARELY VERY SILTY, GRADING IN PART TO SILTSTONE; NO OIL INDICATORS. 3495 ASH FALL TUFF = LIGHT GRAY, WHITE, PALE YELSH BROWN, PALE BLUE; SOFT TO MODERATL Y FIRM; CRUMBLY TO MODERATL Y BRITTLE; CHALKY TO SILGHTL Y RESINOUS LUSTER; DOMINANTLY SMOOTH TO SILGHTL Y GRITTY TEXTURE; NON CALCAREOUS TO LOCALLY SILGHTL Y CALCAREOUS; APPEARS THINLY INTERBEDDED WITH CLA YSTONE/SIL TSTONE; MODERA TL Y BRIGHT LIGHT YELLOW MINERAL FLUORESCENCE; NO OIL INDICATORS. 3540 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SCATTERED CARBONACEOUS SPECKS; SCATTERED MICRO FINE MICA; INTERBEDDED AND GRADING TO CLAYSTONE IN PART; SCATTERED ASH FALL TUFF STREAKS AND BLEBS; NO OIL. 3590 SHALE = DARK GRAY; FIRM; MODERATL Y BRITTLE; MODERATL Y TOUGH; MATTE TO SILGHTL Y SHINY LUSTER; SMOOTH TO MODERATL Y GRITTY TEXTURE; NON CALCAREOUS; CARBONACEOUS IN PART; INTERBEDDED WITH CLAYSTONE; POOR TO MODERATL Y FISSILITY; SCATTERED ASHY LAMINATIONS; NO OIL. 3625 ASH FALL TUFF = LIGHT GRAY, WHITE, PALE YELSH BROWN, PALE BLUE; SOFT TO MODERATL Y FIRM; CRUMBLY TO MODERATL Y BRITTLE; CHALKY TO SILGHTL Y RESINOUS LUSTER; DOMINANTLY SMOOTH TO SILGHTL Y GRITTY TEXTURE; NON CALCAREOUS TO LOCALLY SILGHTL Y CALCAREOUS; APPEARS THINLY INTERBEDDED WITH CLAYSTONE/SIL TSTONE; MODERATL Y BRIGHT LIGHT YELLOW MINERAL FLUORESCENCE; NO OIL INDICATORS. 3670 CLAYSTONE = MEDIUM BROWNISH GRAY WITH SILGHTL Y OLIVE HUES; SOFT TO SILGHTL Y FIRM; CRUMBLY TO OCCASIONAL MODERATL Y BRITTLE; EARTHY LUSTER; MODERATL Y GRITTY TEXTURE; SMALL BLOCKY AND TABULAR CUTTINGS; NON CALCAREOUS; SCATTERED BLEBS OF ASH FALL TUFF; OCCASIONAL CARBONACEOUS LAMS; RARELY VERY SILTY, GRADING IN PART TO SILTSTONE; NO OIL INDICATORS. 3715 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SCATTERED CARBONACEOUS SPECKS; SCATTERED MICRO FINE MICA; INTERBEDDED AND GRADING TO CLAYSTONE IN PART; SCATTERED ASH FALL TUFF STREAKS AND BLEBS; NO OIL. ( ~EPO(:H 16 a ~ Phillips Alaska, Inc. Meltwater 2-P 417 ~ "',765 ASH FALL TUFF = LIGHT GRAY, WHITE, PALE YELSH BROWN, PALE BLUE; SOFT TO MODERATL Y FIRM; CRUMBLY TO MODERATL Y BRITTLE; CHALKY TO SILGHTL Y RESINOUS LUSTER; DOMINANTLY SMOOTH TO SILGHTL Y GRITTY TEXTURE; NON CALCAREOUS TO LOCALLY SILGHTL Y CALCAREOUS; APPEARS THINLY INTERBEDDED WITH CLAYSTONE/SIL TSTONE; SCATTERED TO COMMON VOLCANIC GLASS SHARDS; SCATTERED BLACK PINPOINT SPECKS; TRACE MODERATLY BRIGHT LIGHT YELLOW MINERAL FL; NO OIL INDICATORS. 3830 SHALE = DARK GRAY; FIRM; MODERATELY BRITTLE; IRREGULAR TO PLATEY FRACTURE; ELONGATE TO WEDGE LIKE CUTTINGS HABIT; MATTE TO SPARKEL Y LUSTER; OCCASIONALLY MICROMICACEOUS IN PART; TRACE SILTY IN PART; INTERBEDDED WITH CLAYSTONE IN PART; SCATTERED ASHY LAMINATIONS. 3885 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; SMALL IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SCATTERED CARBONACEOUS SPECKS; SCATTERED MICRO FINE MICA; INTERBEDDED AND GRADING TO CLAYSTONE IN PART; OCCASIONALLY GRADINGTO VERY FINE SANDSTONE WITH CLAY MATRIX; NO OIL SHOWS. ( 3940 CLAY = LIGHT GRAY TO LIGHT GREENISH GRAY; VERY SOFT TO SOFT; CRUMBLY TO PASTEY; IRREGULAR TO SUBPLATEY CUTTINGS; MATTE TO DULL LUSTER; SILTY; INTERBEDDED WITH AND GRADING TO SILTSTONE; RARE TUFFACEOUS ASH LAMINAE AND BLEBS. 3975 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; IRREGULAR AND SUBTABULAR FRACTURE; MASSIVE TO SUBBLOCKY CUTTINGS; MATTE TO SUBSPARKL Y LUSTER; GRITTY TO ABRASIVE TEXTURE; RARE CARBONACEOUS MATERIAL; GRADING TO VERY FINE SILTSTONE IN PART; VERY CLAYEY; NO VISIBLE OIL INDICATORS. 4025 SANDSTONE = LIGHT GRAY TO WHITISH GRAY; FIRM; VERY FINE LOWER TO FINE LOWER; SUBANGULAR; MODERATELY SORTED; MODERATE SPHERICITY; PREDOMINANTLY CLAY MATRIX SUPPORTED; COMPOSED OF PREDOMINANTLY QUARTZ WITH MINOR LITHICS AND RARE CABONACEOUS MATERIAL; VERY SIL TV GRADING TO SILTSTONE; ESTIMATED NIL TO VERY POOR EFFECTIVE POROSITY; NO OIL SHOWS. 4075 CLAY = LIGHT GRAY TO LIGHT GREENISH GRAY; VERY SOFT TO SOFT; CRUMBLY TO PASTEY; IRREGULAR TO SUBPLATEY CUTTINGS; MATTE TO DULL LUSTER; SILTY; INTERBEDDED WITH AND GRADING TO SILTSTONE; VERY RARE DARK GRAY SHALE. ( ~ EPOCH 17 œ ~ Phillips Alaska, Inc. Meltwater 2-P 417 \ '.11 0 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; IRREGULAR AND SUBTABULAR FRACTURE; MASSIVE TO SUBBLOCKY CUTTINGS; MATTE TO SUBSPARKL Y LUSTER; GRITTY TO ABRASIVE TEXTURE; RARE CARBONACEOUS MATERIAL; OCCASIONALLY GRADING TO VERYFINE SANDSTONE IN PART;NO VISIBLE OIL INDICATORS, 4160 CLAY = LIGHT GRAY TO LIGHT GREENISHGRAY; VERY SOFT TO SOFT; CRUMBLY TO PASTEY; IRREGULAR TO SUBPLATEY CUTTINGS; MATTE TO DULL LUSTER; SILTY; INTERBEDDED WITH AND GRADING TO SILTSTONE; VERY RARE DARK GRAY SHALE. 4195 SHALE = DARK GRAY; FIRM TO MODERATLY HARD;CRUMBLY TO MODERATLY TOUGH; MATTE TO SLlSHINY LUSTER; DOMINANTLY SMOOTH TO MODERATLY GRITTY TEXTURE; SMALL PLATY CUTTINGS WITH DISTINCT EDGES; NON CALCAREOUS; SCATTERED CARBONACEOUS SPECKS; SCATTERED CLAYSTONE LAMINATIONS; OCCASIONAL BLEBS TUFFACEOUS MATERIAL; POOR TO OCCASIONAL GOOD FISSILITY; NO OIL INDICATORS. 4240 ASH FALL TUFF = (TRACE AMOUNTS) WHITE,LIGHT GRAY, PALE BLUE, PALE YELLOWISH BROWN; SOFT TO FIRM; CRUMBLY TO RARELY MODERATL Y BRITTLE;CHALKY TO SILGHTL Y RESINOUS LUSTER; DOMINANTLY SMOOTH TEXTURE; NON TO LOCALLY SILGHTL Y CALCAREOUS; THINLY LAMINATED WITH CLAYSTONE; NO OIL INDICATORS. ( +280 CLAYSTONE = LIGHT GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO OCCASIONAL SILGHTL Y BRITTLE;IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER;SMOOTH TO MODERATL Y SILTY TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; INCREASINGLY WATER SOLUBLE;INCREASINGL Y ASHY; SCATTERED TO COM ASH LAMS AND STREAKS; SCATTERED BLACK PINPOINT SPECKS; LOCALLY SILTY GRADING IN PART TO SILTSTONE; NO OIL INDICATORS. 4330 SANDSTONE = LIGHT GRAY OVERALL; FRIABLE; CLASTS RANGE FROM VERY FINE LOWER TO VERY FINE UPPER; SUBANG TO SUBROUND;MODERATL Y WELL SORTED; SILTY; CLAY MATRIX SUPPORTED; ESTIMATED POOR POR AND PERM; NO APPARENT OIL INDICATORS. 4365 COAL = BLACK; FIRM TO MODERATL Y HARD;BRITTLE, MODERATL Y TOUGH; HACKL Y AND TABULAR CUTTINGS WITH SHARP EDGES; RESINOUS LUSTER; SMOOTH TEXTURE; RARE PINPOINTGAS BUBBLES ON FRACTURE SURFS; RARELY LAMINATED WITH ASH FALL TUFF OR CLAYSTONE. ( 4405 ASH FALL TUFF = LIGHT GRAY, WHITE, PALE YELSH BROWN, RARELY PALE BLUE; SOFT TO FIRM, OCCASIONAL MOD ERA TL Y HARD; CRUMBLY TO RARELY MODERA TL Y TOUGH; SMALL IRREGULAR AND PLATY CUTTINGS; SILGHTL Y RESINOUS TO MATTE AND CHALKY LUSTER; SMOOTH TO OCCASIONAL MODERATL Y GRITTY TEXTURE; NON CALCAREOUS TO RARELY MODERATL Y CALCAREOUS; SCATTERED TO COM VOLCANIC GLASS SHARDS; MODERATL Y BRIGHT LIGHT YELLOW MINERAL FL; NO OIL INDICATORS. (J EPO(~H 18 œ m Phillips Alaska, Inc. Meltwater 2-P 417 ( 1455 CLAYSTONE = LIGHT GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO OCCASIONAL SILGHTL Y BRITTLE;IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER; SMOOTH TO MODERA TL Y SILTY TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; INCREASINGLY WATER SOLUBLE; INCREASINGLY ASHY; SCATTERED TO COM ASH LAMS AND STREAKS; SCATTERED BLACK PINPOINT SPECKS; LOCALLY SILTY GRADING IN PART TO SILTSTONE; NO OIL INDICATORS. 4505 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; IRREGULAR AND SUBTABULAR HABIT; LUMPY TO SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; MODERATL Y ABRASIVE TEXTURE; RARE CARBONACEOUS MATERIAL; OCCASIONALLY GRADING TO VERY FINE SANDSTONE IN PART; NO VISIBLE OIL INDICATORS. ( 4555 ASH FALL TUFF = LIGHT GRAY, WHITE, PALE YELSH BROWN, RARELY PALE BLUE; SOFT TO FIRM, OCCASIONAL MODERA TL Y HARD; CRUMBLY TO RARELY MODERA TL Y TOUGH; SMALL IRREGULAR AND PLATY CUTTINGS; SILGHTLY RESINOUS TO MATTE AND CHALKY LUSTER; SMOOTH TO OCCASIONAL MODERA TL Y GRITTY TEXTURE; NON CALCAREOUS TO RARELY MODERATL Y CALCAREOUS; NO OIL. 4595 CLAYSTONE = LIGHT BROWNISH GRAY; SOFT TO SILGHTL Y FIRM; MUSHY TO OCCASIONAL SILGHTL Y BRITTLE; IRREGULAR AND SUBBLOCKY CUTTINGS; MA TIE LUSTER;SMOOTH TO MODERATL Y SILTY TEXTURE; NON TO OCCSLI CALCAREOUS; INCREASINGLY WATER SOLUBLE; INCREASINGLY ASHY; SCATTERED TO COM ASH LAMS AND STREAKS; SCATTERED BLACK PINPOINT SPECKS; LOCALLY SILTY GRADING IN PART TO SILTSTONE; NO OIL INDICATORS. 4645 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; VERY SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY; IRREGULAR AND SUBTABULAR HABIT; LUMPY TO SUBBLOCKY CUTTINGS; MATTE LUSTER WITH SCATTERED SPARKLES; MODERATLY ABRASIVE TEXTURE; RARE CARBONACEOUS MATERIAL; OCCASIONALLY GRADING TO VERY FINE SANDSTONE IN PART; NO VISIBLE OIL INDICATORS, 4695 SHALE = DARK GRAY; FIRM TO MODERATL Y HARD;CRUMBL Y TO MODERATL Y TOUGH; MATTE TO SLISHINY LUSTER; DOMINANTLY SMOOTH TO MODERATLY GRITTY TEXTURE; SMALL PLATY CUTTINGS WITH DISTINCT EDGES; NON CALCAREOUS; ABUNDANT CARBONACEOUS SPECKS; SCATTERED CLAYSTONE LAMINATIONS;OCCASIONAL BLEBS TUFFACEOUS MATERIAL; POOR TO OCCASIONAL GOOD FISSILITY; NO OIL INDICATORS. 4740 SILTSTONE = LIGHT GRAY TO WHITISH GRAY;SOFT; MUSHY IN PART; SUBPLANAR TO IRREGULAR FRACTURE; MASSIVE TO SUB-TABULAR CUTTINGS; PREDOMINANTLY QUARTZOSE WITH OCCASIONAL LITHICS ANDCARBONACEOUS MATERIAL; OCCASIONAL IRON STAINING; GRADING TO VERY FINE SANDSTONE IN PART; COMMON CLAY ASH MATRIX; NO VISIBLE OIL INDICATORS. ( (;I EPO(~H 19 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 { '\790 CLAYSTONE = LIGHT BROWNISH GRAY; SOFT TO SILGHTLY FIRM; MUSHY TO \ OCCASIONAL SILGHTL Y BRITTLE; IRREGULAR AND SUBBLOCKY CUTTINGS; MATTE LUSTER; SMOOTH TO MODERATL Y SILTY TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; INCREASINGLY WATER SOLUBLE;OCCASIONALL Y ASHY; SCATTERED TO ASH LAMS AND STREAKS; SCATTERED BLACK PINPOINTSPECKS; LOCALLY SILTY GRADING IN PART TO SILTSTONE; NO OIL INDICATORS. 4840 SHALE = DARK GRAY; FI RM TO MODERA TL Y HARD;CRUMBL Y TO MODERA TL Y TOUGH; MATTE TO SILGHTL Y SHINY LUSTER; DOMINANTLY SMOOTH TO MODERATL Y GRITTY TEXTURE; SMALL PLATY CUTTINGS WITH DISTINCT EDGES; NON CALCAREOUS; ABUNDANT CARBONACEOUS SPECKS; POOR TO OCCASIONAL GOOD FISSILITY. 4880 TUFFACEOUS ASH = WHITE TO LIGHT GRAY WITH OCCASIONAL MEDIUM GRAY; VERY SOFT TO OCCASIONAL FIRM; PREDOMINANTLY AMORPHOUS TO MASSIVE CUTTINGS HABIT; EARTHY TO OCCASIONAL SPARKL Y LUSTER; APPEARS AS BLEBS IN OCCASIONAL YELLOW MINERAL FLUORESCENCE; RARE VISIBLE GLASS SHARDS. 4920 SILTSTONE = LIGHT GRAY TO WHITISH GRAY;SOFT; MUSHY IN PART; SUBPLANAR TO IRREGULAR FRACTURE; MASSIVE TO SUB-TABULAR CUTTINGS; PREDOMINANTLY QUARTZOSE WITH OCCASIONAL LITHICS ANDCARBONACEOUS MATERIAL; TRACE GRADING TO VERY FINE SANDSTONE; CLAYEY AN ASHY; NO VISIBLE OIL INDICATORS. ( 4965 CLAY = LIGHT BROWNISH GRAY TO TAN; VERY SOFT TO SOFT; CRUMBLY TO MUSHY; VERY SOLUABLE; ERODED BOUNDRIES; MASSIVE TO AMORPHOUS CUTTINGS; SLIGHTLY SILTY IN PART; MATTE LUSTER; SMOOTH TO OCCASIONAL GRITTY TEXTURE; OCCASIONAL TUFFACEOUS ASH AND PYRITE IN SAMPLEES. 5005 SILTSTONE = LIGHT GRAY TO WHITISH GRAY;SOFT; MUSHY IN PART; SUBPLANAR TO IRREGULAR FRACTURE; MASSIVE TO SUB-TABULAR CUTTINGS; PREDOMINANTLY QUARTZOSE WITH OCCASIONAL LITHICS ANDCARBONACEOUS MATERIAL; TRACE GRADING TOVERY FINE SANDSTONE; CLAYEY AN ASHY;NO VISIBLE OIL INDICATORS. 5050 SHALE = DARK GRAY TO BLACK; FIRM TO HARD; TOUGH; JAGGED TO SPLINTERY FRACTURE; ELONGATE TO WEDGE LIKE CUTTINGS; MATTE TO SUB VITREOUS LUSTER IN PART; COMMON TO ABUNDANT CARBONACEOUS MATERIAL; MICROMICACEOUS IN PART; MODERATE FISSILITY; TRACE PYRITE. 5090 CLAY = LIGHT BROWNISH GRAY TO TAN; VERYSOFT TO SOFT; CRUMBLY TO MUSHY; VERY SOLUABLE; ERODED BOUNDRIES; MASSIVE TO AMORPHOUS CUTTINGS; SLIGHTLY SILTY IN PART; MATTE LUSTER; SMOOTH TO OCCASIONAL GRITTY TEXTURE; OCCASIONAL TUFFACEOUS ASH AND PYRITE IN SAMPLES. ( ~ EPO(~H 20 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 ( "130 SANDSTONE = OFF WHITE TO VERY LIGHTGRAY; VERY FINE LOWER TO FINE LOWER;SUBANGULAR TO SUBROUND; MODERATE SPHERICITY; COMPOSED PREDOMINANTLY OF QUARTZ WITH LITHIC FRAGMENTS AND OCCASIONAL CARBONACEOUS MATERIAL AND MICA; PREDOMINANTLY MATRIX SUPPORTED WITH CLAY AND ASH; POROSITY INFILLED; NO VISIBLE OIL SHOWS. 5175 SHALE = DARK GRAY TO BLACK; FIRM TO HARD; TOUGH; JAGGED TO SPLINTERY FRACTURE; ELONGATE TO WEDGE LIKE CUTTINGS; MATTE TO SUB VITREOUS LUSTER IN PART;COMMON TO ABUNDANT CARBONACEOUS MATERIAL; MICRO MICACEOUS IN PART; MODERATE FISSILITY. 5215 SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY; SOFT TO OCCASIONAL MODERATLY FIRM; MUSHY TO CRUMBLY, RARELY MODERATLY BRITTLE; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY TEX; NON TO LOCALLY SILGHTl Y CALCAREOUS; ARGILLACEOUS; GRADES TO AND IS INTERBEDDED WITH CLAYSTONE; COM BLACK PINPOINT SPECKS; SCATTERED MICROFINE MICA; NO OIL. 5290 CLAYSTONE = BROWNISH GRAY WITH OCCASIONAL SILGHTL Y OLIVE HUES; SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY, RARELY SILGHTL Y BRITTLE; 3 TO 5 MM CUTTINGS WITH IRREGULAR AND SUBBLOCKY HABIT; EARTHY LUSTER; GRITTY TEXTURE; NON CALCAREOUS; SILTY IN PART; GRADES TO AND IS INTERBEDDED WITH SILTSTONE; SCATTERED TO COMMON CARBONACEOUS SPECKS; NO OIL. ( j335 TUFF/CLAY MINERAL =WHITE TO VERY LIGHT WITH COMMON MEDIUM GRAY SPOTTED APPEAR- ANCE; SOFT TO SILGHTL Y FIRM; CRUMBLY; SMALL IRREGULAR AND LUMPY SHAPED CUTTINGS; CHALKY TO SILGHTL Y RESINOUS LUSTER; NON CALCAREOUS; NO VISIBLE MINERAL OR PETROLEUM FLUORESCENCE; HAS VAGUE APPEARANCE OF FINE GRAINED SANDSTONE. 5395 CLAYSTONE = BROWNISH GRAY WITH OCCASIONAL SILGHTL Y OLIVE HUES; SOFT TO SILGHTL Y FIRM; MUSHY TO CRUMBLY, RARELY SILGHTL Y BRITTLE; 3 TO 5 MM CUTTINGS WITH IRREGULAR AND SUBBLOCKY HABIT; EARTHY LUSTER; GRITTY TEXTURE; NON CALCAREOUS; TUFFACEOUS; COM BLACK PINPOINT SPECKS; SILTY IN PART, GRADING TO SILTSTONE. 5435 SANDSTONE = WHITISH GRAY; VERY FINE LOWER TO TRACE COARSE LOWER; POORLY SORTED; ANGULAR TO OCCASIONAL SUBROUND; LOW SPHERICITY; MODERATE TO WELL CEMENTED WITH SILICEOUS CEMENT; GRAIN SUPPORTED; COMPOSED OF 40% QUARTZ, 200k CHERT, 400/0 LITHIC FRAGMENTS; ESTIMATED POOR TO FAIR INTERGRANULAR POROSITY; STRONG PETROLIFEROUS ODOR; GOOD SHOW ON INITIAL WASH; BRIGHT PALE YELLOW FLUORESCENCE; SLOW, MODERATELY STRONG, VERY SLOW STREAMING, MILKY WHITE FLUORESCENT CUT W PALE WH RESIDUAL RING. ( " n EPOCH 21 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 ( '\505 SANDSTONE = LIGHT GRAY OVERALL; FRIABLE TO FIRM; CLASTS RANGE FROM SILT TO MEDIUM UPPER, DOMINANTLY VERY FINE TO FINE; ANGULAR TO SUBROUNDED; POORLY SORTED; DOMINANTLY QUARTZ WITH COMMON LlTHICS; TRACE GLAUCONITE; CLAY MATRIX; VERY SLIGHT ACID REACTION; ESTIMATED POOR TO FAIR VISUAL POR AND PERM; 800/0 BRI YELLOW-WHITE SAMPLEE FL; SLOW MODERATLY BRI YELLOW-WHITE CUT FL; TRACE MODERATLY BROWN OIL DROPLETS ON GRAINS. 5560 CLAYSTONE = LIGHT BROWNISH GRAY TO PALE YELLOWISH BROWN; VERY SOFT TO SllGHTL Y FIRM; MUSHY TO CRUMBLY; 3 TO 5 MM CUTTINGS WITH IRREGULAR AND SUBBLOCKY HABIT; EARTHY LUSTER; MODERATL Y GRITTY TEXTURE; NON TO LOCALLY MODERA TL Y CALCAREOUS; SILTY IN PART, OCCASIONAL GRADES TO SILTSTONE; FEW THIN SANDSTONE LAMINATIONS; COMMON CARBONACEOUS SPECKS; SCATTERED TO COMMON ASHY BLEBS AND STREAKS; NO OIL INDICATORS. 5615 ASH FALL TUFF = WHITE, LIGHT GRAY, PALE BLUE; SOFT TO OCCASIONAL FIRM; CRUMBLY TO OCCASIONAL MODERATL Y TOUGH; 3 TO 6 MM CUTTINGS WITH PLATY AND SUBBLOCKY HABIT; CHALKY TO SILGHTL Y RESINOUS LUSTER; MODERATL Y GRITTY TEXTURE; NON TO SllGHTL Y CALCAREOUS; SCATTERED VOLCANIC GLASS SHARDS; SCATTERED TO COMMON BLACK PINPOINT SPECKS; OCCASIONAL MEDIUM GRAY ASHY LAMINATIONS; MODERATL Y BRIGHT LIGHT YELLOW MINERAL FL; NO OIL. ( '5665 SILTSTONE = MEDIUM GRAY, BROWNISH GRAY; SOFT TO FIRM; CRUMBLY TO OCCASIONAL MODERATLY TOUGH; 3 TO 6 MM CUTTINGS WITH IRREGULAR TO OCCASIONAL SUBBLOCKY HABIT; MATTE LUSTER WITH SCATTERED SPARKLES; GRITTY, ABRASIVE TEXTURE; NON TO OCCASIONAL SILGHTL Y CALCAREOUS; SCATTERED MICRO FINE MICA; SCATTERED BLACK PINPOINT SPECKS AND STREAKS; ARGilLACEOUS, GRADING TO AND INTERBEDDED WITH CLAYSTONE; NO OIL INDICATORS. 5715 SHALE = DARK GRAY; FIRM TO MODERATELY HARD; BRITTLE; MODERATELY TOUGH; 4 TO 5 MM CUTTINGS WITH PLATY TO BLOCKY HABIT; EARTHY TO RARELY SILGHTL Y RESINOUS LUSTER; DOMINANTLY SMOOTH TO OCCASIONAL MODERATL Y GRAINY TEXTURE; NON TO SILGHTL Y CALCAREOUS; SCATTERED LAMS OF TUFF; SCATTERED BLACK SPECKS AND STREAKS; POOR TO FAIR FISSILITY; NO OIL INDICATORS. 5760 SANDSTONE = LIGHT WHITISH GRAY; VERY FINE LOWER TO LOWER COARSE; POORLY SORTED; ANGULAR TO OCCASIONAL SUBROUND; MODERATE SPHERICITY; PREDOMINANTLY HARD AND WELL CONSOLIDATED; 500/0 LITHIC FRAGMENTS, 30% QUARTZ, 200/0 CHERT; GRAIN SUPPORTED; ASHY CLAY MATRIX IN PART; SILICEOUS CEMENT; GRADING TO SILTSTONE IN PART; NIL TO POOR INTERGRANULAR POROSITY; COARSER SANDSTONE SHOWS BRIGHT PALE YELLOW FLUORESCENCE WITH VERY SLOW, VERY WEAK, WHITE FLUORESCENT CUT. ( \. [j EPOCH 22 e ~ Phillips Alaska, Inc. Meltwater 2-P 417 ( ')830 SILTSTONE = LIGHT WHITISH GRAY TO LIGHT GRAY; VERY FIRM TO OCCASIONAL SOFT; BLOCKY FRACTURE; TABULAR TO AMORPHOUS CUTTINGS HABIT; COMPOSED OF 40% QUARTZ 50% TUFFACEOUS SILT AND ASH; 10% CLAY; GRADES TO SILTY CLAY IN PART; RARELY GRADING TO FERY FINE SANDSTONE; MATTE TO EARTHY LUSTER; NON-CALCAREOUS; GRITTY TEXTURE; NO VISIBLE OIL INDICATORS. 5880 CLAYSTONE = LIGHT GRAY TO BROWNISH GRAY; VERY SOFT TO SOFT; MUSHY TO CRUMBLY; PREDOMINANTLY AMORPHOUS CUTTINGS; EARTHY LUSTER; GRITTY TEXTURE; COMMONLY SIL TV; GRADING TO SILTSTONE IN PART; COMMON TUFFACEOUS ASH LAMINAE; OCCASIONAL CARBONACEOUS MATERIAL; TRACE PYRITE IN SAMPLEES. 5925 TUFFACEOUS ASH = WHITE TO GRAYISH WHITE; VERY SOFT TO SOFT; MUSHY TO PASTEY; OCCURS AS AMORPHOUS BLOBS TO IRREGULAR CUTTINGS; CHALKY TO SUBRESINOUS LUSTER; OCCASIONALLY GRADES TO TUFFACEOUS SILTSTONE; OCCASIONAL VISIBLE GLASS SHARDS. ( ( ~ EPOCH 23 ~ ~ Phillips Alaska, Inc. Meltwater 2-P 417 ( DAILY ACTIVITY SUMMARY 04/27/2001 Epoch arrives on location and rigs up in preparation for spud. Picked up bottom hole assembly #1 and ran into hole. Spudded well at 103', 2300 hrs. Drilled to a midnight depth of 163'. 04/28/2001 Continued drilling to 266' then stand back drill-out stand of heavy weight drill pipe and pick up monel drill collar stand. Resumed directional drilling 12 %" hole to a midnight depth of 1440'. 04/29/2001 Continued drilling to 1607' then pumped a high viscosity sweep and circulated the hole clean for a wiper trip back to the shoe. The hole was tight from 1 000' to 500'. Pumped out 5 stands to work tight spot. Tripped into hole with no problems. Resumed drilling 12 X" directional hole to a midnight depth of 2280'. 04/30/2001 Continued drilling to surface casing point at 2430', 0600 hrs. Pumped a high viscosity sweep and circulated bottoms up. Wiper tripped back to the shoe and ran back to bottom to circulate hole clean and condition mud. Pulled out of hole, down loaded MWD data and laid down BHA. Held a pre-job safety meeting before rigging to and running 9 5/8' casing. Could not get the casing string to bottom and had to lay down one joint. Held a pre-job safety meeting before rigging up the cementers. ( 05/01/2001 Continued rigging up the cementers and pressure tested the cement lines. Ran cement and plugged down. Rigged out cementers then nippled down and nippled up B.O.P.E.'s. Test B.O.P.E.'S to 250 psi low and 5000 psi high; Test hydril to 250 psi low and 3500 psi high, okay. 05/02/2001 Pick up BHA and run into hole. Tagged cement at 2298'. Break circulation and circulate bottoms up 1 % times. Test casing to 2500 psi for 30 minutes, okay. Drill out cement and float and shoe; wash and ream tight spot at 2414' - 2425'. Drill to 2450' and circulate and condition mud for formation integrity test. Applied 801 psi with 8 pump strokes and bled back 10 gallons, equivalent mud weight of 16 ppg. Drilled ahead to a midnight depth of 2830'. 05/03/2001 Continued to drill ahead to 3830' and circulated hole clean for wiper trip. POOH to 2880' where the hole pulled tight. Slow pumped and back reamed from 2880' - 2770'. 05/04/2001 Pumped out from 2770' to shoe. Slipped and cut drill line and serviced top drive. RIH to 3722' then washed and reamed to bottom then continued drilling to a midnight depth of 4758'. 05/05/2001 Continued to drill ahead to 5262'. Circulated hole clean and monitored well before the wiper trip. Pulled tight and swabbed at 4740'. Back reamed out of hole to shoe. Circulated bottoms up and preformed and recorded L.a.T. Held at 240 Ibs, equivalent mud weight of 15.7. Ran into hole and hit a bridge at 2584'. ( n EPOCH 24 e ~ Phillips Alaska, Inc. Meltwater 2-P 417 ( 15/06/2001 Washed and reamed from 2585' - 2770'. Pumped a high viscosity sweep and loaded up the possum belly with %" - 2" cavings. Pumped out to shoe then tripped out of hole and laid down BHA and picked up hole opener. Ran into hole and hit a bridge at 2540'. Washed and reamed to 2910'. Circulated and increased viscosity then Pumped sweep and POOH to shoe. RIH to 2580' and washed and reamed to 3100'. Circulated and pumped a high viscosity sweep. Returns contained golf ball sized cavings. Circulated and pumped another high viscosity sweep and circulated hole clean. RIH and hit bridge at 2680'. 05/07/2001 Wash and ream 2685' - 2911'. Circulated a high viscosity sweep and reamed 2911 - 3100'. RIH to 3500' with no problems. Circulated two high viscosity sweeps and POOH to shoe. RIH to 5122' washing 2985 - 2992' and washing and reaming 5122 to 5257. POOH to shoe and RIH to 3346' washing through bridge at 2978 - 3068'. POOH to shoe. 05/08/2001 Continue to POOH and lay down BHA. Tested B.O.P.E.'s then picked drilling assembly and ran into hole. Hit a bridge at 3073', worked through then ran in to 5230'. Washed and reamed from 5230' - 5262'. Drilled ahead to core point at 5429'. Circulated up sample and pumped sweep for short trip. 05/09/2001 Circulate and condition mud then short trip to the shoe. Prepared mud pits for coring mud then changed over to coring fluid. Displaced well and circulated and conditioned mud before POOH and laying down BHA. ( 05/10/2001 Pick up core assembly and run in to 3216'. Cut drilling line and continued to RIH. . Washed and reamed from 5324' to bottom. Cored from 5429' to 5489' then circulated bottoms up before POOH and laying down core #1. Picked up inner barrels and RIH for core #2. Washed and reamed from 5386' - 5489' then circulated and pumped ball down and cut core #2 5489 - 5549'. Circulated bottoms up. 05/11/2001 Circulate and condition mud, monitor well and pump slug. Trip out with core assembly at decompression running speeds. Lay down core-- 60' cut, 58.5' recovered. Lay down coring assembly and clear floor. Change BHA, pick up motor and MWD from derrick, make up bit. Initialize MWD, install sources, pickup nonmagnetic drill collars, spiral drill collars, jars and HWDP. Run in hole to 5200', fill drill pipe at 3550', break circulation at 5200', establish slow pump rate. MAD pass with LWD from 5200' to 5449' at 100' per hour. Drill from 5549' to 5801'- -ART 6.75 hours. 05/12/2001 Drill from 5806' to T.D. at 5993'. ART 5.35 hours. Circulate sweep, monitor hole, short trip to 5150', hole is tight and swabbing, 50k over pull. Pump out 5580' to 5457', circulate high viscosity heavy sweep, condition mud. Lay down MWD, motor, stabilizers and bit. Work on top drive. PJSM for E-Iogs, rig up and run E-Iogs. ( [:I EPOCH 25 a W Phillips Alaska, Inc. Meltwater 2-P 417 ( SURVEY INFORMATION ( Measured TVD Inclination Azimuth Coordinates Dog Leg Depth Feet Feet Degrees Degrees N(+) 5(-) E(+) W(-) Deg/100' 149.60 149.60 0.70 17.60 0.87 0.28 0.47 236.90 236.89 1.10 13.00 2.20 0.63 0.47 330.50 330.47 1.10 11.60 3.95 1.01 0.03 421.70 421.65 1.20 6.00 5.76 1.28 0.16 516.10 516.04 0.20 7.70 6.91 1.41 1.06 606.00 605.94 0.20 163.50 6.91 1.48 0.44 698.00 697.94 0.10 212.70 6.69 1.48 0.17 789.10 789.04 0.10 315.70 6.86 1.38 0.17 881.00 880.94 0.10 242.90 6.70 1.25 0.13 972.80 972.74 0.20 270.40 6.66 1.02 0.13 1161.40 1161.34 0.40 235.20 6.29 0.15 0.14 1255.50 1255.44 0.40 206.70 5.82 -0.26 0.21 1348.60 1348.53 0.50 200.70 5.15 -0.55 0.12 1443.90 1443.83 0.50 198.60 4.36 -0.83 0.02 1537.00 1536.93 0.40 193.30 3.66 -1.04 0.12 1631.50 1630.92 0.50 207.00 2.98 -1.30 0.16 1725.30 1725.22 0.40 177.50 2.28 -1.47 0.26 1820.20 1820.12 0.60 211.30 1.52 -1.72 0.37 1914.90 1914.81 0.60 212.70 0.68 ..2.24 0.02 2008.60 2008.51 0.40 204.90 -0.03 -2.64 0.22 2104.40 2103.88 2.20 102.60 -0.73 -1.00 2.43 2198.70 2198.43 4.30 94.90 -1.43 4.30 2.27 2290.60 2289.93 6.30 87.90 -1.54 12.77 2.28 2366.80 2365.51 8.30 86.9 -1.08 22.44 2.62 2442.70 2440.57 8.79 83.64 -0.13 33.67 0.89 2535.70 2532.50 8.61 86.81 1.04 47.69 0.55 2631.60 2627.32 8.61 85.40 2.02 62.01 0.22 2726.10 2720.76 8.53 85.75 3.10 76.05 0.10 2818.20 2811.85 8.44 83.64 4.36 89.58 0.35 2913.50 2906.17 8.09 85.05 5.71 103.21 0.42 3008.00 2999.72 8.09 82.24 7.18 166.42 0.42 3102.60 3093.39 8.00 80.13 9.21 129.50 0.33 3196.50 3186.46 7.29 85.05 10.84 141.88 1.03 3290.10 3279.29 7.38 87.86 11.58 153.80 0.40 3379.70 3368.27 6.15 93.49 11.51 164.34 1.56 3474.20 3462.32 5.01 92.42 11.02 13.52 1.21 3567.90 3555.74 3.78 83.99 11.17 180.68 1.48 3662.90 3650.58 2.99 87.16 11.62 186.27 0.85 (' ~ EPOCH 26 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 ( Measured TVD Inclination Azimuth Coordinates Dog Leg Depth Feet Feet Degrees Degrees N(+) S(-) E(+) W(-) Deg./100' 3757.30 3744.90 1.76 104.03 11.39 190.13 1.49 3850.60 3838.17 0.79 138.14 10.57 191.95 1.28 3943.30 3930.87 0.53 190.87 9.67 192.30 0.68 4037.70 4025.26 1.23 290.01 9.59 191.26 1.50 4130.80 4118.33 1.58 291.82 10.43 189.43 0.38 4227.40 4214.90 1.32 321.65 11.82 187.22 0.79 4322.60 4310.07 1.41 330.44 13.70 185.96 0.24 4416.50 4403.95 1.23 324.82 15.53 184.81 0.24 4511.30 4498.73 0.79 337.47 16.96 183.89 0.52 4603.60 4591.03 0.35 70.99 17.64 184.00 0.96 4696.70 4684.13 0.53 112.12 17.57 184.67 0.38 4792.40 4778.82 0.70 122.67 17.09 185.57 0.21 4886.30 4873.72 0.62 116.34 16.55 186.51 0.12 4980.00 4967.41 0.70 131.46 15.95 187.39 0.20 5076.40 5063.80 0.53 122.67 15.32 188.21 0.20 5168.70 5156.10 0.35 147.28 14.85 188.72 0.28 5262.10 5279.50 0.35 145.52 14.38 189.04 0.01 5356.30 5343.70 0.18 121.61 14.06 189.32 0.21 5452.60 5440.00 0.26 112.47 13.90 189.65 0.09 5544.90 5532.30 0.26 114.93 13.73 190.04 0.01 5638.90 5626.29 0.44 110.36 13.52 190.57 0.19 5825.00 5981.38 0.18 85.30 13.32 192.46 0.15 5993.00 5980.39 0.18 85.30 13.33 192.06 0.00 t ( U EPOCH 27 s ~ Phillips Alaska, Inc. Meltwater 2-P 417 DAILY MUD PROPERTIES Date Depth Den. Vis PV YP Gels HTHP FiI. Cake Solids OillWater Sand PH CI Ca 04/27/01 160 9.8 68 19 34 12/15 0.0 2/0 5.2 0.0/93.0 Trace 9.4 31500 168 04/28/01 1440 9.8 61 18 32 10/18 0.0 2/0 6.2 0.0/92.0 0.75 9.1 32000 160 04/29/01 2280 9.8 59 16 31 10/21 0.0 2/0 6.7 0.0/91.5 2.0 9.0 32000 420 04/30/01 2430 9.9 58 16 30 10/21 0.0 2/0 7.2 0.0/91.0 1.5 9.1 32000 320 05/01/01 2430 9.6 55 15 25 8/13 0.0 2/0 6.2 0.0/92.0 0.7 8.8 32000 320 05/02/01 2815 9.6 46 12 20 6/15 0.0 2/0 4.1 1.0/93.0 0.5 9.3 33000 280 05/03/01 3830 9.5 48 12 19 6/15 0.0 2/0 3.6 0.5/94.0 0.3 9.1 33000 200 05/04/01 4770 9.5 49 13 20 6/18 0.0 2/0 4.8 0.5/93.0 0.25 9.3 30000 140 05/05/01 5262 9.8 48 16 19 4/10 0.0 2/0 4.9 0.5/93.0 0.25 9.2 28000 140 05/06/01 5262 10.0 61 19 26 7/27 0.0 2/0 6.7 0.5/91.0 0.5 9.4 32000 140 05/07/01 5262 10.2 65 23 34 10/29 0.0 2/0 9.8 0.5/88.0 0.5 9.1 32000 160 05/08/01 5429 10.1 70 22 30 8/27 0.0 2/0 8.8 0.5/89.0 0.5 9.3 32000 140 05/09/01 5429 10.2 65 25 27 7/14 8.0 1/2 8.3 0.0/90.0 Trace 8.4 32000 240 05/10/01 5800 10.3 72 27 22 6/19 0.0 2/0 9.8 0.5/88.0 0.5 9.0 32000 240 05/11/01 5510 10.3 68 23 17 3/8 2.8 1/2 10.3 0.5/87.5 0.5 8.2 32000 240 [::j EP0°H 28 '~ -...~ = ~ Phillips Alaska, Inc. Meltwater 2-P 417 BIT RECORD Bit Gradina I 0 D L .B G 0 R N U U 0 E A T E N T L C A U H A E E L A R G E S R R T I E R 0 C I N N R R H 0 G C 0 0 A N S H P W W R A U S S R L L E 0 Bit # Size Make Type SIN Jets Depth Depth Drilled Hours Ave Ave Ave Ave In Out FtlHr WOB rpm psi 1 12~" STC FGSS+C MG 4586 3X24 103 2430 2327 38.5 82.7 9.2 65.3 1062.4 3 7 EC A E 2 WT TD 2 81/2 HTC MXC1 F10JT 1X133X15 2430 5262 2832 39.7 71.3 17.7 71.3 2049.3 1 1 WT A E 1 NO HP 2R1 81/2 HTC MXC1 F10JT 1X133X15 5262 5429 167 6.4 30.9 15.9 67.2 3104.4 2 2 WT A E I NO CP 1C CORE HC ARC412 34508508 TFA 0.770 5429 5550 121 3.2 38.3 14.5 83.5 1000 2R2 81/2 HTC MXC1 F38JC 1X133X15 5550 5993 443 10.6 48.6 34.0 72.6 3100 1 1 WT A D I NO CP [1 EPoru 29 ~ -- r ~. " PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,AJaska 9951~60 R. Thomas Phone(907)26~O Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: ~ Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 200 1, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 200 1. Please call me at 265-6830 should you have any questions. Sincerely, ~~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental: Engel/Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files ~€.c€.\\I€.O 1'" ') f\~ 1 ~ ~ 1..\J j ~ ~ ro\ss\ot\ Cf$\S' co~ O'~ &. Gas n.e þ.,\?/ò¥.a ~ þ.,t\c'\o~a\, lQ I ..- l< Cl-ft lO( , 15 Ct~-Jl ~o,-' fl:f) lO 1 ~ 11 q ~-I 11 tÒ,-~ ;t:rf -1$ ;t) l ....;t) ~ '1&- ~ ~aJ'" ~Q:)-I ~- ¡QT-l ;p1~- ( t"='-,., Annular Disposal durin thefollrth quarter of2001: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes ~i CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 9 2P-417 5331 100 0 5431 0 627 6058 Sept 200 1 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 Ii) lC-16 12338 100 0 12438 0 19679 32117 Sept 200 1 October lC-131, lC-125, lC-102 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 ~~ CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 , 2001 2001 , IC-14 22389 100 0 22489 0 0 22489 Oct 200 1 Nov 2001 1 C-l 09 '~ 2P-438 30331 100 0 30431 212 0 30643 Oct 200 1 Dec2oo1 2P-420, 2P-415, 2P-429 ~ CO2-IS 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only t CD2-47 10315 100 0 10415 375 0 10790 Dec2oo1 Dec2001 CD2-34 '-" Total Volumes into Annuli for which Disposal Authorization Expired during the fourth t; uarter 2001: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus ,\~ 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec2000 2L-317,2L-307 l31 ID-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 ID-42, ID-34 IE CDI-31 6698 100 0 392 7190 Open, Freeze Protected Feb 200 1 March CDI-14 2001 ~; 2N-30S 0 0 0 380 380 Open, Freeze Protected NA** NA** * * freeze protect volumes only 'J3 ID-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec2000 ID-32, ID-40A 3q 2N-349A 0 0 0 0 0 Open, Freeze Protected -- -- -- ~ ID-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 ID-37, ID-39 ( » iü ;U( en ~ 0) Q '- m fò!a ):::¡ J>G) 2: C) :::SO) ("')(1) 50 N m ~g c.::J - CD~ < 0 '"" 0 <:::I m 3 a 3 1'...) Ü)" 0 en õ' :::s { I 'j{7--/ 03 8°0-/3(" dDo-D3Þ ~O 1-;)4 «t ~ o~ -/ 31 aðJ- Oloq ( 02/19/02 Scblum_erger NO. 1820 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Sepia Color Log Description BL CD Date Job# 3H-15 INJECTION PROFILE 02/01/02 1 1 1D-140 22066 RST -SIGMA 01106/02 1 1 1 1 L-20A 22054 SCMT 01/28/02 1 1 C-24 22055 USIT 01/20/02 1 1 C-24 22055 SSLT 01/20/02 1 2P-415 21488 BEST DT -SONIC PROCESSING 11/24/01 1 2P-415 21488 ELAN GLOBAL SOLVER (TVD) 11/24/01 1 2P-415 21488 FRACADE ADVISOR MECH PROPERTIES (TVD) 11/24/01 1 2P-417 21243 ELAN ELEMENTAL ANALYSIS 05/12/01 1 2P-417 21243 FRACADE ADVISOR MECH PROPERTIES 05/12/01 1 SIGN&(A-Q.r¿Q ~ RECEIVED DATE: F EB 1 ) L. Alaska Oil & Gas Cons. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ( 01/24/02 Scblum~epger NO. 1746 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Log Description Sepia CD Color BL Job # Date Ü' ~ ~ 'C) res 2P-417 21242 PEX,AIT, & DSI 05/12/01 1 2P-417 21242 PEX-AIT 05/12/01 1 1 2P-417 21242 PEX-NEUTRON/DENSITY 05/12/01 1 1 2P-417 21242 DSI 05/12/01 1 1 -- ~"'I' . .. "1::'..11:.1 V E:U SIGNE~~~:J JAN 2 5 2002 DATE: Alaska Oil & Gas ConS. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank yo~nchorage ¿;Ðl- ddb ~O '-Qloe¡ ao'- ~~ aOI- ~ðO õ?O)"aa~ ;1,0}- ,L-/ d ,60)-1 g'~ ( 01 /15/02 Scbltn~epgep NO. 1725 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie 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 Sepia CD Color 2P-415A PRESSlTEMP STATION LOGS 12/24/01 1 1 2P-417 STATIC BOTTOM HOLE PRESS SURVEY 12/13/01 1 1 2P-420 PRESSlTEMP STATION LOGS 12/23/01 1 1 1C-135 22010 USIT 12/18/01 1 1 R-36 22009 USIT 12/27/01 1 2N-348 22011 SCMT 12/09/01 1 2P-420 22008 SCMT 12/22/01 1 --,-- .. II. ,.. ~L0t:IVI:U SIGNE~ lnl-(.Lßç~ Jl1J 2 5 200L Alaska Oil & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Anchorage DATE: ( (' PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 9951 Q-0360 C. Mallary Phone(907)265~4 Fax: (907) 265-6224 January 7,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2P-417 (201-069) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Meltwater well 2P-417. If you have any questions regarding this matter, please contact Pat Reilly at 265-6048. Sincerely, C. Mallary Drilling Engineering PAl Drilling c'~ . CM/skad RECEIVED JAN 0 8 ZOOZ Alaska Oil & Gas Cons. Commission Anchorage r7-\~, I (:: 1J {Ii,',,' G I ^, ç)i" t ..,) .. A L ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMrSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil 0 Gas D 2. Name of Operator Phillips Alaska, Inc. 1 iOCA.~ 3. Address :~ P. O. Box 100360, Anchorage, AK 99510-0360 ~ ' 4. Location of well at surface -s...,.....,.FIC' . 878' FNL, 2187' FWL, Sec. 17, T8N, R7E, UM (ASP: 444147, 5868998) '''''''''''.''-''.'¡:;;'1~~-:' --- cr.;; At Top Producing Interval t ';A-- -= ., ~ I Þ , , 5 ' of: 875' FNL, 2251' FWL, Sec. 17, T8N, R7E, UM (ASP: 444211, 5869000) 1: ~~:-:-:-::-:::-~:-: At Total Depth ~,,!t:I}'X":'; . 4 ..ðv 863' FNL, 2899' FEL, Sec. 17, T8N, R7E, UM (ASP: 444340, 5869010) i:::'-:-,:-:-w-:'::.=:::::::'; 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 27.5' feet ADL 373112, ALK 4998 12. Date Spudded 13. Date T.D. Reached 14. Date CÆIJIP., $usp. Or Aband. April 27, 2001 May 13, 2001 ~ 15;~001 ~» 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 6008' MD 1 5995' TVD 5905' MD 1 5892' TVD YES 0 No D 22. Type Electric or Other Logs Run GR/ReslNeu Dens, Platform Express 23. 1. Status of well Suspended D Service D Abandoned D Classification of Service Well 7. Permit Number 201-069 8. API Number 50-103-20375-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2P-417 11. Field and Pool Kuparuk River Field Meltwater Pool 15. Water Depth, if offshore 16. No. of Completions NI A feet MSL 1 20. Depth where SSSV set 21. Thickness of Permafrost NIA feet MD 1455' (approx) CASING SIZE WT. PER FT. GRADE 16" 62.5# B 9.625" 40# L-80 7" 26# L-80 4.5" 12.6# L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 2382' Surface 5302' 5302' 6002' HOLE SIZE 42" 12.25" 8.5" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 5495' - 5515' MD 5482' - 5502' TVD 6 spf CEMENTING RECORD 9 cu yds High Early 380 sx AS3 Lite & 190 sx LiteCRETE AMOUNT PULLED 420 sx Class G included above 4.5" TUBING RECORD DEPTH SET (MD) 5305' PACKER SET (MD) N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5495' - 5515' placed 213M# 16/20 carbolite behind pipe, 12 ppa on perfs. 26. 27. Date First Production December 18, 2001 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift OIL-BBL GAS-MCF 1737 2700 OIL-BBL GAS-MCF 2453 3811 CORE DATA 12/29/2001 17 hours Flow Tubing Casing Pressure press. 337 psi not available 28. Production for Test Period> Calculated 24-Hour Rate> W A TER-BBL 0 W A TER-BBL 0 CHOKE SIZE 171 OIL GRAVITY - API (corr) not available GAS-OIL RATIO 1554 Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. 6f OR\G\NALBBOMSBFL J\N II íIJœ See Attachment Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RECEIVED JAN 0 8 2002 Alaska Oil & Gas Cons. Commission Anchorage '7' Submit in duplicate 29. ( 30. GEOLOGIC MARKER~ FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. T3 TD 5424.5' 6008' 5412' 5995' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Core Description 32. Signed Questions? Pat Reilly 265-6048 Title Drillina Enaineerina SUDervisor Date t (cvn '02 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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 JAN 0 8 2002 OR\G\NAL Alaska Oil & Gas Cons. Commission Anchorage PHilliPS ALASKA, INC. Page 1 of 6 Operations Summary Report Legal Well Name: 2P-417 Common Well Name: 2P-417 Spud Date: 4/27/2001 Event Name: ROT - DRILLING Start: 4/19/2001 End: Contractor Name: Doyon Rig Release: Group: Rig Name: Doyon 141 Rig Number: 141 Date From - To Hours Code Sub Phase Description of Operations Code 4/24/2001 00:00 - 12:00 12.00 MOVE DMOB DEMOB Rig down and Move off Rendevous 2 location. 12:00 - 19:30 7.50 MOVE MOB MOBMIR Move Sub to Meltwater Slowly (Narrow Road). Move Rig Modules onto Meltwater Location. 19:30 - 20:30 1.00 MOVE POSN MOBMIR Spot Sub over Well. (Conductor 2P-417) 20:30 - 21 :00 0.50 MOVE POSN MOBMIR Level Sub - Lay Rig Complex Matts. 21 :00 - 23:00 2.00 MOVE RURD MOBMIR Set 4 Rig Complexes (Pits, Pump, Motor & Boiler Modules) 23:00 - 00:00 1.00 MOVE RURD MOBMIR Hookup Service Lines 4/25/2001 00:00 - 12:00 12.00 MOVE RURD MOBMIR Rig up Complexs @ Meltwater 2P-417. Move Pipe Sheds and all Camp Modules from Rendezvous. 12:00 - 14:00 2.00 MOVE RURD MOBMIR Set & Level Pipe Sheds. 14:00 - 15:00 1.00 MOVE RURD MOBMIR Set & Burn Tioga Htr - Complete Rig Accept List - Rig Accept @ 3:00pm 4/25/01. 15:00 - 22:00 7.00 WELCTL NUND MOBMIR N/U 21 1/4" Diverter System. Load water onto rig. 22:00 - 00:00 2.00 MOVE OTHR MOBMIR C/O Directional Drillers Control Shack - Load pipe shed W/4" DP. 4/26/2001 00:00 - 02:00 2.00 WELCTL NUND MOBMIR Finish NU Diverter - Install turn buckets & flow line. 02:00 - 07:30 5.50 DRILL PULD MOBMIR P/U 162 jts 4" 14# S-135 DP & SB in derrick. 07:30 - 12:00 4.50 MOVE OTHR MOBMIR Spot Cutting Tank. Build spill containment around Tank. 12:00 - 13:00 1.00 WAlTON SFTY MOBMIR Crew review Well Plan (page by page). Safety, objectives, practices & particulars. 13:00 - 18:00 5.00 WAlTON OTHR MOBMIR Help BHI install new wiring sytem from BHI unit to Rig Floor. (Welder building new mounting brackets) 18:00 - 19:00 1.00 RIGMNT RGRP MOBMIR Remove 141 power factor roof cap to improve air flow around unit while on highline. (Doyon will install fans in roof cap and re-install after modification.) 19:00 - 21 :00 2.00 WELCTL BOPE MOBMIR Attempt function test Divertor - One air pump failed on accumulator. Mechanic will repair. - AOGCC Rep. John H. Crisp will come back after repairs are made. 21 :00 - 23:00 2.00 DRILL PULD MOBMIR Load HWDP in shed - Strap & Drift Same - P/U 4" HWDP and SIB in Derrick. 23:00 - 23:30 0.50 RIGMNT RSRV MOBMIR Service Rig & Top Drive 23:30 - 00:00 0.50 DRILL SFTY MOBMIR Fire Drill (Electrical) - De-briefing from Doyon HSE Rep on latest incident. 4/27/2001 00:00 - 01 :00 1.00 DRILL SFTY MOBMIR Crew review Well Plan. (Page by Page). Safety, objectives, practices, and particulars. 01 :00 - 09:00 8.00 RIGMNT RSRV MOBMIR Perform Rig Maintenance, Serv IR, Mix daily chem for Mud, Servo Shakers and Augers 09:00 - 10:30 1.50 DRILL PULD MOBMIR Load 8" DC's in Pipe Shed. P/U and SIB in Derrick. 10:30 - 12:00 1.50 DRILL SFTY MOBMIR Perform Accumulator Drill & Divert Shallow gas drill. Hold Safety Meeting after discuss drills. 12:00 - 13:30 1.50 RIGMNT RSRV MOBMIR Continue Rig Service on all pipe handling equipment. 13:30 - 14:00 0.50 DRILL SFTY MOBMIR Full divert shallow gas drill - Full response time 6 min 17 sec. 14:00 - 15:30 1.50 DRILL SFTY MOBMIR Pre-Spud meeting with all contractors and both drilling crews. 15:30 - 16:30 1.00 WELCTL BOPE MOBMIR Re-Test Accumulator & Test gas alarms w/ AGOC Rep. John H. Crisp. Total Diverter test now complete. 16:30 - 18:30 2.00 RIGMNT OTHR MOBMIR Install Pad Evac. Siren. Work on Electrical power to rig. Repair backup alarm on fork lift. 18:30 - 20:30 2.00 DRILL PULD MOBMIR P/U BHA NO.1. 20:30 - 21 :30 1.00 DRILL PULD MOBMIR Upload MWD. 21 :30 - 22:00 0.50 DRILL SFTY MOBMIR Pad Evac. Drill. Activate Strobe lights and siren. 22:00 - 23:00 1.00 DRILL CIRC MOBMIR Flood Conductor and Check all Surface Mud System for leaks. Dial in and set all BHI & Epoch equipment. 23:00 - 00:00 1.00 DRILL DRLG SURFAC Spud Well @ 103' - Dring 103' - 163'. 4/28/2001 00:00 - 02:00 2.00 DRILL DRLG SURFAC Dir Dring 163' to 265', ADT 1.2 hrs. { ( Printed: 6/14/2001 1 :33:57 PM PHilliPS ALASKA, INC. Page 2 of 6 Operations Summary Report Legal Well Name: 2P-417 Common Well Name: 2P-417 Spud Date: 4/27/2001 Event Name: ROT - DRILLING Start: 4/19/2001 End: Contractor Name: Doyon Rig Release: Group: Rig Name: Doyon 141 Rig Number: 141 Date From - To Hours Code Sub Phase Description of Operations Code 4/28/2001 02:00 - 03:30 1.50 DRILL TRIP SURFAC SIB Drillout std of HWDP. P/U std Mandel DC's. 03:30 - 12:00 8.50 DRILL DRLG SURFAC Dir Drlg 265' to 740'. ADT 7.0 hrs 12:00 - 00:00 12.00 DRILL DRLG SURFAC Dir Drlg 740' to 1440'. ADT 8.0 hrs 4/29/2001 00:00 - 01 :00 1.00 DRILL DRLG SURFAC Dir. Dring 1440-1507' MD. ART .9 hrs 01 :00 - 02:00 1.00 DRILL CIRC SURFAC Pump WVHi Vis Sweep CBU - Circ. till Clean. 02:00 - 05:30 3.50 DRILL WIPR SURFAC Wiper Trip to DC's. Tight hole f/ 1100' thru 500'. Pumped out 6 stds. TIH "No Problems". 05:30 - 12:00 6.50 DRILL DRLG SURFAC Dir Drlg 1507' to 1830'. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Dir. Drill 1830' to 2280' (2279' TVD) ART 5.1 hrs, AST 3.4 hrs. 4/30/2001 00:00 - 05:30 5.50 DRILL DRLG SURFAC Dir. Drill 2280' to 2430' MD (2279 to 2428' TVD) ART = 4.2 hrs. AST =1.0, ADT =5.2 hrs. 05:30 - 07:30 2.00 DRILL CIRC SURFAC Pump WVHigh Vis sweep. Circ and Condition hole until clean. 07:30 - 10:00 2.50 DRILL WIPR SURFAC Observe well prior to POOH, Short Trip f/2430 to 210'. No Problems. Observe Well prior to RIH. 10:00 - 11 :00 1.00 DRILL WIPR SURFAC RIH. No Prolbems, Wash last 73' to bottom. No fill. 11 :00 - 14:00 3.00 DRILL CIRC SURFAC Pump WV High Vis Sweep. Circ and Cond hole for 9-5/8" casing. 14:00 - 15:30 1.50 DRILL TRIP SURFAC POOH to BHA. No Tight spots or problems. 15:30 - 17:00 1.50 DRILL TRIP SURFAC Lay down BHA #1 to MWD. 17:00 - 17:30 0.50 DRILL TRIP SURFAC Down load LWD memory. Make up casing fill-up tool while downloading. 17:30 - 18:30 1.00 DRILL TRIP SURFAC Break Bit. 18:30 - 20:00 1.50 CASE RURD SURFAC Clean and clear floor. Rig up GBR casing equipment. 20:00 - 20:30 0.50 CASE SFTY SURFAC PJSM on casing running operations. 20:30 - 00:00 3.50 CASE RUNC SURFAC Run 60 jts 9-5/8" 40# L-80 casing. No tight spots. No problems. P/U = 120 klbs, 5/0 = 105 klbs. 5/1/2001 00:00 - 01 :00 1.00 CASE RUNC SURFAC Running Csg - Hit Bridge - Wash & Work for 2' - Unable to work past-Disicion was made to lay down 1 jt of casing 01 :00 - 02:00 1.00 CASE OTHR SURFAC UD Landing Jt & Hanger - UD Jt #60 - P/U Landing jt and Csg Hng 02:00 - 05:30 3.50 CASE CIRC SURFAC Circu & Condition to CMT Csg 05:30 - 08:00 2.50 CEMEN" PUMP SURFAC CMT per well plan(see detail) - Full returns to surface - Displace with Rig pumps 1634 stks - Held 500 psi over bump for 5 min - Ck floats "Held" CIP 07:45 08:00 - 10:30 2.50 CEMEN" RURD SURFAC RID Cmt Head,Landing Jt - Clean all casing tools from Rig floor 10:30 - 12:00 1.50 WELLSF NUND SURFAC NID Diverter System 12:00 - 13:00 1.00 WELLSF NUND SURFAC N/U & Orient FMC Gen V well head 13:00 - 13:30 0.50 DRILL SFTY SURFAC Held Full "PAD EVAC" drill with all contractors on Pad and all personell on pad. 13:30 - 19:00 5.50 WELLSR NUND SURFAC N/U 135/8" 5K BOP 19:00 - 23:30 4.50 WELCTL BOPE SURFAC Test BOPs - Test 250 / 5000 Hi - Annular 250/3500 23:30 - 00:00 0.50 WELCTL EaRP SURFAC Install Wear Ring - RILDS 5/2/2001 00:00 - 05:00 5.00 DRILL PULD PROD P/U BHA #2 - 05:00 - 06:00 1.00 DRILL TRIP PROD TIH -m Tag CMT @ 2298' 06:00 - 06:30 0.50 DRILL CIRC PROD Break Circu - Circu 11/2 Time DP volume- Blow down TD 06:30 - 07:30 1.00 CASE DEQT PROD Test Csg to 2500 psi Hold 30 min on Chart - Loss 42 psi 07:30 - 09:30 2.00 DRILL DRLG PROD Drlg Plugs,FC,CMT,FS, CMT - @ 2425' Tight & Torque Up 09:30 - 10:30 1.00 DRILL REAM PROD Wash & Ream until clean 2414' - 2425' 10:30 - 11 :00 0.50 DRILL DRLG PROD Drlg 2425' to 2450'MD - No Problems or Torque 11 :00 - 12:00 1.00 MOVE POSN PROD Level Sub 12:00 - 12:30 0.50 DRILL CIRC PROD Draw down mud system & Ready pits 12:30 - 14:00 1.50 DRILL CIRC PROD Pump Spacer - Circu into Mud system fresh mud - Circu & balance mud density for LOT 14:00 - 15:00 1.00 CEMENl FIT PROD Preform LOT to FIT 16.0ppg EMW 15:00 - 00:00 9.00 DRILL DRLG PROD Drlg 8 1/2" hole (TVD 2823') ART 7.1 hrs (' ~I Printed: 6/14/2001 1 :33:57 PM PHilliPS ALASKA, INC. Page 3 of 6 Operations Summary Report Legal Well Name: 2P-417 Common Well Name: 2P-417 Spud Date: 4/27/2001 Event Name: ROT - DRILLING Start: 4/19/2001 End: Contractor Name: Doyon Rig Release: Group: Rig Name: Doyon 141 Rig Number: 141 Date From - To Hours Code Sub Phase Description of Operations Code 5/312001 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Dir Drlg 8 1/2" hole 12:00 - 20:00 8.00 DRILL DRLG INTRM1 Dir Drlg 8 1/2" hole 20:00 - 21 :00 1.00 DRILL CIRC INTRM1 Circu Hole Clean (Rot & Recip pipe at all times) 21 :00 - 22:30 1.50 DRILL WIPR INTRM1 Wiper Trip to Shoe - Pulled Tight @ 2880 22:30 - 00:00 1.50 DRILL WIPR INTRM1 Tight hole -Had to back ream & pump out-Had pack off problems 5/4/2001 00:00 - 01 :30 1.50 DRILL WIPR INTRM1 Tight @ 2770 - Back Ream & pump out of hole 01 :30 - 02:30 1.00 RIGMNT RURD INTRM1 Cut Drill Line ( 67' Cut) 02:30 - 03:00 0.50 RIGMNT RSRV INTRM1 Service Top Drive 03:00 - 04:00 1.00 DRILL WIPR INTRM1 TIH @ 3722' tight 04:00 - 04:30 0.50 DRILL REAM INTRM1 Wash & Ream 3722' to 3830' 04:30 - 12:00 7.50 DRILL DRLG INTRM1 Dir Drlg 3830' to 4205' MD (4193 TVD) ART 4.1 ,AST .75 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Dir Drlg 4205' to 4771' MD ( 4758' TVD) ART 8.5 , AST 1.0 5/5/2001 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Dir Drlg 4771' to 5242' MD (5230' TVD) ART 9.7 ,AST 0.0 12:00 - 13:00 1.00 DRILL DRLG INTRM1 Dir Drlg 5242' to 5262' MD (5249' TVD) ART ??? 13:00 - 14:30 1.50 DRILL CIRC INTRM1 Circulate hole clean. PJSM Pinch Points 14:30 - 15:30 1.00 DRILL WIPR INTRM1 Monitor well & POOH. Pulled tight & swabbed @4740' 15:30 - 19:00 3.50 DRILL WIPR INTRM1 Backream 4740' to 3840'.30 spm, 30 rpm. Pulling good. 19:00 - 20:30 1.50 DRILL WIPR INTRM1 Backream 3840' to 3450'. Tight hole & swabbing. Raise mud weight to 9.8. 20:30 - 21 :30 1.00 DRILL WIPR INTRM1 Backream 3450' into shoe. 21 :30 - 22:00 0.50 DRILL CIRC INTRM1 C.B.U. @ 2390'. 22:00 - 23:00 1.00 CEMENl LOT INTRM1 Perform & record LOT at shoe on 5249' TVD wellbore @ 14 strokes. Form. broke @ 750#. Pump additional 2.5 bbls 9.8 ppg mud. Initial SlOP @ 280#. Held 10 min. Flatlined @240#. EMW=15.7 ppg. 23:00 - 00:00 1.00 DRILL WIPR INTRM1 TIH. Hit solid bridge @ 2585'. Wash & Ream wI drilling parameters. 5/6/2001 00:00 - 02:00 2.00 DRILL DRLG INTRM1 Wash & Ream 2585' to 2770' (Pump WtlHi vis sweep - Getting 1/2" to 2" debris back across shakers) - Raise Mud wt to 9.8 ppg 02:00 - 04:00 2.00 DRILL TRIP INTRM1 TOH to Shoe - Monitor well for flow 04:00 - 05:30 1.50 DRILL TRIP INTRM1 Can't TOH to Jars 05:30 - 08:00 2.50 DRILL PULD INTRM1 SIB 1std DCs &1 std NM DCs- PJSM - Remove RA sources -Dn Load MWD - Brk Bit - SIB MWD & Motor 08:00 - 09:30 1.50 DRILL PULD INTRM1 P/U BHA #3 - HO Assy - P/U 3 steel sprial DCs 09:30 - 10:00 0.50 DRILL TRIP INTRM1 TI H to Shoe - Fill Pipe 10:00 - 10:30 0.50 DRILL TRIP INTRM1 TIH - Bridge @ 2540' 10:30 - 12:00 1.50 DRILL URM INTRM1 Wash & Ream 2540' to 2806' - Pump WtlHi Vis sweeps as needed - Getting very large debris 1/2" ro 2" size Mostly Claystone,Siltstone & Ash fall Tuff 12:00 - 13:00 1.00 DRILL URM INTRM1 Wash & Ream wlHO 2806 - 2910' 13:00 - 14:30 1.50 DRILL CIRC INTRM1 Circ & Condition - Raise Vis to 60 - Wt up to 1 O.Oppg to attempt to stabilize hole. 14:30 - 15:00 0.50 DRILL TRIP INTRM1 TOH to Shoe 15:00 - 19:00 4.00 DRILL URM INTRM1 Wash & Ream 2580' to 2625' - Work 2625' to 3100 - Snug to free at 3400' 19:00 - 20:30 1.50 DRILL CIRC INTRM1 Circu & Pump Sweep -Large amount - Large debris to surface as before 4 to 6 cubis feet or more 20:30 - 22:00 1.50 DRILL CIRC INTRM1 Circu second wtIhi vis sweep - Circu until clean 22:00 - 23:00 1.00 DRILL TRIP INTRM1 TOH to Shoe (2382') (Had tight hole 2850' & 2550' (25K overpull) 23:00 - 23:30 0.50 DRILL TRIP INTRM1 TIH- Bridge@ 2680' 23:30 - 00:00 0.50 DRILL URM INTRM1 Wash & Ream 2680' to 2685' 517/2001 00:00 - 01 :30 1.50 DRILL REAM INTRM1 Wash & Ream 2685' to 2911' MD ( Tight @ 270'1,2820',2885') 01 :30 - 02:00 0.50 DRILL CIRC INTRM1 Circu WtlHi Vis Sweep - Minimal debris returns with Sweep 02:00 - 03:00 1.00 DRILL REAM INTRM1 Wash & Ream 2911' to 3100' 03:00 - 03:30 0.50 DRILL TRIP INTRM1 TIH 3100' to 3550' - No obstructions (' ( Printed: 6/14/2001 1 :33:57 PM (. ( PHilliPS ALASKA, INC. Page 4 of 6 Operations Summary Report Legal Well Name: 2P-417 Common Well Name: 2P-417 Spud Date: 4/27/2001 Event Name: ROT - DRILLING Start: 4/19/2001 End: Contractor Name: Doyon Rig Release: Group: Rig Name: Doyon 141 Rig Number: 141 Date From - To Hou rs Code Sub Phase Description of Operations Code 517/2001 03:30 - 05:00 1.50 DRILL CIRC INTRM1 Circu & Pump Pigie Back WtlHi Vis Sweeps - Minimal debris returns with Sweep 05:00 - 06:30 1.50 DRILL TRIP INTRM1 TOH to 2385' - Tight 3185' to 2905' , 2740' to 2720' 06:30 - 07:00 0.50 DRILL TRIP INTRM1 TIH 2385' to 2830' Bridge 07:00 - 09:30 2.50 DRILL REAM INTRM1 Wash & Ream 2830' to 3150' - No obstructions 3150' to 3650' 09:30 - 10:30 1.00 DRILL CIRC INTRM1 Circu & Pump Pigie Back WtlHi Vis Sweeps - Minimal debris returns with Sweep 10:30 - 12:00 1.50 DRILL TRIP INTRM1 TOH to 2687' - Tight @ 3160,2985,2970 12:00 - 14:00 2.00 DRILL TRIP INTRM1 TIH to 5122' (Wash 2985' to 2998') Tag fill @ 5122' 14:00 - 17:00 3.00 DRILL REAM INTRM1 Wash & Ream Fill 5122' to 5257' 17:00 - 19:00 2.00 DRILL CIRC INTRM1 Circu & Pump Pigie Back WtlHi Vis Sweeps - Good returns of debris with Sweep 19:00 - 00:00 5.00 DRILL TRIP INTRM1 TOH to Shoe - TI H to 3346' (Had small bridge @ 2978' & 3068' no problems) - TOH for Drilling Assy 5/8/2001 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 TRIP OUT F/2380-229' 01 :00 - 02:00 1.00 DRILL PULD INTRM1 BHA, UD 3 SPIRAL DCLRS, SETBACK 1 STD SPIRAL DCLRS, UD HOLE OPENER & NB STAB. 02:00 - 02:30 0.50 WELCTL OTHR INTRM1 PULL WEAR RING, INSTALL TEST PLUG. 02:30 - 07:00 4.50 WELCTL BOPE INTRM1 TEST BOPE, WITNESSING WAIVED BY SHEAVEY-AOGCC. 07:00 - 07:30 0.50 WELCTL OTHR INTRM1 PULL TEST PLUG, INSTALL WEAR RING. 07:30 - 09:30 2.00 DRILL DEQT INTRM1 BHA, P/U MWD & MOTOR, M/U BIT, ORIENT & INITIALIZE MWD, INSTALL SOURCES, P/U NM DCLRS, P/U SPIRAL DCLRS & JARS. 09:30 - 13:00 3.50 DRILL TRIP INTRM1 TRIP INTO 3023', HIT BRIDGE @ 3023', WORK THRU BRIDGE & CONTINUE RIH TO 5230'. 13:00 - 14:00 1.00 DRILL REAM INTRM1 WASH & REAM F/5230-5262'. 14:00 - 20:30 6.50 DRILL DRLG INTRM1 DRLD F/5262-5421', ADT 6 HR. 20:30 - 21 :30 1.00 DRILL CIRC INTRM1 CIRCULATE BTMS UP F/SAMPLE. 21 :30 - 22:00 0.50 DRILL DRLG INTRM1 DRLD F/5421-5429', TAKE SPR & FLOW, ADT .2 HR. 22:00 - 00:00 2.00 DRILL CIRC INTRM1 CIRCULATE SAMPLE AND PUMP SWEEP F/SHORT TRIP. TOTAL MUD LOSSES WHILE DRILLING 120 BBL. 5/9/2001 00:00 - 04:00 4.00 DRILL CIRC INTRM1 Circ. & Condo hole 04:00 - 08:30 4.50 DRILL WIPR INTRM1 Short trip to shoe and back to bottom 08:30 - 19:00 10.50 DRILL CIRC INTRM1 Circ. & Condo hole, pump high vis weighted sweep, clean and prepare mud pits for coring fluid, pump 75 Bbl. low vis spacer, followed with coring fluid, displace hole with 10.2 ppg. coring fluid, circ. & Condo mud, observe well for flow, pump slug. 19:00 - 21 :30 2.50 DRILL TRIP INTRM1 POOH to BHA 21 :30 - 00:00 2.50 DRILL TRIP INTRM1 POOH with BHA, lay down MWD 5/10/2001 00:00 - 02:00 2.00 CORE CORE INTRM1 P/U CORING ASSY 02:00 - 02:30 0.50 CORE TRIP INTRM1 RIH TO 2316' 02:30 - 03:30 1.00 RIGMNT RURD INTRM1 CUT DRLG LINE 03:30 - 04:00 0.50 RIGMNT RSRV INTRM1 SERVICE TOP DRIVE & DRAWWORKS 04:00 - 05:00 1.00 CORE TRIP INTRM1 RIH TO 5324' 05:00 - 06:00 1.00 CORE WASH INTRM1 WASH F/5324-5390', REAM F/5390-5429' 06:00 - 08:00 2.00 CORE CORE INTRM1 CORE F/5429-5489' 08:00 - 09:30 1.50 CORE CIRC INTRM1 CIRC & COND, MAX GAS ON BTMS UP 269 UNITS. 09:30 - 14:00 4.50 CORE TRIP INTRM1 TRIP OUT USING DECOMPRESSION SCHEDULE 14:00 - 15:00 1.00 CORE RCVR INTRM1 UNLOAD 60' CORE, 60' CUT & RECOVERED. 15:00 - 16:30 1.50 CORE PULD INTRM1 M/U INNER BBL & RIH TO 2300' 16:30 - 17:00 0.50 RIGMNT RGRP INTRM1 REPAIR SIDE DOORS IRON ROUGHNECK. 17:00 - 19:00 2.00 CORE TRIP INTRM1 CONTINUE RIH WICORE #2. 19:00 - 20:00 1.00 CORE WASH INTRM1 WASH & REAM F/5386-5489' -5' FILL ON BTM. 20:00 - 23:00 3.00 CORE CORE INTRM1 CORE F/5489-5549', 2.5 HR ADT Printed: 6/14/2001 1 :33:57 PM ( (' PHilliPS ALASKA, INC. Page 5 of 6 Operations Summary Report Legal Well Name: 2P-417 Common Well Name: 2P-417 Spud Date: 4/27/2001 Event Name: ROT - DRILLING Start: 4/19/2001 End: Contractor Name: Doyon Rig Release: Group: Rig Name: Doyon 141 Rig Number: 141 Date From - To Hours Code Sub Phase Description of Operations Code 5/10/2001 23:00 - 00:00 1.00 CORE CIRC INTRM1 CIRCULATE BTMS UP. 5/11/2001 00:00 - 00:30 0.50 CORE CIRC INTRM1 CIRC & COND MUD, MONITOR WELL & PUMP SLUG. 00:30 - 05:00 4.50 CORE TRIP INTRM1 TRIP OUT W/CORE ASSY AT DECOMPRESSION RUNNING SPEEDS. 05:00 - 06:00 1.00 CORE RCVR INTRM1 LAY DOWN CORES, 60' CUT 58.5' RECVD. 06:00 - 07:00 1.00 CORE PULD INTRM1 UD CORING ASSY & CLEAR FLOOR. 07:00 - 09:30 2.50 DRILL PULD INTRM1 BHA, P/U MTR & MWD F/DERRICK, M/U BIT, INITIALIZE MWD, INSTALL SOURCES, P/U NM DCLRS, SPIRAL DCLRS, JARS & HWDP, 09:30 - 12:00 2.50 DRILL TRIP INTRM1 RIH TO 5200', FILL D.P. @ 3550', BREAK CIRC @ 5200', EST SLOW PUMP RATE. 12:00 - 16:30 4.50 DRILL SURV INTRM1 MAD PASS WILWD F/5200-5449' @ 100'/HR. 16:30 - 00:00 7.50 DRILL DRLG INTRM1 DRLD F/5549-5806' ART 6.75 HR. 5/12/2001 00:00 - 05:30 5.50 DRILL DRLG INTRM1 Drill from 5806' to 5993' 05:30 - 07:00 1.50 DRILL CIRC INTRM1 Pump and circ. sweep around, monitor well for flow 07:00 - 09:00 2.00 DRILL WIPR INTRM1 Short trip to 5150', tight spot from 5580' to 5457', had to pump out, 50k over pull in spots, cleaned up ok. 09:00 - 11 :30 2.50 DRILL CIRC INTRM1 Circ. and Cond hole, Circ. high vis weighted sweep around 11 :30 - 12:00 0.50 RIGMNT RGRP INTRM1 Problems with hydraulic pump on TDS, Remove link tilt on TDS 12:00 - 14:30 2.50 DRILL TRIP INTRM1 POOH from 5993' to 1200' 14:30 - 18:30 4.00 DRILL TRIP INTRM1 Pull BHA, lay down 3 non-mag drill collars, down load MOW data, lay down MWD tools, motor and stabs. 18:30 - 19:30 1.00 RIGMNT RGRP INTRM1 Remove hydraulic pump and filter housing from top drive 19:30 - 20:00 0.50 FRMTST SFTY INTRM1 Pre-job safety meeting for logging 20:00 - 00:00 4.00 FRMTST OTHR INTRM1 R/U Schlumberger open hole 10ggers,RIH W/Run #1 Platform Express Tight going in from 2500' to 2700' & 5288' to 5322', coming out we had tight a spot at 5322' to 5288' pulled 6000 to get thru and at 2530' it took 5000 overpull. 5/13/2001 00:00 - 07:00 7.00 FRMTST OTHR INTRM1 Finish logging run #1 Platform Express, because of hole condition it was decided not to run the FMI with the DSI Run #2 DSI - RIH to within 20' of bottom (5973'), log up, stuck tool at 5450', work tool up to 6500 psi over pull, came free going down after 15 mins working, finsh logging run, POOH. Decision was made from town not to attempt any more logging runs, R/D Schlumberger 07:00 - 08:30 1.50 DRILL TRIP INTRM1 PIU BHA 08:30 - 11 :00 2.50 DRILL TRIP INTRM1 TIH to 5913' 11 :00 - 11 :30 0.50 DRILL REAM INTRM1 Wash F/5913' to 5993', found fill at 5970' (23' of fill) 11 :30 - 13:00 1.50 DRILL DRLG INTRM1 Drill from 5993' to 6008', to get rat hole for running casing -I>- 13:00 - 15:00 2.00 DRILL CIRC INTRM1 Circ. sweep around, drop survey, observe well for flow, pump slug 15:00 - 17:30 2.50 DRILL TRIP INTRM1 POOH to BHA 17:30 - 20:00 2.50 DRILL PULD INTRM1 UD HWDP,Jars, DC's,Stab. and Bit 20:00 - 20:30 0.50 DRILL OTHR INTRM1 Retrieve wear bushing 20:30 - 22:30 2.00 CASE RURD INTRM1 P/U casing tools and R/U to run casing 22:30 - 00:00 1.50 WAlTON EOIP INTRM1 4 1/2" casing elevators were dressed with wrong slip dies, waiting on set to come from another rig 5/14/2001 00:00 - 01 :00 1.00 WAlTON EOIP INTRM1 Wait on 4 1/2" casing elevators 01 :00 - 02:30 1.50 CASE RUNC INTRM1 Run 21 jts. 4.5" 12.6# L-80 BTC casing and Baker seal bore 02:30 - 03:30 1.00 CASE RURD INTRM1 Change out 41/2" tools to 7" tools, R/U Franks fill up tool 03:30 - 10:00 6.50 CASE RUNC INTRM1 Run 127 jts. 7" 26# L-80 BTC casing, set at 6002' 10:00 - 10:30 0.50 CEMEN" PULD INTRM1 RIU Dowell cement head 10:30 - 14:00 3.50 CEMEN" CIRC INTRM1 Attempt to break circulation, lost returns, pump at low rate to regain returns reciprocating slowly, lost 594 bbls before getting full returns, circ. and condo hole Printed: 6/14/2001 1 :33:57 PM (: (' PHilliPS ALASKA, INC. Page 6 of 6 Operations Summary Report Legal Well Name: 2P-417 Common Well Name: 2P-417 Spud Date: 4/27/2001 Event Name: ROT - DRILLING Start: 4/19/2001 End: Contractor Name: Doyon Rig Release: Group: Rig Name: Doyon 141 Rig Number: 141 Date From - To Hours Code Sub Phase Description of Operations Code 5/14/2001 14:00 - 17:00 3.00 CEMEN" PUMP INTRM1 Held pre-job safety meeting, test lines, pump 40 bbl. CW100 pre-flush, 60 bbls. Mud Push spacer, mix and pump 420 sx CI. G (90bbl) at 15.8 ppg., release top plug and displace with15 bbl h20/polymer pill followed by water, over displace by 1/2 bbl. and shut down, did not bump plug, check floats and held, RID Dowell. 17:00 - 17:30 0.50 CASE RURD INTRM1 Wash off top of hanger and lay down landing jt. 17:30 - 18:30 1.00 WELCTL NUND INTRM1 Install wellhead pack off and test 18:30 - 19:30 1.00 CASE RURD INTRM1 Lay down 7" casing handling equipment and clear floor of equip. no longer needed 19:30 - 20:30 1.00 WELCTL EORP INTRM1 Change lower pipe rams from 4" to 5" 20:30 - 21 :00 0.50 RIGMNT RSRV INTRM1 Rig service 21 :00 - 21 :30 0.50 RIGMNT RGRP INTRM1 Replace hydraulic pump on TDS 21 :30 - 00:00 2.50 DRILL RIRD INTRM1 Change out saver sub on TDS from 4" FH to NC50 for 5" DP. 5/15/2001 00:00 - 01 :00 1.00 DRILL RIRD INTRM1 Hold crew change pre-job safety meeting, Finish change out of saver sub from 4" to 5" 01 :00 - 01 :30 0.50 DRILL PULD INTRM1 Install wear bushing 01 :30 - 03:00 1.50 DRILL PULD INTRM1 RIH W/54 stds. 4" DP. 03:00 - 06:30 3.50 DRILL PULD INTRM1 POOH UD 4" DP. 06:30 - 07:00 0.50 DRILL PULD INTRM1 Pull wear bushing 07:00 - 08:00 1.00 CASE DEOT INTRM1 R/U and test casing to 3000 psi for 30 mins. Dropped 50 psi in 30 mins. 08:00 - 09:00 1.00 CMPL TN RURD CMPL TN R/U to run 41/2" tubing 09:00 - 16:00 7.00 CMPL TN RUNT CMPL TN RIH WI baker seal assemblyand locator, 5- camco GLM's and 161 jts 41/2" 12.6# L-80 BTC tubing as per program, set seal assembly at 5302' 16:00 - 19:00 3.00 CMPL TN SOHO CMPL TN Space out and land tubing 19:00 - 19:30 0.50 CMPL TN SOHO CMPL TN Screw in lock down screws on tubing hanger 19:30 - 23:00 3.50 CMPLTN DEOT CMPL TN R/U and test down tubing to 3000 psi for 30 mins, bled tubing back to 500 psi. Pressure test 41/2" X 7" annulus to 3000 psi for 30 mins., bled tubing to 0 psi, shear valve didn't shear in gas lift mandrel, pressure annulus to 3100 psi and shear valve sheared, pressure in annulus dropped to 1600 psi and stopped, tried to circulate, but only had slight bleed off after shutting pump down. Pressure to 3500 psi with same results. Pumped down tubing to try and get circulation, but only had slight bleed off with pump down. Plan to have the Wells group fish valve with slick line today, then we can freeze protect casing and tubing. 23:00 - 00:00 1.00 CMPL TN NUND CMPL TN NID BOP's 5/16/2001 00:00 - 00: 15 0.25 WELCTL SFTY INTRM1 Pre-job safety meeting 00:15 - 01 :30 1.25 WELCTL NUND INTRM1 NID BOP's 01 :30 - 04:30 3.00 WELCTL NUND INTRM1 N/U Tree, test pack off to 5000 psi, test tree 250 psi low and 5000 psi high, pull back pressure valve in tubing hanger. Release Rig at 0430 hrs. 05/16/01 and start move to 2P 438 04:30 - 07:30 3.00 CMPL TN FRZP INTRM1 R/U pressure truck on 7" X 9 5/8" annulus, perform LOT, broke back at a 12.2 equivilent mud weight, Pump 200 bbls water to flush annulus followed by 60 bbls of diesel for freeze protection. printed: 6/14/2001 1 :33:57 PM SENT BY: /. Date 12/11/01 12/12101 12/13101 12/14101 12/15/01 12/16101 .- 12/19/01 1-11- 2 :10:28AM : PHILLIPS AK INC~ :# 3/ 3 ( 2P-417 Event History ( Comment ' . JETTED OUT FlUIDSNISC. BRINE TO HARD TAG AT 5665' CTM WI A 1.751 VORTECH DOWN.JET NOZZLE; UNABLE TO MAKE ANY MORE HOLE. TBG. FREEZE PROTE~D TO' 2500'+ WI DIESEL [FCO. VOATECH) TAGGED F1ll 0 6687' RKB. INSTAllED SPARTEK SIDEPOCKET GAUGE 0 51791 RKB. PT IA TO 300Of. GOOD. (TAG, PRESSURE DATA] 1ST RIH : LOGGED JEWELRY WITH TEMP/PRESSURE - TAGGED TO AT 5684 FT MO. 2ND R'H: SHOT 3.38- HSD . 6 SPF - 3406 POWERJET CHARGES; INTERVAL = 5495-5516 FT MD 3RD R'H: LOGGED TIE ,- IN PASS PLUS SBHP STATIONS AT 5505 FT MD AND 5179 FT MD. NOTE THAT THE WHP HA PUMPED INITIAL FRACTURE TREATMENT. TREATED WITH 30# LOW GUAR SYSTEM, 40 BPM. AVERAGE TREA1lNG PRESSURE = PLACED 213M# 16120 CAABOUfe BI::HIND PIPE, 12 PPA ON PERFS. HAD NWBSO, LEFT 30M# IN WELLBORE. 71 % OF DESIGN PLACED. CLEANED OUT Fill TO 5667' CTM W/2.25" JET-SWIRL NOZZLE USING SEAWATER J313 ANt) DIESEL GEL. WELL FREEZE PROTECTED WI DIESEL TO 2500'. NOTE: NO CRUDE RETURNED. TeST OF ' FLOWBANK TANKS INDICATE RA TRACER PRES~NT IN SOLIDS; ONE TANK AT 2.0 MRlHR, OTHE.R ^ T 0 . TAGGED FILL" 5516' RKB. EST.1' RATHOLE. PULLED SPARTEK & INSTALLED OV @ 5179' RKB. (GtV. TAG,,,PRESSURE DATA] , -'---" FLOWING LOG. DOWN & ,UP FROM 5000' WLM TO 5511' WLM [PRESSURE DATA) RECEIVED JAN .1 120HZ ,Alaska Oil &.Gas Coos. Commission . Anchorage . Page 1 of 1 11312002 .- - - - - - - - - - - - - - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 045(}.OOOB2 Sidetrack No. -- Page 1 of ~ . , Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field MELlWATER Well Name & No. PAD 2P/417 Survey Section Name Definitive Survey BHI Rep. AJ HARSTAD INTEQ. WELL DATA Target TVD (Fl) Target Coord. N/S Slot Coord. N/S -889.91 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E¡W 2063.98 Magn. Declination 25.560 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mO Vert. Sec. Azim. 85.97 Magn. to Map Corr. 25.560 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Bui~d Rate W~lk Rate Date Tool Depth Angle Direction Length TVD Section N( +) / S(-) E( +) / W(-) DL BUild (+) Right (+) Comment Type (Fl) (DO) (DO) (Fl) (Fl) (Fl) (Fl) (Per 100 F1) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT -..., - 28-APR-01 MWD 149.60 0.70 17.60 149.60 149.60 0.34 0.87 0.28 0.47 0.47 28-APR-01 MWD 236.90 1.10 13.00 87.30 236.89 0.78 2.20 0.63 0.47 0.46 28-APR-01 MWD 330.50 1.10 11.60 93.60 330.47 1.28 3.95 1.01 0.03 0.00 28-APR-01 MWD 421.70 1.20 6.00 91.20 421.65 1.69 5.76 1.28 0.16 0.11 28-APR-01 MWD 516.10 0.20 7.70 94.40 516.04 1.89 6.91 1.41 1.06 -1.06 28-APR-01 MWD 606.00 0.20 163.50 89.90 605.94 1.96 6.91 1.48 0.44 0.00 28-APR-01 MWD 698.00 0.10 212.70 92.00 697.94 1.94 6.69 1.48 0.17 -0.11 28-APR-01 MWD 789.10 0.10 315.70 91.10 789.04 1.85 6.68 1.38 0.17 0.00 28-APR-01 MWD 881.00 0.10 242.90 91.90 880.94 1.72 6.70 1.25 0.13 0.00 28-APR-01 MWD 972.80 0.20 270.30 91 .80 972.74 1 .49 6.66 1.02 0.13 0.11 28-APR-01 MWD 1161.40 0.40 235.20 188.60 1161.34 0.59 6.29 0.15 0.14 0.11 28-APR-01 MWD 1255.50 0.40 206.70 94.10 1255.44 0.14 5.81 -0.27 0.21 0.00 -- - 28-APR-01 MWD 1348.60 0.50 200.70 93.10 1348.53 -0.19 5.14 -0.56 0.12 0.11 29-APR-01 MWD 1443.90 0.50 198.60 95.30 1443.83 -0.53 4.36 -0.84 0.02 0.00 29-APR-01 MWD 1537.00 0.40 193.30 93.10 1536.93 -0.78 3.65 -1.04 0.12 -0.11 29-APR-01 MWD 1631.50 0.50 207.00 94.50 1631.42 -1.09 2.97 -1.30 0.15 0.11 29-APR-01 MWD 1725.30 0.40 177.50 93.80 1725.22 -1.31 2.27 -1.47 0.27 -0.11 29-APR-01 MWD 1820.20 0.60 211 .30 94.90 1820.12 -1.61 1 .52 -1 .72 0.37 0.21 29-APR-01 MWD 1914.90 0.60 212.70 94.70 1914.81 -2.19 0.68 -2.24 0.02 0.00 29-APR-01 MWD 2008;60 0.40 204.90 93.70 2008.51 -2.64 -0.03 -2.65 0.22 -0.21 29-APR-01 MWD 2104.40 2.20 102.60 95.80 2104.28 -1.04 -0.74 -0.99 2.42 1.88 29-APR-01 MWD 2198.70 4.30 94.90 94.30 2198.43 4.19 -1.43 4.30 2.27 2.23 30-APR-01 MWD 2290.60 6.30 87.90 91.90 2289.93 12.63 -1 .54 12.77 2.28 2.18 -7.62 . - - - - - - - - - - - ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0450-00082 Sidetrack No. Page 2 of 3 - -- Company PHILLIPS ALASKA, INC. Rig Contractor & No, Doyon Drilling Co. - Rig: #141 Field MELTWATER --- Well Name & No. PAD 2P/417 Survey Section Name Definitive Survey BHI Rep. AJ HARSTAD INTEQ WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. N/S -889.91 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E¡W Slot Coord. E/W 2063.98 Magn. Declination 25.560 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mD 10mO Vert. Sec. Azim. 85.97 Magn. to Map Corr. 25.560 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100FT) Drop (-) Left (-) /' 30-APR-01 MWD 2366.80 8.30 86.80 76.20 2365.51 22.31 -1.08 22.44 2.63 2.62 -1.44 - 02-MA Y-01 MWD 2442.70 8.79 83.64 75.90 2440.57 33.58 -0.13 33.67 0.89 0.65 -4.16 02-MAY-01 MWD 2535.70 8.61 86.81 93.00 2532.50 47.64 1.04 47.69 0.55 -0.19 3.41 02-MAY-01 MWD 2631.60 8.61 85.40 95.90 2627.32 62.00 2.02 62.01 0.22 0.00 -1.47 02-MAY-01 MWD 2726.1 0 8.53 85.75 94.50 2720.76 76.08 3.10 76.05 0.10 -0.08 0.37 03-MA Y-01 MWD 2818.20 8.44 83.64 92.10 2811.85 89.66 4.36 89.58 0.35 -0.10 -2.29 03-MAY-01 MWD 2913.50 8.09 85.05 95.30 2906.16 103.36 5.71 103.21 0.42 -0.37 1.48 03-MAY-01 MWD 3008.00 8.09 82.24 94.50 2999.72 116.64 7.18 116.42 0.42 0.00 -2.97 03-MAY-01 MWD 3102.60 8.00 80.13 94.60 3093.39 129.83 9.21 129.50 0.33 -0.10 -2.23 03-MA Y-01 MWD 3196.50 7.29 85.05 93.90 3186.46 142.29 10.84 141.88 1.03 -0.76 5.24 03-MAY-01 MWD 3290.10 7.38 87.86 93.60 3279.29 154.23 11.58 153.80 0.40 0.10 3.00 03-MA Y-01 MWD 3379.70 6.15 93.49 89.60 3368.27 164.74 11.50 164.34 1.56 -1.37 6.28 03-MAY-01 MWD 3474.20 5.01 92.42 94.50 3462.32 173.86 11.02 173.52 1.21 -1.21 -1.13 .~- - 03-MA Y-01 MWD 3567.90 3.78 83.99 93.70 3555.74 181 .02 11.17 180.68 1.48 -1.31 03-MAY-01 MWD 3662.90 2.99 87.16 95.00 3650.58 186.62 11.62 186.27 0.85 -0.83 04-MAY-01 MWD 3757.30 2.02 101.57 94.40 3744.89 190.69 11.41 190.35 1.22 -1.03 04-MA Y-01 MWD 3850.60 0.79 138.14 93.30 3838.16 192.66 10.60 192.40 1.57 -1.32 04-MA Y-01 MWD 3943.30 0.53 190.87 92.70 3930.85 192.95 9.70 192.74 0.68 -0.28 04-MAY-01 MWD 4037.70 1.23 290.01 94.40 4025.24 191 .91 9.62 191.71 1.50 0.74 , 04-MA Y-01 MWD 4130.80 1.58 292.82 93.10 4118.32 189.85 10.46 189.58 0.38 0.38 04-MA Y-01 MWD 4227.40 1.32 . 321 .65 96.60 4214.89 188.04 11.85 187.67 0.79 -0.27 - 04-MAY-01 MWD 4322.60 1.41 330.44 95.20 4310.06 186.91 13.73 186.41 0.24 0.09 04-MAY-01 MWD 4416.50 1.23 324.82 93.90 4403.94 185.89 15.56 185.26 0.24 -0.19 04-MA Y-01 MWD 4511.30 0.79 337.47 94.80 4498.72 185.16 16.99 184.42 0.52 -0.46 , = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00082 Sidetrack No. Page 3 of 3 - -- - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field MELTWATER ---- Well Name & No. PAD 2P/417 Survey Section Name Definitive Survey BHI Rep. AJ HARSTAD INTEQ WELL DATA . -- .----- Target TVD (F1) Target Coord. N/S Slot Coord. N/S -889.91 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E¡W Slot Coord. E/W 2063.98 Magn. Declination 25.560 Calculation Method MINIMUM CURVATURE -- Target Direction (DO) Build\Walk\DL per: 1 OOft~ 30mO 10mD Vert. Sec. Azim. 85.97 Magn. to Map Corr. 25.560 Map North to: OTHER SURVEY DATA . Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F1) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 F1) Drop (-) Left (-) 04-MA Y-01 MWD 4603.60 0.35 70.99 92.30 4591.02 185.23 17.67 184.44 0.96 -0.48 - 04-MA Y-01 MWD 4696.70 0.53 112.12 93.10 4684.11 185.89 17.60 185.11 0.38 0.19 04-MAY-01 MWD 4792.40 0.70 122.67 95.70 4779.81 186.76 17.12 186.01 0.21 0.18 04-MAY-01 MWD 4886.30 0.62 116.34 93.90 4873.70 187.66 16.59 186.95 0.12 -0.09 04-MA Y-01 MWD 4980.00 0.70 131.46 93.70 4967.40 188.49 15.98 187.84 0.20 0.09 04-MAY-01 MWD 5076.40 0.53 122.67 96.40 5063.79 189.26 15.35 188.65 0.20 -0.18 04-MAY-01 MWD 5168.70 0.35 147.28 92.30 5156.09 189.74 14.88 189.16 0.28 -0.20 04-MA Y-01 MWD 5262.10 0.35 145.52 93.40 5249.49 190.02 14.41 189.48 0.01 0.00 11-MAY-01 MWD 5356.30 0.18 121.61 94.20 5343.68 190.29 14.09 189.77 0.21 -0.18 11-MA Y-01 MWD 5452.60 0.26 112.47 96.30 5439.98 190.61 13.93 190.10 0.09 0.08 11-MA Y-01 MWD 5544.90 0.26 114.93 92.30 5532.28 190.98 13.76 190.48 0.01 0.00 11-MAY-01 MWD 5638,90 0.44 110.36 94.00 5626.28 191.49 13.55 191.01 0.19 0.19 12-MA Y-01 MWD 5825,00 0.18 85.30 186.10 5812.38 192.44 13.32 191 .98 0.15 -0.14 _. , - 13-MAY-01 MWD 5991 .00 0.50 85.50 166.00 5978.38 193.42 13.40 192.96 0.19 0.19 Mag Single Shot Survey 13-MAY-01 MWD 6008.00 0.50 85.50 17.00 5995.37 193.57 13.41 193.11 0.00 0.00 Projected Data - NO SURVEY I I t I , ( (;ÀU I-u~ L) f Phillips Alaska, Inc. Drill Site 2P 417 slot *417 Meltwater North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes IN'l'EQ Your ref: MND <0 - 6008'> Our ref: svy6522 License: Date printed: ll-Jul-200l Date created: 30-Apr-2001 Last revised: 25-May-2001 Field is centred on 441964.235,5869891.466,999.00000,N Struoture is centred on 441964.235,5869891.466,999.00000,N Slot looation is n70 3 9.890,w150 26 49.100 Slot Grid coordinates are N 5868997.699, E 444146.798 Slot looal ooordinates are 877.19 S 2189.52 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED JÞ.N 1 7 2002 Alaska Oil & Gas Cons. Commission Anchorage ( ( Phillips Alaska, Inc. SURVEY LISTING Page 1 Drill Site 2P,417 Your ref: MWD <0 - 6008'> Mel twa tar, North Slope, Alaska Last r8VÌsed : 25-May-2001 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COORDS Depth Degrees Degrees Depth COORDINATES Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 444146.80 5868997.70 14 9. 60 0.70 17.60 149.60 0.87N 0.28E 0.47 0.34 444147.08 5868998.57 236.90 1.10 13.00 236.89 2.20N 0.63E 0.47 0.78 444147.44 5868999.89 330.50 1.10 11.60 330.47 3.95N 1.01E 0.03 1.28 444147.84 5869001.64 421.70 1.20 6.00 421.65 5.76N 1.28E 0.16 1. 69 444148.13 5869003.45 516.00 0.20 7.70 515.94 6.90N 1.41E 1.06 1.89 444148.26 5869004.59 606.00 0.20 163.50 605.94 6.91N 1.48E 0.43 1.96 444148.33 5869004.60 698.00 0.10 212.70 697.94 6.69N 1.48E 0.17 1. 94 444148.33 5869004.37 789.10 0.10 315.70 789.04 6.68N 1.38E 0.17 1.85 444148.23 5869004.36 881.00 0.10 242.90 880.94 6.70N 1.25E 0.13 1.72 444148.10 5869004.39 972.80 0.20 270.30 972.74 6.66N 1.02E 0.13 1.49 444147.87 5869004.35 1161.40 0.40 235.20 1161.34 6.29N 0.15E 0.14 0.59 444147.00 5869003.99 1255.50 0.40 206.70 1255.44 5.81N 0.27W 0.21 0.14 444146.58 5869003.51 1348.60 0.50 200.70 1348.53 5.14N 0.56W 0.12 -0.19 444146.28 5869002.84 1443.90 0.50 198 . 60 1443.83 4.35N 0.84W 0.02 -0.53 444146.00 5869002.06 1537.00 0.40 193.30 1536.93 3.65N 1.04W 0.12 -0.78 444145.79 5869001.36 1631. 50 0.50 207.00 1631.42 2.96N 1.30W 0.15 -1.09 444145.52 5869000.67 1725.30 0.40 177 . 50 1725.22 2.27N 1.47W 0.27 -1.31 444145.34 5868999.98 1820.20 0.60 211.30 1820.12 1.52N 1.72W 0.37 -1.61 444145.09 5868999.23 1914.90 0.60 212.70 1914.81 0.68N 2.24W 0.02 -2.19 444144.56 5868998.39 2008.60 0.40 204.90 2008.51 0.03S 2.65W 0.22 -2.64 444144.15 5868997.69 2104.40 2.20 102.60 2104.29 0.74S 0.99W 2.42 -1.04 444145.80 5868996.97 2198.70 4.30 94.90 2198.43 1.43S 4.30E 2.27 4.19 444151.08 5868996.23 2290.60 6.30 87.90 2289.93 1.54S 12.77E 2.28 12.63 444159.55 5868996.06 2366.80 8.30 86.80 2365.51 1.08S 22 . 44E 2.63 22.31 444169.23 5868996.44 2442.70 8.79 83.64 2440.57 O.14S 33.67E 0.89 33.58 444180.47 5868997.31 2535.70 8.61 86.81 2532.50 1.04N 47.69E 0.55 47.64 444194.49 5868998.37 2631.60 8.61 85.40 2627.32 2.01N 62.01E 0.22 62.00 444208.81 5868999.24 2726.10 8.53 85.75 2720.76 3.10N 76.05E 0.10 76.08 444222.86 5869000.22 2818.20 8.44 83.64 2811.85 4.36N 89.58E 0.35 89.66 444236.40 5869001.37 2913.50 8.09 85.05 2906.17 5.71N 103.21E 0.42 103.36 444250.04 5869002.62 3008.00 8.09 82.24 2999.72 7.18N 116.42E 0.42 116.64 444263.26 5869003.99 3102.60 8.00 80.13 3093.39 9.21N 129.50E 0.33 129.83 444276.36 5869005.92 3196.50 7.29 85.05 3186.46 10.84N 141.88E 1.03 142.29 444288.74 5869007.46 3290.10 7.38 87.86 3279.29 11 . 58N 153.80E 0.40 154.23 444300.67 5869008.10 3379.70 6.15 93.49 3368.27 11 . 50N 164.34E 1.56 164.74 444311.21 5869007.95 3474.20 5.01 92.42 3462. 32 11 . 02N 173.52E 1.21 173.86 444320.38 5869007.39 3567.90 3.78 83.99 3555.74 11.17N 180.68E 1.48 181.02 444327.54 5869007.49 3662.90 2.99 87.16 3650.58 11 . 62N 186.27E 0.85 186.62 444333.13 5869007.90 3757.30 2.02 101.57 3744.89 11. UN 190.36E 1.22 190.69 444337.22 5869007.66 3850.60 0.79 138.14 3838.16 10.60N 192.40E 1.57 192.66 444339.25 5869006.83 3943.30 0.53 190.87 3930.85 9.70N 192.74E 0.68 192.95 444339.59 5869005.93 4037.70 1.23 290.01 4025.25 9.62N 191.71E 1.50 191.91 444338.55 5869005.86 4130.80 1.58 292.82 4118.32 10.46N 189.58E 0.38 189.85 444336.44 5869006.71 4227.40 1.32 321.65 4214.89 11 . 85N 187.67E 0.79 188.04 444334.53 5869008.12 4322.60 1.41 330.44 4310.06 13.73N 186. 41E 0.24 186.91 444333.29 5869010.01 4416.50 1.23 324.82 4403.94 15.56N 185.26E 0.24 185.89 444332.15 5869011.84 4511.30 0.79 337.47 4498.72 16.99N 184.42E 0.52 185.16 444331.33 5869013.28 4603.60 0.35 70.99 4591.02 17.67N 184.44E 0.96 185.23 444331.35 5869013.96 4696.70 0.53 112.12 4684.11 17.60N 185.11E 0.38 185.89 444332.02 5869013.89 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot 1417 and TVD from rotary table (254.00 Ft above mean se. level). Bottom hole distance is 193.57 on azimuth 86.03 degrees from wellhead. Vertical section is from wellhead on azimuth 85.97 deqrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Bughes INTEQ ( (' Phillips Alaska, Inc. SURVEY LISTING Page 2 Drill Site 2P,417 Your ref : MWD <0 - 6008' > Meltwater,North Slope, Alaska Last revised : 25-May-2001 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COORDS Depth Degrees Degrees Depth COORDINATES Deq/l00ft Sect E.sting Northing 4792.40 0.70 122.67 4779.81 17.12N 186.01E 0.21 186.76 444332.92 5869013.40 4886.30 0.62 116.34 4873.70 16.59N 186.95E 0.12 187.66 444333.85 5869012.86 4980.00 0.70 131.46 4967.40 15.98N 187.84E 0.20 188.49 444334.73 5869012.25 5076.40 0.53 122.67 5063.79 15.35N 188.65E 0.20 189.26 444335.54 5869011.61 5168.70 0.35 14 7 . 28 5156.09 14 . 88N 189.16E 0.28 189.74 444336.05 5869011.14 5262.10 0.35 145. 52 5249.49 14.UN 189.48E 0.01 190.02 444336.36 5869010.66 5356.30 0.18 121.61 5343.69 14 . 09N 189.77E 0.21 190.29 444336.65 5869010.34 5452.60 0.26 112.47 5439.99 13.93N 190.10E 0.09 190.61 444336.98 5869010.18 5544.90 0.26 114.93 5532.28 13.76N 190.48E 0.01 190.98 444337.36 5869010.01 5638.90 0.44 110.36 5626.28 13.55N 191. OlE 0.19 191.49 444337.89 5869009.79 5825.00 0.18 85.30 5812.38 13.32N 191.98E 0.15 192.44 444338.85 5869009.56 5991.00 0.50 85.50 5978.38 13.40N 192.96E 0.19 193.42 444339.83 5869009.63 6008.00 0.50 85.50 5995.38 13. UN 193.llE 0.00 193.57 444339.98 5869009.64 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot *417 and TVD from rotary table (254.00 Ft above mean sea level). Bottom hole distance is 193.57 on azimuth 86.03 degrees from wellhead. Vertical section is from wellhead on azimuth 85.97 degree.. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Pre.ented by Baker Hughes INTEQ ( ( Phillips Alaska, Inc. Drill Site 2P,4l7 HeJ.twater,North Slope, Alaska SURVEY LISTING Page 3 Your ref : HWD <0 - 6008' > Last r8VÌsed : 25-May-2001 Caaments in wellpath HI) 'rVD Rectangular Coords. COJII'II8nt ----------------------------------------------------------------------------------------------------------- 5991.00 5978.38 13.40N 192.96E Mag Single Shot Survey 6008.00 5995.38 13. 4lN 193.llE Projected Data - NO SURVEY Casing positions in string 'A' Top HI) Top 'rVD Rectangular Coords. Bot HI) Bot 'rVD Rectangular Coords. ea8ing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OOE 6002.00 5989.38 13.4lN 193.051: 4 1/2" Casing O.OON O.OOE 2382.00 2380.55 0.95S 24.64E 9 5/8" Casing Targets associated with this wellpath Geographic Location T.V.D. Rectangular Coordinates Revised Target name ----------------------------------------------------------------------------------------------------------- MW(G) Rvsd 3-Apr-01 444213.000,5868998.000,999.00 5479.00 0.81N 66.20E 22-Feb-2001 0 ORE RUN #2: RAN IN HOLE WITH SAME ASSEMBLY AS CORE #1. REAMED FROM 5475' TO 5489' IN 1.5 HRS. CLEANED HOLE UP AND DROPPED BAll TO BEGIN CORE. STARTED WITH 350 GPM, 50 RPM AND5K WOB. INCREASED WOB TO 18K AND RPM TO 90. PUMP RATE STAYED AT 350 GPM. ,',i 'WE CORED PAST THE 2 HR LIMIT SET BY PHILLIPS AFTER GEOLOGIST REQUEST AND SLOW ROP. :,;,;~;;,;,<;:qUT60FEET OF CORE IN 2.62 HRS. PULLED OFF BOTTOM WITH FULL BARREL AND TRIPPED f;~~;~¡.,:~,.:'.,"'OUT OF THE HOLE AT A REDUCED RATE PER PHilLIPS PROCEDURE. RECOVERED 59 FEET rCO~E FOR A 98% RECOVERY. -;:;;;~a- r~ii. I BAKER HUGHES NTEQ ( ( CORING SUMMARY NOTES' ORE RUN #1: PICKED UP 60' OF HT30 CORE BBLS WITH ALUMINUM INNERS AND AN 8 1/2" X 4" ARC412C3 COREHEAD. RAN TO BOTTOM, CLEANED HOLE AND DROPPED BAll TO BEGIN CORE. STARTED OUT WITH 350 GPM, 5K WOB, 70 RPM. WE STAYED WITH 350 GPM THOUGHOUT THE CORE AND GRADUALLY INCREASED THE WOB TO 12K LBS AND THE RPM TO 80. TORQUE WAS ERRATIC DURING ENTIRE CORE INTERVAL RANGING FROM 5K-20K FT-LBS. CUT 60 FEET OF CORE IN 1.85 HRS. PULLED OFF BOTTOM WITH FULL BARREL. TRIPPED OUT OF THE HOLE AT A REDUCED RATE PER PHILLIPS PROCEDURE. 1000/0 RECOVERY OF THE CORE CUT. . .' ,. .:." ~,..,:'~;;;:~¡!~\"TAL FOOTAGE CORED WAS 120 FEET, TOTAL FOOTAGE CORE RECOVERED WAS 119 FEET I~ 89.2% RECOVERY. TOTAL TIME CORING WAS 4.47 HRS. . " ,:~:;~:~~i::.;.:;~"E BIT SIN 4508506 IS WELL WORN, BUT WOULD MAKE A REASONABLE BACKUP. .. ''¡" ~: . .' J;2f.{~~- FUTURE OPERATIONS, INNER TUBE CLAMP (GUilLOTINE CLAMP) REQUIRES " :J MODIFICATION TO IMPROVE OPERATIONS. F. Anton..n, G Heath , ( II r~ííll Job No. 148437 BAKER I Core Job Summary I II HUGHES INTEQ II Customer: Phillips Alaska Inc. Hole Size: 8 1/2" Date On: 02-MaY-01 Well: Meltwater 2P-417 Hole Angle: VERT Date Off: 11-MaY-01 Rig: Doyon #141 Last Csg Size: 9 5/8" Pmp/Lnrs: 6" X 12" Engineer: RAY SPRINGER Csg Shoe Depth: 2382' Mud Type: LSND Core DEPTH CORE BARREL Barrel Length Length % Coring Run Depth Depth Size Inner Tube Catcher Length. Cut Recover Recovery Hours ROP " No. From To Type Type Ft Ft Ft FtlHr 1 5429' 5489' 63/4" X 4" Aluminum Low Inv. Spring 60 60 60 100% 1.85 32.43 98% 2.62 22.93 ,'",.,. . "".' ."""""", , >,i "'.""'"CUMULATIVE PERFORMANCE" 120 119 99.2% 4.47 26.87 I ' " '", '"CoreheadUsagf! I .> ','.',i, ',,' CoreSERI~LNO. SIZE TYPE TFAFEETHOURS ROP CONDITION % WORN ('""i',,i' "',CUT ' FtlHr Before After, ,',., ~ni.,' . ',' ¡ 1 4508508 81/2" X 4" ARC412C3 0.77 60 1.85 32.43 0% 1% ¡ 2 4508508 8 1/2" X 4" ARC412C3 0.77 60 2.62 22.90 1% 10% ¡ 3 \ 4 1 I I I I I I I I I I I I I I ", I I - - , , ~ r&ií- BAKER HUGHES INTEQ I( Phillips Alaska Inc. Doyon #4 Meltwater 2P-417 DEARL GLADDEN F.ANTONSEN,G.HEATH Parameters Feet K.lbs KftLbs. K.lbs K.lbs r. .m. . .m. , "~>CQr.headS cificatior1$: .!-3~ r !.9 1.40 11 + l= 8 112 ::j Hughes Christensen ARC412C3 SIN 4508508 TFA .77 2.3'--, 3.7~ 4' --. 26'--' 41 --. 26'--. 41 --. 1.4'--' ( CORE BARREL ASSEMBLY #1,2 60'BBL TOP SUB L.D. SUB Complete Coring BHA Length 71.45' STABILIZER 8 7/16" OUTER BARREL 63/4" X 4" STABILIZER 8 7 /16" OUTER BARREL 63/4" X 4" STABILIZER 8 7/16" ARC412C3 r~iill BAKER HUGHES INTEQ COMPANY: PHilLIPS ALASKA ¡'I ~~ BHI Job # 148437 BAKER HUGHES INTEQ CorIng 1,2 BOTTOM HOLE ASSEMBLY BHA No: 4 Date: 10-118 -Ð1 Well Name & No.: Field: location: STA TE MELlWATER 2P-417 KUPARUK NORTH SLOPE ALASKA TYPE Serial No. 'lFA De out Bit ARC412C3 4508508 .77 0.4 5.489 1.4 Down Up Mfr' SerIal No. Gauge 00 BodyOD Fish Neck Length(ft) Total Length(ft) HT30 Pin HT30 Box BHI 8 711ft' 6314" 2.40 4.00 5.4 HT30 Pin HT30 Box BHI 6314" 26,00 31A HT30 Pin HT30 Box BHI 8 7/16" 6314" 2.40 4.00 35A HT30 Pin HT30 Box BHI 6314" 26.00 61A HT30 Pin HT30 Box BHI 8 7/16" 6314" 2.40 4.00 6SA HT30 Pin HT30 Box BHI 6314" 3,75 69.15 HT30 Pin 4 1/2" IF BOX BHI 6314" 2.30 71.45 41/2" IF PIN 4 112" IF BOX DLY 61/4" 2. 9375" 1.83 32.32 103.77 4 112" IF PIN 4" FH BOX RIG 61/4" 2.625" 1.63 105.4 4" FH PIN 4" FH BOX RIG 891.36 996.76 Dlfferen,ce: StablllzèrSlz,' Width STABILIZER 8 7/16 RWM 4 1.00 X STABILIZER 8 7/16 RWM 4 1.00 X STABILIZER 8 7/16 RWM 4 1.00 X Grade S135 4"FH In.lr Connections BeloW J.. TO CUT 120' OF CORE OVER 2 RUNS CUT 120' OF CORE. RECOVERED 119' OF CORE FULL BARREL . r&ii8 ( BAKER HUGHES . INTEQ COMPANY Phillips Alaska Inc. RIG: Doyon # 141 ~LL No.: Meltwater 2P-417 . DATE: 10-May-01 EQUIPMENT . BARREL SIZE: LENGTH (ft): INNER TUBE TYPE: L.SHOElCATCHER: 63/4" X 4" X 60' 60 ALUMINUM LOW INVASION SPRING I . . COREHEAD CONDITION: IR OR 0 0 1 1 BIT CONDITION AT RUN START: BIT CONDITION A TRUN ,END: BACKGROUND PARAMETERS "...'.', t,'" I I "OF, FBTMSTRINGWTS UP,(Klbs) 119 , "f'C'\ RotÄTIN~~Klbs) 119 '.' DOWN (Klbs) ",' 116 ," " TORQUE kit-l" ",' , BALL VALVE;, PRESS INC. OFFBO.TTOtJ , "I 5 FLoWRATEI 350 ONBOTTOM " 10 to 15 PRESSURE INCREAse 1 210 '", PRESSURE. BALL SEATED , " GPM FLOwaAT'E 350 IGPM PSI OFFaoTTOM " 1400 I,' 'PSI ONBO'TTOM 1440 I Psi I I ,,' " MUD,PROPERTlES :"MUD">li""",, TYPE,.""""'" '," >' KCL Coring Fluid 65 I Vise I TIMINGS , "","', " :{:',\i:'::;..'".,,"'. "",',' PICKUP ')'ii,' "", ,,' ",1'..',,','., ,,' ',i ,BåL,' ~!f~RT: . ,1,1 , (24HOU~r "'" ',""'.,' : START IN ' "",." HOLE . 00:00 I I 18 I - 8 - - ~Tnp."" ,;:>i'. ,,'" ,'. .:-',:"'" "'" 02:00 2:00 I ICORE#: DEPTH IN: DEPTH OUT: HOLE SIZE: HOLE ANGLE: CORÈ RUN LOG ( Sales Order #: I 148437 I CD 5429' 5489' 8 112" ODEG. FORMATION: DESCRIPTION: FTG. THIS RUN: PREV. FOOTAGE: BERMUDA SAND 601 0 TOTALFT: I 60 COREHEAD/BIT # : ARC412C3 SERIAL No:: 4508506 SIZE: 8 112" X 4" DAFD TOOL: NO INNER TUBESTABILlZER : YES DC NO NO 10 % WEAR 11 % WEAR LOC A A SURF TEMP 50 DH TEMP. 112 SPACING 0.75 CORE JAM INDICATOR: INO BIT END'BEARING: NO BlS x x G/16 0 0 oc NO NO RPLD INTERVA:I.. ",' , ,"".',' ".,', CONNECTIONS: "I NO CONNECTION Cõnoectiøn I .,.1./1"2 ,,'," "".1. '."""""".3,< """.""'",1 4, "'I" ~~b; I ".",.'. PERFORMANCE I 1,1i.':.i: ,,",i~"": ,:.', - Depth Out ,:'-,)':"";"'!::.:'" '.'..,-:' "" WT pv. "', yp I GEL WL ,,), % SAND, %H20101L ,', ,. ',' 7/14 3 TR 0/90 DAY OF START ",' '.GORINß&:' ~'CIRÇU~T~ CØNNS. ", " P.O.D.H. ,,', ,,", "," ,', """,'.., ',".' ,',' "'LAYDOWN, 'i, "', CORE ,"" ,', 05:50 07:40 14:00 07:40 14:00 15:00 1:50 6:20 1:00 5 "I "",61 I '1 """',18 ,', "'.""'" . 10.2 25 27 5489 "'A;!~-::~.i, ,.,COring' ',>cnl. .~~T~~ :""", FeetReœvered ",",:","", """%,.",i",,' ",,"',.,','......'.,.,. i.)..,,/,?'\, HøurS "',:<, "",,>«, .' ,',/ "i:'. ',",'. ",,'i' 60 1.85 32.43 60 5429 EFFICIENCY: ",,', 100% SPARE PARTS 'USED: "."'" ,', I 2 1 1 1 40 40 2 1 RAY SPRINGER Customer Representative: . ,,"", . DaPR '~L.t 02:00 05:30 05:30 05:50 0:20 2:30 IREASONFORSTOPPIN(;CORING: "," ,',' :1 FULL BARREL 100% ALUMINUM LOWER SHOES BEARING CATCHER CAPS CLAMPS INNER,BBL. STABS. UPPER SHOE BH INTEQ Representative: 'I F. ANTONSEN 1 G. HEATH II r~íi. Sa les Order #: 1 148437 BAKER ( , CORE RUN LOG ( I HUGHES I NTEQ ICORE #: CD OMPANY Phillips Alaska Inc. DEPTH IN: 5489' FORMATION: BERMUDA m: Doyon #141 DEPTH OUT: 5549' DESCRIPTION: SAND ,ŒLL No. : Meltwater 2P-417 HOLE SIZE: 8 1/2" FTG. THIS RUN: 60 ATE: 1 O-Mav-Q 1 HOLE ANGLE: ODEG. PREVo FOOTAGE: 60 TOTAL FT: I 120 EQUIPMENT I LA.RREL SIZE: 6 3/4" X 4" X 60' COREHEADIBIT # : ARC412C3 SURF TEMP 50 ENGTH (ft): 60 SERIAL No. : 4508506 DH TEMP. 112 liNER TUBE lYPE: ALUMINUM SIZE: 8 1/2 X 4 SPACING 0.75 ISHOE/CATCHER: LOW INVASION SPRING DAFD TOOL: NO CORE JAM INDICATOR: INO I OREHEAD CONDI110N: INNER TUBE STABILIZER: YES BIT END BEARING: NO IR OR DC LOC BIS G/16 OC RPLD I 1 1 NO A X 0 NO 1 1 CT N X 0 NO IT CONDITION AT RUN START: 1 % WEAR BIT CONDITION AT RUN END: 10% WEAR II BACKGROUND PARAMETERS t OFF 81M STRING wrs TORQUE kft-lba BALL VALVE; PRESS INC. PRESSURE-BALL SEATED UP (Klbs) 120 OFF BOTTOM " 5 FLOWRATE 350 GPM FLOWRATE 350 GPM II~ ROTATING (Klbs) 119 ON BOTTOM 8 TO 20 PRESSURE INCREASE 1 240 PSI OFFBOTTOM 1400 PSI DOWN (Klbs) 114 ON BOTTOM 1470 PSI I , , 'UD PROPERTIES VISC WT YP MUD PV GEL WL % SAND %H20/01L I,TYPE "'" IL Corino Fluid 65 10.2 25 27 7/14 3 TR 0190 , MINGS '24 HOUR) ,",','" ,,' "",>" DAY OF START F PICKUP START IN , DROP""" CORING & P.O;O.H. LAY DOWN 'TART: INNERBBL HOLE "" """",'BALL " CONNS. SERVICE BBL STD BCK BBL ,," "",,' 15:00 02:00 20:15 20:30 23:15 05:00 TOP: 16:30 20:15 20:30 23:15 05:00 07:30 INTERVAL 1.5 18:15 0:15 2:45 5:45 2:30 ~NNECTlONS: INO CONNECTION nnedion 'I 1 2 J ," 3 ",.,,1 4 1 5 1 6 1 7 8 I Deoth 1 PERFORMANCE I , Depth in Depth Out Feet Cut '/ Cqring ,'",. ROPFT/HR Feet Recovered " %, Recovered , . HoùÌ"S .,'. 5489 5549 60 2.62 22.93 59 98.3 % FFICIENCY: 98% I REASON FOR STOPPING CORING: 1 FULL BARREL PARE PARTS USED: 2 ALUMINUM 1 LOWER SHOES 1 CATCHER 40 CAPS 40 CLAMPS 2 INNER BBL. STABS. r 4 CUTTER WHEELS I:ustomer Representative: 1 UPPER SHOE RAY SPRINGER BH INTEQ Representative: F. ANTONSEN IG. HEATH . I I I I . . I I I I I - - ""I , ~ 11_',.,;,"','""" . II - þ ( (" Rit. 8AKIR CORING PARAMETERS LOG - BHIJOB.: I NTF.Q 14M37 COMPANY: Phlll1a8 A-a Inc. CORE BARRel SIZE : 8 314" X ." X 80' DATE : 1o.118v-01 CORE ENCMEEJt IM:LL No. : ...~ 2P-I17 BlTSIZE&TYPE : ' 112" X." ARC412C3 CORE No: 1 FRED ANTONSEN RIG No, : Dovon ~.1 CORE INTERVAL : 5429'-ð48t' REC,% : 100% OI.BQI HEATH DEPTH NO. R,O,P PENETRATION RATE. FTMR OPERATING CONDITIONS FORMATION FT. CORED. MnIFt A/Hra W.O.S RP.M F.RATE PRESS. TORQUE TYPE KLba GPM P8 KR-Lbs ! !!! !!! 5429 0 5 50 350 1430 7 Bermuda 5430 1 2,00 30,0 5 50 350 1430 8 5431 2 4.00 15,0 5 55 350 1430 15 5432 3 4.00 15,0 7 55 350 1430 8 5433 4 4.00 15,0 7 70 350 1430 8 5434 5 2,00 30,0 7 70 350 1430 10 5435 6 2.00 30.0 8 70 350 1430 10 5436 7 2.00 30.0 9 70 350 1430 10 5437 8 2.00 30,0 9 70 350 1430 11 5438 9 2.00 30.0 9 70 350 1430 15 5439 10 4.00 15.0 9 70 350 1430 11 5440 11 6.00 10,0 10 70 350 1430 11 5441 12 2.00 30,0 10 70 350 1430 11 5442 13 2.00 30,0 10 70 350 1430 15 5443 14 3,00 20.0 10 80 350 1430 15 5444 15 2.00 30.0 10 80 350 1430 15 5445 16 2.00 30.0 10 80 350 1430 10 5446 17 2.00 30,0 10 80 350 1430 10 5447 18 1,00 60.0 10 80 350 1430 15 5448 19 2.00 30.0 10 80 350 1430 15 5449 20 2.00 30.0 10 80 350 1430 15 5450 21 2.00 30.0 10 80 350 1430 15 5451 22 2.00 30.0 10 80 350 1430 10 S452 23 2,00 30.0 10 80 350 1430 10 5453 24 1.00 60.0 12 80 350 1430 10 5454 25 2.00 30.0 12 80 350 1430 12 5455 26 1.00 60,0 12 80 350 1430 12 5456 27 1,00 60,0 12 80 350 1430 12 5457 28 1.00 60.0 12 80 350 1430, 12 5458 29 2.00 30.0 12 80 350 1430 8 5459 30 2.00 30.0 12 80 350 1430 8 5460 31 2.00 30,0 12 80 350 1430 8 5461 32 1.00 60.0 12 80 350 1430 12 5462 33 1.00 60.0 12 80 350 1430 12 5463 34 1.00 60.0 12 80 350 1430 12 5464 35 1.00 60.0 12 80 350 1430 12 5465 36 2.00 30.0 12 80 350 1430 15 5466 37 2.00 30,0 12 80 350 1430 15 5467 38 2,00 30,0 12 80 350 1430 15 5468 39 1.00 60.0 12 80 350 1430 15 5469 40 2.00 30.0 12 80 350 1430 8 5470 41 1.00 60.0 12 80 350 1430 8 5471 42 1.00 60.0 12 80 350 1430, 8 5472 43 3.00 20.0 12 80 350 1430 10 5473 44 2,00 30.0 12 80 350 1430 10 5474 45 1.00 60.0 12 80 350 1430 15 5475 46 2.00 30.0 12 80 350 1430 15 5476 47 1.00 60.0 12 80 350 1430 12 5477 48 2.00 30.0 12 80 350 1430 12 5478 49 2.00 30.0 12 80 350 1430 15 5479 50 1.00 60.0 12 80 350 1430 15 5480 51 1,00 60.0 12 80 350 1430 15 5481 52 2,00 30.0 12 80 350 1430 15 5482 53 1,00 60.0 12 80 350 1430 15 5483 54 1.00 60.0 12 80 350 1430 15 5484 55 1.00 60.0 12 80 350 1430 15 5485 66 1.00 60,0 12 80 350 1430 15 5486 57 2,00 30,0 12 80 350 1430 15 5487 58 1.00 60.0 12 80 350 1430 15 5488 59 1.00 60.0 12 80 350 1430 15 5489 60 1.00 60.0 12 80 350 1430 15 TOTAL TIME 111.0 I ( I Ria. 8ADR CORI NO PARAMETERS LOG I HUGI8 BHI JOB': INTF.Q 148437 COMPANY: Phllllpa Alan Inc. CORE BARREL SIZE : 8 3148 X 48 X 80' DATE : 1o.M8v-41 CORE ENGINEER \/\ELL No, : MeItw8t8r 2P-417 BlTSIZE&TYPE : 8 112" X 48 ARC412C3 CORE No: 2 FRED ANTONSEN RIG No, : Dovon 1t141 CORE INTERVAL : 5489'~5W 80' REC, '!Eo : 100% GLENN HEATH - DEPTH NO, RO.P PENETRATION RATE, FTJHR. OPERATING CONDmONS FORMATION FT, CORED. MnIFt Rn-ira W.O,S RP,M F.RATE PRESS, TORQUE TYPE KLbs GPM PIli KR-Lba 1 1!! ~ 5489 0 5 50 350 1470 5 Bermuda 5490 1 2,00 30.0 7 50 350 1470 5 5491 2 2.00 30,0 8 70 350 1470 5 5492 3 4.00 15,0 10 70 350 1470 7 5493 4 4.00 15.0 12 80 350 1470 7 5494 5 3,00 20.0 16 90 350 1470 5 5495 6 5,00 12.0 16 90 350 1470 5 5496 7 4,00 15,0 16 90 350 1470 10 5497 8 4.00 15.0 16 90 350 1470 10 5498 9 4.00 15,0 16 90 350 1470 15 5499 10 1,00 60.0 16 90 350 1470 15 5500 11 2,00 30.0 16 90 350 1470 15 5501 12 1,00 60.0 16 90 350 1470 12 5502 13 2.00 30.0 16 90 350 1470 12 5503 14 2.00 30.0 16 90 350 1470 12 5504 15 2.00 30,0 18 90 350 1470 8 5505 16 2.00 30.0 18 90 350 1470 8 5506 17 5.00 12.0 18 90 350 1470 10 5507 18 7.00 8,6 18 90 350 1470 10 5508 19 4.00 15.0 18 90 350 1470 10 5509 20 2,00 30.0 18 90 350 1470 8 5510 21 2.00 30.0 18 90 350 1470 8 5511 22 2.00 30.0 18 90 350 1470 8 5512 23 2.00 30,0 18 90 350 1470 8 5513 24 4.00 15.0 18 90 350 1470 15 5514 25 2.00 30.0 18 90 350 1470 15 5515 28 2.00 30.0 18 90 350 1470 15 5516 27 2.00 30,0 18 90 350 1470 15 5517 28 2.00 30.0 18 90 350 1470 15 5518 29 2.00 30.0 18 90 350 1470 15 5519 30 2.00 30.0 18 90 350 1470 15 5520 31 4.00 15,0 18 90 350 1470 8 5521 32 3,00 20.0 18 90 350 1470 15 5522 33 2.00 , 30.0 18 90 350 1470 15 5523 34 4,00 15.0 18 90 350 1470 8 5524 35 5,00 12.0 18 90 350 1470 10 5525 36 4.00 15.0 16 90 350 1470 10 5526 37 2,00 30.0 18 90 350 1470 10 5527 38 3,00 20.0 18 90 350 1470 10 5528 39 3,00 20.0 18 90 350 1470 10 5529 40 2,00 30.0 18 90 350 1470 10 5530 41 2.00 30,0 18 90 350 1470 10 5531 42 2.00 30.0 18 90 350 1470 10 5532 43 3.00 20.0 18 90 350 1470 10 5533 44 2,00 30,0 18 90 350 1470 10 5534 45 3.00 20.0 18 90 350 1470 10 5535 016 1,00 60,0 18 90 350 1470 10 5536 47 2.00 30.0 18 90 350 1470 15 5537 48 2.00 30.0 18 90 350 1470 15 5538 49 2,00 30.0 18 90 350 1470 15 5539 50 2,00 30.0 18 90 350 1470 15 5540 51 1.00 60,0 18 90 350 1470 12 5541 52 2,00 30.0 18 90 350 1470 12 5542 53 2,00 30,0 18 90 350 1470 12 5543 54 3.00 20,0 18 90 350 1470 12 5544 55 3,00 20.0 18 90 350 1470 20 5545 56 2,00 30,0 18 90 350 1470 20 5548 57 2.00 30.0 18 90 350 1470 20 5547 58 2.00 30,0 18 90 350 1470 20 5548 59 2.00 30.0 18 90 350 1470 20 5549 60 1.00 60.0 18 90 350 1470 20 TOTAL TIME 157.0 I I - . M I - II - - ~ - <. - - II Date 12/11/01 12/12/01 12/13/01 12/14/01 12/15/01 12/16/01 12/19/01 ( ( 2P-417 Event History Comment JETTED OUT FLUIDSNISC. BRINE TO HARD TAG AT 56651 CTM W/ A 1.751 VORTECH DOWN-JET NOZZLE; UNABLE TO MAKE ANY MORE HOLE. TBG. FREEZE PROTECTED TO 2500'+ W/ DIESEL. [FCO, VORTECH] TAGGED FILL @ 5687' RKB.INSTALLED SPARTEK SIDEPOCKET GAUGE @ 5179' RKB. PT IA TO 3000#. GOOD. [TAG, PRESSURE DATA] 1ST RIH : LOGGED JEWELRY WITH TEMP/PRESSURE - TAGGED TD AT 5684 FT MD. 2ND RIH: SHOT 3.38" HSD @ 6 SPF - 3406 POWERJET CHARGES: INTERVAL = 5495-5515 FT MD 3RD RIH: LOGGED TIE IN PASS PLUS SBHP STATIONS AT 5505 FT MD AND 5179 FT MD. NOTE THAT THE WHP HA PUMPED INITIAL FRACTURE TREATMENT. TREATED WITH 30# LOW GUAR SYSTEM, 40 BPM. AVERAGE TREATING PRESSURE = PLACED 213M# 16/20 CARBOLlTE BEHIND PIPE, 12 PPA ON PERFS. HAD NWBSO, LEFT 30M# IN WELLBORE. 71 % OF DESIGN PLACED. CLEANED OUT FILL TO 56671 CTM W/ 2.25" JET-SWIRL NOZZLE USING SEAWATER J313 AND DIESEL GEL. WELL FREEZE PROTECTED W/ DIESEL TO 2500'. NOTE: NO CRUDE RETURNED. TEST OF FLOWBANK TANKS INDICATE RA TRACER PRESENT IN SOLIDS; ONE TANK AT 2.0 MR/HR, OTHER AT 0 TAGGED FILL @ 55161 RKB. EST.11 RATHOLE. PULLED SPARTEK & INSTALLED OV @ 5179' RKB. [GLV, TAG, PRESSURE DATA] FLOWING LOG, DOWN & UP FROM 5000' WLM TO 5511' WLM [PRESSURE DATA] Page 1 of 1 1/3/2002 Re: 2P-417 Disposal ( ( .)0\- 0 Co~ Subject: Re: 2P-417 Disposal Date: Thu, 20 Dec 2001 09:57:09 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Thomas A Brockway <tbrockw@ppco.com> CC: Cammy Oechsli <Cammy_Oechsli@admin.state.ak.us>, Daniel T Seamount JR <dan_seamount@admin.state.ak.us>, Julie Heusser <julìe_heusser@admin.state.ak.us> Tom, Thanks for the note. I have checked how the regulation is worded with the Commissioners. Our position on the issue is that the 90 days does not have to be a continuous period within the 1 year approval window. In most cases once disposal starts in a well, I believe the available disposal volume is pretty well "used" in a continuous period of less than 90 days. We are aware of the drilling pause on Meltwater due to the green gravel. By copy of this emaH, you have approval to resume disposal into the annulus of 2P-417 subject to the usual volume, time and absence of any problems. Good luck. Tom Maunder, PE AOGCC Thomas A Brockway wrote: > Tom, > > PAl would like to resume annular disposal operations early next week on > we1l2P-417 (permit #301-136, expiration date 6/1/2002), but prior to doing > $0 I would like to get clarification on the 90 day operating limit. This > well was used to di$pose of fluid on 2 occasions earlier this year, with > the first occurrence on 9/4/01 (620 bbls of effluent during the Meltwater > shutdown) and the second on 10/17/01(490 bbls of drilling related fluids). > > Is the 90 day clock for these permits considered to be a continuous time > period from the date of first disposal of any kind (9/4/01), a continuous > period from the date of first disposal of drilling related fluids > (10/17/01), or is it considered to be 90 days of actual operating time > which can be split up over the year life of the permit. > > Thanks for the help. > > Tom Brockway > Lead Drilling Engineer > Phillips Alaska, Inc. > Ph: (907) 263..4135 > Cell: (907) 244-5956 > Fax: (907) 265-1535 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1of2 12/20101 9:57 AM ( ( PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY P.O, BOX 100360 ANCHORAGE, ALASKA 99510-0360 SAMPLE TRANSMITTAL RECE\\IEO DEC 1 0 200\ ()\\&GaSeons.~ ,.;a A~ TO: AOGCC 333 WEST 7TH AVE. ANCHORAGE, AK. 279-1433 DATE: DECEMBER 10, 2001 AIR BILL: AL5131155 AFT: 01-12-10-01/02 CHARGE CODE: 51268 OPERATOR: PAl NAME: 2P415 & 2P417 API NO: NUMBER OF BOXES: 10 SAMPLE TYPE: DRIES SAMPLES SENT: MELTWATER 2p.415 MELTWATER 2p.417 300'.11075'* 93'.5993'* ;;to J-àb1. s~St~~(j S-cy *SAMPLES SENT AS RECEIVED FROM MUDLOGGERS SENT BY: D. L. PRZYWOJSKI UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED: CC: PHILLIPS BAYVIEW GEOLOGICAL FACILITY 619 EAST SHIP CREEK AVE SUITE 102 ANCHORAGE, AK. 99510 ~ ()~ ATTN: DAN PRZYWOJSKI ABV100 S. MOOTHART AOGCC S~~ -4 J.J:{ )11)0" !>-'{:1 C{ )'-t.t'-iù - ~''-L'{..C( ~- r.t ~'{} - ~~ ~q \rV~ó - r't~'l J-q 1ò - 1>-q,,{,-q JY/8~ - >-'Ù ~ ~v'{,'\;ù - rt.{,~ Tfn~û - þ-ra,q )~'-'LU - ~~=~q >~---}.ú ,-- ~ \j JSf. S--~- J ()- ~~-1. 't )' ~f.t» - t þ~'t7 e VL¿ :z b l ~ ~~ <\ /{/I- c" Î i( i ( Transmittal Form f'í. BAKER. HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: ,.. U Sq vJe..t:p ì e. " JI. Reference: MW 2P-417 - Kuparuk River Meltwater, North Slope, Alaska Contains the following: RECEIVED 1 - Multiple Propagation Resistivity, Neutron, ,Density, GR-RW A (1 :600) Measured Depth & TVDPrint 1 - Multiple Propagation Resistivity, N eutron,Density, GR-RW A (1 :240) Meast~red Depth&: TVIl.Priht 1 - Multiple Propagation Resistivity, GR;;RWD Print (1:600) Measured Ðepth &,TVDPrínt I-Multí:pléPro¡Jagation Re~istivity;(jR-RWD Print (1:240) Measured Depth &'f'VDPrint 1 - 8epiaFiltnforeachprocyss OCT 2 6 lOa'! A\aska Oil & Gas COilS. Commlssimlì Anchorage Sent By: Josef Berg ReceiVedBY:~ ~ Date: Oct 23,2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORA nON (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave, S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 ~~ iJï:M' ,~':i1 i.¡1 ~ n.; Schlumbepger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job# Log Description Date LEAK DETECTION LOG 05/16/01 LEAK DETECTION LOG 05/18/01 LEAK DETECTION LOG 05/17/01 TEMP/PRESS/DENSITY SURVEY 05/19/01 TEMP/PRESS/DENSITY SURVEY 05/19/01 LEAK DETECTION LOG 05/14/01 PRESSURE SURVEY 05/11/01 21224 SCMT 04/24/01 21223 USIT 04/23/01 21243 FRACADE ADVISOR 05/12/01 ~~. S'GNEDð~ ~ -- 5/30/2001 NO. 1178 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Sepia Color Print 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -- ffEGETVED DATE: JUri£112001 Alaska Oil & Gas ConS. Commiaeion Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Anchorage 5/23/2001 Schlumbel'ger NO. 1155 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie 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 Sepia Color Print -- .~. 1D-39 aœ-.-:Jlto 21221 SCMT 04/12/01 . 1 2P-417d()J-Ù/A 21242 PROCESSED DSI 05/12/01 1 . . ---_ ! n ........ '"' "' t::.' t:.IVr::U SIGN~ ~ (1Q,~ DATE: Jun 0 1 2001 Alaska Oil & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank YOMchOr89! ( ~V~VŒ (ill~ ~~~~[{~ A.1{A.~1iA. OIL AND GAS CONSERVATION COMMISSION Mr. James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Application for Sundry Approval Meltwater 2P-417 Annular Disposal Request Dear Mr. Trantham: June 1,2001 ( d,or-o ~c¡ TONY KNOWLES, GOVERNOR 333 w. "JTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 The Alaska Oil and Gas Conservation Commission has reviewed the Phillips Alaska, Inc. application to conduct annular disposal operations on Meltwater well 2P-417. Shallow well log data is scarce in this portion of the North Slope and our analysis is based on the limited evidence of Total Dissolved Solids (TDS) of formation water from other area wells: Kalubik 1, Colville River State 1, Cirque 2 and Tarn 2N- 349. Using this limited TDS information, the formation water at and immediately below the casing shoe in Meltwater 2P-417 has been estimated at a TDS greater than 3000 ppm but below 10,000 ppm. Approval of Phillip's request to conduct annular disposal operations on, Meltwater well 2P-417 is granted, however, approval of future annular disposal requests will be contingent upon providing well log or water sample analysis to support the preliminary assessment of TDS greater than 3000 ppm but less than 10,000 ppm. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of Meltwater 2P-417 must comply with the requirements and limitations of 20, AAC 25.080. Approval of this sundry does not authorize disposal of drilling waste in a volume greater than 35,000 baITels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Sincerely, ~M,~ Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this I ~ day of June, 2001. ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,AJaska 9951CHD360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 May 21,2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval - 2P-417 Application for Annular Disposal Dear Ms. Commissioner: As per AOGCC regulations 20AAC25.080, Phillips Alaska, Inc. is submitting this Application for Sundry Approval for annular disposal in the Meltwater well 2P-417. Also submitted with this application are attachments to meet the requirements for annular disposal as stipulated by AOGCC. If you have any questions regarding this matter, please contact me at 265-6434 or Pat Reilly at 265-6048. Sincerely, Ja~~ \ JQ~VUA-~ J. Trantham Drilling Engineering Supervisor PAl Drilling RECE\VEO MA'< 2 3 200' Commission 0'\ & Gas Cons. A\aska' Anchorage JT /skad ORfGJNÞ~L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Description summary of proposal- Detailed operations program - BOP sketch- Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic - X 14. Estimated date for commencing operation, 15. Status of well classification as: May 24, 2001 16. If proposal was verbally approved ( 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 891' FNL, 2061' FWL, Sec. 17, T8N, R7E, UM At top of productive interval 877' FNL, 2252' FWL, Sec. 17, T8N, R7E, UM At effective depth At total depth 877' FNL, 2252' FWL, Sec. 17, T8N, R7E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 6008' 5988' 5905' 5893' measu red true vertical Casing Conductor Surface Production Liner Length 80' 2358' 5278' Size 16" 9.625" rx4.5" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth 4.5", 12.6#, L-80 @ 5302' Packers & SSSV (type & measured depth) No packer, No SSSV 13. Attachments Operational shutdown - Plugging - Pull tubing 5. Type of Well: Development _X Exploratory - Stratigraphic - Service (ASP's: 444021, 5868986) (as proposed) feet feet Plugs (measured) feet feet Cemented Junk (measured) 9 cu yds High Early ::JIjU sx A~::J Lite & 1 ~U sx I it",r.~u=n= 420 sx Class G Oil_X ~ Name of approver Date approved Service - 17. I fì by certify that the foregoing is true and correct to the best of my knowledge. Title: Drilling Engineering Supervisor (' ~ c.~ Re-enter suspended well - Time extension - Stimulate - Variance Per10rate 6. Datum elevation (OF or KB feet) RKB 80 feet 7. Unit or Property name Other _X Annular Disposal Kuparuk River Unit 8. Well number 2P-417 9. Permit number / approval number 201-069 10. API number 50-1 03-20375-00 11. Field I Pool Kuparuk River Field / Meltwater Pool Measured Depth 108' 2382' 5302' 6002' True vertical Depth 108' 2380' 5290' 5982' RECEIVED MAY 2 3 Z001 Alaska Oil & Gas Cons. Commission Anchorage Gas- Suspended - Questions? Pat Reilly 265-6048 Date Sß3frl FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. 3 l- \ 3(0 Plug integrity -- BOP Test - Location clearance - t 0 Mechanical Integrity Test - Subsequent form required 1 0- ~O\ (.t.""\1 'o~ '''~~ \. \, ORIGINAl. SIGNED BY ( A 0 \ i) A roved b order of the Commission Commissioner Date VJ'" '\ Form 10-403 Rev 06/15/88 . nr:?!Cl,~r\f '\ I ""~' l \ ! tJ r [: \~ F\ L.". SUBMIT IN TRIPLICATE ( ( Annulus Disposal Transmittal Fòrm a. Designation of the well or wells to receive drilling wastes; b. The depth to the base of freshwater aquifers and permafrost, if present; c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater; d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste; e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry; f. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission to confirm containment of drilling wastes. 2P-417 No Aquifers;Bpf=1455 tvd - RKB From the 9-5/8" shoe to the Cement top, all that is open is interbedded claystone and siltstone with occasional tuffaceous ash beds See Attached Map indicating no wells within 1/4 miles or water wells within 1 mile. The map (traveling cylindar plot) shows two wells in the area of 2P-417. Both wells are beyond 1/4 mi. at the surface shoe depth of 2381 TVD. Types of fluids can be mud, diesel, cement, water, drilling rig domestic waste water. Maximum volume to be pumped is 35,000 bbls Maximum anticipated pressure at casing shoe during disposal operations is 2082 psi. See attached calculation page attached cementing reports, LOT/FIT reports, and casing reports attached: casing summary sheet and calculation pages. ( Casing Detail 95/8" surface casing (' PHilLIPS Alaska, Inc. WELL: 2P-41 7 DATE: 4/28/01 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LDS = 2880' TOPS Above Rotary 6.70' 95/8" Landing Joint (35.20 total) RKB tc 28.80 95/8" FMC GEN IV FLUTED MANDREL HANGER 2.14 28.80 30.94 30.94 jts 3-59 95/8", 40# L-80 BTCM 2272.01 30.94 Gemeco Float Collar 1.65 2302.95 jts 1 -2 95/8", 40# L-80 BTCM 75.36 2304.60 Gemeco Float Shoe 1.75 2379.96 81M OF SHOE @-----»»> 2381.71 TD 12 1/411 HolE 2430' Csg Hanger goes in the top of Joint # 59 26 TOTAL, Gemeco Bow Spring Centralizers - 3 Stop Rings 3- Centralizers in center of jts.l , 2 & 3 over stop rings 23 - Centralizers over collars of jts,4-12, 15, 18, 21, 24, 27, 30, 33 36,39,42,45,48,51,54 ** Fill using "Franks" fill tool - Remove tool on Joint before Hanger ** Baker Lok all connections from the Top of FC down ** Monitor returns closely ** Remove air from slips for first 1 0 jts ## Torque first 10 and average-Torque to A VG - Watch Diamond Remarks: String Weights with Blocks: 7 75k Up, 7 79k On, 39k TO & Blocks. Ran 59 joints of casing. Drifted casing with 8.599" plastic rabbit. Used Best-a-Life 2000 thread compound on all connections. Doyon 747 Drilling Supervisor: Dearl W. Gladden (' ( PHILLIPS ALASKA INC. Cementing Report Page 1 of 3 Legal Well Name: 2P-417 Common Well Name: 2P-417 Event Name: ROT - DRILLING Report #: Start: 1 4/19/2001 Spud Date: 4/27/2001 Report Date: 5/1/2001 End: Cement Job Type: Primary Prima Plu Hole Size: TM 0 Set: Date Set: Csg Type: Csg Size: 12.250 (in) 2,382 (ft) 5/1/2001 Surface Casing 9.625 (in.) Hole Size: SO TMD: (ft) SO Date: SO Type: Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Cmtd. Csg: Cementer: Steve Doughten Pipe Movement: Reciprocating PlpeMovement Type: Cement Casing Start Mix Cmt: Disp Avg Rate: (bbllmin) Returns: Volume Excess %: Start Slurry Displ: Disp Max Rate: (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: Bump Plug: N Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: Press Prior: (psi) To Cementing: End Pump Date: Press Bumped: (psi) Ann Flow After: N Mud Circ Rate: (gpm) Top Plug: N Press Held: (min) Mixing Method: Mud Circ Press: (psi) Bottom Plug: N Float Held: N Density Meas By: Mud Data Type: Polymer Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: CF) Displacement Fluid Type: PVIYP: (cp)/ (lb/100ft2) Gels 10 sec: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Stage No: 1 Slurry No: 10f 4 Slurry Data Fluid Type: FLUSH Slurry Interval: 2,382.00 (ft)To: (ft) Water Source: Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Class: Density: 8.40 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Temp (OF) (OF) Pressure (psi) (psi) Temperature: CF) Temperature: (OF) Temperature: CF) Compressive Strength 1: Compressive Strength 2: CF) Printed: 5/9/2001 8:48:45 AM {' II' ( PHILLIPS ALASKA INC. Cementing Report Page 2 of 3 Legal Well Name: 2P-417 Common Well Name: 2P-417 Event Name: ROT - DRILLING Report #: Start: Spud Date: 4/27/2001 Report Date: 5/1/2001 End: 1 4/19/2001 Stage No: 1 Slurry No: 2 of 4 Slurry Data Fluid Type: PRIMARY Slurry Interval: 1,445.00 (ft)To: (ft) Water Source: Test Data Thickening Time: 3.33 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: AS3 Lite Cmt Vol: 301.0 (bbl) Slurry Vol: 380 (sk) Class: G Density: 10.70 (ppg) Yield: 4,44 (ft3/sk) Water Vol: 187.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Time Temp rF) (OF) Pressure (psi) (psi) Temperature: 80 rF) Temperature: (OF) Temperature: rF) Compressive Strength 1: Compressive Strength 2: (OF) 0124 0053 S001 0046 0079 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Concentration Stage No: 1 Slurry No: 3 of 4 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Time Temp rF) rF) Pressure (psi) (psi) Temperature: (OF) Temperature: (OF) Temperature: (OF) Compressive Strength 1: Compressive Strength 2: (OF) _..-. ---..-...- --- Stage No: 1 Slurry No: 4 of 4 ----_0 ---- Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 2,382.00 (ft)To: 1,475.00 (ft) Cmt Vol: 81,0 (bbl) Water Source: Slurry Vol: 190 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Class: G Density: 12.00 (ppg) Yield: 2.39 (ft3/sk) Water Vol: 37.0 (bbl) Other Vol: 0 Purpose: TAIL Mix Water: (bbl) Foam Job: N Time Temp (OF) (OF) Pressure (psi) (psi) Temperature: (OF) Temperature: rF) Temperature: rF) Compressive Strength 1: Compressive Strength 2: (OF) Printed: 5/9/2001 8:48:45 AM ( ( PHILLIPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: 2P-417 Common Well Name: 2P-417 Event Name: ROT - DRILLING Report #: Start: 1 4/19/2001 Spud Date: 4/27/2001 Report Date: 5/1/2001 End: Stage No: 1 Slurry No: 4 of 4 - Additives Trade Name T Concentration Units Li uid Conc, Units 0065 1.0 % 0079 0.1 % 0046 0.2 % Casing Test Shoe Test Liner Top Test Test Press: 2,500 (psi) Pressure: 16.00 (ppge) Liner Lap: For: 30 (min) Tool: N Pos Test: (ppge) Tool: N Cement Found between Open Hole: 20 (ft) Neg Test: (ppge) Tool: N Shoe and Collar: N Hrs Before Test: 1.50 Hrs Before Test: Cement Found on Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) N Printed: 5/9/2001 8:48:45 AM CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P-417 Date: 5/2101 Supervisor: Dearl W. Gladden Reason(s) for test: 0 Initial Casing Shoe Test D Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/811 40# L-80 BTC M Casing Setting Depth: 2,382' TMD Hole Depth: 2,432' TMD 2,381' TVD 2,430' TVD Mud Weight: 9.7 ppg Length of Open Hole Section: 50' EMW= Leak-off Press. + Mud Weight = 801 psi + 9.7 ppg 0.052 x TVD 0.052 x 2,430' EMW for open hole section = 16.0 ppg Fluid Pumped = 0.9 bbl Pump output = 0.1010 bps 2.800 psi 2.700 psi 2.600 psi 2.500 psi 2.400 psi 2.300 psi 2.200 psi 2.100 psi 2.000 psi 1.900 psi 1.800 psi 1. 700 psi w 1.600 psi g 1.500 ps~ ~ 1.400 ps~ w 1.300 pSI g: 1. 200 psi 1.1 00 psi 1.000 psi 900 psi BOO psi 700 psi (jJJ psi 500 psi 400 psi 30J psi 200 psi 100 psi Opsi T I -,... I I I ;1ME LlNEm< 1- ~ i,..,i-1_k~.""L=,,,,,,",L,",,L / ONE ;.", >v /-_.u>-_.. 1111 I ¡ . i .- I. -- ,- , , '-l-_=r~1: -J -e-LEAK-OFF TEST - - : ""'CASING TEST - /l...N;;>.. LOT SHUT IN TIME - - J -:Á- CASING TEST SHUT IN TIME - , I I. II ~ '" 1\ jJ ¡I ø - - r-.;J "" '" ú,) -....I ---" 01 -0 c.> c.> ... b  01 01 ~ ~ ~ -....I -....I ~ -0 ú,) ~ ---" 01 -0 ~ ~ ~ ~ ~ ~ :g § ~ ~ ---" ---' ---" ---" - --' 1'0 "" (.0) ......, .- 01 STROKES NOTE: STROKES TURN TO MINUTES DURING IISHUT IN TIMEII:see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE C~~~~~~~~~~~~~I~~~~~~!~~~~~I~~~~Q~ë~I~~J L_______n__---_L__~_~~_~~___L___~~J~~!_---j ¡ ¡ 4 stks ¡ 260 psi ¡ '- ----- _n -- - n__-'- - ----- n ___n -- ~- n -- --- n - - - - - n i ! ¡ 6 stks ! 540 psi: :-_n - ---- ------ _-{n- -- - ---- -- -- - - +-- -- -- -- -- - - n n- ~ ¡ ! 8 stks ! 790 psi! ¡~~~~~~~~~~~~~~~I~~~~~~~~~~~~I~~~~~~~~~~~~~ì i- ------ --- - - -- -- t- ------- -- -- ---t - -- - - -- --- - - - - - --1 ¡---- ---__---__n i--- -- -- ------- n t--- ---- - -- --- --- - t ¡~~~ ~~~~~ ~~ ~~~ ~~ ~ ¡~~ ~ ~~ ~~ ~~~ ~ ~ ~~ ~¡~~~~ ~ ~ ~ ~ ~~ ~ ~~~ ~ ~ ~ ~ I I I I ¡- ----- - ---- - - - -- t - -- ----- -- ----- t - n n n --- - - - - - - - t !---------_____nt---------_---nt---nnn--------i :-- - n --- -- --- - - - ~--- - - - n --- - - - - - t n_- - - - - - - - - - - - - - i J I I I :- -- --- - ----- - - --~-- - - --- - - -- -- - - - f - -- - - -- -- ---- - - - - f : : : : !:~~~~~~~~:~~~~~!~~~:~~~~~~~~~~l~~~~~~~:~~~~~~~~ I I I I I I I I ¡----------------t---------------t-----------------1 I::::::::::::::::t~=:=~:~~.:: :===::::::=:~ L-~~_~!_I_~_~-~!=-L-------------_~~~!_I_~~~_~~~~~E ! 0.0 min ! ¡ 801 psi ¡ ¡~~~I9-~~~~~~r~~~~~~~~~~~~~~r~~?~~~~~~~~~] : 2.0 mln : ; 797 pSI: :--- ------- - ---- - -I- --- - - -- n- --- - - + - - - ----- -- - - - - - --1 ! 3.0 min ! ! 797 psi! 1-" ----.. ----...... --.,--"" --- --...... -- -- 'T""""" --.... -- ---- -- "T L--~:9-_~i~-.l-__------------l---.?~~J?_~!._-j L-§:9-_~i~__L-------------j--_.?~~J?_~~---j L__§:9-_~i~nL_____--__n___L_.?~~J?_~!__.J ¡ 7.0 min ! ! 794 psi ¡ ;-- --- - - n_-: -- --~- - - - _n n - - - - --- t - - - -- n n -- --: - -- i : 8.0 mln : : 794 pSI: ;-- --- - n___- - - _--in - - n_-- n - - - - -t -- ---- -- -- - - - - - - - i ¡ 9.0 min ¡ ! 794 psi! [jQ~~~~I~~I~~~~~~~~~~~~~~I~~~?~~~p~~I~~j CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ¡~~:~~~~~~~~~~~T~~~~~!~:~~~F~¡«~~j ¡ : 6 stks : 457 psi! '. - - - - - - - - - n n- - - ~ - -- - - -" - - - --- - - ~ - - n- - - - - - - - -- - - --{ ¡ ¡ 8 stks ¡ 721 psi! r----------------r---1 Ö-š-tks--¡-_n929 "j)š-i---l [~~~~~~~~~~~~~~I~~i~~~~~~~~Ij~I~Ië~F~~ ! ¡ 14 stks ! 1,443 psi, ........................ --- --......... -- --....... -_.......J....... --............... --...... ~ ! ! 16 stks ¡ 1,686 psi! :. - n- - - - -- - - - - - - - ~ - - - -- - - - -- n - - --I - -- - - - - - - - - -- - -;- - ~ : : 18 stks : 1,957 pSI: :. -- n - - - - - - - - - - - - ~ -- - -- - - - - - -- - - - -1- - - n - - - - - - -- -- - --{ ! ¡ 20 stks ¡ 2,233 psi! 1'----------- -----r-- 22-štkš--¡--2~5õ-3ï;si-l ................... -- ---........... --............... --.... -1-'" ---...... --.... --......... , I . I l- -- ---... --............ -l-.... --.................... J.. --.................... -- --.. J I I , I I I I I t....................... --....... L --.. --................" --.. J...... --........ --- -- --.. J I t I I I I I I I I I I :. - - - - - - n n - -- - -- ~ - -- - - - - - - - - - -- - i - - - - - - - - -- - - -- - - - ~ I I I I ¡. - - - - n - - - - - - - - - - t - - - - - - - - - - - - - - - i - - - -- - - - - - - - -- n - i .............. --..................... r""" --.............. - --....,- - - -... --...... - - - -- --..., I I I I : : : : r - -...... - - - - - - - - - -- - r - - - -... -... - - - - - -- -,- -... - - --......... - - - - ---, ¡. - -- _n - - - - - - - - - - r - - - -- - - - - - - - n - i - - - - - --- - - - -- - --- i I I I I fSHUTINilr.~E ! SHUT IN PRESSURE :._-- ------------- ~---------------,--- ----- --- n- n__, : 0.0 min : : 2,503 psi: ;. - - - - - - - - -- - - n- - ~ n - - - - - - - - - - --- ~ - - - - - -- - - - - - - --- --{ ¡ 1.0 min ¡ ¡ 2,496 psi ~ r---¿-.O-nirñ---r------- --------¡--2~49-.ïpsi' - r---3'-õ-nifñ--- r------_----_nT--2~¡93-psi- ¡ r---¡.ö-nii-ñ---r-------- -------1--2~49-õ-psi¡ r---š-.ö-nii-ñ---r-------- -------I--2~¡ã-Š-psi-1 :. - -- - - - -- - -- - - --- ~ - - - - - -- - - - - -- - - i - - - - - - - - - - - - - - - --~ : 6.0 min : : 2,486 psi: :. - -- -- n- - - - - - -- - ~ - - - - - - - - - - - - - - -1- - -- - - - --- - - - - - ---{ ! 7.0 min ¡ ! 2,486 psi ¡ r'" - -... - - -- -... - - --- -r - - - - -... -...... -... - - - -, -... -... - -- - - - -- - - - -..., ! 8.0 min ¡ ! 2,485 psi! r---g.ö-nii-ñ-- -r -- -- -------- - - -1--2~ ¡ã-3-psi-l r-1-õ~Ö-n'-in--r---------------1--2 ~4ã-2-psi-l r--1-Š~O-n'-in--r- --------------I--2~4ã-2-psi-1 ;. - - - - - - -- - - - - - - - -~ - - - - - - - - - - - - - - - i - - - - n - - - - -- - - - --~ ¡.__?_g.:2_~Jn__~___------------~--~!~~_«?_E~L~ ~-_?~:Q_~jn__~___------------l--~!~~_q_e~~-l L_~g:2_~_i_~_.l__---- ---------j--~!~~_~_E~~_j NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Page 1 of 2 Legal Well Name: 2P-417 Common Well Name: 2P-417 Event Name: ROT - DRILLING Report #: Start: 2 4/19/2001 Spud Date: 4/27/2001 Report Date: 5/14/2001 End: String Type: Production Casing Permanent Datum: Rotary Kelly Bushing Hole Size: 8.500 (in) Hole TMD: 6,008.0 (ft) Hole TVD: 5,988.0 (ft) KB-Datum: 0.00 (ft) Water TMD: (ft) Str Wt on Slips: 125,000 (Ibs) Ground Level: (ft) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 8.30 (°) Circ Hours: 2.00 (hr) Mud Lost: 254.0 (bbl) KB to Cutoff: 26.40 (ft) Days From Spud: 18.00 (days) Manufacturer: Hanger Model: FMC Model: Packoff Model: Monobore Top Hub/Flange: 11.000 (in) / 5,000 (psi) BTM Hub/Flange: (in) /5,000 (psi) Actual TMD Set: 6,000.43 (ft) Manufacturer I Model I Condo I Max aD Min ID I Camp. Name (in) (in) Casing Hanger 7.000 26.00 L-80 6.151 BTC 1.25 26.40 FMC EW 10.800 6.276 7" 26# L-80 casi Casing 7.000 26.00 L-80 6.151 BTC 127 5,268.52 27.65 EW 7.656 6.276 7" 26# L-80 casi Casing - Pup Jt 7.000 26.00 L-80 6.151 BTC 8.20 5,296.17 BAKER EW 7.656 6,276 7" 26# L-80 casi Cross Over 7.000 12.60 L-80 6.151 BTC 1.04 5,304.37 BAKER EW 7.656 6.276 Baker thrd X BT Casing Seal Assembly 6.250 12.60 L-80 4.750 NSCT 19.37 5,305.41 BAKER EW 6.250 4.750 Casing Seal ASE Cross Over 7.000 12.60 L-80 3.833 NSCT 0.83 5,324.78 BAKER EW 8.052 3.958 4 1/2" x 7" Casing - Pup Jt 4.500 12.60 L-80 3.833 NSCT 5.75 5,325.61 BAKER EW 5.200 3.958 41/2" pup jt Bak Cross Over 4.500 12.60 L-80 3.833 BTC 3.12 5,331.36 BAKER EW 5.200 3.958 4 1/2" BTC P X B Casing 4.500 12.60 L-80 3.833 BTC 18 571.84 5,334.48 EW 5.200 3.958 4 1/2" 12.6# L-80' Float Collar 4.500 BTC 1.44 5,906.32 WEATHERFORD EW 5.200 Float Collar Shoe jts 4.500 26.00 L-80 3.833 BTC 3 92.67 5,907.76 EW 5.200 3.958 41/2" 12.6# L-80 Float Shoe 4.500 BTC 6,000.43 WEATHERFORD EW 5.200 Float Shoe Spacing (ft) Interval How Fixed Bowspring Centralizer Bowspring Centralizer WEATHERFORD WEATHERFORD 21 12 5,350.0 4,826.0 Bottom (ft) 5,995.0 I OverCollar 5,295.0 OverCollar Printed: 5/23/2001 2:00:28 PM Page 2 of 2 Legal Well Name: 2P-417 Common Well Name: 2P-417 Event Name: ROT - DRILLING Report #: Start: 2 4/19/2001 Spud Date: 4/27/2001 Report Date: 5/14/2001 End: Interval How Fixed Top (ft) 2,306.0 1,932.0 Bottom (ft) 1,932.0 I Slid On 58.0 Slid On Filled pipe and broke circulation with Franks fill up tool going in hole. Mud losses in Bermuda while circulating hole after getting to bottom. Regained close to 100% returns after thinning mud and circ. at slow rate for 4 hrs. Total mud lost while circ. hole = 594 bbls. Full returns on cement job for 130 bbls pumped. Calculated top of cement at -3480' MD. Printed: 5/23/2001 2:00:28 PM ( Legal Well Name: 2P-417 Common Well Name: 2P-417 Event Name: ROT - DRILLING Prima Hole Size: TMD Set: Date Set: Csg Type: Csg Size: 8.500 (in) 6,002 (ft) 5/14/2001 7" x 4-1/2" monobore 7,000 (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger ( PHILLIPS ALASKA INC. Cementing Report Report #: Start: 2 4/19/2001 Cement Job Type: Primary Hole Size: sa TMD: sa Date: sa Type: Cmtd. Csg: (ft) Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Steven Doughten Pipe Movement: Page 1 of 2 Spud Date: 4/27/2001 Report Date: 5/14/2001 End: Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Type: Cement Casing Volume Excess %: 75.00 Meas. From: Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 350 (gpm) Mud Circ Press: 2,000 (psi) Start Mix Cmt: Start Slurry Displ: Start Displ: End Pumping: End Pump Date: Top Plug: Bottom Plug: Type: KCL Density: 10.1 (ppg) Visc: 40 (s/qt) Bottom Hole Circulating Temperature: 136 (OF) Displacement Fluid Type: Fresh Water 15:18 16:15 16:15 16:45 5/14/2001 Y N Stage No: ,1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: Mud Data 8.00 (bbl/min) 8.00 (bbl/min) N 1 ,200 (psi) (psi) (min) Y Returns: Total Mud Lost: Cmt Vol to Surf: (bbl) (bbl) Ann Flow After: N Mixing Method: Density Meas By: scale PVNP: 12 (cp)/10 (lb/100ft2) Gels 10 sec: 3 (lb/10Oft2) Gels 10 min: 7 (lb/100fF) Bottom Hole Static Temperature: 150 rF) Density: 8.3 (ppg) Volume: 193.00 (bbl) Stage No: t Slurry No: 1 of1 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 6,002.00 (ft)To: 4,810.00 (ft) Cmt Vol: 90.0 (bbl) Water Source: Slurry Vol: 420 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: rF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 15.80 (ppg) Yield: 1.20 (ft3/sk) Water Vol: 52,0 (bbl) Other Vol: 0 Purpose: ZONAL ISOLA Mix Water: (bbl) Foam Job: N Compressive Strength 1: Compressive Strength 2: Time Temp (OF) (OF) Pressure (psi) (psi) Printed: 5/21/2001 10:26:14 AM ( ( PHILLIPS ALASKA INC. Cementing Report Legal Well Name: 2P-417 Common Well Name: 2P-417 Event Name: ROT - DRILLING Casing Test Test Press: 3,000 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Log/Survey Evaluation CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Report #: Start: Shoe Test ( 2 4/19/2001 Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Page 2 of 2 Spud Date: 4/27/2001 Report Date: 5/14/2001 End: Liner Top Test Tool: N Tool: N (ft) Interpretation Summary N Cement Top: How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Printed: 5/21/2001 10:26: 14 AM CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P- 417 Date: 5/15/01 Supervisor: Don Presnell 0 Initial Casing Shoe Test Reason(s) for test: [2] Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/811 #40 L-80 BTC M Casing Setting Depth: 2,382' TMD Hole Depth: 4,810' TMD 2,381' TVD 4,803' TVD Mud Weight: 10.1 ppg Length of Open Hole Section: 2,428' EMW= Leak-off Press. + Mud Weight = 520 psi + 10.1 ppg 0.052 x TVD 0.052 x 4,803' EMW for open hole section = 12.2 ppg Pump output = 0.1010 bps 3.100 ps' 3JXX) ps 2.900 ps 2.800 ps 2.700 ps 2.600 ps 2.500 ps' 2.400 ps 2.300 psi 2,200 psi 2.100 psi 2,000 psi 1. 900 psi 1.800 psi ~ 1.700 psi ::) 1.600 psi ~ 1.500 psi ~ 1.400 psi a.. 1.300 psi 1.200 psi 1.1 00 psi 1.000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 Fluid Pumped = 4.0 bbl I' 1.7¡'~ -;¡'7"i.~ -,-,,\..,..-...,-4,- ~4,~ I A / -" TIME LINE .",..."....."'."'."."'..'.'".1 ONE MINUTE IICK~ , --I' - L --1- , -0- LEAK-OFF TEST , , ~CASING TEST , , LOT SHUT IN TIME ß , ,k- CASING TEST SHUT IN TIME ". , -' -' , "' J ..,.. , , , - I I / I / I~ v Ñ ~ STROKES ~ ~ ~ ~ õ= NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE !:::::::::::::::I:~~~~:::E:i~f:~¡;:::J ¡ ! 4 stks ¡ 450 psi ¡ :- --- -- --- - - - ---- ofn n_n - n-__- - - t - - - --- - n - - n -: - - - i : : 6 stks : 450 pSI: :-- -- ----- - - - --- - - -- - -- n n_n n - - f - -- ---- - - n - - n - - f ¡ ¡ 8 stks ¡ 450 psi ¡ ¡--______nn----r-:¡()stks--r-47S-p-š¡--1 ¡-----______n__-¡--:¡-istks-l---soõ-p-š¡---l [~~~~~~~~~~~~~~I~~~~~~~~E~~I~~§Q~~~~~~] ¡ ¡ 16 stks ¡ 500 psi ¡ '-- - - _n -- - -- --- _.J- - - - - n n ___n n ¡ - - - n_- -- - - - - - - n i ! ! 18 stks ¡ 520 psi: :-- - - --- - - - ----- - - --- -- - - --- -- -- n f- ___n - - - - - - - - - - - f ¡ ¡ 20 stks ¡ 500 psi ¡ 1- - - ---- - --- -- -- - -.- -- - - --- -- - -- ---T -- -- - - - - -- -- --- - -, L------_n_n_--l--~~--~~~~--1--______n- ------J L--_n_-__------l--~~--~~~~-.l----______n_____j !-___n___n_____~--~~--~~~~--!-----------------! : : 28 stks : : :-- -- ---- - - n _n - - -- _n - - n ----- - - t - - - n - -- - - - - - - - - - i : : 30 stks : : :n - - ---- - - -- -- - - - -n - - --- -- - - - - -- f - - - - - - - - - - - - n- --f i---_n_--_------L--~~--~~~~--!----- ------------~ L--_n_---___---l--~~--~~~~--1--------- --------J L-------------.l--~~--~~~~--1--------- --------j L______------_-1_-~~__~~~~nl______--- --- _____1 ¡ ! 40 stks ¡ ¡ ¡- --- - ---- - - - ----1- - -- - -- - - - - -- --- t - - - - - - -- - - - - - -- --1 i-- - - - - --- - -- --- -i- nn n - - - n - - - - t - - - -- - --- - - n - - - - i 1-- - - - --- - - -- - - - -1"'''''''''''''''''''''''''''''''''''''''''''''':-'''''''''''''''''''''''''''''''''''''''''"''''''''1 I I I I L-~~-~!_~~-~-~~J.--------------~~_~!_I_~~~_~~~~!!E ! 0.0 min ¡ ¡ 0 psi ¡ !~~~I9-~6]~~~I~~~~~~~~~~~~~~~!~~~§Q~~P~~~~J : 2.0 mln : : 275 pSI: C~~~Q~6]l~~~t~~~~~~~~~~~~~l~~~~~~p~~IJ Ln~:QE'~!~_J-__n---_------L---~~Q.J?_~~_nJ L--§:Q-~!~-.l-____nn_-----Ln_~~~_l'_~~_nj L---~:Q_~!~__l____________n_L___~~~_l'_~~-j ! 7.0 min ¡ ¡ 250 psi ¡ :- --- - n_- - -: n - -of- - - - _n - - - - - - -- -t - - - n ----- - n -: - -- i : 8.0 mln : : 250 pSI: ;- ----- n ___n - n- - -- - - - - --- -- - - - - t - -- ___n - - - n -- - - i ! 9.0 min ! ! 250 psi! [~iQ~~~~I~~~r~~~~~~~~~~~~~I~~~~~~~~~I~] i5 CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE t:::::::::::::::r:~:~~~EJ:::i~::~~:::J ¡ ¡ 4 stks ¡ 720 psi ¡ '.- - - - - - - - - - - - - - - - ~ - - - - - - -- - - - - - - - i- - - - - - - - - - - - - - - - _.J ¡ : 6 stks : 900 psi ¡ :. - - - - - - - - - - - - - - - - ~- - - - - - -- - - - - - - - f- - - - - - - - - __n - - - - ~ ! ¡ 8 stks ¡ 1,110 psi! r------------ ---- r--10-štks- -r--'¡~3õ-õ-psi-l r------- ---- _n_-f-- -'¡2-štks--l---'¡~52-õ-psi-J- C~~~~~~~~~~~~~~I~l~~~~~~~I~~i~f!~~ë~L~ ~-- -- ------------~-- -~ ~-:;-~~~-- ~--~!~~-~- E~~_~ : : 18 stks : 2,240 psi: :. -- - - - - - - - - - - - - - - ~- - -- - - - - - - - - - - - ~- - - - - - n - - - - - - -- - ~ ¡ ¡ 20 stks ¡ 2,490 psi! r------- ------- --r--22-štks--1--2~ =;õ-õ-psi-l [~~~~~~~~~~~~~~~~ [~~~~~~~~~~~I~~ ~~~~~~ë~~~J ~--- ------------ -t--~~ -~_tJ5~--i--~!Q.Q_~_E~~-i ¡. -- - - - -- -- - - - - - - - t - - - - - - - - -- - - - - -1- -- - - - - n- - -- - - --1 !. n - - - - - - - - - - - - - - r- - - - - - - - - - - - - - -1- - - - - - - - - - - - - - - - - i f:::::::::::::::r:::::::::::::f::::::::::::::1 r- SHUT IN TIME ¡ SHUT IN PRESSURE '. - - - - - - n - - - - - - - - L- - - - - - - - - - - - - - -1- - - - - - - - -- -- - - - - -- ¡ 0.0 min ! : 3,000 psi ¡ :. -- - - - - - - __n - - - - ~ - - - - - - - - -- - - - - - ~ - -- - - - - - -- -- - - - - - ~ ¡ 1 .0 min ¡ ¡ 3,000 psi J-. r ---2-.Ö- mï"ñ---r------ n -- -----¡- -'3:öõõ-¡)sf' , l~ll~~~]~~::~~:~:~~:~~~1:]j!{!~!~¡:j : 6.0 mln : : 2,990 psi: :. - - -- - - - - - n - - - - - ~- -- - - - - - -- - - - - - ~ - - - - - - - - - - - - - - - - --I ¡ 7.0 min ! ¡ 2,980 psi! r---s-.ö- mi-ñ---r------ ------- --1--2~9ã-õ-psi-l r---g.ö-mi-ñ---f----- -- --------1--2~9ã"õ-psi-l r--1-Õ~O -r;l¡ñ--r---- - - - --------1--2~97-õ-psi-l r--1-5~O-m-iñ-- r--- ---- --------1--2~9i õ-psi-¡ :. - - - - - - - - - -- -.- - - - ~ - - - - - - - - n -- - - - - - n - - - - - - - -- - - - --of : 20.0 mln : : 2,960 psi: ¡.-- -- - - - - --- - - - - - ~ - - - - - - - ---- - - - - ~ ---- - - - - - - - - - - ----I ¡ 25.0 min ¡ ¡ 2,950 psi! L~g~Q~~J~~I~~~~~~~~~~~~~I~~~~~~~~ë~CJ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY 'm PHILLIPS Alaska Inc. ~ A SYbsJd"''Y 01 PHilLIPS P€TROlEUM ~OMPANY ~. ~" " Subject 2.. P - Y ~ ß. . ,J,JJ} 4- ( File Sheet number Calculations Chart I of Z- Date Sz.-Z./Ð! fl- J gun 1" ::. S l)Ù r),' ) '8~ ~"jt -- 'i,rt7 r";,~ A, S5 cJ ~~",', WI\-r{m c.J !'AcJc,.. > t p/ð ~ q $7.t''' 1,59;) .P~; M~ I~SÇ0"tVo~ ~~~~....~ ,fIA:: .f!rY> , , " I " Þe:~$ ",I 1"1 Tc) . ß~J,!, i 'i )1& : i; ;; SOO , ,('\ ''-\J~"J ,4- ~'}~cÐ)~) (~'3>ðIJ ,-; ~~'~õ1.¡'.(';:'~-¿T")""~i::: ,,::,;,.,::,.:,--~,:",,"...:.....:.:..~ " . '1~~::~H:::~? . J : I I . I . . QUALITY LITHO PRINTING. ANCHORAGE. AK (907) 563-4743 159-5881 ( ( Calculations Chart File - &.{ ~ ~ þ.f'J ~ .;1 ~ Þ (~p ~s. 4'L- By P3~ Sheet number ~ Date ~/-z., 1>/ of ~ II( 2& Jd L- - ð'D Pcot{¥ s <- ?S~4 p«(#U4-t(~ - SIt.{ lOp..: Li/S oz t f \ " ~ \> \ ~ç u{ .çro p.... '/1 1 ) 5'iA-v-I~ .t v~ ~ ~ l' - VV\ ~FtJ It) ì)~$,"~ f'o )~r ~(, ~~ 7 ffÄ) ,., ô )" (8',,/ rP'J) ~ ~ c~ oltA-¡ø $ ~ 7 I . 4$ îð +- \îì5 (ð~~)(~~')) t(~~I{1 ~ f~)?")(~5 'L)(~~~) ~. I t.S-~O+",'"",M~(,.tJi~),¡:S","b',1 " "'" I I' , \:>:PP) I,' ;> ~'~~ I Þ, ~..; (~, t>.~~~tr~. ~. s,.$ ~J,,~ ". &w .. ..." '1, ~~ j? , , ~~,~ (;" ~ . ,1ß$;'(j~~ , ,.,I~, l~~, '., 1H~ ~ (~?>I~Æ:. 1}.(c~.J~) :z~~, ~,.,~. 3(~~"L.~~~R'!;)., I ' ~ cr. L~(t~~~!e!J ,~()Í : If=. . r~pj>j" . , !.. ,~~",PI\L . , EL.-~'.\?" -- ~ \fD ja,P)' j QUALITY LITHO PRINTING. ANCHORAGE. AK '(907) 563-4743 159-5881 (f ~:' ""-''''''--''''-'''''-'''-'-'''' ..-.-._u.-...-..-.......-....--..-.".--.... Well: 417 m_".~~.~_?!L?.__~."..:......~.'?!..!n~"n_~.!_~P~. 'm. A I ask a ; ".. BAKER HUGHES INTEQ :. ___m_..__.EQn_~_!_!jJ!~-_.!\"!.. a_,~_~._~_l____!,.~"-~-_:"....n".._..,..__._..., Structure: Drill Site 2P Field: Meltwater 350 TRUE NORTH -<:::r = 0 10 340 1440 20 250 330 30 320 40 310 50 300 60 290 70 280 80 270 260 100 110 240 120 230 130 220 140 1........,..~:~~~:~:~~:~t~s~~~~;','::"""""'1 I Coordinates or. in f..t relerence slot '4'7. I IT'U. V.rt;.ol D.pth. ore ,.1,..".. ,olory 10bl.. 1..............~.~~...:~~:..~:~.~::,~=:~~..=~.~.............J 210 150 Horizontal Clearance - Feet 190 180 170 160 All depths shown ore Vertical depths an Reference Well 200 { '" { Scale 1 inch = 100 ft Phillips Alaska, Inc. . .'-'St~~'~ïü-;~"~"D~¡iï"s¡¡;'Ù;""-""''''''''''''-''-''''W;ìï'~''''¡1i' ..,.. , ...r.~I!I9. .:. ~':'.~!,I.':'.CJ..!e!. ... ,....,..~,~_c_Cl.ti.(),:,: .,.N..~.rt,~....s..~~'p'e~- ,\I,CJ..S.~CI: Ecst (feet) -> 00 1400 1300 '00 1000 1100 1200 1300 r&.. BAKER HUGHES INTEQ E3 ", """'''''''''"" '....., ""'......., " """'" ""''''''' er "'''''''''''''''''''''''''''''C~';~t'~d'''b'ÿ'f¡~'~'h'''''''''''''''''''''''''''''''j Date plotted: 21 -May-2001 I Plot Referenc. 1, PMSS <0-17?0>. I Coordinates are in feet rcfarence slot N-417. ! Tryo Vertical Depths are reference rotary tabla.! ..............n~.~.=..~.~~.~.:..~~.~~.:~..:~.~~.~..=.==...............1 ,m ..00 300 ^ I Z ~ :;: :: 100 V 300 500 800 700 800 (J) "00 g ¡;; 1200 ~ 11 1300 0 0 1400 ..... (' { Phillips Alaska, Inc. Drill Site 2P 417 slot #417 Meltwater North Slope, Alaska H 0 R I Z 0 N TAL P LAN E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: PMSS <0-6008'> Our ref: svy6522 License: Date printed: 21-May-2001 Date created: 30-Apr-2001 Last revised: 21-May-2001 Field is centred on 44l964.235,586989l.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.890,w150 26 49.100 Slot Grid coordinates are N 5868997.699, E 444146.798 Slot local coordinates are 877.19 S 2189.52 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with Horizontal Last revised Distance M.D. 26-Feb-2001 6736.7 2135.8 26-Feb-2001 2616.2 6008.0 26-Feb-2001 888.9 5731.9 6-Mar-2001 47070.3 6008.0 21-May-2001 420.1 0.0 Plane method Diverging from M.D. 5309.2 6008.0 5731. 9 6008.0 0.0 PMSS <0-6122'>"MWN#l,Meltwater North #1 PMSS <0-6300'>"MWN#2,Meltwater North #2 PMSS <2212-7349'>"MWN#2A,Meltwater North #2 PMSS <0-8935'>"MWSouth1,Meltwater South #1 PMSS <O-???'>, ,438,Drill Site 2P Phillips Alaska, Inc. Drill Site 2P,417 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 1 Your ref: PMSS <0-6008'> Last revised: 21-May-2001 M.D. T.V.D. Rect Coordinates Object wellpath : PMSS <0-???',>,,438,Drill Site 2P Horiz Horiz Bearing Dist M.D. T.V.D. Rect Coordinates Min'm Dist Reference wellpath 2382.52,381.0 0.9S 24.7E 2850.0 2381.0 1238.6S 788.4W 213.3 1480.9 973.9 'Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #417 and TVD from rotary table (254.00 Ft above mean Vertical section is from wellhead on azimuth 85.97 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). FROM: PHILLIPS ~K F~X NO.: 91372651535 136-131-131 1ø:35~ P.ø2 i " Page 1 of 1 PHILLIPS ALASKA, INC. Daily Drilling Report . ,JOB NUMBeR: ! !!VENT CODE' 24 HRS PRO!;: .1'MD I TVD OFS I REPT NO. ¡DATE: ?E..4JL_.. : 1 ! ODR I ! 6,008,0 I 5.988.0 i 20.00: 23 l2/16/2001 'sÙPER,VISOR 'AIO NAME & NO. ----. \FII~LI;~S NO:----'AUTH MD ¡t>AiLŸTA~G-'" "-~lèÜM'.n;'ANG -.- B.:Y". Sp~lQg.er!¡;>.A. Pr~_~D.~...._.. ..~n 1~_.' Meltwater 5992.°-L 333,503.00 415.216.00 CURRENT STATUS ~C!DE~';¡4 HRS,? .IDÄllY !NT W/O MUD' .,,-. lëüM INTÅÑG'~/M'OO--'- ....-. _Big r'eleas~ . ¡ 149736,76 I 3010737.86 :l4 HR FORECAST .-' ~ DÃTEõFL:Aš'T SAFETY MEETlN¿l DAfL Y TOTA~ . ,--, - .-..- : CUMëõ~TW; MLïõ- ....-- , _._n ._,MQ.ve "9 to ~þ 4~.~..- ._--._. '-'" -" . qr16!.fQ.Q~ . -,_..:......-.. .~~!L.. .i .. on'--- 3.,4~b.~29 ... lITHOLOGY ! JAA HR$ OF SER\fIC~ i aHA HRS SINCE INSP ! LEAI(OFF ; ,AFr;; 'AUTH. I I I' .....-..,. .-.... 5Jl ~?IO.~-~.., .....--..L... ..--..... .1_, .----.1 ..-.-... ,..,L._. A~91§'~......__... I........ ._._?¿929..?Z£_. LAST $URVEY: DA.TE TMD INC AZlM ¡ lAST C^SING ,NEXT CASING I Ljl.gT PO" PRES Te~T . 5/131.~90.1 , - 6.oq~,9(L.. . !?~QQ-_... . ~.5,5QL..[ ~.50Q_U'll@ ._~~Q.2.0 (ft) . --_ill:!L@ ,._..._(~} L " "...",-, 5/81~_Q.Q.1 -- D::'s~~~~!'.lG~~~3f~wJ:r:~~crr.~oL ;rC6;~A~4~~~~~~ ~~rLYp~~:;T~:~' Pff~?O.. "---~I¡' (;~,~ ë~~TLH'2~-''':'~I~E "~$- :16.J...}1._I..-ï...n!-:~~~-~ . _-ì~. CI..851~.Æ ~.1-32ô.t_:~ . ,._~.,_.. "--.~r'.' ... OPERÄTIONS šÙMMARŸ ..-----,, , . , ' ,,~,~~"I--T?~'.~, ¡ ,~?~RS-r=~~~'ij""TR.~-~7Ë ¡ ......SUB.. ! PHAse' ¡ . '" .. ." ,~.._, .", ~ DESCRIPTt,ÔN .....:,~~': ~,~~:~...~,-=,.. .. , u --~o:oo ,~<?:H5 f ... 0.25 "....~.~tC}~L P!._....__l~F!:~RM!.l!:~job ~afety..me.~Ung.._._._.. ,-.--.--"...." ....-- ."....-..,,,..-....,, '~~:¡ci'¡I: ~~~~! ;~~'6"'''1~~t~~t ~' "'-!~'~~b ! :~~~~~"! ~~~ ~~::~est paëk off'to sóöû p~i. te$1 tre; 250 p~¡lç~ ~'nd soöö"p;¡'high, pull ! : back pressure I/àlve in tubing hanger. : I : i , \ \ : ..'00" ,,, , ".. ". ..-.-. .--... . -! ~~':1.Çlse Rig at 0430 hr9:.Q.~.16/01Jmd s~ar1 t'!.'~~.'::.. <J 2P 4~~, , ""--"".- 04:30 ì 07:30! 3.00 : CMPL TN Pi "':f::RZP ,I INTRM1 . RJU pressurl? truçk on 7" X 9 5/8" annulus, pérform LOT, broke back:31 a 12.2 I I , .___1, , I ! ~ eqvivilf:.!nt mud weight Pump 200 bblS w~ter to flu$h annulus followed by 60 bbl¡;¡ ,~,- ! .-.-.~ of di.~5el, f.or fr~z:e ~.rot~!i2!!.:- . ,-_._". --..--' Wl:lL NAME i ....,-,., ,,! mm ""...., .....--.., ".--...-.. ,,--,-"-" ,._-,. ,--, ....-..--. '"''''--.''.-''' , ...,...", ',..-.-..., ~~ HR Sl'.,M.MA~V: N/D B.,?~:~:,~(~ tree and test..:: R~!~i:'IG~. Rig ?t 04~.O hrS."05/16/01,,,.__.., """-,.--.. --~-" ,.-..,,-.. PER.SONNEL DATA ,~':"""'''' Co.~PAN.~.'''' L.......,_.~,~:'~~ëRYICE'.=~~:~~, T... NÖ~!Hõ'u~~.'" "'~ëõ'~pÃ~:!-' "=+---=~~se:~~~=__.... ..." ¡ ,~~:~~~" T.H~ÕRS.' Mh3,~..,~e~$onl1el. '-'-' "....-. ¡ ",--_.. , : ...~,_.... ~Phi)IiPS '-'" ,-_.---1-. ,-.......-..". ! 4 ¡ ~~~ c~Pe.~~,~,~,n~!.... . ...--..-. ,,_.._....__.~. ,.. 6 i ... ilDoyoo- ,.-- 1___, ",.",..., "... ì ..3.~._,,---_.. ,. :.~:=::~~~_...- _.:[-=::~~... I ü.~G::~rEo~i~~~~oNs-4~~TI~~~.. u:rrG .YS~~~----¡:- ON ~~: - ~~~~,~~.9.~ì.I,~!~,~.. ..--.... :~=='. ~::~:--: ._.~j:~~'" f U ^~::~~b,. t~~ter, .~ot~~~.,,=~, bbl~ .=..i~"_._"." "U. ,..8~~",~:-..::.._.~::...~::~~50 ...- '-...-., ,._n..."..-" ,..,-...-. "'..-.., ......_n"'--- .'-'..'-""^",-.--..", ".-_N-. "'..---.." ,---_.. ..,-..-...-... '''---..---.' ,.",_....-,. ".., . INJECTION _.'-~~".."..~~:sT""""':"~~~,:~~L.. vo~:'~-r---=_.~'~:- S,OURC~ ,.~., .~ u'.. ~~šT" -TVOl~ '-r-=:~. .i?:~:~cË-' p~.~ G&I, u..~.. u.. ..---Ì,.." ,..!~~.!., ,~._...,~.." "., I) 1r-,1,~,,~.. ..----Ì-. a~~!Z...." .".....,......---"" . "".....-...-"....", "'"--''''''1..--'-''' Frlnt;¡~: 5/1712001 6;15:35 AM FROM: PHILLIPS ~K F~X NO.: 9072651535 06-01-01 10:14R P.02 ( Page 1 of 2 WELL NI\P-\E PHILLIPS ALASKA, INC. Daity Drilling Report Joe NUMBER; EVENT CODE ¡ M HRS PROG ; TMD \ TVD I DFS : ~EPT NO. DATE 2~:41! .._----:-.. .L-l- ODR.-Ì. --. ._L.b430.0 !~9 ] .._§.:OQ_. " ..u..~.._... .?/1I2001 SUPERVISOA RIG NAME. ð NO. i F1ELD N^M'Ë I OCS NO, : AI.TT1i MD : D^ILY TANG I CUM, TANG -. ~:_W~ Glad~~I)_._, : DOY.9..!!J..41 ...---- j ~__~eltwater -L. 5,9~.2.0~. --.-!!~QQ.~qo. .J..,_.....11.0~?~", CURReNT STATUS : ACCIDENTS LAST 24 HRS.'? 'DAILY INT w/OMUD 'cUM INTI\NC wI MUD --",''''- ..-.. --.... .TJ.HJ9_TagC~I- "- --_..; '00_.. ---- .-L~ 101.7§4,~~.. ..~. .......1.03~\?~~~.. ... 21 HA F'ORECAS'f ~ DATE OF LAST SAFETY MEETING; OAIL'1 TOTAL . CUM ÇOST WI MUD :rAG Cf..1:r--JEST CS<;3.. - ORIl;~_9~I 20'.NEW H9LÈ;~9R~.L__, . .5/1/200~. ...-.L.. .---193.~?4..__,! .tg.~4.70.L-. UfHOLOGY JAR HRS OF SERVICE: BHA HRS SINCE INSP ¡ lEAKOFF ' ^F~ ¡ AUTH, . ..' . .-.-.. : ..---...-L --.. .L-. .. ~ ._AK016~_..._. ¡ ..... ......?:!:J29,~?..!..-_. LAST 5URV~1': D~TE -mO tNC AlIM! LAST CASINQ ¡ NEXT CAS~NG I \...AST BOP PRES TEST .....§!..1.{2901.._... .-... :2,3~~ßO ..._.~~~oo ._...~:.eoo.-L- (in>.. @ n- .~L.,'. .~~~§J!Ñ @---^.~.OO,O (~L: ...'.. ~(!t.?'.Q.Q':!"_. , "~5:5~~1~(5~/~95~h8:/E1'~3~6j _:LM5'!'."o~/:~1~ - F~/-S~ !!:EC~I ~J M;,IU~~/7~dIM.-~~~ D~!Li;8PS/; t- t,.:Pf/;:I,--- ~1~¡:::3~2.~o:1:~2iJ1~~ - ES ..--... I ,.........~..! ......"....~..- ,-,...._". ..-.--.... ...--1- ..~:':i~~~t ".~.- ...L_.-.. ,....., .....l.....J.._,-, ;~;:~~o~~,:JI-'-~$~iN~Wr;'~- - ~~I~:~~~~J.Q~~::~~_~~T ~T~ !O~~E:I~~ir~-~ r-t 'e:~~~~r~~- ..... ,~.." .-.- ...-......--.....! ..~~ ..._,.~ I ..---"' ,.. ! "..~..".._.. I ..1".............,:,', °f"~?-~-" . "",-,-",..-. ....,_...,_...!!~M D~~C~IP!I.ON,__..._..., ....--+" NO..JTS -1... L~NG~,t1 ~,_..ò. )~ "-L.,,,,~,~' ,,~....C(),~N SIZE.... _C:?~-~,p.~ -",,,_.., ..,,,..., ,...-.., ,--.-- ""--..-..-. .---L .._L ,-_..l .._.1 .--.....-.. I .......,.........." ...--- ,...__...."~--'''.'''' ..-r--"" ---'" ..--""'" .._--~.,... -...--'"'''' ,..."...,..,"'"''-''''''' ,...---.-.....,.., , B~ ' . . B.~T I '!VN --:t==~iz~~A~í!PE ! SE~I.ÄL NO..' '- JETS' OR TFA--=:LD~lii' D~TE ~:I.~--'.o.D~'B-G-Õ:R-::-= 1/..... ..1.. -.... .---.-, ".--L---.., ,,--1-.-. ,_1.._, .-- ..._....._.1 .__.?,~_,.~/24/g??.1¡O~~,:----- ",,--.'.'-" ,... .-,.".- ,.-,'-." ,.~--_.. ......-.."....--....,. BIT OPERATIONS ':~::~:~~! R~~ ~::_.L "~?~"..~, -'~.PM'=l..GP~''''.''IP'R~$~.~'BI~'' \ 'H~S ~~H~~!iT ".~~-~:~oP L~~~,H:~'S \ cU~:.~~~.~ \ 'c'U,~ R~' SURVEY DATA ~~'ö~2.c.'L....'TAziM~!H ~ T~V.D:' : N/S CUM1~~~TIONTNï:D:¡ INC.L'- [-~.~~"".Œ~.D._", f'Ñïš'~~!.~1~§u~SECTIÕÑ . 801 8 ' :' I I ' L _~~366:..~,0..- 8.30o.J".......86.8~.~.~~~.5.5~,L"..-.~~\ ,,22.4~ 22~~.. ,~-, I, ..,- I ....._--,......~, ..L", ". .-..-... ,.--....-,......"'" ....-....,,,"" .",n._...__.,.."" "'" .......,...-...............,,,,,,., ...- OPERATIONS SUMMARY "~¿~~~l~t'~o.~~:r~~s' \[ ëA~ED~ - . rt:UBLE; R~~~ ! :u~:i~:~nin9 ë~g -:-~it B~=: -W~Sh ~~~:~~:-~nãbIO .10 w~~-òã;:~';Ci~~ I :, I I 2:ÙO I õ~::~! .1-:Ö?='[Q.~sEI~ -'JP.Tim--+sü~FAci~~ :~~~~~ ~;~;/ ~;~~;~~~ù -~ndin9 jì .'!~ g.gfi~~-=--=-- ~ ~~~ II ~~:~~ i ~.~ : ¿:~i~-ri- 1 ¡ ;~~pi ~~=:1~: ¿~~ ~~~~~i~~:n~e~':t~~)g- Fulï,otum.- i;;~~~f.",,: 6i;pi~ce mlh Rig - i l ~ '; I i pumps 1634 stk~ - Held 500 r~i over bump for 5 min. Ck "oa'$ "Held" CIP -. ""T""'" l.." ....., 1 .--.--..: ----1, "._L "--1..97:45,_.,, ..-. ,,--.., .."--...,,.-. ',...""..-.-..'" .~~~.~O U.g;~2', 2:.?_?,....-i~E~~NT ~ _._....-!.RU~~,3-UR~~RJD Cm~ad,~~nd,i.~j)....!,!..:..~!ea~~~_~~_~~ng tool.~, Ir?rn Rig t.I~,~.~"..._...__... ,,!?:30 U.~,:.~,O , ~,:.~.~..._+Y"E~lS~,~" ,,_.no: N~.ND.-.LSUR~AC~ N/D Di~ert.~~yste':1 ,--_. ..--... .. ....., .". ,,,..,, "..,,,....'..,, .~ "~1'~6~' 1':' ~ ~;~'6 f. '.. ~:~~ ".'1 ~~it~S;'t-- .J ~~~' !: ~0~:;¿!' ~~~d &F~~j:~:6~~Ä~~ d~iI~:~~~:~d~~tf;~i~r$ on 'Pad and all pëiso~-;¡ ~n I I I , I I "13:3'õ "1'9:00 r' 5~50 \'WELLSR ~...~._" \NÜND-tSUÄFA()~;~' 135/8" 5K60P' ,,-- ,_." "'-".' '" ",_.. "..._-,_., '1:~7õo 1!".~~:;:~o ¡ '~,::5~:~.,,: WE.~~!~_~~ "-=-.,,~~o'P.E lS'~Ri=1\çi~~~t ~Ö,f'S - T.e~~ 25~L~.qoo Hi - ~nùl'ar.?~~<,~~500 , ..-.. ",::'~::::.. =--~:, ..?~.:~.Q-- O~.:9~ L" 0.50 : W~~~T.~ ._~.~Q.~~,~RFAC:, ~nst~" .~~g - .~~,~. .-'-" , ".-" , ,.~...,.'.'.'.'" ..",,,".'- ......._...-J-_. --'-'''' ,.--. ---, ~"'n ...--.J..I_'" .,.--- ,.-.....-..... .........,'"'-''''' .-- 24 ",R SUMMARV~ Drill from 2280' to 2430' MD. Pump and circulate WV HV pill, CBU. Do wiper trip. Circulate WtJ HV pill. POOH and Ia.y down "."" "".._~HA .~2..~~!J'wg~? r~~asin~. ~~a" c~9.~ .~,._.. ..-.---, .. ..-.- --""'.-.' ,--.--'" ..-- .--.. "-"-"""".U'" . .....-......., ,....-..---.,.. .- p( n\<:>Q: 61112001 8~37-:~l; AM FROM: PHILLIPS RK FRX NO.: 9072651535 06-01-01 10:15R P.03 ~: Page 2 of 2 ~f~~1.Z- ... PHilliPS ALASKA, INC. Daily Drilling Report ..,~~,N~~~~~J:~Dc~DE.L~s PROG .._~1~o.Q..l~Ag.8.0..\DFsS,90 ~R£~u~~'....t;~2q01 WELL !liMAI' . --;-... ...._--, --'--'--- PERSONNEL DATA n_. .~~-~~~~v ..~~_.::~t~'-.:.'. .:---ŠiRVi.CE .,.=~~ No'~-THo~R5~~oM~ÂÑÝ.~- '--T~~':šE~~!.?e'n.. . P~iIli?~_" -_.- ..~...__.4 L_ÜMisc Person~~,._.. l £?oy_?~,- -... . ..: 1--=---= "--- !.--L-. 26 ~__ll S~rvice F'erson~1 u_.:- ..---...-- -..-----. -':,~~o.~.--.J HÕiJR'S ..---"~:~?~j~~.- ---... ...-......"...-.... ,,--,.,--- '''-_a. "---.---,.' . ..... MATERIALS I CONSUMPTION Fuel ..IT~M-=-~.r- Ug:is~- ¡USAGE : .o~~~:~--ç:::~,e-2 .. U:b:sT-i~AGE:F~~:~~ ~~t~-;.Q~ili.i.~_?,."'.. -'~:J '-~í"T.;-' .'~:..~=:. .~:_-~,-_:. -1 :~55~'. =~.~-". !~~-=..__.r:-'--."--.' ..-... . .......... ''''I''~:::==~._~..... -,"-...-". ..----.. - '..n____._-.. -.--.-... ",,-.,. .... "'---....--.", '-..... ...-........",..-.."" SUPPORT CRAFT ~:~:=~~PE~_:=]-=~hj~P~1i - :~~.EM~RKs - ..--:.1 . iY~~::] :N~'=1-= _.-:_~_:.~~MAÄK_~=~:._~~ '-'- Prir>te<!: 6I1~OO1 8:32:26 AM Well Name: CASING TEST and FORMATION INTEGRITY TEST Date: 2P-438 5/22101 Supervisor: R.W. SPRINGER @ Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# L-80 BTC M Casing Setting Depth: 2,992' TMD Hole Depth: 3,025' TMD 2,457' TVD 2,475' TVD Mud Weight: 10.0 ppg Length of Open Hole Section: 33' EMW= leak-off Press. + Mud Weight = 770 psi + 10.0 ppg 0.052 x TVD 0.052 x 2,475' EMW for open hole section = 16.0 ppg Pump output = 0.1010 bps Fluid Pumped = 0.8 bbl 2,800 psi I T 2.700 psi 2,600 psi t;fIME lINE E - 2,500 psi 7IONE MINUTE TICKS - 2.400 psi I 2,300 psi 2,200 psi I 2,100 psi , 2,000 psi I ~ II 1,900 psi I I 1,800 psi I ¡"""lEAK-OFF TEST w 1,7oopsi K II: 1,600 psi 7 ¡"'-CASING TËST I I ;:) 1,500 psi tIJ 1,400 psi fa 1.300 psi a:: 1,200 psi 0.. 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200psì 100 psi 0 psi -~-lOT SHUT IN TIME -----CASING TeST SHUT IN TIME ~ !R $ ... '" & t ~ ~ '" <D ~ '" ... !!J .. .. '" ~ ~ '" '" STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time nne above ... ... LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r-------------r-Õ-stï<š--T----õ-¡;šr---' }----------+--------------~---------------~ L_---______L__~_~s____L_J_~J~!~-_.J L---------j--~!tks---l--!?~-PS_i_-j i-----------!-~!!-~~----t---~_~~.P.!LJ ~------------~--~_!~~---~--_?_?~P'~_i___~ , J I , I I I I ~_.._-------_..~--_..._--------t---------"-----1 I ; : : :-------------,..-------"'-----r-------------1 f I , . ~------------+-------------~----------------.. I I I I }--~---------+------------~----------------~ I J I I t , I I f-------------r-------------¡-------------1 r------------¡------------r--------------1 I I I : r----------..,..-------------"----------------'" I I I I }----------+---------------~---------------~ I t I I 1 . r 1 L__------------'----------------"----------- ----'" : I : I I J I I to------------""--------------"'----------------" I f 1 r , r I I '------------"'1""--------------1"----------------" I , I I }-------------+---------------~---------------.{ : If: L______---------.&.------.. ----... -- ..L--- -----.... -----~ ~---------------+--------------~---------------4 I . I 1 ~ ---------------+----- - -- ---- -- -~- -- - ----- -------1 I : I : t-------------t--------------t---------------1 ~--------------T-------------~------------"'---1 1 I t I t--------------+...............................t..............................."1 I 1 I ! I SHUT IN TIME: SHUT IN PRESSURE }----------~--+-----------r----------~---¡ : 0.0 mln : : 770 psi I [=~~~~F.~~t~~==~~~~~~J=~?l~~P.!r~] ¡--_?.:g_~l!!_-!-_------------~--_?_?!.P.!.i_--J i-~.:g-~~!!_-~--------------~--_?_?~_P.~L_~ : 4.0 mln : : 770 psi I L_-----------~"'-------------"-------------1 l---?.:g-~!.f!--L-----------l--?_?~_p~L.J t--?.:~- m i!!_-!-_-----------~--_?_?~_P'~)--j : 7.0 min I : 760 psi I }n_____--:----+-------------~---------------'¡ L-ê. 0 _~l!!_.L___--______l_.?_~~_p-~L.J ¡ 9.0 min ¡ ¡ 760 psi ¡ [1_0~q_~1~- f~~~~~~~~~~~~~I~I~~~p-!.CJ CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r-------------I---õ-štkš---Y----õ.pšT---l t--------------t--2-Šikï--t---14Õ---ã¡--1 l__- ----- ----- - -..L.- - -------- ----1.- -- - __--_e_--- --f t-------------t---:-¡::---+---~;g-~-~~---1 r ----- --- - --- --T ------ ----- -- --1---- ---- - --- -----, ~---------------+---~-~~!---1--~~~.P_!!_--~ ~------------_.L_!.~_!.~_!--1---~!~.e_1!!_-_1 r--------------t--~~-¡~-~--t-t~~-~~-P.¡+-1 r----- --- --- -- -,...---------- -- - -..,..-- --- --- --~- - --, ~---------------¡--~~_!.~_!_-t-!!~-~~_P'!_I_~ L_--________--L_~_~_!.~~__L!l_~~_p'~_I_J L----------___L-~~-!5~_I!._+--~!~-~~-p'~-'--1 i---------------!--~-~_!'!~_!_+-~!~-~~-p'~-'_-~ t---------------t--~~_!.!~~--t-~!~-~~-P.~!-1 L__- - - -- - -.. --- --......- ----- ----.. ----'--- - -- --- -.. - -----" I I , f J : : I I::::::::::::::!:::::::::::~!:::::::::::::::¡ I I , , ,--- - --- -- - - - --t- --- - --- -- - --t-- - - - ---- - --- - --1 r--- ----- -- -- ---t - -- --- ----- - - -t----- --- - - - - ----1 I I I I ~_!!f_~!_!.'!_!'.~~+----------____S¡H_~!_~~!.~_~!!~~E I 0.0 min 2,460 psi I 1----- -.- - ~- -- -t- - ------ ---- - - ---- - --- - - --- - --~ L---~.:õO -~l0.--.¡.---------___-_l_~!~-~~-p.~-rl -~ I L.. mm I t' £,4vu pI I ~ --------- - - - --t - ----- --- ---- - ---- ------ -- - ---~ ~---~.:Q-~~~--+--------------+-~!~-~~_P.~-'--~ L_--~.:Q_~10.__1______-_--____L~!~-~~_p'~_I__l L__?.:Q_~lD..__+__------------+-~!~-~~-p'~_I-.l ~--_?.:Q-~~D.._-~--------------+-~!~-~~-P.~-'--i t~=~~~~~m=t~~~~~~~~~~~~~!~~~~~~~~:~~:J L-~.:Q. ~1D..__+--_-----------+-~!~-~~-p.~-,_.J ~--~g.:Q-~!~-+--------------~-~!~_~~_P-~L~ ~--~-~.:Q-~~~-+--------------¡-~!~_~~_I!~L~ L_?g.:Q_~!~_L--___---_____L~ð_~~_p.~Lj L?_~.:Q~!~_-1-------------t-~!~_~~_P.~L{ L_~_~.:Q_~!~_i______---------~!~_~~_p.~LJ ~- NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~" ,( NOTE TO FILE PPCo Application for Annular Disposal Meltwater 2P-417... PTD 201-069 Phillips has made application requesting approval for annular disposal (AD) on their first Meltwater well, 2P-417. The information provided by PPCo indicates that the casing was successfully run and cemented, although there is no clear statement that cement was circulated to surface. The data provided by PPCo for the initial leak off test is little confusing. It is indicated that the test was conducted with a total of 50' of hole below the casing shoe, but with only 2' of new hole drilled. The pressure trace is rock solid at 16.0 ppg EMW. I discussed this with the engineer and he indicated that a ledge had been encountered while running the last joint of casing and it had not proven possible to work the casing past it. The casing was therefore set 48' off bottom and cemented. It does appear that only 2' of new hole was drilled prior to conducting the LOT. I feel additional hole should have been drilled prior to conducting the test. On further discussion, the engineer indicated that the pressure response was similar to that seen in the Tarn area as well as the LOT conducted on the second Meltwater well 2P..438. I requested that PPCo provide the surface casing LOT for the second well, 2P-438 as well as the drilling reports when the casing was run. These are included in the packet. According to the information provided for 2P438, sufficient new hole was drilled prior to conducting this test. The pressure trace is nearly identical to that of 2p..417 and shows only a minor pressure decline during the observation period. PPCo provided a subsequent LOT that was performed while drilling the 8...112" hole. This test was conducted prior to entering the target zone. It is clearly indicated that the formation accepted fluid at a nearly constant EMWof 12.2. Due to the low number of strokes required to achieve pump in, it is difficult to see the pressure break. Looking at the pressure decline, the pressure drops quickly to 275 psi and only experiences 25 psi additional drop through the observation period. I asked the engineer if additional information was available from the freeze protection operation. He located and faxed the drilling report from the operation. No pressure plot was prepared. It is stated on the report that the formations open between the surface casing shoe and TOC accepted the flush and diesel volumes at 12.2 EMW. I believe that the provided information indicates that the casing is well cemented and that any fluid disposed of will be accepted by open hole sections likely well below the surface casing shoe. I recommend approval of Phillips application. ~~ T~nder, PE Petroleum Engineer AOGCC ( June 1, 2001 Shallow Water Salinity 2P-417 Tom: In 2P-417, annular disposal should be allowed because: 1. the TDS content of the water at and below the casing shoe can be reasonably expected to exceed 3,000 PPM, and 2. this water does not now serve as a source for a public water system, and it cannot reasonably be expected to be a source in the foreseeable future. Best evidence to date indicates that the TDS of formation water at and immediately below the casing shoe in Meltwater 2P-417 will lie in the range of about 6,000 PPM. Shallow well log data is scarce in this portion of the North Slope. In support of the Meltwater AIO application, Phillips' petrophysicist analyzed logs from the Kalubik 1, Colville River State 1, Cirque 2 and Tarn 2N-349 wells. Of these, the Cirque 2 is closest to 2P-417 (5 miles to the north) followed by Tarn 2N-349 (9 miles to the north). In Cirque 2, salinities beneath the permafrost calculated to be 2,500 to 5,400 PPM at 1,450 feet depth based on Rwa and SP techniques, respectively. In 2N-349, calculated salinities are 4,500 PPM and 6,900 PPM at 1910 feet using Rwa and SP. The difficulty with log analysis in this area is that gas hydrates occur in the shallow part of the geologic section. Hydrates increase apparent formation water resistivity values and suppress SP response, both of which yield lower calculated water salinity values than are the actual case. Based on this, Phillips believes the salinity to be 6000 PPM under the permafrost increasing to 21,000 PPM below 2,200 feet, and I think their estimates are reasonable. I am currently trying to ascertain whether shallow resistivity and porosity logs were run in the 2P-438 well. If so, I will examine them and calculate TDS values as quickly as possible. ,~- . Steve DaVIes Attachment: Attachment 13 (Aquifer Exemption) to the Meltwater Area Injection Order Public Testimony ~: ~. Meltwater Area Injection Order Attachment 13 20 AAC 25.402 (c)(13) Aauifer Exemotion The proposed Meltwater pool lies just south of the current Kuparuk River Unit (KRU) exemption area established by the EPA on May 11, 1984 (see Attachment 13A). An extension of the existing KRU Aquifer Exemption Area is being sought. Analysis of all available data indicates there are no potential fresh water sands suitable for human consumption in the proposed Meltwater injection area. No porosity logs were acquired in the surface portion (above approximately 1900' tvd subsea) of the Meltwater North wells. ' Wells in the general vicinity of the proposed Meltwater injection area (Le., Kalubik #1, Colville River St. #1, Cirque #2 and 2N-349) were analyzed for fresh water acquifers using the SP Technique and the RWapparent Technique. (The RWapparent Technique is referred to as the Resistivity-Prosity Technique, or "RP", in EPA literature.) Both are well known techniques within the industry. Discussion is provided below on the limitations of each method and the associated salinity estimates. Two of the wells (Kalubik #1 and Colville River St. 1) are outside the existing KRUand Alpine Aquifer Exemption Areas. The third well (Cirque 2) is located within the KRU Aquifer Exemption Area. The following table is a list of salinity calculations for the sand underneath the permafrost. Calculated fluid resistivities are corrected to 75° F and salinity numbers are in NaCI equivalent, or total dissolved solids (TDS). Kalubik #1 Colville River St 1 Cirque 2 2N-349 Rmf= 1.19 Q-m@ 69° Rmf = 2.52 Q-m @ 68° Rmf = 2.28 Q-m @ 85° Rmf = 3.3 Q-m @ 63° Permafrost @ 1510' Permafrost @ 1360' Permafrost @ 1170' Permafrost @ 1310' Sand @ 1740'-90' Sand @ 1510'-20' Sand @ 1440'.60' Sand @ 1905'-15' c:þ = 36 Rt=12Qm <I> = 36 Rt =2.1 Om <I> = 34 Rt = 26 Om <1>=31 Rt=10Qm Rwa = 1.09 Om Rwa = 0.24 Om Rwa = 2.1 Om Rwa = 0.8 Om (5.3 Kppm) (28 Kppm) (2.5 Kppm) (6.9 Kppm) SP = -35 mv (@ 35°) SP = -40 mv (@ 34°) SP = -20 mv (@ 35°) SP = -20 mv (@ RwSP = 0.38 Om RwSP = 0.5 Om RwSP = 1.03 Om 44°) (15 Kppm) (20 Kppm) (5.4 Kppm) RwSP = 1.19 Om (4.5 Kppm) Hole badly washed Zone slightly shaly. Hydrates known .SP Hydrates below out. SP probably Salinities quite high. more representative Permafrost R wa more representative. though still too low. more representative. Meltwater Area Injection Order Page 26/32 '(, ¡'" \ In the Kalubik and Cirque wells, average resistivities drop dramatically below these sands, indicating much saltier waters. In the Colville well, the high salinities begin at the base of permafrost. 2N-349 Base Permafrost picked at 1310' with the section below interpreted to be hydrate bearing. This is supported by a shallow gas sample log obtained in the 2N-305 well (see Attachment 13B). Shale resistivities suggest salinities in the 6-10 kppm range. Rwa in the sand at 1910' calculates TDS of 6.9 kppm. This section of the well has wireline logs to 2330' with LWD below that. LWD resistivity decreases systematically below 2400', implying an increase in salinity below that depth. There are no appreciable sands present below in which to verify this salinity, though estimates from the shales would suggest salinities of 20+ kppm TDS. Included as Attachment 13C is a plot of Rwa versus depth for the shallow portion of this well. Kalubik Water salinities below permafrost are estimated to be in the 10-12 Kppm range (TDS), increasing to 25 Kppm below 1950'. An analysis of a water sample from Albian aged sands (5050-5250') in this well tested 24.3 KPPM TDS. Colville River St. 1 Salinities below permafrost are approximately 25 Kppm TDS. Cirque 2 Under permafrost, salinities are 6+ Kppm increasing to 21 Kppm below 2200'. The sand immediately below the permafrost is believed to contain gas hydrates. This causes log based salinity calculation results to be too low. None of the wells exhibit decreased salinity below these depths. Meltwater Area Injection Order Page 27/32 Attachment 138 Tarn 2N-305 Shallow Cuttings Samples TARN 2N-305 SHALLOW CUTTINGS GAS SAMPLES CO2 C2 C3 iC4 iC5 nC5 C1/C2+ C3 iC4/nC4 IC5/nC5 C6 nC4 neoC5 C1 0 3000 ~~~~~tb~~~~~'o~~~~~ uUL O:'~C> uUL §8§§8 C>8~§~ C>~~~~ê o_~~~ ~ g <0 r- ~ § 8 :?! 8 uLfL uL L uLlL uL,'L N uUL ~~~N~ 0 ~ ~ uLiL ~ ~ c)........NC"')~O"'=l"CO("\J ci Ó ~ a--NM OC'\.l~(,QCC uUL Meltwater Area Injection Order Gas Hydrates -- Page 29/32 ~' ( Attachment 13C Rwa vs. Depth for 2N-349 ¡:- W lI!iDO W ~ :r: 17 DO t- o. w 18{10 C Meltwater Area Injection Order t2D[] 13DO 1400 IWO 19ÜO 20DO 2100 22[10 10 q 0 RWA I DEPTH Crossplot Well: 2N-349 ~2 00 ,0.2200.0 fEE fbr: RHO B <2 22 ..- 0 q I() RWA@75 (OHMM) 0 . ~&~",I,¡'¡,'~\~1:~,!{~,)'\~GiIII- _"~\;-:;:':t'::, Color: VS H Page 30/32 rf. it' ~Vffi1VŒ (ID~ ~~~~~~ AIfASIiA ORAND GAS CONSERVATION COJDIISSION J ames Trantham Drilling Engineering Supervisor Phillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 Kuparuk River Unit 2P-417 Phillips Alaska Inc Permit No: 201-069 Sur Loc: 891' FNL, 2061' FWL, SEC. 17, T8N, R7E, UM Btmhole Loc. 877' FNL, 2252' FWL, SEC. 17, T8N, R7E, UM Re: Dear Mr. Trantham: TONY KNOWLES, GOVERNOR 333 w. -¡TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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 úam 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 confirmed 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 2P pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit 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. I( ~ ¡I' Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, d--uJ:..Ù:.. Ivt.. ~U?'~~- Julie M. Heusser Commissioner BY ORDER OF THE ÇOMMISSION ..,~ -P f..... DATED this u' - day of April, 2001 jjcÆnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. t! ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1 a. Type of work: Drill 0 Redrlll 0 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil 0 Re-entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 0 2, Name of Operator 5. Datum elevation (OF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 80 feet 3. Address 6.Pro~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 AD , Meltwater Pool 4. Location of well at surtace 7. Unit or property Name 11. Type Bond (see 20 AAC 25,0251) 891' FNL, 2061' FWL, Sec. 17, T8N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 877' FNL, 2252' FWL, Sec. 17, T8N, R7E, UM 2P-417 #59-52-180 At total depth 9. Approximate spud date Amount 877' FNL, 2252' FWL, Sec, 17, T8N, R7E, UM May 1, 2001 $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) 877' @ TO feet none feet 2560 5992' MD 15980' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 2000 MD Maximum hole angle 8° Maximum surface 1940 psig At total depth (TVD) 2549 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Include stMe data) 42" 16" 62.5# H-40 welded 80' 30' 30' 110' 110' 9 cy High Early 12.25" 9.625" 40# L-80 BTC, ABmoc 2370' 30' 30' 2400' 2398' 370 sx AS Lite & 190 sx Litecrete 8.5" 7" 26# L-80 BTC, ABmoc 5301' 30' 30' 5331' 5319' 480 sx Class G 8.5# 4.5" 12.6# L-80 IBT, ABMod 661' 5331' 5319' 5992' 5980' 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 RECE~ Production Liner APR 1 1 2001 Pertoration depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Dlverter Sketch 0 Drilling program 0 Drilling fluiq program 0 Time vs depth plot DRefractlon analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby certi' that the for.~true and correct to the best of my knowledge Questions? Tom Brockway 263-4135 Signed ~ /LULS , $~ -nUs: DriHing Eng;,...ring Supe",;"" Date 11 A-f cL 'Z.1ðD1 a s rantham ~ hv _~h~rnn 1J/lC:/ln-Dr::l/a. Commission Use Onl~ Permit Number b 7 API number APpro;f~ 7 ' 0 / See cover letter ~O/.... 0 50-/ð3- zo 3 75 for other requirements Conditions of approval Samples required 181 Yes 0 No Mud log required I~ Yes 0 No Hydrogen sulfide measures 0 Yes ~ No Directional survey required ~ Yes 0 No Required working pressure for BOPE D2M; ~~ 0 5M; 0 10M;D 0 Other: ORIGiNAl SIGNED BY by order of ~é)I' Ô I Approved by .1M/g. Commissioner the commission Date Form 10-401 Rev. 12/1/85. ORIGINAL Submit in triplicate ( APP~' 'ion for Permit to Drill, Well 2P-417 Saved: 11-Apr-01 Permit It - Meltwater 2P- 417 Application for Permit to Drill Document MClximizE Well Vglu~ Table of Contents 1. Well Name... .... ... ....... ....... ... .... ... .... ..... .... .... .... ........ ...... ... ... ... ......... .......... ......... .......3 Requirements of 20 AAC 25.005 (f)....... ............. ......... ........................ ......... ................... .......................3 2. Location Summary.. ... ... ... ........ ...... ....... ... ..... .......... ...... ........ ....... .................. ..... .....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. Dri II i ng 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 I nformati on ..... ............................... ........... ................................ .... 5 Requirements of 20 AAC 25. 005( c)(7) ............................ '''''''''' .............. ...............................................5 8. Dri II i ng FI u id Program ........... .... ........ ............... ........ ..... ...... ............. ............... ........ 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 10. Seismic Analysis ............... ..... ... ......... .... ..... ..... ......... ..... ..... ..... ....... ...... ..... ....... ... ....6 Requirements of 20 AAC 25.005 (c)(1O) . ............. ............ ................ ....... .......... ................. .................... 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bondi ng.. ...... ........ ................ ..... .......... ........... ... ............ ........ ..... ...... ....6 Requirements of 20 AAC 25.005 (c)(12) ..................................... .......................... .......... ....................... 6 2P-417 PERMIT IT 4-11-01.doc Page 1 of 7 Printed: 11-Apr-01 ( APP~~ Lion for Permit to Drill, Well 2P-417 Saved: 11-Apr-01 13. Proposed Dri Iii ng Program...... ... ............. ...... .... ... ......... ... ... ....... ..... ... ..... ........... .....6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................ ................. ....................................... ."..... 7 15. Attachments .... .... ....... ... ............ ........ ......... ... .... ............ .............. .... .......... ... ..... ....... 7 Attachment 1 AOGCC Form 10-401 (Front of permit package) ............................................................7 Attachment 2 Directional Plan. .............. ............."... .......... .................................................... ..........,...... 7 Attachment 3 Doyon Rig 141 BOP Schematic ......................................................................................7 Attachment 4 Drilling Hazards Summary................................. ...... ...................................., ................... 7 Attachment 5 Doyon Rig 141 Diverter Schematic .................................................................................7 Attachment 6 Doyon Rig 141 Fluid System Components ..................................................................... 7 Attachment 7 Well Schematic................................................ ................................................................ 7 2P-417 PERMIT IT 4-11-01.doc Page 2 of 7 Printed: 11-Apr-01 ( APP~ <;on for Permit to Drill, We1l2p.417 Saved: 11-Apr-01 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branche~ 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-417. 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~ owners and showing (A)the coordinates of the plvposed 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 oftl7e well at tl7e surface, referenced to the state plane coordinate !iy~.tem 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 1 891' FNL, 2061' FWL, Sec 17, T8N, R7E, UM NGSCoordinates I RKB Elevation: 255.0 ft AMSL Northings: 5868985.943 Eastings: 444021.176 Pad Elevation: 225.0 ft AMSL Location at Top of Productive Interval Bermuda Formation NGS Coordinates Northings: 5868998.0 877' FNL, 2252' FWL, Sec 17, T8N, R7E, UM Eastings: 444213.0 5431 ' 5164' 5419' Location at Total De th NGS Coordinates Northings: 5868998.0 Eastings: 44213.0 and (D) other ¡¡1formation required by 20 AAC 25~050{b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect the application for a Permit to Drill (Form .10-40.1) must (1) include a plat~ drawn to a !iuitable scale, showing the path of the proposed wellbore, including all adjacent wellbores witf1in 20{) feet of any portio{) of the propO!ied well; Please see Attachment 2: Directional Plan and (2) for all wells within 200 feet of the proposed wellbOle? (A) list the names of the operators of those well.$¡ to the extent that those names are known or discoverable 1/1 publiC records, 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. 2P-417 PERMIT IT 4-11-01.doc Page 3 of 7 Printed: 11-Apr-01 APpr "on for Permit to Drill, Well 2P-417 Saved: 11-Apr-01 3. Blowout Prevention Equipment Information Requirements of 20 MC 25.005(c)(3) An application for a PermIt to Drill must be accompanied by each of the following Items, except for an item a/ready on file with the commission and Identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 AAC 25.036, or 20 MC 25.03~ as applicable; Please see Attachment 3: Doyon Rig 141 BOP Schematic 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a PermIt to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum down/70/e pressure tl7at may be encountered" crIteria used to deter/mi7e i~ and maximum potent/~J/_t;urface pressure based 017 a methane gradient~. The expected reservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.46 psi/ft, or 8.5 to 8.9 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. 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 1940, calculated as follows: MPSP =(5541 ft)(0.46 - 0.11 psi/ft) =1940 psi Assuming a leak off of 15.9 ppg (0.83 psi/ft) based on open hole LOT results from offset Meltwater exploration wells, formation breakdown at the surface casing shoe (2399'lVD) can be expected to occur at 1992 psi. Therefore, the MPSP may be based on the maximum pressure gradient as calculated above. (8) data on potenl1~11 gas zones; No potential gas zones have been identified along the planned 2P-417 well path. and (C) data conceming potential causes of hole problems such as abnormally fJeo-pres..c:,'Ured stratal lost circulation zones~ and zones that 17iwe a propensity for differe(}tÜ~1 stk*ing; Please see Attachment 4: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application far a Permit to Drill must be accompanied by each of the following items, except for an itl.'H71 already on file with the commis.':;ion and Identified in the application: (5) a desaiption of the proædure for conducting fOI7Tøtio(] integrity test5~ as' required under 20 AAC 25.0JO(f); 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 the fo/lowing Items¡ except for an item already on file with the commission and identified in the application: (6) a complete proposed ca~1ng and cementing program as required by 20 AAC 25.0301 and a description of any slotted line/; pre- perforated liner, or screen to be in!:J1alled; 2P-417 PERMIT IT 4-11-01.doc Page 4 of 7 Printed: 11-Apr-01 APP~ "')n for Permit to Drill, Well 2P-417 Saved: 11-Apr-01 Casina and Cementing Program Hole Top Btm CsgfTbg Size Weight Length MDfTVD MDfTVD OD (in) (in) (Ib/ft) Grade Connection (ti) (ft) (ft) Cement Proqram 30 X 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 9 cy High Insulated Early 9-5/8 12-1/4 40.0 L-80 BTC,AB 2370 30 / 30 2400 / 2398 370 sx 10.7 Modified ppg AS3 Lead, 190 sx 12.0 ppg LiteCrete Tail Planned Top of Cement: Su rface 7 8-1/2 26.0 L-80 BTC,AB 5301 30 / 30 5331 / 5319 480 sx 15.8 Modified ppg Class 'G' 4-1/2 8-1/2 12.6 L-80 IBT, AB 661 5331 / 5319 5992 / 5980 Planned Top of Mod Cement: 4831' MD 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit tv Dnll must be accompanied by eaL17 of the tollowing item~ except for an item already on file with tfle commis..sion and identified in the application: . (7) a diagram and desaiption of the diverter system as required by 20 AAC 25.035; unless this- requirement is waived by the commission under 20 AAC 25.035(17)(2)/ Please See Attachment 5: Doyon Rig 141 Diverter Schematic. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application fvr a Perrl7lt tv Drtl/ must be ðccompanied by each of the following item~ except fÒr an item a/reðdy on file with the commi.5sion and identtfied in the application: (8) a dlilling fluid programl including a diagram and des-cTiptio/7 of the dl1Jlinfj fluid sys-tern as required by 20AAC25:033; Water based drilling fluid systems will be utilized to drill this well from spud to TO. These systems will be built and maintained to the following specifications: Spud to 9-5/8" 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 9.8 9.4 9.8 9.8 9.8 Funnel Viscosity 80 100 50 65 50 65 (seconds) Yield Point 35 45 10 25 20 30 (cP) Plastic Viscostiy 13 21 6 14 6 14 (Jb/100 sf) 10 second Gel 10 15 2 6 4 7 Strenqth (lb/100 sf) 10 minute Gel 15 40 4 8 4 8 StrenQth (lb/100 sf) pH 9.5-10 9.5-10 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5 API Filtrate(cc) <15 <15 <6 <6 8-10 8-10 2P-417 PERMIT IT 4-11-01.doc Page 5 of 7 Printed: 11-Apr-01 APP(; ~jon for Permit to Drill, Well 2P.417 Saved: 11-Apr-01 Please See Attachment 6: Doyon Rig 141 Fluid System Components 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already 017 file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well; a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory of stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a PermIt to 0/7/1 must be accompanied by each of the following Item~ except for an item already 017 file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory of stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Pel7mt to 0/7/1 must be accompanied by each of the following Item5~ except for an Item already on file with the commission and identified in the application: (11) for a well drilled from an off:,l1ore platform, mobile bottom-founded structure,jack.up rig, or floating drilling vessel an ana/ysi'i 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 following Items, except for an item already on file with ttle commiS5ion and identlfìed in the app/k<.1tion: (12) evidence showing that the requkements of20 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 Dnll must be accompanied by each of the followlng items, except for an item already on file witl7 t/1e commiss1on and identif¡ed in the application: The proposed drilling program is listed below. Please refer as well to Attachment 7: Well Schematic: 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 1101 RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon 141. Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/ 2400 MDI) according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. 4. Run and cement 9-5/8" 40.0# L-80 BTCM 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. 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 2P-417 PERMIT IT 4-11-01.doc Page 6 of 7 Printed: 11-Apr-01 (' APP~' Lion for Permit to Drill, Well 2P-417 Saved: 11-Apr-01 6. Shut in BOP's and pressure test casing to 2500 Dsi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. 8. Directionally drill 8-1/2" hole to top Bermuda (5430' MD) according to directional plan. Run MWD I LWD logging tools in drill string for directional monitoring and formation data gathering. Circulate and condition hole. POOH. 9. Swap to bland core fluid and rotary core to the base of the Bermuda interval. POOH and lay down core. ~ \~a't-I'~~CJ~ 10. RIH with drilling BHA and drill 8-1/2" hole to well total depth (+/- 5992' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH. 11. Run open hole e-line or drill pipe conveyed logs as needed. 12. Run and cement 7" 26.0# L -80 BTCM x 4-1/2 12.6# L -80 BTCM tapered production casing string with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' above the planned top perforation. 13. Run and land 4-1/2" tubing. Displace well to completion brine. 14. 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. 15. Freeze protect well. Set BPV. Release rig and turn well over to production. 16. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to 017// mU!:>7:C be accompanied by each ot'the following Items, except for an Item already on file with the commission ami identified in t/](,; application: (14) a general description of how tl1e operc:Jtor plans to dispo::.è? of drilling mud and cuttings and a statement of whether the operator intend~ to request authorization under 20 AAC 25:080 for an annular dLt;posal operation in the wel/.,; Waste fluids generated during the drilling process will be hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, a request will be submitted for 2P-417 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 Doyon Rig 141 BOP Schematic Attachment 4 Drilling Hazards Summary Attachment 5 Doyon Rig 141 Diverter Schematic Attachment 6 Doyon Rig 141 Fluid System Components Attachment 7 Well Schematic 2P-417 PERMIT IT 4-11-01.doc Page 7 of 7 Printed: 11-Apr-01 Vertical Depths are reference rotary toble. ~t; ~ ~ 0 400 800 1200 1600 ,,--..., -+- Q) 2000 Q) '+- ............ ..c 2400 -+- 0.. Q) 0 2800 0 Ü -+- 3200 L Q) > Q) 3600 :J L I- I 4000 V 4400 4800 5200 5600 6000 400 Base Permafrost Base W Sak KOP 2,00 4.00 X l 6.00 ~~~o 9 5/8 C-so Begin Drop 7.50 C-40 6.00 4.50 C-37 3.00 1.50 EOD ( Well: 417 :Phillips Alaska, Inc. Field: Meltwater Location: North Slope, Alaska Structure: Drill Site 2P --. -------.-----.------- -.-..-...--.-.-- 25 0 25 50 ESTIMATED SURFACE LOCATION: 891' FNL, 2061' FWL SEC. 17, T8N, R7E (f- oc,'<.. <:<,'<..\0 «,o"~'*" Gc,o, <:<,e.\. '? \'ò 'òC) C)« c,e. c,e. ~ Go' 85.97 Az 't '0°<?)0 ~ ~ -.;¡ DLS: 2.00 deg per 100 ft Csg PtjEOC TANGENT ANGLE 8 DEG DLS: 1.50 deg per 100 ft FINAL ANGLE "VERTICAL" T4,1 (Cairn) 13 (Top Bermuda) Target-Bermuda MidPt T2 ,Base Bermuda) C35 (Top Albian) j l TO - Csg pt 0 400 800 1200 1600 2000 Vert i c a I See t ion (f e e t ) - > Azimuth 85.97 with reference 0.00 N, 0,00 E from slot #417 .__.__._---_.._-_......_--_...._-~---_.--~--_...._.__.. ------.-.- East (feet) -> 75 100 125 150 175 200 225 250 275 300 75 125 100 75 oç blC) <::}G' ¿y,<::- <?)e. 'ò<:<,'<.. =::ì ~~ èI .;Þ~òo «,-0~i:\ . ,(;\ e.'<"'<" <?)e.' 0-~ <:<,'<.. 0' '<Ö <Qe. e. R 0, lSj'oç.¿ 0<:> ,,\0 G<:> R) " \2' "e. ~ (... '- , ~C),\bI-\,,:> ,\o':(r¡, G"j~<:) ~ " ) I ::ï-';¡ ,":> G 25 ^ I z 0 """'i -+ :r 50 25 ,,--..., - CD CD -+ ............ 50 100 85.97 AZIMUTH 192' (TO TARGET/TD) ...Plane of Proposal... 125 , TRUE ( ( Phillips Alaska, Inc. Drill Site 2P 417 slot #417 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 2P-417 Version#2 Our ref: prop4509 License: Date printed: 4-Apr-2001 Date created: 25-Feb-2001 Last revised: 4-Apr-2001 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 9.765,w150 26 52.717 Slot Grid coordinates are N 5868985.943, E 444021,176 Slot local coordinates are 889.91 S 2063.98 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( (' Phillips Alaska. Inc, PROPOSAL LISTING Page 1 Drill Site 2P,417 Your ref : 2P-417 Version#2 He1twater,North Slope, Alaska Last revised : 4-Apr-2001 Measured Inclin, Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 0,00 0.00 0,00 0.00 0.00 N 0,00 E 0,00 0,00 100.00 0,00 85.97 100,00 0.00 N 0,00 E 0.00 0,00 200.00 0,00 85.97 200,00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 85.97 300,00 0.00 N 0.00 E 0.00 0.00 400.00 0,00 85.97 400,00 0.00 N 0.00 E 0.00 0,00 500,00 0.00 85.97 500.00 0.00 N 0,00 E 0,00 0.00 600.00 0.00 85.97 600.00 0.00 N 0,00 E 0,00 0.00 700.00 0.00 85.97 700,00 0.00 N 0.00 E 0.00 0.00 800.00 0.00 85.97 800,00 0.00 N 0,00 E 0,00 0.00 900,00 0,00 85,97 900,00 0,00 N 0.00 E 0,00 0.00 1000.00 0,00 85.97 1000.00 0,00 N 0.00 E 0.00 0.00 1100,00 0.00 85,97 1100,00 0,00 N 0,00 E 0,00 0,00 1200,00 0.00 85,97 1200.00 0,00 N 0.00 E 0,00 0,00 1300.00 0,00 85,97 1300.00 0.00 N 0.00 E 0.00 0.00 1400.00 0.00 85.97 1400.00 0,00 N 0.00 E 0,00 0.00 1455.00 0,00 85,97 1455,00 0.00 N 0,00 E 0.00 0.00 Base Permafrost 1500.00 0.00 85.97 1500,00 0,00 N 0.00 E 0.00 0,00 1600.00 0.00 85.97 1600.00 0.00 N 0.00 E 0.00 0,00 1700,00 0.00 85,97 1700.00 0.00 N 0.00 E 0.00 0.00 1800,00 0.00 85,97 1800,00 0,00 N 0.00 E 0.00 0,00 1835,00 0.00 85,97 1835,00 0.00 N 0,00 E 0,00 0,00 Base W Sak 1900.00 0.00 85.97 1900,00 0.00 N 0,00 E 0,00 0.00 2000.00 0.00 85.97 2000,00 0.00 N 0,00 E 0,00 0.00 KOP 2100.00 2.00 85.97 2099,98 0.12 N 1. 74 E 2.00 1. 75 2200.00 4,00 85,97 2199,84 0.49 N 6,96 E 2,00 6.98 2300,00 6.00 85,97 2299,45 1,10 N 15.65 E 2.00 15.69 2400,00 8,00 85,97 2398,70 1. 96 N 27.81 E 2.00 27,88 2400,13 8.00 85,97 2398.83 1. 96 N 27.83 E 2.00 27.90 9 5/8" Csg Pt/EOC 2500,00 8.00 85.97 2497,73 2,94 N 41.70 E 0,00 41. 80 2507,34 8.00 85.97 2505,00 3.01 N 42.72 E 0.00 42.82 C-80 3000.00 8,00 85.97 2992,86 7.84 N 111,14 E 0,00 111. 41 3038.52 8,00 85,97 3031.00 8.21 N 116,48 E 0,00 116.77 C-50 3313.27 8,00 85.97 3303.07 10.90 N 154.64 E 0,00 155.02 Begin Drop 3346.78 7.50 85,97 3336.28 11 . 22 N 159,15 E 1. 50 159.54 3377,75 7,04 85,97 3367.00 11.50 N 163,06 E 1. 50 163.46 C-40 3446,78 6.00 85,97 3435.58 12,05 N 170.87 E 1. 50 171.30 3546,78 4.50 85.97 3535.16 12,69 N 180.00 E 1. 50 180.45 3580.71 3.99 85,97 3569,00 12,87 N 182,51 E 1. 50 182.96 C-37 3646,78 3.00 85.97 3634.94 13,15 N 186.52 E 1. 50 186.99 3746.78 1. 50 85.97 3734.86 13 ,43 N 190.44 E 1.50 190.91 3846,78 0.00 85.97 3834,85 13 ,52 N 191.75 E 1.50 192,22 EOD 4000.00 0.00 85.97 3988,07 13 .52 N 191.75 E 0.00 192,22 4500.00 0,00 85.97 4488,07 13.52 N 191.75 E 0.00 192,22 5000.00 0,00 85.97 4988,07 13 ,52 N 191.75 E 0.00 192 ,22 5224.93 0,00 85.97 5213 ,00 13 .52 N 191. 75 E 0.00 192,22 T4.1 (Cairn) 5430.93 0.00 85.97 5419,00 13.52 N 191. 75 E 0.00 192,22 T3 (Top Bermuda) 5491. 91 0,00 85.97 5479,98 13 .52 N 191.75 E 0.00 192,22 Target-Bermuda MidPt 5491. 93 0.00 85,97 5480,00 13.52 N 191. 75 E 0.00 192.22 MW(G) Rvsd 3-Apr-01 5500,00 0,00 85.97 5488.07 13.52 N 191.75 E 0.00 192,22 5552.93 0,00 85,97 5541. 00 13 .52 N 191. 75 E 0.00 192.22 T2 (Base Bermuda) All data is in feet unless otherwise stated. Coordinates from slot #417 and TVD from rotary table (255.00 Ft above mean sea Bottom hole distance is 192,22 on azimuth 85.97 degrees from wellhead. Total Dogleg for wellpath is 16,01 degrees, Vertical section is from wellhead on azimuth 85.97 degrees, Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ( { Phillips Alaska, Inc. Drill Site 2P,417 Heltwater, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: 2P-417 Version#2 Last revised: 4-Apr-200l Heasured Inclin. Azimuth True Vert Depth Degrees Degrees Depth R E C TAN G U L A R COO R DIN ATE S Dogleg Deg/100ft Vert Sect 5636.93 5991. 93 0.00 0,00 85.97 85.97 5625.00 5980.00 13 ,52 N 13 ,52 N 191. 75 E 191. 75 E 0.00 0.00 192.22 C35 (Top Albian) 192.22 TD - Csg Pt All data is in feet unless otherwise stated. Coordinates from slot *417 and TVD from rotary table (255.00 Ft above mean sea Bottom hole distance is 192.22 on azimuth 85.97 degrees from wellhead. Total Dogleg for wellpath is 16.01 degrees. Vertical section is from wellhead on azimuth 85,97 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) , Phillips Alaska, Inc, Drill Site 2P.417 Heltwater,North Slope. Alaska MD TVD Rectangular Coords, \ PROPOSAL LISTING Page 3 Your ref: 2P-417 Version#2 Last revised: 4-Apr-2001 Comments in wellpath -- ---- --------- ----- ----- ----- ----- ----- - --- - ---- - -- - - -- -- - -- -- - ----- -- -- ------------ - ----- ---- - -- -- ------ - - - -- - ------ - ----- - - - - -------- -- --- - -- --- Comment 1455.00 1835,00 2000.00 2400,13 2507,34 3038,52 3313 .27 3377.75 3580.71 3846.78 5224,93 5430.93 5491. 91 5491. 93 5552.93 5636,93 5991. 93 1455,00 1835,00 2000.00 2398.83 2505.00 3031.00 3303.07 3367.00 3569.00 3834.85 5213.00 5419.00 5479.98 5480.00 5541.00 5625,00 5980,00 Top MD Top TVD 0.00 N 0.00 N 0.00 N 1.96 N 3.01 N 8.21 N 10.90 N 11. 50 N 12.87 N 13 .52 N 13.52 N 13 ,52 N 13 .52 N 13 .52 N 13 .52 N 13 ,52 N 13 ,52 N 0.00 E 0.00 E 0,00 E 27.83 E 42 .72 E 116,48 E 154.64 E 163,06 E 182.51 E 191. 75 E 191. 75 E 191. 75 E 191. 75 E 191.75 E 191. 75 E 191. 75 E 191. 75 E 0.00 0.00 O.OON O,OON Rectangular Coords, Base Permafrost Base W Sak KOP 9 5/8" Csg Pt/EOC C-80 C-50 Begin Drop C-40 C-37 EOD T4.1 (Cairn) T3 (Top Bermuda) Target-Bermuda MidPt MW(G) Rvsd 3-Apr-01 T2 (Base Bermuda) C35 (Top Albian) TD - Csg pt Casing positions in string 'A' ------------------------------ ------------------------------ Bot MD Bot TVD Rectangular Coords. Casing - -- -- - - - - - - - - - -- - -- - - --- - -- - -- - - - - - - - -- - - - ---- - -- -- -- - --- --- - -- --- -- - - -- - - - - -- --- - - - - - - --- - -- - - - - --- ---- - -- Target name 0.00 0.00 O.OOE 5991.93 5980,00 O.OOE 2400,13 2398.83 191.75E 7" Casing 27,83E 9 5/8" Casing 13 .52N 1.96N Geographic Location Targets associated with this wellpath T.V.D, Rectangular Coordinates Revised - ----- - --- --- - --- - - --- - - - - - -- - - ---- -- ---- - -- --- --- - --- -- -- - - - - - --- - - ------ - - --- -- - - - - - ----- ---- - - -- - - - - - - -- - - - - - - - - - -- ---- - --- - - -- - - - - - - -- - - -- -- - - - - - - - - - - - --- - - - - - -- - - - - -- - - - - - -- --- MW(G) Rvsd 3-Apr-01 444213.000,5868998,000,999,00 5480,00 13 ,52N 191,75E 22-Feb-2001 : Created by bmichoel For: T Brockway! ; Dote plotted: 4-Apr-2001 i Plot Reference is 2P-417 Version#2. , Coordinates ore in feet reference slot #417. J ¡True Vertical Depths ore reference rotary tOble.¡ ~¡¡¡ ~ """'----~_.____m___.__._---------~_-~~__m__..__----------- TNT1H~) ==== ¡ ----- Point ----- ¡ Base Permafrost IBase W Sak IKOP ¡9 5/8 CS9 Pt/EOC iC-80 iC-50 1 Begin Drop IC-40 ¡C-37 IEOD IT4.1 (Cairn) IT3 (Top Bermuda) ¡Target-Bermuda MidPt IT2 (Base Bermuda) jC35 (Top Albion) 0 MD 1455.00 1835.00 2000.00 2400.13 2507.34 3038.52 3313.27 3377.75 3580.71 3846.78 5224.93 5430.93 5491.91 5552.93 5636.93 lJJ?_--=---ç,§g-_Et_--_u_-------_u_-______5 9 -~J. . 9 3 -------------------------------------______n______-------------........----, : i ¡Phillips Alaska, Inc. ¡ Structure: Drill Site 2P Well: 417 Field : Meltwat~___L~ation : North ~~pe, Ala_~_~J ~ LE COMMEN DATA ! i == ====>' == == ! Inc Dir TVD North East V. Sect Deg/1 00 0.00 85.97 1455.00 0.00 0.00 0.00 0.00 0.00 85.97 1835.00 0.00 0.00 0.00 0.00 0.00 85.97 2000.00 0.00 0.00 0.00 0.00 8,00 85.97 2398.83 1.96 27.83 27.90 2,00 8.00 85.97 2505.00 3.01 42.72 42.82 0.00 8.00 85.97 3031.00 8.21 11 6.48 116.77 0,00 8,00 85.97 3303.07 10.90 1 54.64 155,02 0.00 7.04 85.97 3367.00 11.50 163,06 163.46 1.50 3.99 85.97 3569.00 12.87 1 82,51 182.96 1,50 0,00 85,97 3834,85 13.52 191 .75 192,22 1.50 0.00 85.97 5213.00 13.52 191 .75 192.22 0.00 0.00 85.97 5419.00 13.52 191 .75 192.22 0.00 0.00 85.97 5479.98 13.52 191 .75 192.22 0,00 0.00 85,97 5541.00 13.52 191 .75 192.22 0.00 0,00 85.97 5625.00 13.52 191 ,75 192.22 0.00 0.00 85.97 5980.00 13.52 191 .75 192.22 0.00 ___mnn__m____mmn.. .. --nm___....._m...... ". ~ -." (" Phillips Alaska, Inc. ~'-'_._~-______n_'._~._--_.- '.'-"--'-"--' ._0,----- ._--,,~.__._---..- . Created by bm;chael For: T Brockway Dole plotted: 4-Apr-2001 Plot Reference is 2P-417 Vc:rsionN2. Structure: Drill Site 2P Well: 417 Field: Meltwater Location: North Slope. Alaska Coordinates arc: in feet reference slot 1417. Vertical Depths ore reference rotary toble.' -. ',------,"u.-..---.,-..,,"-- h ---....- ---.-....--- - Eí~. ~ TNTI:Q 10 10 20 30 40 East (feet) -> 60 50 70 80 90 100 110 120 130 40 40 t 30 ,;. 700 20 ,¡.600 -$-300 600 '.>1<.. 6æ- .. J :' 30 ^ I -$390 10 ^ I z 0 -; -+ ::J 20 10 700 'I< .. ... . " 800 "J .6. 3000'.* N '701f.300 2800 2900 - - - 4- - - - - 417 ..Q.,,300 ' 0If ~OO, 2600 2~0_0 - - - 4- - - - - -.... - - -.:;:r 500 ., - -- - - - - - * 300 - - - - ~ ':':*-":;: - - - - - "*2-5ÔO- -, * :uO @ - - - - 2300 2400' "* 600 ' >I<.}OO -$-300 ,-.... -+- 0) 0) '+- '--" ..c -+- I.... 0 Z .*600 10 M ~ .* 800 , '.'>1< 700 ,-.... - (1) 10 ~ '--" 20 .>1<,700 , * .900 *.,800 20 30 '", 800 ~ . * ,1000",.900 ..~ "EÐ 30 10 0 10 20 30 40 60 East (feet) -> 50 70 80 90 100 110 120 130 East (feet) -> 100 110 120 130 140 150 160 170 180 190 200 210 220 230 40 40 500 600 700 ...S J C..300., ...J C". '..>1<' ,., J :. ,.. 30 1000 1100 30 900 "''ie' ... 412fT 700 800 .' '" ..' . 'J : >1<..600 >1<". ...>1<.. .." ^ .'2/T' ^ I 20 20 I ,-.... ''IN >I< ?(¡O 3400 3500 3600 3900 -+- - 800 3200 3~0_0 - - -.... - - - -lit- - - Ii<' - -1iI2I z 0) 0 0) 10 - - -.- - - - ~~.~~o'õ"""7.,~-:: -. - - - - * 10 -; '+- 417 -+ '--" 3000 900 1000 ::J ..c !If.. ,-.... -+- 1100 0 - I.... CD 0 '.'1<'. CD Z -+ '--" 10 . of''''/V 10 20 20 100 110 120 130 140 150 160 170 180 190 200 210 220 230 East (feet) -> :( , Phillips Alaska, Inc. Created Ðy bm;choe' For: T Brockway Structure: Drill Site 2P Well: 417 Doto p'olled: 4-Apr-2DDl Plol Reference is 2P-417 Versionl2. Field: Meltwater Location: Narth Slope, Vertical Depths are reference rotory lISiI. 8ffÐIU INTT.Q TRUE NORTH ~ c::::::J 350 0 10 340 20 330 70 30 ø 1300.- ." 320 40 ~ 1100 310 5Q ,~900 300 60 290 70 280 80 270 90 260 100 11 0 240 120 230 130 ~ 220 . .',\ 140 210" 150 "~ \it 900 200 160 1100"'. ". 190 180 170 "" '~ ~... ~ ~ ~ ~... Norma I Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ,( .,f ~ Phillips Alaska, Inc. Structure: Drill Site 2P Well: 417 Plot Reference is 2P-417 VcrsionN2. Field: Meltwater Location: North Slope, Alaska Vertical Depths orc reference rotary table., Bill'll ~ TNTI.Q TRUE NORTH ill ~ c:J 350 0 10 340 20 330 210 30 !Ii 1500 320 40 310 50 @ 300 60 290 280 80 270 90 260 100 250 240 "~O \W30 130 220 140 '!I<., 1500 ~ "/~-tr;. 210 15Ò, 200 17Q '160 1 90. \80 ' ~ ~ <& ~ ~ ~ ~ ~.. Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ( ~' Phillips Alaska, Inc, Drill Site 2P 417 slot #417 Meltwater North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: 2P-417 Version#2 Our ref: prop4509 License: Date printed: 4-Apr-2001 Date created: 25-Feb-200l Last revised: 4-Apr-2001 Field is centred on 441964.235,5869891.466,999,OOOOO,N Structure is centred on 44l964,235,5869891,466,999,OOOOO,N Slot location is n70 3 9.765,w150 26 52.717 Slot Grid coordinates are N 5868985.943, E 444021.176 Slot local coordinates are 889.91 S 2063.98 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath MW AI Version 1.a,,401/AI,Dri1l Site 2P MW J Version l,a,,420/J,Drill Site 2P MW I Version La,,415/I,Drill Site 2P MW A Version La, ,449/A,Drill Site 2P MW H Version La,,429/H,Drill Site 2P MW D Version La,,438/D,Drill Site 2P MW AN Version La, ,451/AN,Dri11 Site 2P MW C Version La, ,447/C,Dri11 Site 2P MW B Version 1.b,,445/B,Drill Site 2p MW AO Version La" 444/AO,Dri11 Site 2P MW AM version La" 443/AM, Drill Site 2P MW EVersion La" 442/E, Drill Site 2P MW F Version 1, a, ,441/F, Drill Site 2P MW AP Version 1.a,,440/AP,Dri11 Site 2P MW AL Version 1.a,,439/AL,Drill Site 2P MW AD Version 1.a,,437/AD,Drill Site 2P MW X Version La,,436/X,Drill Site 2P MW AK version La, ,435/AK,Drill Site 2P MW N Version l,a,,434/N,Drill Site 2P MW Q Version La, ,433/Q,Drill Site 2P MW R Version La, ,432/R,Drill Site 2P MW AE Version 1.a,,431/AE,Drill Site 2P MW Y Version l,a,,428/Y,Drill Site 2P MW M Version l,a,,427/M,Drill Site 2P MW 0 Version La" 426/0, Drill Site 2P MW K Version La, ,424/K,Drill Site 2P MW Z Version 1.a, ,423/Z,Drill Site 2P MW AB Version La" 422/AB,Drill Site 2P MW L Version 1.a, ,421/L,Drill Site 2P MW AF Version La, ,419/AF,Drill Site 2P MW AC Version La, ,418/AC,Drill Site 2P MW W Version La, ,416/W,Drill Site 2P MW S Version La,,414/S,Drill Site 2P MW V Version La,,413/V,Drill Site 2P MW T Version La, ,412/T,Drill Site 2P MW U Version La, ,410/U,Drill Site 2P MW P version La,,408/P,Drill Site 2P MW AG VERSION La" 406/AG,Drill Site 2P MW AJ Version La, ,404/AJ,Drill Site 2P MW AH version La" 402/AH,Drill Site 2P PMSS <0-8935'>"MWSouth1,Meltwater South #1 PMSS <2212-7349'>, ,MWN#2A,Meltwater North #2 PMSS <0-6122' >, ,MWN#l, Meltwater North #1 Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M.D, Diverging from M,D, 24-Feb-2001 320.0 200.0 200,0 25-Feb-200l 40.5 1500.0 1500.0 25-Feb-2001 40,0 100.0 100,0 23-Feb-2001 640,1 400,0 400,0 25-Feb-2001 240,0 300.0 300.0 23-Feb-2001 420,0 300.0 300,0 23-Feb-2001 680,1 400,0 400.0 23-Feb-2001 600.1 500.0 500.0 23-Feb-2001 560,1 400.0 400.0 23-Feb-2001 540,1 200.0 200,0 23-Feb-2001 520,0 500,0 500.0 23-Feb-2001 500.0 500,0 500.0 23-Feb-2001 480.0 700.0 700,0 23-Feb-2001 460.0 200.0 200.0 23-Feb-2001 440.0 200.0 200,0 23-Feb-2001 400.0 200.0 200,0 23-Feb-2001 380,0 2000,0 2000,0 23-Feb-2001 360,0 200.0 200,0 25-Feb-2001 340,0 300,0 300,0 25-Feb-2001 320.0 200.0 200.0 25-Feb-2001 300.0 700.0 700.0 25-Feb-2001 280.0 100,0 100,0 25-Feb-2001 220,0 400.0 400.0 25-Feb-2001 185,2 1000.0 1000.0 25-Feb-2001 178.2 700.0 700.0 25-Feb-2001 137,8 600,0 600,0 25-Feb-2001 118.1 800.0 800,0 25-Feb-2001 92.8 800.0 800.0 25-Feb-2001 73,9 600.0 600.0 25-Feb-2001 35.1 600.0 600.0 25-Feb-2001 16,3 600,0 600,0 24-Feb-2001 20,0 200,0 200,0 25-Feb-2001 60.0 300,0 1700.0 24-Feb-2001 80.0 200,0 200.0 24-Feb-2001 100.0 200,0 200,0 24-Feb-2001 140,0 200.0 200,0 24-Feb-2001 180.0 200.0 200,0 24-Feb-2001 220,0 100,0 100.0 24-Feb-2001 260,0 200.0 200.0 24-Feb-2001 300,0 200.0 200,0 6-Mar-2001 47044.0 5991,9 5991,9 26-Feb-2001 969,5 5800,0 5800.0 26-Feb-2001 6718.9 1900,0 4100.0 { Phillips Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS (' 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER wI companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP wI pipe rams on top and blind rams on bottom 3" 5,000 psi WP Shaffer GATE VALVE ~raUliC actuator ~ CHOKE LINE ~ 3" 5,000 psi WP OCT ~ MANUAL GATE VALVE 13-5/8" 5,000 psi WP DRilliNG SPOOL wI two 3" 5M psi WP outlets Kill liNE 3" 5,000 psi WP OCT MANUAL GATE VALVE 3" 5,000 psi WP Shaffer GATE VALVE wI hydraulic actuator I DSA 13-5/8" 5,000 psi WP ~ X 11" 5,000 psi WP I~ SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP wI pipe rams ( ( 2P-417 Drilling Hazards Summar'l (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/411 Hole /9-5/8" Casina Interval Event Conductor Broach Well Collision G ravel and sand slou hin Shaker/Trough Cuttings S stem Overflow Permafrost Hydrates Shoe Fractu re/Lost Returns during cement 'ob Risk Level Low Low Low Low Moderate Low Controlled drilling, reduced pump rates, higher mud weights, lower viscosities, and lecithin additions as needed Reduced pump rates, and lightweight tail cement 8-1/2" Hole /7" x 4-1/2" Casina Interval Event Lost Circulation in Bermuda interval High ECD and swabbing if higher MW is re uired Hole stability during coring and e-line runs Risk Level Low Low Moderate Miti ation Strate Good drilling practices. LCM as needed. Possible PBL sub on corin assembl Pumping and rotating out on all trips to reduce swab and barite sag potential. Emphasis on maintaining mud properties. Clean out runs as needed. Good drilling ractices 2P-417 Drilling Hazards Summary. doc prepared by Thomas A. Brockway 04/09/01 Page 1 of 1 21 %" 2,000 psi WP DRilliNG SPOOL wI 16" Outlet ( .~hillips Alaska, Inc. Doyon 141 Diverter Schematic L Flowline f . 21 %" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER liNE 16" 62 ppf PES CONDUCTOR PIPE set at 80' (GL) It Doyon Rig 141 Drilling Fluids System Components Meltwater Phase 1 April 10, 2001 3 - Derrick Shale Shakers Desander Desilter Centrifuge Degasser Pit Level Indicator (wI visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators TAB, 4-10-01 I 12 KILL UNE CHOKE MANIFOLD ~ f '~ 5 12 DERRICK 2000 SHAKER fLOWUNE IJ JIB VENT TO OUTSIDE GAS BUSTER 7 -1 -1 -1 CUffiNG TROUGH-1 ---L ,- /'ãx 0 0 " . I 1\I~n~ 00 .. . - d ~ ~ ~ O~;¡I 0 ... , <!! _. ~ O!1!ï 0 ì : § - SJ g ~5 g l L " - g g ro "",m".",,", roffi' ~t' I .. . .. - HOlE FILL 2x3 . œJ ------'---------;:- / / ''''''' ~' I / oI\f-[ . CHAAGE ~, ~\12, "Jx4E1\ 4 11\ \~ (!) GI\4/' ~"~M'~_, G~ ~ 11-1 ~ ~~J: 2x3 \I-~ I ~ '7 ~\~&;¡:;- ~£ .2 3x~ .-r- ,?I// ~ : I " .1_1- /~-~ --- 5 FROM (J) 15 ŒI 3 CENTRIFUGE rfF. 3 l m rl-~~F~iT-r',," IQi ~: t ~ 0 , 0 m ~1' . ø 11' m ø / I ~ ø r- i ¡ . m ø ~ = -d:T m 'dI~--+~N[JdJ¡I-i~ ¡I ~ ) ~t lti.. -~ m .@' I _iJ'""""'" J-----Ll-J6- H .. , , "C, ::3: ~=}-ì~ Q ~ ' + + 7' N.:f N------þ \ Y\I--J\! -,- I 8--1\1.7 /' T MIX '7- '/,. 8x6 CENTR~~ 3 3x2 HOPPERS ð8 6 , M. IX ðX6 , OESI,L.:, ~~ ~. ~OER"6 8X~~ OJ-i'Jo=- MIX P X\þ, "M' ~ "''' ~ cJ1 , ¡ I. -. "'M. s¡ .\" -N .L 1\1 11\1 . LA ,- TO AUTOC:ÞO ":!!'- Œ5CIW'nCIH J.tglli) 1><1 GAlE VN.VE 1\1 øumRFl.Y VN.VE œJ SUCT!OH VN.VE / ~ 1M) QJN ŒI AGITATOR IIOTOR ~'" .- COMPARTMENT CAPACITY COt.lPNmlENT CAPACITY BSlS/in 8815 0 DECASSØI PIT aJ 0.95 ill Ðf;SHWI PIT 85 0.91 ill D&TER PIT 85 0.91 G) PU PIT J5.8 O.H ill CENT£R PIT J6.4 0.42 @ , ~ PIT 121.3 1,4 (J) socnœt PIT 448 6.1 (!) HCtE fU PIT 64 1.08 @ WATER TNt< 64 1.08 -'. ~=~~~~Of .~oyon RIG'I41 PIPING (SCHEMATIC ii£V. 0 "'f' OF Meltwater 2P-41 i Proposed Completion Schematic Big Bore Base Case - 4-1/211 Completion String 30" X 16" 62.6# @ +1-110' MO (Insulated) Depths are based on Doyon 141 RKB Surface csg. 9-5/8" 40.0# L-80 BTCM +1- 2400' MD / 2399' TVD Intermediate csg. 7" 26.0# L-80 BTCM run CSR to surface +/- 5331' MO / 5319' TVD Future Perforations Production csg 4-1/2" 12.6# L-80 IBT TO to CSR +1- 5992' MD / 5980' TVO ( PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 4-1/2" FMC Gen 5 Tubing Hanger, 4-1/2" L-80 IBT pin down 4-1/2" 12.6# L-80 IBT Spaceout Pups as Required 4-1/2" 12.6# L-80 IBT Tubing to Surface 4-1/2" Cameo 'DB' nipple wI 3.875" No-Go Profile. 4-1/2" x 6' L-80 handling pups installed above and below, IBT set at +1- 500' MD 4-1/2" 12.6# L-80 IBT tubing to landing nipple 4-1/2" X 1" Cameo 'KBG-2' Mandrels wI DV's and BKlatch's (Max. 005.985",10 3.833"), IBT pin x pin, 4-1/2" x 6'L-80 IBT box x box handling pupinstalled above, 4-1/2" x 6' L-80 IBT box x pin handling pup installed below. Spaced out w/4-1/2" 12.6# L-80 IBT tubing as follows: MD-RKB GLM # TVD-RKB GLM Numbers and Spacing To Be Determined 4-1/2" X 1" Cameo 'KBG-2' mandrel wI DCK-2 shear valve and BEK latch (Max. 005.985",103.833"), IBT pin x pin, pinned for 3000 psi shear (casing to tubing differential), 4-1/2" x 6' L-80 IBT box x box handling pup installed above, 4-1/2" x 6' L-80 1ST box x pin handling pup installed below 1 jt 4-1/2" 12.6# L-80 IBT tubing 4-1/2" Baker 'CMU' sliding sleeve w/ 3.81" Camco No-Go profile, IBT box x pin. 4-1/2" x 6' L-80 1ST handling pup installed above 4-1/2" Cameo 'DB' nipple w/3.75" No-Go profile. 4-1/2" x 16' L-80 IBTspacaeout pup installed above, 4-1/2" x 6' handling pup installed below 1 jt 4-1/2" 12.6# L-80 IBT tubing 4-1/2" Baker 80-47 GBH-22 casing seal assembly wI 15' stroke, 4-1/2" L-80 IBT box up, 4-1/2" x 6' L-80 1ST handling pup installed on top Baker Casing Seal Receptacle, 194-47, 7" BTCM x 4-1/2" IBT Baker 7" (Max) 00 x 4-3/4" 10 17' Seal Bore Extension CSR set at +/- 100' above top perforation TAB, 4/05/00 PHILLIP(,-, Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 April 10, 2001 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Meltwater Producer 2P-417 Dear Commissioner Seamount: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2P-417. Diverter, BOP, and fluids handling systems schematics for Doyon Rig 141 have been included in this permit application. Current plans call for Doyon 141 to drill and complete all Meltwater Phase 1 wells and Phillips Alaska, Inc. requests that these schematics be placed on file with the Commission for reference in future permit to drill documents. 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 orGKA 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 MC 25.070) 263-4612 B) Geologic Data and Logs Steve Moothart, Geologist (20 MC 25.071) 265-6965 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or James Trantham at (907) 265-6434. The anticipated spud date for this well is May 1, 2001. J'ncereIY, (lMllSl Q.oIJ)~~ , mes Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. Phone (907) 265-6434 Fax: (907) 265-1535 Email: jtranth@ppco.com RECEIVED APR 11 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL, { (.s.-t ~\ ":> "\ ":> \- ~C(o ~s ~ &. 0\ C)?~ \- 'ÑQ:. \ \ 0- \- \-\«:. \ -\ ~ <J.~ ~ ~ o\Sb -\-~~ ~«-'o0\- é)~ ö.'I'-~~ ~~\~\-\- \,ÛC~s,~' ??~O \S 'bCc0c:ç\'O\>\ ~ -\\~\"> ~~C~ ~\~0-~ ~""ð\>\C\.~~ --'t-o I. ~ "'--O\~~ --\-<ë. -\- ~ s s -\-'(\ <ê. G. C- 'Cf> S ~ "\ , CJ-- <:; ~Q:. -¥:;., \~Q \ r- ''f\.~~~ '\'S -+0 'Nt \ ~ \ ~s~\<è \'\c~ 'Ç>«Ù~ \<t: 'ð\t)I\..L\ ~ \=-::> S c.À" "! -\-- ~ X"'..s. ~~~CLS \~~:~~ ~:~~ \6~L~\ï ~Q~ O()C~r *0 S()D'('<'-\~-\~~ ~ Ç>úCbSK G."'~ Q\'-O~~ MIÇ -\a \ì'CJ'\<l.~ ~~J;- +~'i "'~'¿)~<0<L~~. ~Os.(ê~ Ò~ ~~è\- ~<t:.Cè+\"--~ -\-~G:ì ~\~~\0tJCè\J S'V<G~\~\c.. <::g'M<L~.\\~,> ~ \. '-- '-.j \G.-~~~ S:. . J:::: -+ ~ \ '""- \- -\-\-\.\S .\0 """"~-\- ~ \ \ \ 'DCL '.j <è:. ~ W Ð ç-\U2k b \'ê ~ 4 of 4 '-'--'-r \ ( ( -.L.iç- '1.0 '-.J ~ '0 Q. 'C.)., Ii'-. '---{ c....O ~ 'N\Q::V'\.. \'S, l í? '- '<:..SJ.-- <;. Q:: \ ¡¿ \7 4/23/01 2:04 PM K~~\ ~ (' American Express~ Cash Advance Draft 125 PAY TO THE ORDER OF 82-'fOJI 021 slloo~GV --r DOLLARS Issued by Integrated Payment System, Inc. Enzlewood, Colorado Payable at Norwest Bank of Grand Junction - Downtown, NA Grand Junction, Colorado PERIOD ENDING S-R é), p,- (/ II I: ~ 0 2 ~ 0 0 ... 0 0 I: j 5 II~ 0 ~ ? 5000 5 j bill 0 ~ 2 5 ... WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION 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 wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can. be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 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.. . . . . . . . . . . . Y N 23. If diverter required, does it meet regulations. . . . . . . . . . N I.. ~ ~'I L.iJ k 24. Drilling .fluid program schematic & equip list adequate. . . . . N A..J,.. J' ~,....f',"'''''' s:: e P~'[; r..f . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Y N / (/ . 26. BOPE press rating appropriate; test to 5(){}C) , psig. N M.b-'-\> It.~~ ~ \~ '-\~ '?c::\. ~c....c "\: ~~~~ \ ~ \'\~'-\. ~ ~'\~ " iÇÐc 27. Choke ~anifold C?mplies w/A~I RP-53 (May 84). . . . .. . . N .' 5"000 ~ \. ' )' 28. Work will occur without operation shutdöwn. . . . . . . . . . . N - 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures. . . . 'iA" Y N f1 . . A PR . ~P1. ~i ~::E:~E£~:?~~ ii~!~:):~7 ~~n~~ : : : : : : : : ~. Þ 11 , . . . - 'IL.i/I!dI 34. Contact name/phone for weekly progress reports [explorat°f'"t, Iy] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan, . ~~,,\~~~ \-~,~ ~\\, ~t)..~o..~~~Q;:~ <=-\(}.~~ ~'J ~\-\:\~~~~ C\..~~\':)'-ú, (A) will contain waste in a suitable receiving zone; . . . . . ,. . Y N \- ' . . ð~~~\ \>~N (B) will not contaminate frèshwater; or cause drilling waste. .. Y N !ù Ð }I'~ 1"'0 ~upp J-.tLO IN I PrO 7ð S uPfJoIL7 fì I\\A.)VJ-J\L- .. to surface; , V1H. '" !\)t...t:...D ç:ùj...¡"" 4£> i-A ~"'1, 0 f'-.) W)-4-03 (C) will not impair mechanical integrity of the well used for disposal; Y N} (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~þ~¿ ~f' ~ ;M 9g~J~ -5 lÆ- ~þl ENGINEERING DATE 'i I;t. '-l, APPR DATE COMPANY INIT CLASS WELL NAME De,v /-ðf ) , c:\msoffice\wordian\diana\checklist (rev. 11/01/100) PROGRAM: exp - dev ¡/' redrll - serv - well bore seg _ann. disposal para req - GEOL AREA f'"7 CJ UNIT# ~ . Ò ON/OFF SHORE ~ N Y ~,f it 1'/: ~ , r. -de -ß.d ~JI ,,., -/)~ ~ ~; ::~A;/~ ~ = ~:: 01 -;£ Y N N N N CŸ)N ~~ ~ #~/~a/ /!,,/ ¿«r'-£~- ~i c 0 Z 0 -t ~ ::u { # - -t m - Z -t :I: en » :::0 m » (" Commentsllnstructions: ~ ~?1Jh .ILl). (;p:;;ti::Lv '->- PCU7l '1'1- 210 ( { Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. " To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN,DIX. No special 'effort has been made to chronologically",,: organize this category of information. ~ ~ '" **** REEL HEADER **** LDWG 02/06/26 AWS 01 **** TAPE HEADER **** LDWG 02/06/19 01 *** LIS COMMENT RECORD *** II!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! ! !! ! ! ! !! ! ! 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: LDWG File Version 1.000 Extract File: LISTAPE.HED MWD RUN 1 1 C. WONG D. GLADDEN MWD RUN 4 4 W. GUILLOTTE R. SPRINGER # 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 ~ 2P-417 501032037500 Phillips Alaska, Inc. BAKER HUGHES INTEQ 26-JUN-02 MWD RUN 2 2 K. THRASHER D. GLADDEN MWD RUN 5 18 aN 7E N/A 255.00 N/A MWD RUN 3 3 M. BELAVADI R. SPRINGER MWD RUN 6 C7 U¡-U(O 7 1091/ RECEIVED JUL 1 u 2002 Alaska Oil & Gas Cons. Commission Anchorage OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 42.000 16.000 109.0 ! f'"\ ~ # REMARKS: 3RD STRING PRODUCTION STRING 12.250 8.500 9.625 2382.0 5994.0 Tape Subtile: 1 Minimum record length: Maximum record length: PER PHILLIPS ALASKA INSTRUCTIONS, 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 TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N70 DEG 3' 18.521" LONG: W150 DEG 27' 52.172" LOG MEASURED FROM D.F. AT 255 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) BAKER HUGHES INTEQ RUN 1 UTILIZED A MULTIPLE PROPAGATION RESISTIVITY TOOL IN A STEERABLE ASSEMBLY FROM 93 - 2430 FEET MD (93 - 2428' TVD). 2) BAKER HUGHES INTEQ RUNS 2 THROUGH 4 UTILIZED A TRIPLE COMBO TOOL COUPLED WITH THE MULTIPLE PROP. RESISTIVITY TOOL (MPR) IN A STEERABLE ASSEMBLY FROM 2430 TO 5994 FEET MD (2428 - 5981' TVD). REMARKS: 1) 16 INCH CASING DEPTH - LOGGER: 109' MD (109' TVD). 16 INCH CASING DEPTH - DRILLER: 109' MD (109' TVD). RESISTIVITY DATA OVER THE INTERVAL FROM 109 - 450' MD (109 - 450' TVD) IS EXTREMELY ERRATIC DUE TO DRILLING THROUGH PERMAFROST. 2) 9.625 INCH CASING DEP - LOGGER: 2384' MD (2383'TVD) 9.625 INCH CASING DEP - DRILLER: 2382' MD (2381'TVD) THE INTERVAL FROM 2385 TO 2430' MD (2384 - 2428'TVD) WAS LOGGED UP TO 54.0 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO SET 9.625" CASING, CEMENT AND PICK UP BAKER HUGHES INTEQ TRIPLE COMBO TOOL AND A STEERABLE ASSEMBLY FOR THE 8.5" SECTION OF THE HOLE. 3) THE INTERVAL FROM 5222 TO 5262' MD (5209 - 5249'TVD) WAS LOGGED APPROXIMATELY 74.0 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO MAKE A HOLE OPENER RUN. 4) THE INTERVAL FROM 5388 TO 5429' MD (5375 - 5416'TVD) WAS LOGGED APPROXIMATELY 67.0 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO MAKE TWO CORING RUNS. THE INTERVAL FROM 5429 TO 5549' MD (5416 - 5536' TVD) WAS LOGGED UP TO 32.0 HOURS AFTER BEING CORED. THE ROP'S OVER THIS INTERVAL ARE REAMING ROP'S SINCE THE INTERVAL HAD BEEN PREVIOUSLY CORED. 5) THE INTERVAL FROM 5955 TO 5994' MD (5942 - 5981'TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET. $ 92 records... 8 bytes 13 2 bytes LDWG .001 **** FILE HEADER **** 1024 .. ,-.... *** LIS COMMENT RECORD *** ~ I!!!!!!!!!!!!!!!!!! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILEO01.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD MWD MWD MWD $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 47.0 2384.0 5222.0 5387.0 STOP DEPTH 2384.0 5222.0 5387.0 5953.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 4 # REMARKS: MERGE TOP 93.0 2430.0 5263.0 5428.0 MERGE BASE 2430.0 5263.0 5428.0 5994.0 MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU WDFN LCC CN WN FN COUN STAT ------------------------------ 2p417 _5. xU 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ---------------------------------------------------- ODEP GR RAD RPD RPS RPX NPHI RHOB DRHO PEF CALN MTEM GR RAD RPD RPS RPX NPHI RHOB DRHO PEF CALN MTEM GRAM RACLM RPCLM RPCHM RPCSHM NPCKSFM BDCFM DRHFM DPEFM CALM TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ~ .. ROP FET Rap FET ROPS RPTH 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 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: One depth per frame (value: 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RAD MWD 68 1 OHMM 4 4 3 RPD MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 NPHI MWD 68 1 PU-S 4 4 7 RHOB MWD 68 1 G/C3 4 4 8 DRHO MWD 68 1 G/C3 4 4 9 PEF MWD 68 1 BN/E 4 4 10 CALN MWD 68 1 IN 4 4 11 MTEM MWD 68 1 DEGF 4 4 12 ROP MWD 68 1 FPHR 4 4 13 FET MWD 68 1 HR 4 4 ------- 52 Total Data Records: 654 Tape File Start Depth 109.000000 Tape File End Depth 5994.000000 Tape File Level Spacing: 0.500000 Tape File Depth Units: feet **** FILE TRAILER **** Tape Subfile: 2 708 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: FILEO02.HED FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MAD $ .5000 START DEPTH 5100.0 STOP DEPTH 5994.0 # MERGED DATA SOURCE PBU TOOL CODE MAD $ MAD RUN NO. MAD PASS NO. 1 1 MERGE TOP 5100.0 MERGE BASE 5994.0 # REMARKS: MAD PASS. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT mad_5.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RAD RAD RAD 0.0 RPD RPD RPD 0.0 RAS RAS RAS 0.0 RPS RPS RPS 0.0 NPHI NPHI NPCKSM 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 44 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: One depth per frame (value= 0) Datum Specification Block Sub-type is: 23 1 FRAME SPACE: 0.500 * F /"""'- ~ ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units Size Length 1 GR MAD 68 1 GAP I 4 4 2 RAD MAD 68 1 OHMM 4 4 3 RPD MAD 68 1 OHMM 4 4 4 RAS MAD 68 1 OHMM 4 4 5 RPS MAD 68 1 OHMM 4 4 6 NPHI MAD 68 1 PU-S 4 4 7 RHOB MAD 68 1 G/C3 4 4 8 DRHO MAD 68 1 G/C3 4 4 9 PEF MAD 68 1 BN/E 4 4 10 MTEM MAD 68 1 DEGF 4 4 ------- 40 Total Data Records: 78 Tape File Start Depth 5100.000000 Tape File End Depth 5994.000000 Tape File Level Spacing: 0.500000 Tape File Depth Units: feet **** FILE TRAILER **** Tape Subfile: 3 114 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: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 1 .2500 START DEPTH 47.0 STOP DEPTH 2384.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 30-APR-Ol /""'\ 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 MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. # 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): # ,,-.... MSB 18704 8.25 MPR MEMORY 2430.0 47.0 2384.0 0 .0 8.3 TOOL NUMBER MPR 14990 SRIG 4049 12.250 109.0 KCL / PHPA 9.80 .0 .0 32000 .0 .000 .000 .000 .000 .00 .000 .0 0 BIT RUN 1. GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP 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) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VAtU ------------------------------ WDFN LCC CN WN FN 2p417.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater .0 .0 .0 .0 ~ .. COUN STAT North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 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: 36 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: One depth per frame (value: 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE: 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 334 Tape File Start Depth: 47.000000 Tape File End Depth: 2384.000000 Tape File Level Spacing: 0.250000 Tape File Depth Units: feet **** FILE TRAILER **** Tape Subfile: 4 420 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** ~ ~. LDWG .004 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! !!!! !!!!!!!!!!!!!!! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILEO12.HED 4 '" log header data for each bit run in separate files. 2 .2500 START DEPTH 2384.0 STOP DEPTH 5222.0 # 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 CN DEN MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL NEUTRON DENSITY MULT. PROP. GAMMA RAY RESIST. # 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: 05-MAY-Ol MSB 18704 6.75 TC MEMORY 5263.0 2384.0 5222.0 0 0.4 8.8 TOOL NUMBER CCN 8886 ORD 10022 MPR 17846 SRIG 5332 8.500 2382.0 KCL / PHPA 9.50 .0 .0 30000 .0 .000 .000 .000 .000 SANDSTONE .0 .0 .0 .0 ~ ~ ~ MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 # REMARKS: BIT RUN 2. GR/MPR/CN/DEN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP 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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p417.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 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: 56 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: 18 ~ /""'... 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 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 631 Tape File Start Depth: 2384.000000 Tape File End Depth: 5222.000000 Tape File Level Spacing: 0.250000 Tape File Depth Units: feet **** FILE TRAILER **** Tape Subfile: 5 731 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY LDWG File Version 1.000 Extract File: FILEO13.HED 5 log header data for each bit run in separate files. 3 .2500 "...--.... VENDOR TOOL CODE MWD $ START DEPTH 5222.0 STOP DEPTH 5387.0 # 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 CN DEN MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL NEUTRON DENSITY MULT. PROP. GAMMA RAY RESIST. # 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: ........... 08-MAY-01 MSB 18704 6.75 TC MEMORY 5428.0 5222.0 5387.0 0 0.4 0.4 TOOL NUMBER CCN 8886 ORD 10022 MPR 17846 SRIG 5332 8.500 2382.0 KCL / PHPA 10.10 .0 .0 32000 .0 .000 .000 .000 .000 SANDSTONE .00 .000 .0 0 BIT RUN 3. GR/MPR/CN/DEN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP 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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY .0 .0 .0 .0 ~ ,......... CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) # *** INFORMATION TABLE: CONS MNEM VAtU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p417.xtf 150 Phillips Alaska, Inc. 2P-4l7 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 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: 56 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: One depth per frame (value: 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE: 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 Î'\ 10 CALM MWD 68 1 IN 4 4 11 RaPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 37 Tape File Start Depth 5222.000000 Tape File End Depth 5387.000000 Tape File Level Spacing: 0.250000 Tape File Depth Units: feet **** FILE TRAILER **** Tape subfile: 6 136 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .006 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILEO14.HED !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 6 /"""'\ log header data for each bit run in separate files. 4 .2500 START DEPTH 5387.0 STOP DEPTH 5953.0 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL CN NEUTRON 11-MAY-01 MSB 18704 6.75 TC MEMORY 5994.0 5387.0 5953.0 0 0.2 0.4 TOOL NUMBER CCN 8886 ~ DEN MPR GRAM $ DENSITY MULT. PROP. RESIST. 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): # ~ ORD 10022 MPR 17846 SRIG 5332 8.500 2382.0 KCL CORING 10.30 .0 .0 32000 .0 .000 .000 .000 .000 SANDSTONE .00 .000 .0 0 BIT RUN 4. GR/MPR/CN/DEN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP 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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p417.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .0 .0 .0 .0 /~ ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 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: 56 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: One depth per frame (value: 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE: 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 135 Tape File Start Depth: 5387.000000 Tape File End Depth 5994.000000 Tape File Level Spacing: 0.250000 Tape File Depth Units: feet **** FILE TRAILER **** Tape Subfile: 7 235 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes ~ /~ . **** TAPE TRAILER **** LDWG 02/06/19 01 **** REEL TRAILER **** LDWG 02/06/26 AWS 01 Tape Subtile: 8 Minimum record length: Maximum record length: - ~ 2 records... 132 bytes 132 bytes ( **** REEL HEADER **** LDWG 02/06/19 AWS 01 **** TAPE HEADER **** LDWG 02/06/19 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: LISTAPE.HED TAPE HEADER MELTWATER UNIT MWD/MAD LOGS # WELL N101E: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING MWD RUN 1 1 C. WONG D. GLADDEN MWD RUN 4 4 W. GUILLOTTE R. SPRINGER MSL 0) ( 2P-417 501032037500 Phillips Alaska, Inc. BAKER HUGHES INTEQ 19-JUN-02 MWD RUN 2 2 K. THRASHER D. GLADDEN MWD RUN 5 18 8N 7E N/A 255.00 N/A MWD RUN 3 3 M. BELAVADI R. SPRINGER MWD RUN 6 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 42.000 16.000 109.0 aDJ-Ó04 11071 ( ( # REMARKS: 3RD STRING PRODUCTION STRING 2382.0 5994.0 Tape Subfile: 1 12.250 8.500 9.625 PER PHILLIPS ALASKA INSTRUCTIONS, 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 TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N70 DEG 3' 18.521" LONG: W150 DEG 27' 52.172" LOG MEASURED FROM D.F. AT 255 FT. ABOVE PERM. DATUM (M. S.L.) . COMMENTS: 1) BAKER HUGHES INTEQ RUN 1 UTILIZED A MULTIPLE PROPAGATION RESISTIVITY TOOL IN A STEERABLE ASSEMBLY FROM 93 - 2430 FEET MD (93 - 2428' TVD). 2) BAKER HUGHES INTEQ RUNS 2 THROUGH 4 UTILIZED A TRIPLE COMBO TOOL COUPLED WITH THE MULTIPLE PROP. RESISTIVITY TOOL (MPR) IN A STEERABLE ASSEMBLY FROM 2430 TO 5994 FEET MD (2428 - 5981' TVD). REMARKS: 1) 16 INCH CASING DEPTH - LOGGER: 109' MD (109' TVD). 16 INCH CASING DEPTH - DRILLER: 109' MD (109' TVD). RESISTIVITY DATA OVER THE INTERVAL FROM 109 - 450' MD (109 - 450' TVD) IS EXTREMELY ERRATIC DUE TO DRILLING THROUGH PERMAFROST. 2) 9.625 INCH CASING DEP - LOGGER: 2384' MD (2383'TVD) 9.625 INCH CASING DEP - DRILLER: 2382' MD (2381'TVD) THE INTERVAL FROM 2385 TO 2430' MD (2384 - 2428'TVD) WAS LOGGED UP TO 54.0 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO SET 9.625" CASING, CEMENT AND PICK UP BAKER HUGHES INTEQ TRIPLE COMBO TOOL A.J.'JD A STEERABL:C ASSEl1BLY FOR THE 8.5" SECTION OF THE HOLE. 3) THE INTERVAL FROM 5222 TO 5262' MD (5209 - 5249'TVD) WAS LOGGED APPROXIMATELY 74.0 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO MAKE A HOLE OPENER RUN. 4) THE INTERVAL FROM 5388 TO 5429' MD (5375 - 5416'TVD) WAS LOGGED APPROXIMATELY 67.0 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO MAKE TWO CORING RUNS. THE INTERVAL FROM 5429 TO 5549' MD (5416 - 5536' TVD) WAS LOGGED UP TO 32.0 HOURS AFTER BEING CORED. THE ROP'S OVER THIS INTERVAL ARE REAMING ROP'S SINCE THE INTERVAL HAD BEEN PREVIOUSLY CORED. 5) THE INTERVAL FROM 5955 TO 5994' MD (5942 - 5981'TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET. $ 92 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** 1024 ( *** LIS COMMENT RECORD *** 'If Il ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD MWD MWD MWD $ 1 clipped curves¡ all bit runs merged. .5000 START DEPTH 47.0 2384.0 5222.0 5387.0 STOP DEPTH 2384.0 5222.0 5387.0 5953.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 4 # REMARKS: MERGE TOP 93.0 2430.0 5263.0 5428.0 MERGE BASE 2430.0 5263.0 5428.0 5994.0 MERGED PASS. , NO DEPTH SHIFTS WERE )',.PPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU WDFN LCC CN WN FN COUN STAT ------------------------------ 2p417_5.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ---------------------------------------------------- ODEP GR RAD RPD RPS RPX NPHI RHOB DRHO PEF CALN MTEM GR RAD RPD RPS RPX NPHI RHOB DRHO PEF CALN MTEM GRAM RACLM RPCLM RPCHM RPCSHM NPCKSFM BDCFM DRHFM DPEFM CALM TCDM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ( l ( ROP FET ROP FET ROPS RPTH 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 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: One depth per frame (value= O) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RAD MWD 68 1 OHMM 4 4 3 RPD MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 NPHI MWD 68 1 PU-S 4 4 7 RHOB MWD 68 1 G/C3 4 4 8 DRHO MWD 68 1 G/C3 4 4 9 PEF MWD 68 1 BN/E 4 4 10 CALN MWD 68 1 IN 4 4 11 MTEM MWD 68 1 DEGF 4 4 12 ROP MWD 68 1 FPHR 4 4 13 FET MWD 68 1 HR 4 4 ------- 52 Total Data Records: 654 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 109.000000 5994.000000 0.500000 **** FILE TRAILER **** Tape Subfile: 2 708 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 ( *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 ¡( log header data for each bit run in separate files. 1 .2500 START DEPTH 47.0 STOP DEPTH 2384.0 # 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 MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. # 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: BIT RUN 1. GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY 30-APR-01 MSB 18704 8.25 MPR MEMORY 2430.0 47.0 2384.0 0 .0 8.3 TOOL NUMBER MPR 14990 SRIG 4049 12.250 109.0 KCL / PHPA 9.80 .0 .0 32000 .0 .000 .000 .000 .000 .0 .0 .0 .0 .00 .000 .0 0 (OHM:M) ( (' RPCL - DEEP 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) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p417.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 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: 36 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: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- ( ( 32 Total Data Records: 334 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 47.000000 2384.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 420 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 MWD $ 3 log header data for each bit run in separate files. 2 .2500 START DEPTH 2384.0 STOP DEPTH 5222.0 # 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: 05-MAY-01 MSB 18704 6.75 TC MEMORY 5263.0 2384.0 5222.0 0 0.4 8.8 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CN DEN MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL NEUTRON DENSITY MULT. PROP. GAMMA RAY TOOL NUMBER RESIST. CCN 8886 ORD 10022 MPR 17846 SRIG 5332 # ( 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): # ( 8.500 2382.0 KCL I PHPA 9.50 .0 .0 30000 .0 .000 .000 .000 .000 .0 .0 .0 .0 SANDSTONE .00 .000 .0 0 BIT RUN 2. GR/MPR/CN/DEN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETP~TION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p417.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RACL RPCL RPCH GRAM RACL RPCL RPCH GRAM RACLM RPCLM RPCHM 0.0 0.0 0.0 0.0 ( ( RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 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: 56 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: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RACL MTJ'JD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 631 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 2384.000000 5222.000000 0.250000 **** FILE TRAILER **** Tape Sub file: 4 731 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 ( 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 ( log header data for each bit run in separate files. 3 .2500 START DEPTH 5222.0 STOP DEPTH 5387.0 # 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 CN DEN MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL NEUTRON DENSITY MULT. PROP. GAMMA RAY RESIST. # 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): 08-MAY-01 MSB 18704 6.75 TC MEMORY 5428.0 5222.0 5387.0 0 0.4 0.4 TOOL NUMBER CCN 8886 ORD 10022 MPR 17846 SRIG 5332 8.500 2382.0 KCL I PHPA 10.10 .0 .0 32000 .0 .000 .000 .000 .000 .0 .0 .0 .0 SANDSTONE .00 .000 ( ( # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 # REMARKS: BIT RUN 3. GR/MPR/CN/DEN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP 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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) # *** INFORMATION TABLE: CONS Iv:INEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p417.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO Iv:INEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 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: 56 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: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 37 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 5222.000000 5387.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 5 136 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 log header data for each bit run in separate files. 4 .2500 START DEPTH 5387.0 STOP DEPTH 5953.0 ~, # 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 CN DEN MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL NEUTRON DENSITY MULT. PROP. GAMMA RAY RESIST. # 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): # (' 11-MAY-01 MSB 18704 6.75 TC MEMORY 5994.0 5387.0 5953.0 0 0.2 0.4 TOOL NUMBER CCN 8886 ORD 10022 MPR 17846 SRIG 5332 8.500 2382.0 KCL CORING 10.30 .0 .0 32000 .0 .000 .000 .000 .000 .0 .0 .0 .0 SANDSTONE .00 .000 .0 0 BIT RUN 4. GR/MPR/CN/DEN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP 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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (GICC) BDCF - BULK DENSITY COMPENSATED, FILTERED (GICC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ REMARKS: ( (' # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p417.xtf 150 Phillips Alaska, Inc. 2P-417 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 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: 56 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: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RACL MWD 68 1 OHM:M 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 ( ~r 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 135 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 5387.000000 5994.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 6 235 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 02/06/19 01 **** REEL TRAILER **** LDWG 02/06/19 AWS 01 Tape Subfile: 7 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes
