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Home My WebLink About204-0262025-0715_Location_Clear_KRU_2P-449_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 07/18/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Site Clearance Petroleum Inspector KRU 2P-449 ConocoPhillips Alaska LLC. PTD 2040260; Sundry 324-519 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-449 which has been P&A and buried. The area was clean of debris and had a settling mound for soil over the well location. We verified the well-site with the pad location map and well conductor “as built”. Marker plate and top of well are at 6 feet 4 inches below original tundra. Overall, the site clearance was in good condition. The well site still had barriers around due to other work going on in the area. Only follow up would be a full pad site clearance once CPAI has completed all pad P&A work. Attachments: Photo 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.16 14:18:05 -08'00' 2025-0715_Location_Clear_KRU_2P-449_ksj Page 2 of 2 Surface Abandonment Inspection – KRU 2P-449 (PTD 2040260) Photo by AOGCC Inspector K. StJohn 7/15/2025 2024-1207_Surface_Abandon_KRU_2P-449_gc Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 12/08/24 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector KRU 2P-449 ConocoPhillips Alaska Inc. PTD 2040260; Sundry 324-519 12/07/24: I arrived on site and met with Roger Mauser with ConocoPhillips. We discussed the well and excavation then confirmed the well’s casing was cut-off 6 feet 4 inches below tundra level. The cement was to surface and fully cured. I inspected the identification plate and confirmed the information welded on it was correct. The identification plate was not to be welded onto the casing today. The welding took place on 12/08/2024 and pictures were sent to me to confirm the plate was indeed installed. Attachments: Photos (4) 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.02 12:34:28 -09'00' 2024-1207_Surface_Abandon_KRU_2P-449_gc Page 2 of 3 Surface Abandonment – KRU 2P-449 (PTD 2040260) Photos by AOGCC Inspector G. Cook (except as noted) 12/7/2024 2024-1207_Surface_Abandon_KRU_2P-449_gc Page 3 of 3 KRU 2P-449 csg stub prepped (left); Marker plate installed (right) – photos courtesy of CPAI MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Nordic 3 Rig Elevation: 25 ft Total Depth: 9946 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: P&A: XXX Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3008 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5 1/2"x3 1/2" O.D. Shoe@ 9940 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8933 Feet Tbg Cut@ 3064 Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 3071 ft 2530 ft 9.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1700 1560 1515 IA 1700 1560 1515 OA 1700 1560 1515 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Ronnie Dalton Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Set 10K lbs on top of cement plug at 2530 ft MD. Tested to 1500psi. Good Tag and Test. November 12, 2024 Brian Bixby Well Bore Plug & Abandonment KRU 2P-449 ConocoPhillips Alaska Inc. PTD 2040260; Sundry 324-519 none Test Data: P Casing Removal: rev. 3-24-2022 2024-1112_Plug_Verification_KRU_2P-449_bb 9 9 9999 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.21 16:23:29 -09'00' 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: 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 2337' 5.5" L-80 5146' 3.5" L-80 5656' 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 8915' SIZE DEPTH SET (MD) 9940' 26' 5146' 62.45# 40# 108' 26' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 7187' (SW TOC) - 8825' 31 bbls 15.8 ppg Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 9392-9402' MD and 5374-5379' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information N/A PACKER SET (MD/TVD) 24" 12.25" 15 bbl AS I 28'337 sx AS III, 274 sx LiteCrete 9.3# 28' 8915' 3008'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# WT. PER FT.GRADE 2/19/2004 CEMENTING RECORD 5863620 1406' MD / 1347' TVD SETTING DEPTH TVD 5862927 TOP HOLE SIZE AMOUNT PULLED 440065 440057 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 50-103-20486-00-00 KRU 2P-449 ADL0373112, ADL0389058 1026' FNL, 1564' FWL, Sec. 17, T8N, R7E, UM 1700' FNL, 1879' FEL, Sec. 19, T8N, R7E, UM ALK 32092, ALK 32409 2/11/2004 9946' MD/ 5659' TVD 7187' MD/ 4330' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443523 5868854 1006' FNL, 1873' FEL, Sec. 19, T8N, R7E, UM 9. Ref Elevations: KB: 28' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 9/5/2024 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 604 sx Class G w/ GasBlok8.5" 8933' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 14. Permit to Drill Number / Sundry: 204-026/ 324-397 By James Brooks at 3:40 pm, Sep 18, 2024 Suspended 9/5/2024 JSB RBDMS JSB 093024 xGDSR-10/14/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1406' 1347' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Suspended N/A- Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.09.18 15:02:16-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 9,320.0 2P-449 6/24/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut 2P-449 9/5/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/29/2010 haggea Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.70 28.1 3,007.8 2,336.7 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 8946' 5 1/2 4.95 25.7 9,940.0 5,656.2 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.5 Set Depth … 8,933.0 Set Depth … 5,154.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.5 23.5 0.03 HANGER 8.000 FMC TUBING HANGER 3.500 465.8 465.6 4.46 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 2,693.5 2,188.5 62.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,147.4 3,371.0 61.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,761.4 4,133.6 62.73 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 7,970.2 4,690.2 61.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,803.6 5,093.2 61.60 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,853.6 5,117.0 61.65 SLEEVE 4.500 CAMCO CMU SLIDING SLEEVE W/CAMCO 2.813" DS PROFILE CAMCO CMU 2.810 8,869.6 5,124.6 61.75 NIPPLE 4.490 CAMCO D NIPPLE CAMCO D 2.750 8,914.2 5,145.6 62.00 LOCATOR 4.500 BAKER G-22 LOCATOR G-22 3.000 8,915.0 5,146.0 62.01 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSEMBLY w/ 1/2 MULESHOE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,350.0 2,498.3 61.07 CUT 2.5" JET CUT 9/5/2024 2.992 8,825.0 5,103.4 61.49 TUBING PUNCH TUBING PUNCH, 3FT @ 6 SPF, 0 DEGREE PHASE. 8/6/2024 2.992 8,869.5 5,124.5 61.75 FISH Nose cone and pinning ring from latch 10/23/2020 0.000 8,900.0 5,138.9 61.92 FISH Check & Spring JUNK LEFT IN TUBING - CHECK AND SPRING FROM 1" OV - BOTTOM LATCH 3/19/2004 3/19/2004 9,369.3 5,362.9 60.20 CIBP 2.63" CIBP (MID-ELEMENT AT 9370' RKB) OAL=1.39' TTS CIBP N/A 4/2/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,693.5 2,188.5 62.13 1 GAS LIFT Open 1 8/27/2024 5,147.4 3,371.0 61.91 2 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 6,761.4 4,133.6 62.73 3 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 7,970.2 4,690.2 61.59 4 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 8,803.6 5,093.2 61.60 5 GAS LIFT DMY BTM 1 0.0 8/3/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,392.0 9,402.0 5,374.2 5,379.2 T-3, 2P-449 3/5/2004 6.0 IPERF 60 deg phase, PJ 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) 9,392.0 9,402.0 1 FRAC 3/13/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,240.0 9,369.3 5,299.7 5,362.9 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 9320' RKB 6/24/2024 7,187.0 8,828.0 4,329.9 5,104.8 Cement Plug PUMPED 31 BBLS OF 15.8 CLASS G CEMENT FOR INTERMEDIATE BALANCED PLUG 8/23/2024 2P-449, 9/17/2024 9:54:35 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 8946'; 25.7-9,940.0 FRAC; 9,392.0 IPERF; 9,392.0-9,402.0 CIBP; 9,369.3 Cement Plug; 9,240.0 ftKB FISH; 8,900.0 FISH; 8,869.5 TUBING PUNCH; 8,825.0 GAS LIFT; 8,803.6 GAS LIFT; 7,970.2 Cement Plug; 7,187.0 ftKB GAS LIFT; 6,761.4 GAS LIFT; 5,147.4 CUT; 3,350.0 SURFACE; 28.1-3,007.8 GAS LIFT; 2,693.5 NIPPLE; 465.8 CONDUCTOR; 28.0-108.0 KUP PROD KB-Grd (ft) 32.41 RR Date 2/22/2004 Other Elev… 2P-449 ... TD Act Btm (ftKB) 9,946.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048600 Wellbore Status PROD Max Angle & MD Incl (°) 63.09 MD (ftKB) 7,801.71 WELLNAME WELLBORE2P-449 Annotation Last WO: End DateH2S (ppm) 30 Date 11/23/2015 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 7/31/2024 ACQUIRE DATA (P&A) T X IA DDT (COMPLETE) 8/2/2024 ACQUIRE DATA DRIFT 10' X 2.50" FOR E-LINE TO 9026' RKB. LDFN. JOB IN PROGRESS 8/3/2024 ACQUIRE DATA SET 1'' BTM INT DMY VLV IN ST#5 @ 8804' RKB. PULL DMY FROM ST#1 @ 2693' RKB. LDFN. JOB IN PROGRESS 8/4/2024 ACQUIRE DATA SET 1'' BTM INT CSG SOV (2000 PSI) IN ST#1 @ 2693' RKB, GOOD TBG PT TO 1000 PSI. WELL READY FOR E-LINE. 8/6/2024 ACQUIRE DATA LOG CORRELATED TO TUBING TALLY DATED 21-FEBRUARY-2024 PUNCHER DEPTH=8825'-8828', CCL OFFSET=6.6', CCL STOP DEPTH=8818.4' LRS CONFIRM T X IA COMMUNICATION WELL LEFT S/I 8/23/2024 ACQUIRE DATA INTERMEDIATE CEMENT BALANCE PLUG. LOAD TBG & IA WITH 9.8 PPG KWF. PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 64 BBLS OF 9.8 PPG KWF. PLACING TOC IN TBG & IA @ ~7325' MD. IN PROGRESS 8/26/2024 ACQUIRE DATA ATTEMPT TO SHEAR SOV (SEE LOG) 8/27/2024 ACQUIRE DATA DRIFT & TAG TOC @ 7187' RKB. PULL SOV IN ST#1 @ 2693' RKB. CIRCULATE 65 BBLS OF DIESEL FROM TBG TO IA. READY FOR SW TOC/TEST. 9/2/2024 ACQUIRE DATA PERFORM STATE WITNESS( Austin McLeod) TAG TOC @ 7187' RKB. PERFORM PASSING CMIT TO 1500 PSI. READY FOR E-LINE. NETWORK # 10460709 9/3/2024 ACQUIRE DATA (P&A) FUNCTION TEST ALL T LDS/GNS (COMPLETE), T POT (PASSED) T PPPOT (PASSED), FUNCTION TEST ALL IC LDS/GNS (COMPLETE), IC POT (PASSED) IC PPPOT (PASSED), 9/4/2024 CHANGE WELL TYPE UNABLE TO GET TO DEPTH W/ 2.5" JET CUTTER TOOLS STUCK AT 2667', HAD TO PULL 200# OVER MSP TO GET TOOLS FREE RD & MOVE EQUIPMENT FOR SL 9/4/2024 CHANGE WELL TYPE DRIFT 2.61" GUAGE RING DOWN TO 3500' RKB, READY FOR E LINE 9/5/2024 CHANGE WELL TYPE LOG CORRELATED TO TUBING TALLY DATED 2/20/2004 CUT TUBING W/ 2.5" JRC JET CUTTER AT 3350' WELLEFT S/I NETWORK #10460709 2P-449 Intermediate Suspend Summary of Operations ORIGINATED TRANSMITTAL DATE: 9/10/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5038 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5038 2P-449 50103204860000 Tubing Cut Record 4-Sep-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 204-026 T39535 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.10 11:24:42 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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): 9946'8869', 8900' 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) 263-4597 Senior CTD Engineer KRU 2P-449 5659' 7325' 4394' 7325', 9240', 9369' 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: shane.germann@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8915' MD and 5146' TVD N/A Shane Germann STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-026 P.O. Box 100360, Anchorage, AK 99510 50-103-20486-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst 8933' MD 108' 2337' 108' 3008' 5656'9940' 16" 9-5/8" 80' 2980' 9392-9402' (below cement plug) 9914' 5374-5379' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 10/28/2024 3-1/2" Packer: Baker 80-40 Seal Assy 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 Grace Christianson at 1:11 pm, Sep 10, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2024.09.10 10:47:43-08'00' Foxit PDF Editor Version: 13.0.0 324-519 BOPtestto2500psig Annular preventer test to 2500 psig A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. XXX DSR-9/13/24 June 30, 2025 A variance from 20 AAC 25.112(a)(1)(A)which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata is granted to instead allow 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. X 10-407AOGCC witness required after wellhead cutoff and prior to top job if needed VTL 10/20/2024 787 Abandon See attached "Conditions of Approval" Abandoned SFD SFD 10/4/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.21 20:06:07 -08'00'10/21/24 RBDMS JSB 102224 KRU 2P-449 Abandonment Conditions of Approval: 1. 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. 2. 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). 3. A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. 4. 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. 5. If surface abandonment operations are not initiated within 30 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 within 30 days after the completion of workover operations to date. 6. Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20 AAC 25.120. 7. 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. 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It has no known tubing or IA integrity issues. This well will be P&A’d as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for the Willow development project in 2026. This well was suspended via reservoir cement plug and intermediate cement plug. The objective of this procedure is to pump the surface casing shoe cement plug and final abandonment cement plug with Nordic 3 and ultimately execute final abandonment. Well Data Meltwater Formation: x Reservoir pressure 7/4/2018 = 1259 psi @ 5400’ TVD x MASP = 719 psi C-80 Formation: x OAP = 209 psi (11/5/22) (fluid packed with diesel) x MASP = 787 psi Anticipated intermediate plug TOC = 7325’ MD Anticipated tubing cut depth = 3350’ MD Production Casing Cement: 125.9 bbls of 15.8# Class G Cement Calculated TOC @ 7,280' KB 2P-449 Well Suspension Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 8,946' KB, 15.5# x 9.3#, L-80 BTCM Set @ 8,933’ KB T-3 Peforations: @ 9,392' – 9,402' KB (10') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,007.8' KB (2337' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUEM Set @ 8,933' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &DdƵďŝŶŐ,ĂŶŐĞƌ Ϯϯ͘ϱΖ Ϯ ĂŵĐŽ^EŝƉƉůĞ ϰϲϱ͘ϴΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ ĂŵĐŽϮ͘ϴϭϯΗ^WƌŽĨŝůĞ ϴ͕ϴϱϯ͘ϲΖ ϰ ĂŵĐŽEŝƉƉůĞ ϴ͕ϴϲϵ͘ϲΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌ ϴ͕ϵϭϰ͘ϮΖ ϲ ĂŬĞƌϴϬͲϰϬ^ĞĂůƐƐĞŵďůǇǁͬ ϭͬϮDƵůĞƐŚŽĞ ϴ͕ϵϭϱΖ C80 @ 3200' KB C80 @ 3200' KB Plug #1 – Reservoir TOC ±9240' RKB Plug #2 – Intermediate TOC ±7325' RKB BOC @ ±8825' RKB Surface Casing Plugs – Rig Date: 9-9-2024 Prepared by: Shane Germann Estimated Start Date: 10-28-2024 MIRU 1. MIRU on 2P-449. 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 31 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 5-1/2” casing is between 150’ – 200’ TVD inside the surface casing shoe based on space out of a casing collar at the Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe Set bridge plug in production casing 100’ below surface casing shoe target a Ʊnal TOC ±150’ TVD Pump cement plug through the production casing cut MU landing joint for production casing hanger and conƱrm casing is free from cut. Cut production casing 50’ below surface 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 b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư- rig remediation. .Tag cement and PT to 1,500 PSI with state witness A Variance is requested to 20 AAC 25.112 requirin g cement 100’ below hydrocarbon bearing zones. It is our intention to recover 50’ of production casin g 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. Production Casing Cement: 125.9 bbls of 15.8# Class G Cement Calculated TOC @ 7,280' KB 2P-449 Well Surface Shoe Cement Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 8,946' KB, 15.5# x 9.3#, L-80 BTCM Set @ 8,933’ KB T-3 Peforations: @ 9,392' – 9,402' KB (10') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,007.8' KB (2337' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUEM Set @ 8,933' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϯ͘ϱΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϭϭϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ ĂŵĐŽϮ͘ϴϭϯΗ^WƌŽĨŝůĞ ϴ͕ϴϱϯ͘ϲΖ ϰ ĂŵĐŽEŝƉƉůĞ ϴ͕ϴϲϵ͘ϲΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌ ϴ͕ϵϭϰ͘ϮΖ ϲ ĂŬĞƌϴϬͲϰϬ^ĞĂůƐƐĞŵďůǇǁͬ ϭͬϮDƵůĞƐŚŽĞ ϴ͕ϵϭϱΖ C80 @ 3200' KB C80 @ 3200' KB Plug #1 – Reservoir TOC ±9240' RKB Plug #2 – Intermediate TOC ±7325' RKB BOC @ ±8825' RKB Base of 5-½” Casing 350'-400' MD Inside Surface Shoe Plug #3 – Surface Shoe TOC 2690' RKB (2187' TVD) BOC @ ±3110' RKB ϮWͲϰϰϵϮĂůĐƵůĂƚĞĚWdKΛϳϮϴϬ͛Z<^^ŚŽĞΛϯϬϬϳ͛Z</WΛϯϭϭϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϲϵϬ͛Z<WƵƚΛϯϬϲϬ͛Z<ϴϬΛϯϮϬϬ͛Z<5119' RKB 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 3060 3110 Open Hole 8.5 0.06460 3.2 Displacement of Prod Casing Stub Included in BBL/FT calc 3008 3060 Open Hole 8.5 0.07018 3.6 2690 3008 Surface Casing 8.83 0.07574 24.1 30.9 Total Volume of Plug Surface Casing 23 2690 Surface Casing 8.83 0.07016 187.1 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-449 c. PTD #: 204-026 d. API #: 50-103-20486-00-00 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 Production Casing Cement: 125.9 bbls of 15.8# Class G Cement Calculated TOC @ 7,280' KB 2P-449 Well Final P&A Schematic Conductor: 16" Conductor 108' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 8,946' KB, 15.5# x 9.3#, L-80 BTCM Set @ 8,933’ KB T-3 Peforations: @ 9,392' – 9,402' KB (10') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,007.8' KB (2337' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUEM Set @ 8,933' KB 6 /ƚĞŵĞƉƚŚͲƚŽƉƐ ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϯ͘ϱΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϭϭϬΖ ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ ĂŵĐŽϮ͘ϴϭϯΗ^WƌŽĨŝůĞ ϴ͕ϴϱϯ͘ϲΖ ϰ ĂŵĐŽEŝƉƉůĞ ϴ͕ϴϲϵ͘ϲΖ ϱ ĂŬĞƌ'ͲϮϮ>ŽĐĂƚŽƌ ϴ͕ϵϭϰ͘ϮΖ ϲ ĂŬĞƌϴϬͲϰϬ^ĞĂůƐƐĞŵďůǇǁͬ ϭͬϮDƵůĞƐŚŽĞ ϴ͕ϵϭϱΖ C80 @ 3200' KB C80 @ 3200' KB Plug #1 – Reservoir TOC ±9240' RKB Plug #2 – Intermediate TOC ±7325' RKB BOC @ ±8825' RKB Plug #3 – Surface Shoe TOC 2690' RKB (2187' TVD) BOC @ ±3110' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2690' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 9,320.0 2P-449 6/24/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled SOV. 2P-449 8/27/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/29/2010 haggea Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.70 28.1 3,007.8 2,336.7 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 8946' 5 1/2 4.95 25.7 9,940.0 5,656.2 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.5 Set Depth … 8,933.0 Set Depth … 5,154.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.5 23.5 0.03 HANGER 8.000 FMC TUBING HANGER 3.500 465.8 465.6 4.46 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 2,693.5 2,188.5 62.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,147.4 3,371.0 61.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,761.4 4,133.6 62.73 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 7,970.2 4,690.2 61.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,803.6 5,093.2 61.60 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,853.6 5,117.0 61.65 SLEEVE 4.500 CAMCO CMU SLIDING SLEEVE W/CAMCO 2.813" DS PROFILE CAMCO CMU 2.810 8,869.6 5,124.6 61.75 NIPPLE 4.490 CAMCO D NIPPLE CAMCO D 2.750 8,914.2 5,145.6 62.00 LOCATOR 4.500 BAKER G-22 LOCATOR G-22 3.000 8,915.0 5,146.0 62.01 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSEMBLY w/ 1/2 MULESHOE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,825.0 5,103.4 61.49 TUBING PUNCH TUBING PUNCH, 3FT @ 6 SPF, 0 DEGREE PHASE. 8/6/2024 2.992 8,869.5 5,124.5 61.75 FISH Nose cone and pinning ring from latch 10/23/2020 0.000 8,900.0 5,138.9 61.92 FISH Check & Spring JUNK LEFT IN TUBING - CHECK AND SPRING FROM 1" OV - BOTTOM LATCH 3/19/2004 3/19/2004 9,369.3 5,362.9 60.20 CIBP 2.63" CIBP (MID-ELEMENT AT 9370' RKB) OAL=1.39' TTS CIBP N/A 4/2/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,693.5 2,188.5 62.13 1 GAS LIFT Open 1 8/27/2024 5,147.4 3,371.0 61.91 2 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 6,761.4 4,133.6 62.73 3 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 7,970.2 4,690.2 61.59 4 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 8,803.6 5,093.2 61.60 5 GAS LIFT DMY BTM 1 0.0 8/3/2024 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,392.0 9,402.0 5,374.2 5,379.2 T-3, 2P-449 3/5/2004 6.0 IPERF 60 deg phase, PJ 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) 9,392.0 9,402.0 1 FRAC 3/13/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,240.0 9,369.3 5,299.7 5,362.9 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 9320' RKB 6/24/2024 7,325.0 8,828.0 4,393.8 5,104.8 Cement Plug PUMPED 31 BBLS OF 15.8 CLASS G CEMENT FOR INTERMEDIATE BALANCED PLUG 8/23/2024 2P-449, 8/28/2024 9:13:49 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 8946'; 25.7-9,940.0 FLOAT SHOE; 9,939.4-9,940.0 FLOAT COLLAR; 9,845.2- 9,845.9 FRAC; 9,392.0 IPERF; 9,392.0-9,402.0 CIBP; 9,369.3 Cement Plug; 9,240.0 ftKB SBE; 8,926.5-8,946.0 SEAL ASSY; 8,915.0 LOCATOR; 8,914.2 FISH; 8,900.0 NIPPLE; 8,869.6 FISH; 8,869.5 SLEEVE; 8,853.6 TUBING PUNCH; 8,825.0 GAS LIFT; 8,803.6 GAS LIFT; 7,970.2 Cement Plug; 7,325.0 ftKB GAS LIFT; 6,761.4 GAS LIFT; 5,147.4 SURFACE; 28.1-3,007.8 FLOAT SHOE; 3,006.1-3,007.8 FLOAT COLLAR; 2,929.9- 2,931.4 GAS LIFT; 2,693.5 NIPPLE; 465.8 CONDUCTOR; 28.0-108.0 HANGER; 28.1-29.3 HANGER; 25.7-28.2 HANGER; 23.5 KUP PROD KB-Grd (ft) 32.41 RR Date 2/22/2004 Other Elev… 2P-449 ... TD Act Btm (ftKB) 9,946.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048600 Wellbore Status PROD Max Angle & MD Incl (°) 63.09 MD (ftKB) 7,801.71 WELLNAME WELLBORE2P-449 Annotation Last WO: End DateH2S (ppm) 30 Date 11/23/2015 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. From:Germann, Shane To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); O"Connor, Katherine Subject:RE: [EXTERNAL]DS-2P Surface casing shoe abandonment operations questions Date:Monday, September 30, 2024 3:20:07 PM Victoria, Greg Hobbs, Katherine O’Connor, and I compiled the answers in red to your questions below. They should fill in points that were made in prior meeting discussions but not fully captured. Let me know if anything further is needed. Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, September 30, 2024 11:28 AM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Germann, Shane <Shane.Germann@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL]DS-2P Surface casing shoe abandonment operations questions 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. Greg, Shane, Outlined below are several requests/questions concerning the DS-2P future abandonments: 1. I know we have reviewed this question in meetings but would like a written response to this question: What are the advantages/disadvantages to using the production casing as the cementing string? Efficiency and reduction of pipe handling on-rig are the biggest advantages. Pulling the PC on each well would add a substantial amount of rig time and pipe handling for the crews throughout the entirety of the campaign. The only disadvantage of using the PC as the cementing string is the tighter annulus clearance which can increase the likelihood of cement contamination versus using a smaller string. Our goal is to utilize the PC successfully considering the changes we’re making to cement designs, but we’ll keep the option open to use a smaller string (most likely 3.5” tubing) if we’re seeing issues. 2. We had discussion concerning cutting the production casing 50’ below the surface casing shoe versus a deeper cut. There was some discussion on the value of logging prior to making the cut. Also, there was past experience information presented. Please provide information justifying the 50’ cut below the surface casing shoe. Experience with casing recovery operations have found that logs may not show the extent of formation collapse around casing that prevents it from being movable. The most recent example of this was 3S-626 where logs showed free pipe, but cement debris led to the pipe being pulled in 40-foot sections or less due to the cement debris around it that was not noted from the logging pass. Greg Hobbs brought extensive experience with slot recovery operations from BP. That experience found that recovery of casing deeper than 50 feet below the surface casing shoe became significantly harder with multiple cuts and jarring operations to retrieve the short sections of casing. This experience was replicated in the few slot recovery operations at Kuparuk in the past 10 years. The reflection of this experience during our meetings led to the intermediate casing cut point 50 feet below the surface shoe. 3. What modifications have been made in the cementing procedure for the surface casing shoe plug given the difficulties in setting the plug for 2P-415A? Here are the cement design and procedure changes we’re targeting for this campaign: a. Targeting a 150’ TVD cement height instead of MD b. Cement design- additives being utilized to help combat microannuli and improve bond to casing c. Improvements to wellbore cleanup techniques prior to pumping cement (surfactant wash targeting a minimum contact time) d. Batch mixing cement instead of mixing on the fly 4. If the well is suspended and the rig moved off, what are the plans, including timing for the non-rig abandonment? The general plan is to cleanout cement to the surface casing shoe using a coil underreamer. Then do a hesitation squeeze program with a fairly aggressive cement ramp, and lay in the same size plug as the rig laid in. Specific timing for this would be based on SIMOPS with the rig & excavation crew, but intention would be to follow the rig timing fairly closely. The hope is still to get these wells fully abandoned ASAP. 5. What are the timing plans for the surface abandonments included in these sundries? After the rig is successful abandoning the wells to surface, the excavation crew will be following ~4 wells behind to do the excavation and cuts. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From:Germann, Shane To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451 Date:Wednesday, September 25, 2024 2:52:29 PM Hi Victoria, That's correct, the depths provided are the top of the C-80. For the C-80 bottom depths, our geologist informed me to use the top of the C37 which should be picked on each of the logs I sent you. He said the C-37 marker is the next best correlative marker below the C-80 marker. I have provided those depths below: 2P-451 - 3556' RKB 2P-449 - 5119' RKB 2P-448A - 4594' RKB We are planning to have 15 sundries/wells will this type of SC shoe cement plug. Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 -----Original Message----- From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, September 25, 2024 1:48 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451 For the three sundries, please send me the C80 bottom depths, RKB. I'm assuming the depths provided are the top of the C-80? Also, how many sundries(wells) will have this type of plug at the SC shoe? -----Original Message----- From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Tuesday, September 17, 2024 9:11 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451 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. Hi Victoria, I attached a PDF version of the slides I created for the 3 wells. Each well has a slide with its log and the desired annotations described below. Please let me know if you have any questions. Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 -----Original Message----- From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, September 13, 2024 3:08 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451 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. Shane, Please provide for each well a log showing the C-80 and the depths of the SC shoe, retainer, cement plug TOC, TOC outside PC and PC cut. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 1 Christianson, Grace K (OGC) From:Loepp, Victoria T (OGC) Sent:Monday, October 21, 2024 4:07 PM To:Christianson, Grace K (OGC) Subject:Fwd: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag Please PDF this email and add it to the 3 2P sundries in the Commissioners folders Thank you Sent from my iPhone Begin forwarded message: From: "Germann, Shane" <Shane.Germann@conocophillips.com> Date: October 21, 2024 at 3:57:14ௗPM AKDT To: "Loepp, Victoria T (OGC)" <victoria.loepp@alaska.gov> Cc: "Hobbs, Greg S" <Greg.S.Hobbs@conocophillips.com>, "O'Connor, Katherine" <Katherine.OConnor@conocophillips.com> Subject: RE: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag Hi Victoria, See below table for the data requested. This should cover the sundries submitted so far except for the 2P-434 which we’re checking pressures on. These pressures are the latest I had available which is from the most recent work done on the well. If more recent pressures are desired, please advise as we’ll have to request somebody take the readings. Keep in mind that other prep work being done on the wells may affect the T&IA pressures due to U-tubing, circ outs, temperature changes, etc. I’ll make sure to include this data for future submissions as well as show the actual TOC depths for previous plugs on the schematics. Well Name Previous plug tag depth (RKB) PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-451 3785' Pass 9/2/2024 50 psi 50 psi 75 psi 9/5/2024 2P-449 7187' Pass 9/2/2024 0 psi 75 psi 190 psi 9/3/2024 2P-448A 5076' Pass 10/5/2024 0 psi 0 psi 220 psi 10/6/2024 2P-443 3789' Pass 9/2/2024 0 psi 0 psi 175 psi 9/4/2024 2P-441 3846' Pass 10/5/2024 0 psi 0 psi 230 psi 10/17/2024 2P-438 6495' Pass 9/2/2024 0 psi 0 psi 175 psi 9/3/2024 Thanks, Shane Germann CTD/RWO Engineer 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. 2 ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, October 21, 2024 12:36 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag 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. Shane, Please provide the following information for each 2P well abandonment sundry. 1. Date and results of passing state witnessed PT and tag of previous plug. 2. Current pressures of all annuli and tubing. Please provide for 2P-448A, 2P-449 and 2P-451 asap and follow with the others. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 ORIGINATED TRANSMITTAL DATE: 8/8/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4984 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4984 2P-449 501032048600 Tubing Puncher Record 6-Aug-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 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 204-026 T39394 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.08 13:39:30 -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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:17 8N Range:7E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:9946 ft MD Lease No.:ADL 0373112 Operator Rep:Suspend:X P&A:NA Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ NA Feet Surface:9-5/8"O.D. Shoe@ 3008 Feet Csg Cut@ NA Feet Intermediate:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production:5-1/2" x 3-1/2"O.D. Shoe@ 9940 Feet Csg Cut@ NA Feet Liner:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing:3-1/2"O.D. Tail@ 8933 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 8825 ft MD 7187 ft MD 9.8/6.7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1950 1870 1845 IA 1760 1720 1710 OA 256 279 248 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to location to witness the slickline tag and combo mechanical integrity test (CMIT TxIA) of the intermediate cement plug that was pumped on 8/23/2024. With an 1-3/4 inch bailer assembly they tagged at 7187 ft MD (62°) with multiple hard set downs. Sample observed in bailer. With the top gas lift mandrel sheared they then completed a passing CMIT to a target of 1500psi. Tubing was punched at 8825 ft MD (bottom depth of plug) prior to cement job. August 2, 2024 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-449 ConocoPhillips Alaska, Inc. PTD 2040260; Sundry 324-397 none Test Data: CMIT TxIA P Casing Removal: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0902_Plug_Verification_KRU_2P-449_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: Suspend- intermediate Plug 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9946'8869', 8900' 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-449 5659' 9240' 5230' 9240' 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): 8915' MD and 5146' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-026 P.O. Box 100360, Anchorage, AK 99510 50-103-20486-00-00 Kuparuk River Field Meltwater Oil Pool- Suspended ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst 8933' MD 108' 2337' 108' 3008' 5656'9940' 16" 9-5/8" 80' 2980' 9392-9402' (below cement plug) 9914' 5374-5379' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 3-1/2" Packer: Baker 80-40 Seal Assy 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 07/22/2024 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: 2024.07.11 16:02:40-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor 324-397 By Grace Christianson at 9:22 am, Jul 12, 2024 DSR-7/15/24SFD 7/15/2024 X VTL 7/17/2024 X 10-407 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.17 14:22:11 -08'00'07/17/24 RBDMS JSB 072324 Procedure Wireline & Pumping 1. Punch tubing at ±8,825’ RKB 2. Pump the following schedule taking returns up the IA: a. ±50 bbls surfactant wash b. ±200 bbls 9.8 brine c. ±31 bbls cement d. ±64 bbls 9.8 brine displacement 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 7325’ MD 4. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline 1. RIH with jet cutter and cut tubing at ±3350’ KB. Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 8825 3.5" 9.3# 2.99" 0.0087 8825 76.6 115.1 from punch depth 3-1/2" x 5-1/2" Annulus 0 8825 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 8825 105.0 84.0 from punch depth Tubing Cement 7325 8825 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 7325 8825 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0 2P-449 Intermediate Plug Procedure Date Written: 6-3-24 Prepared by: Katherine O’Connor (214-684-7400) Background & Objective 2P-449 was a producer shut-in in mid 2021. It has no known tubing or IA integrity issues. 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 has been suspended, and the objective of this procedure is to pump an intermediate balanced cement plug before the rig shows up to complete the P&A in Q4 2024. Well Data Reservoir pressure 7/04/2018 = 1259 psi at 5400’ TVD = 0.233 psi/ft MASP = 719 psi TxIA communication, MITT failed at 2500 psi. LLR 0.004 gpm @ 3000 psi Last TD tag 5/2/2016 @ 9400’ KB Well has history of mild paraffin Suspended with CIBP and cement.TOC tagged 9240’ KB. Passing CMIT-TxIA 4/2/42 2P-449 Well Suspension Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 125.9 bbls of 15.8# Class G Cement Calculated TOC @ 7,280' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 8,946' KB, 15.5# x 9.3#, L-80 BTCM Set @ 8,933’ KB T-3 Peforations: @ 9,392' – 9,402' KB (10') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,007.8' KB Production Tubing: 3 ½”, 9.3# L-80 EUEM Set @ 8,933' KB 6 Item Depth - tops (KB) 1 FMC Tubing Hanger 23.5' 2 Camco DS Nipple 465.8' 3 Baker CMU Sliding Sleeve w/ Camco 2.813" DS Profile 8,853.6' 4 Camco D Nipple 8,869.6' 5 Baker G-22 Locator 8,914.2' 6 Baker 80-40 Seal Assembly w/ 1/2 Muleshoe 8,915' C80 @ 3010' KB C80 @ 3010' KB Plug #1 – Reservoir TOC 9240' RKB Plug #2 – Intermediate TOC ±7325' RKB BOC @ ±8825' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 9,320.0 2P-449 6/24/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement on top of CIBP 2P-449 6/24/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/29/2010 haggea Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.70 28.1 3,007.8 2,336.7 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 8946' 5 1/2 4.95 25.7 9,940.0 5,656.2 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.5 Set Depth … 8,933.0 Set Depth … 5,154.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.5 23.5 0.03 HANGER 8.000 FMC TUBING HANGER 3.500 465.8 465.6 4.46 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 2,693.5 2,188.5 62.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,147.4 3,371.0 61.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,761.4 4,133.6 62.73 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 7,970.2 4,690.2 61.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,803.6 5,093.2 61.60 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,853.6 5,117.0 61.65 SLEEVE 4.500 CAMCO CMU SLIDING SLEEVE W/CAMCO 2.813" DS PROFILE CAMCO CMU 2.810 8,869.6 5,124.6 61.75 NIPPLE 4.490 CAMCO D NIPPLE CAMCO D 2.750 8,914.2 5,145.6 62.00 LOCATOR 4.500 BAKER G-22 LOCATOR G-22 3.000 8,915.0 5,146.0 62.01 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSEMBLY w/ 1/2 MULESHOE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,869.5 5,124.5 61.75 FISH Nose cone and pinning ring from latch 10/23/2020 0.000 8,900.0 5,138.9 61.92 FISH Check & Spring JUNK LEFT IN TUBING - CHECK AND SPRING FROM 1" OV - BOTTOM LATCH 3/19/2004 3/19/2004 9,369.3 5,362.9 60.20 CIBP 2.63" CIBP (MID-ELEMENT AT 9370' RKB) OAL=1.39' TTS CIBP N/A 4/2/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,693.5 2,188.5 62.13 1 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 5,147.4 3,371.0 61.91 2 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 6,761.4 4,133.6 62.73 3 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 7,970.2 4,690.2 61.59 4 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 8,803.6 5,093.2 61.60 5 GAS LIFT OPEN 1 3/22/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,392.0 9,402.0 5,374.2 5,379.2 T-3, 2P-449 3/5/2004 6.0 IPERF 60 deg phase, PJ 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) 9,392.0 9,402.0 1 FRAC 3/13/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,240.0 9,369.3 5,299.7 5,362.9 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 9320' RKB 6/24/2024 2P-449, 7/11/2024 1:19:46 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 8946'; 25.7-9,940.0 IPERF; 9,392.0-9,402.0 FRAC; 9,392.0 CIBP; 9,369.3 Cement Plug; 9,240.0 ftKB FISH; 8,900.0 FISH; 8,869.5 GAS LIFT; 8,803.6 GAS LIFT; 7,970.2 GAS LIFT; 6,761.4 GAS LIFT; 5,147.4 SURFACE; 28.1-3,007.8 GAS LIFT; 2,693.5 NIPPLE; 465.8 CONDUCTOR; 28.0-108.0 KUP PROD KB-Grd (ft) 32.41 RR Date 2/22/2004 Other Elev… 2P-449 ... TD Act Btm (ftKB) 9,946.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048600 Wellbore Status PROD Max Angle & MD Incl (°) 63.09 MD (ftKB) 7,801.71 WELLNAME WELLBORE2P-449 Annotation Last WO: End DateH2S (ppm) 30 Date 11/23/2015 Comment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Rig Elevation: Total Depth: 9946 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface: 9 5/8" O.D. Shoe@ 3008 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5 1/2"x3 1/2" O.D. Shoe@ 9940 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 8933 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 9369 ft 9240 ft 8.4 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1700 1660 1640 IA 1560 1540 1525 OA 247 242 238 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Pre-test pressures Tbg = 240 / IA =1200 / OA 195 July 5th 2024 Brian Bixby Well Bore Plug & Abandonment KRU 2P-449 ConocoPhillips Alaska Inc. PTD 2040260; Sundry 323-600 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0705P_Plug_Verification_KRU_2P-449_bb 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.14 14:51:46 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 108' 9.625" L-80 2337' 5.5" L-80 5146' 3.5" L-80 5656' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above8.5" TUBING RECORD 604 sx Class G w/ GasBlok8.5" 8933' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 7/5/2024 204-026/ 323-600 50-103-20486-00-00 KRU 2P-449 ADL0373112, ADL0389058 1026' FNL, 1564' FWL, Sec. 17, T8N, R7E, UM 1700' FNL, 1879' FEL, Sec. 19, T8N, R7E, UM ALK 32092, ALK 32409 2/11/2004 9946' MD/ 5659' TVD 9240' MD/ 5230' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443523 5868854 1006' FNL, 1873' FEL, Sec. 19, T8N, R7E, UM 9. Ref Elevations: KB: 28' WT. PER FT.GRADE 2/19/2004 CEMENTING RECORD 5863620 1406' MD / 1347' TVD SETTING DEPTH TVD 5862927 TOP HOLE SIZE AMOUNT PULLED 440065 440057 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A N/A PACKER SET (MD/TVD) 24" 12.25" 15 bbl AS I 28'337 sx AS III, 274 sx LiteCrete 9.3# 28' 8915' 3008'28' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# 9240' (SW TOC) - 9369' 0.26 bbls 15.8 ppg Class G cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 9392-9402' MD and 5374-5379' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 8915' SIZE DEPTH SET (MD) 9940' 26' 5146' 62.45# 40# 108' 26' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 1:32 pm, Jul 12, 2024 Suspended 7/5/2024 JSB RBDMS JSB 071724 xGSFD 3/25/2025 DSR-8/27/24 252' SFD Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1406' 1347' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Suspended N/A- Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'ConnorDN: 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: 2024.07.11 14:30:14-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 9,320.0 2P-449 6/24/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement on top of CIBP 2P-449 6/24/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/29/2010 haggea Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 28.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.70 28.1 3,007.8 2,336.7 40.00 L-80 BTC PRODUCTION 5.5"x3.5" @ 8946' 5 1/2 4.95 25.7 9,940.0 5,656.2 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.5 Set Depth … 8,933.0 Set Depth … 5,154.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUEM ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.5 23.5 0.03 HANGER 8.000 FMC TUBING HANGER 3.500 465.8 465.6 4.46 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875 2,693.5 2,188.5 62.13 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 5,147.4 3,371.0 61.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,761.4 4,133.6 62.73 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 7,970.2 4,690.2 61.59 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,803.6 5,093.2 61.60 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 8,853.6 5,117.0 61.65 SLEEVE 4.500 CAMCO CMU SLIDING SLEEVE W/CAMCO 2.813" DS PROFILE CAMCO CMU 2.810 8,869.6 5,124.6 61.75 NIPPLE 4.490 CAMCO D NIPPLE CAMCO D 2.750 8,914.2 5,145.6 62.00 LOCATOR 4.500 BAKER G-22 LOCATOR G-22 3.000 8,915.0 5,146.0 62.01 SEAL ASSY 3.980 BAKER 80-40 SEAL ASSEMBLY w/ 1/2 MULESHOE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,869.5 5,124.5 61.75 FISH Nose cone and pinning ring from latch 10/23/2020 0.000 8,900.0 5,138.9 61.92 FISH Check & Spring JUNK LEFT IN TUBING - CHECK AND SPRING FROM 1" OV - BOTTOM LATCH 3/19/2004 3/19/2004 9,369.3 5,362.9 60.20 CIBP 2.63" CIBP (MID-ELEMENT AT 9370' RKB) OAL=1.39' TTS CIBP N/A 4/2/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,693.5 2,188.5 62.13 1 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 5,147.4 3,371.0 61.91 2 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 6,761.4 4,133.6 62.73 3 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 7,970.2 4,690.2 61.59 4 GAS LIFT DMY BTM 1 0.0 2/21/2004 0.000 8,803.6 5,093.2 61.60 5 GAS LIFT OPEN 1 3/22/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,392.0 9,402.0 5,374.2 5,379.2 T-3, 2P-449 3/5/2004 6.0 IPERF 60 deg phase, PJ 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) 9,392.0 9,402.0 1 FRAC 3/13/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,240.0 9,369.3 5,299.7 5,362.9 Cement Plug Dump bailed cement with Slickline on top of CIBP. Estimated TOC @ 9320' RKB 6/24/2024 2P-449, 7/11/2024 11:13:56 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 8946'; 25.7-9,940.0 IPERF; 9,392.0-9,402.0 FRAC; 9,392.0 CIBP; 9,369.3 Cement Plug; 9,240.0 ftKB FISH; 8,900.0 FISH; 8,869.5 GAS LIFT; 8,803.6 GAS LIFT; 7,970.2 GAS LIFT; 6,761.4 GAS LIFT; 5,147.4 SURFACE; 28.1-3,007.8 GAS LIFT; 2,693.5 NIPPLE; 465.8 CONDUCTOR; 28.0-108.0 KUP PROD KB-Grd (ft) 32.41 RR Date 2/22/2004 Other Elev… 2P-449 ... TD Act Btm (ftKB) 9,946.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032048600 Wellbore Status PROD Max Angle & MD Incl (°) 63.09 MD (ftKB) 7,801.71 WELLNAME WELLBORE2P-449 Annotation Last WO: End DateH2S (ppm) 30 Date 11/23/2015 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 3/23/2024 CHANGE WELL TYPE PULL 2.75" CSV FROM D NIPPLE @ 8869' RKB, DRIFT 2.623" DUMMY CIBP TO TD @ 9401' RKB, READY TO LOAD AND SET CIBP. 4/2/2024 CHANGE WELL TYPE LOAD TBG & IA WITH SEAWATER AND DIESEL FREEZE PROTECT. SET 3.5" CIBP AT 9370'. CMIT TxIA TO 1500 PSI (PASS) JOB COMPLETE, READY FOR SLICKLINE 6/22/2024 CHANGE WELL TYPE TAG CIBP @ 9369' RKB, LDFN. JOB IN PROGRESS 6/23/2024 CHANGE WELL TYPE DUMP CEMENT ON TOP OF CIBP @ 9369' RKB, LDFN. JOB IN PROGRESS 6/24/2024 CHANGE WELL TYPE DUMP CEMENT ON TOP OF CIBP @ 9369' RKB, RIH & TAG CEMENT @ 9320' RKB, LET CEMENT CURE FOR 72 HOURS THEN READY FOR SW TAG & TEST. 7/5/2024 CHANGE WELL TYPE TAG TOC @ 9240' SLM.PERFORM PASSING MIT-T TO 1500 PSI. STATE WITNESSED BY BRIAN BIXBY. READY FOR NEXT CEMENTING PROCEDURE. 2P-449 Suspend Summary of Operations 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): 9946'8869', 8900' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11/20/2023 3-1/2" Packer: Baker 80-40 Seal Assy SSSV: None Perforation Depth MD (ft): L-80 2980' 9392-9402' 9914' 5374-5379' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 108' 3008' 5656'9940' 16" 9-5/8" 80' 8933' MD 108' 2337' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112, ADL0389058 204-026 P.O. Box 100360, Anchorage, AK 99510 50-103-20486-00-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8915' MD and 5146' TVD N/A Katherine O'Connor Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com (907) 263-3718 Well Interventions Engineer KRU 2P-449 5659' 9946' 5659' None 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 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: 2023.11.06 07:48:12-09'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 323-600 By Grace Christianson at 9:22 am, Nov 06, 2023 X X 10-407 DSR-11/8/23SFD 11/8/2023 12/31/24 VTL 11/14/2023*&:JLC 11/15/2023 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.11.15 14:27:22 -09'00'11/15/23 RBDMS JSB 111623 2P-449 Suspension Date Wrien: 10-03-23 Execuon Date: Nov 20, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-449 was a producer shut-in in mid 2021. It has no known tubing or IA integrity issues. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 7/04/2018 = 1259 psi at 5400’ TVD MASP = 719 psi TxIA communication, MITT failed at 2500 psi. LLR 0.004 gpm @ 3000 psi Last TD tag 5/2/2016 @ 9400’ KB Well has history of mild parrafin Procedure Wireline & Pumping 1. Pull CSV from 8865’ KB 2. Drift with dummy CIBP to TD. If unable to get within 50’ of perforations, contact Katherine O’Connor 3. Fluid pack tubing & IA as necessary with KWF and freeze protect 4. Set CIBP @ ±9,370’ RKB (must be set within 50’ of the top of perforations). 5. Perform CMIT-TxIA to 1500 psi, record results 6. Dump bail at least 30’ of cement on top of CIBP 7. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 8. RIH and tag TOC, approx. 9,340’ RKB (MUST BE AOGCC WITNESSED) 9. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 10. Perform DDT to 0 psi and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval 2P-449 Well Suspension Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 125.9 bbls of 15.8# Class G Cement Calculated TOC @ 7,280' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 8,946' KB, 15.5# x 9.3#, L-80 BTCM Set @ 8,933’ KB T-3 Peforations: @ 9,392' – 9,402' KB (10') Surface Casing: 9-5/8", 40#, L-80 BTC Set @ 3,007.8' KB Production Tubing: 3 ½”, 9.3# L-80 EUEM Set @ 8,933' KB 6 Item Depth - tops (KB) 1 FMC Tubing Hanger 23.5' 2 Camco DS Nipple 465.8' 3 Baker CMU Sliding Sleeve w/ Camco 2.813" DS Profile 8,853.6' 4 Camco D Nipple 8,869.6' 5 Baker G-22 Locator 8,914.2' 6 Baker 80-40 Seal Assembly w/ 1/2 Muleshoe 8,915' C80 @ 3010' KB C80 @ 3010' KB Plug #1 – Reservoir TOC ±9340' RKB ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 4- - () ;)...(0 Well History File Identifier Organizing (done) ~wo-sided 1111111111111111111 D Rescan Needed 1111111111111111111 ;?:,CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: o Diskettes, No. D Maps: D Greyscale Items: D Other, No/Type: D Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: o Logs of various kinds: NOTES: o Other:: BY: , Maria) Date: 4: S / (J (0 151 m-2 111111111111111111I Project Proofing BY: ~ Maria) Date: Lf 5- /0 fa 151 mp Scanning Preparation ~ x 30 =f;D + ï' = TOTAL PAGES ~l tV{Q ~ Date: If ~ /J ~ . (Count does not include cover sh et) BY: 151 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: to g (Count does include cover sheet) Page Count Matches Number in Scanning ~ï..Paration: V YES CMaria.J Date: It /5'/ Db Stage 1 If NO in stage 1, page(s) discrepancies were found: 151 NO }1fJ BY: YES NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111 III BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • -,.. =~; - .. MICROFILMED 03101/2008 DO NOT PLACE y_: ~..., .ham' °"~. ~y , ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc Œ 04/05/07 SI~.~eI'IIP RECEIVED NO. 4205 .... .".....'-~ ". "- .~.. . .~ -' '.......... Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR 0 6 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ 011 & Gas Cons. Commission Anchorage SCANNED APR 1. 0 2007 {)tI-( - Wk, Field: Kuparuk WeU Job# Log Description Date BL Color CD 2M.12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1 H-02 11638845 GLS 03/21/07 1 2W-05 11632686 SHUT IN BHP 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-331' N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'6 . . '~ ..--- Conoc~hillips Alaska REcC~·~1\!ED .JUL 1) 5 2G06 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 _j}~'1a3:{~ .., :+1 ~ i:cmm¡3$h}~ ;~n&~lCrage June 06,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ~Ci\NNED ,JUL 0 ~? 2006 a,OL-J 0 .;L~ 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 of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG240 1, then filled with a viscous hydrocarbon based sealant, Royfill 404B~ 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. ~ ~o Perry Klein ConocoPhillips Problem Well Supervisor (" (.. ~ ~........ J, d ~ 06!~O/06 Attachment - -. ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Corrosion Well Initial top Vol. of cement Final top of Cement top Royfill404B inhibitor/ Name PTD# of cement pumped cement off date RG2041 vol vol. sealant date ft bbls ft Qal gal 5/19/2006 2P-406 2Q4.022 4 ,0.0' 4 na :. 5;7 17.1 ' 5/1912006 2P-415a 201-226 5.5 0,0 5.5 na 7.1 30.9 5/19/2006 2P-417 201-069 7.5 0.7 2.5. 51-1/2006 ,5.7 9 5118/2006 ' 2P-419 204-017 1 0.0 1 na 6.7 0 5/18/2006 2P-4:2O' '201-182 3.5 0;0 ' -3;5' na 7.1 -17.3 -5/1812006 2P-422a 202-067 13.5 2.3 2.5 5/1/2006 7.1 10.7 5/18/2006 2P-424a 204-009 4~5 0.0 4.5 "na 5.7 .17.6 5/1812006· . 2P-427 202-018 10 1.6 2.5 5/1/2006 7.1 13.7 5/18/2006 . 2P~29 '201~102 2 0.0 2 na 3.8 5~7 511812006 2P-431 202-053 13 1.9 2.5 5/1/2006 7.1 10.1 5/18/2006 2P-432 202-091 8.5 0.9 2.5, 5/1/2006 . ..' 5] 13.8 - 5/1812006 2P-434 203-153 14 2.0 2.5 5/1/2006 5.7 6.2 5/18/2006 2P-438 ,201.~ 5 0.0 5 na - 5.7 21:9 5/18/2006 2P-441 202-107 15 2.0 2.5 5/1/2006 7.1 13.1 5/18/2006 2P-443 2Q4.;()32 3.5 0.0 3.5 na' 8.7 11.4 5/1'812006·, 2 P-44 7 203-154 2.5 0.0 2.5 na 9.5 0 5/18/2006 2P-448a- . 202-005 1.5 0.0 1.5 na 9.5 0 5/18/2006 2P-449 204-026 3 0.0 3 na 5.7 11.5 5/31/2006 "2P-451 202-008 10 2.1 2.5 5/1/2006 . . 7.1 6.5 . 5/1812006 ) ConocÓÁ,illips Alaska 'E"" ("<::!It: f\/r¡;;;.... ).', :AD I;~,,~:;:/.., l'r.l' ~ ': ~~ ~ J U [\\ 1 .~~ . l.; .; ,AJa~¡(a :[m&~3$ GiJU1!S. G0mrnÜ:ir-iml ~\J1Jt~IDW:a~te P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 éX04-1D~(p June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED JUN 2 7 lOUD 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. c Attachment ) ') ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Initial top of cement ft t:,I:~.t"2Þ~~::':':.;"~ .... >;4',':"· 2P-415 5.5 i·,.ò;~i2P.ij't7.·:': ,:':" .ii$;··· 2P-419 1 r)~~~~f.:'::;::·,:.:·'.: :~'5.;: ",. 2P-422 13.5 trni%~~1f~::'; . .' ·:45~·.: .'·~1 2P-427 10 . . ::/2~9:..\ '< '·"2:';' i 2P-431 13 . ·':::;2it"2~:;·::; .:,: ..··.,8j5:~· 2P-434 14 ·"'\2~&~';,'i"; :.:.< : . '.5;:" ,::.~.,): 2P-441 15 '~:~~·i~:i~"~. ,\".' >. ..~~i· ..¡' ·....3:!i<:· 2P-447 2.5 '....;:î'þ~.:', ):···....,.;t5:·· 2P-449 3 ... .. ;:.2P~1. . 'J().:.' Kuparuk Field June 6,2006 Vol. of cement Final top of Cement top pumped cement off date RG2041 vol J bbls ft . ,. ::.~.:.a·· ..:: '.: ·4··· ...' :.. ·...åå ,: . . .' $ 0.0 5.5 na .. ..' ,·,t-7'" . ' . .. , . :'''':':5' . ';:':" "5"1' f1t'j~O·~ '. . "v., ", . ". .' :":&,.' ~ . '.; ,"'.." r. t:£u. ~. '. . QO 1 na ¡ . ;:: '::'::01"C)'<>" ,\::::":-. .:' :":','3.5::'": :'t:' :",·.:<:ma¡:>: :~< ,'''' 2.3 2.5 5/1/2006 :; .:~:a¡(f:.;,:· "'~:~: '.: t..'· ,:)J2!$.:' .:..;; ">:'..:: :'·øa.::;~,:::.':; .,"'~ i: . 1.6 2.5 5/1/2006 :,1 '-";'·:""ot:O:>" ')'2',\ '. ·::~;r~.·:nä.?,: .." .' 1.9 2.5 5/1/2006 . "'(';"'" ."-::'~i9:. . .,. ,¡ ·;~2$~..:,~:~'::5lt_6!· 2.0 2.5 5/1/2006 '.' ·;.:·;ô~:ò.'::'· .. ":."':'::;$'" ~... <;Aå<:·/~:;::· 2.0 2.5 5/1/2006 ,:.:.; :..';0;0' :',.:. .;. .:: '~.:: ·~·53;5,.:·,:..~,,·'.··:· ··:,.:·,tJå<:: 0.0 2.5 na ·,··o:Ö ,..... . .' .' ;:~1~:5' ,." . . na .> . 0.0 3 na . ·.2:J1·· . ·'2~5:' " ··51.~12006 ,. Corrosion inhibitor/ sealant date 5/19/2006 :'·;:~.·""SJf9_Er: .:,< 5/19/2006 . ··,.i.:~i>{ 5/18/2006 , '" ···ri:J.·ø~·"··' ...~ ·:',::.':':·r~~~,~~µ:</:...~· 5/18/2006 . ',:':5' .;r~G'I~Atì~::~.·· /. :', ,; ....~ R·~~~~\)I~··~·,t '~ 5/18/2006 .' .,;' ,:.....·:$It'ÌSQ.1t)..·;:; 5/18/2006 ¡::·,<:;$l~;i::.<; 6.2 5/18/2006 :; ';:21,:::9.' ~., .:~'" !- ,:\;:i~:I.:.·:j' 13.1 5/18/2006 ,··1:'1·.:A. '. "',' . ':::<J:'~~~: . . :. .,,~ ,. ..... .' :. ..~~,;~.C;.~:. o 5/18/2006 '. ·0···.. :'~'.. . .J:'"~~;ift"~;:':.:.. .' _ .~.\.1;~~.~..:,: 11.5 5/31/2006 ·6~5 ~ .".511812006;', '.' Royfill4048 vol. Qal " . ··j:1'.t:: 30.9 " '..... '9'" o ...., ··17.3,:: 10.7 . .~.~ ..' . :t7:6;'~" 13.7 ....' '. '.·:.5'/1.;; 10.1 ...,. '. ··.·1;~:8;··,; Qal .'. ';:5::7':" 7.1 ··...:S~:7'.'·· 6.7 ::'"'?'dt;.'·. .~ 7.1 ··5~'.7:,·: 7.1 .3:~:8;·:. 7.1 .·,.·······5~1.::::, 5.7 ·.::-:,5.l-·· .. 7.1 .. ::"'."&7:; ,,., !'........., 9.5 ·::"·9:.5;:" ,>", 5.7 :: :·it Permit to Drill 2040260 MD 9946 r --- --- ---- ----- -----~ REQUIRED INFORMATION ----------- ---- --~ .--.- --- ------------- ~Og : Log :k ~ ~g ,rGVC Ûi6 Lis S- fJ.p Y'j" .l. ~ ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Well Name/No. KUPARUK RIV U MELT 2P-449 Operator CONOCOPHILLlPS ALASKA INC 51? d i I¡c:.t.k À-IJ 0 '-I API No. 50-103-20486-00-00 TVD 5659 r Completion Status DATA INFORMATION Types Electric or Other Logs Run: GR / RES / DEN / NEU Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number ~-------- ,~ /" Completion Date 3/5/2004 Mud Log No Samples No Name Directional Survey Log Log Scale Media Run No Directional Survey Pressure 5 Blu 5 Blu 25 Blu 11() 25 Blu ¡Vb Perforation Neutron Neutron Induction/Resistivity I nd uction/Resistivity 12651 Induction/Resistivity 25 Blu V\ " 25 Blu ìV I) Blu ~ 12651 LIS Verification -~---- Well Cores/Samples Information: Name Interval Start Stop Sent Received 1-01L Current Status 1-01L UIC N Directional suÇ" y~s ) (data taken from Logs Portion of Master Well Data Maint Interval OHI --...-/ Start Stop CH Received Comments 0 9946 6/21/2004 108 9946 3/3/2004 8750 9553 ~ 3/26/2004 Perforating Record and SBHP 8750 9553 WI; 3/26/2004 Perforating Record and SBHP 108 9905 ~C;;' 4/21/2004 CALIPER CORRECTED NEUTRON OPTIMIZED ROTATIONAL DENSITY RWD 108 9946 ~(llV' CALIPER CORRECTED c;ase 4/21/2004 NEUTRON OPTIMIZED ROTATIONAL DENSITY RWD ~V\ 108 9946 _ 4/21/2004 GRRWD '\A 108 9946 ~ 4/21/2004 GRRWD - 108 9946 eJlJ 4/21/2004 GR, RWD, GRlMPRlCCN/ORD, GRAPHIC IMAGES 108 9946 ~ V\.. 4/21/2004 GR, RWD, GRlMPRlCCN/ORD, GRAPHIC IMAGES Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2040260 Well Name/No. KUPARUK RIV U MELT 2P-449 Operator CONOCOPHILLlPS ALASKA INC MD 9946 TVD 5659 Completion Date 3/5/2004 Current Status 1-01L Completion Status 1-01L ADDITIONAL INFORMATION Well Cored? V I~ Chips Received? Vrn- &)N f1)N Daily History Received? Formation Tops Analysis Received? ~ - - -- -------------- - - -~------ -----~ Comments: - -~- ~ I Date: Compliance Reviewed By: API No. 50-103-20486-00-00 UIC N ~ 8~J.~~~ ..~ ) } C::¡e,(t~e;12 Co Transmittal Form RECEIVED r-,r:r~ 2 1 2004 ,&.. BAKER HUGHES :;iaska O~I& Gas COOtS commU!$6ï()¡ (tf\f':hIV~t: INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: "- Robin Deason . ~Co (I Reference: 2P-449 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log 1 blueline - CCN-ORD Measured Depth Log 1 blueline - CCN-ORD TVD Log LAC Job#: 630939 sent~~el / J r Receiv~ /~(/'W~ÁV Date: Apr 19, 2004 Date: 9ft ( 0'1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 995]8 Direct: (907) 267-66] 2 FAX: (907) 267-6623 l:e=~~:;~:':;;~;:;~~;~~:;~:T' c....'"'"'"..._;;;;¡.,;';;";;¡'¡O¡;¡;"",...,..,..-J r~ ...; ,w'''¥'::"';'''':;.i '~------::-¡'f¡'W ~ ~~. 11I"\ .11I\..... . ~;:'~. ";'~i;':'-'-'- ~:.~~".,..:-,.._'-'-;;.-. .~'~.. -,"" ~.- ,'" "1 ....." .... ----.'-~_.- ,-- ...~ _un_.. .____...~.___..._.._..,_ ') ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJP'hillips p, O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 April 15, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2P-449 (APD # 204-026) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Meltwater well 2P-449. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, RECEIVED APR 162004 Alaska Oil & Gas Cons C '. . °mmìss,on Anchorage 1Z~\~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U WINJ D WDSPL D GINJ D 2. Operator Name: ConocoPhillips Alaska, Inc, 3. Address: Plugged 0 Abandoned D 20AAC 25.105 No. of Completions _ P. O. Box 100360, Anchorage, AK 99510-0360 4a, Location of Well (Governmental Section): Surface: 1026' FNL, 1564' FWL, Sec. 17, T8N, R7E, UM At Top Productive Horizon: 1006' FNL, 1873' FEL, Sec, 19, T8N, R7E, UM Total Depth: 1700'FNL, 1879'FEL, Sec. 19,T8N,R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 443523 ¡/ y- TPI: x- 440065 y- Total Depth: x- 440057.1 y- 18, Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res/Den/Neu 22. CASING SIZE WT. PER FT. 16" 62.5# 9.625" 40# 5.5" 15,5# 3.5" 9,3# GRADE B L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 3008' Surface 8915' 8915' 9940' 5868854 v 5863620 5862927 .,/ Zone-4 Zone-4 Zone-4 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): / 9392'-9402' MD 5374'-5379' TVD 6spf Suspended 0 WAG D 1b. Well Class: 20AAC 25.110 Development 0 Exploratory D Other _ Service D Stratigraphic Test D 5. Date Comp., Susp., ltlM': ~ ~ 2. Permit to Drill Number: or Aband.: FebrJ~04 /-Þ ,;204-026 I 6. Date Spudded'( t{.J..:t,y!{s. API Number: February 11, 2004 50-1 03-20486-00 7. Date TD Reached: 14. Well Name and Number: February 19, 2004 ,I 2P-449 8. KB Elevation (ft): 15. Field/Pool(s): 28' RKB Kuparuk River Field 9. Plug Back Depth (MD + TVD): Meltwater Oil Pool 9845' MD I 5606' TVD 10. Total Depth (MD + TVD): 16, Property Designation: ,. 9946' MD 15659' TVDý" ADL 373112/389058 11. Depth where SSSV set: none 19. Water Depth, if Offshore: N/A feet MSL 17. Land Use Permit: ALK 320921 32409 20. Thickness of Permafrost: 1406' MD HOLE SIZE CEMENTING RECORD 15 bbl AS I AMOUNT PULLED 42" 12.25" 337 sx ASIII, 274 sx LiteCrev-. 604 sx Class G w/GasBlok ~ I- ( ; ,..... , VI:. D see above 8.5" 8.5" 24. A P R1 6 20M TuAbtßacQì):¡lSt 68:0 CAnS_ Cgmmåli DEPTH SET (MD) Anc 10ra tACK~ËFiS~9I» 8932' g none SIZE 3.5" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9392'-9402' 317,000# of 16/20 Carbo lite 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 25, 2004 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO 3/29/2004 17 hours Test Period --> 1437 2231 92 100% 809 Flow Tu.bing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) press. 320 psi 862 24-Hour Rate -> 1093 884 92 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". - ...~~....... ..-...~ "'.~··...IIiI,·'."'.~.", !.:~L·.'; :-~~'-~~-~G>~ ' 1"" ,,~,.., , ; , :3 ~.~~~: ; ~1J3l:~ ~ ~ ,~.~~._~,.,-.~ t ~.JO:i'I"~I~"''''\..J'' ..~, ""\I:...o~-~ "':".I.~'" ," .~L_."...,;.:.. Form 10-407 Revised 2/2003 NONE stflJ¡ CONTINUED ON R")ÌfÍ Submit in duplicate ,/ V !J 8,13. 28. ') 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results, List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2P-449 T3 T2 9142' 9634' 5253' 5497' NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Schematic 31. I hereby certify that the foregoing is true and correct to the. best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed ~m~ Signature \ F\, Thom~ Title: ~~ ~ ~ne Kuparuk Team Leader Lf.,.S 6-2 ~o Date 'r ((5 ('07 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated, Each segregated pool is a completion, Item 4b: TPI (Top of Producing Interval), Item 8: the Kelly Bushing elevation in feet abour mean low low water, Use same as reference for depth measurements given in other spaces on this form and in any attachments, Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26, (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none", Item 29: list all test information, If none, state "None", Form 1 0-407 Revised 2/2003 ) ) C/O Top Drive saver sub to 41/2" IF P/U,M/U and std bk 1 std NM DCs P/U BHA #1 - Initialize MWD Hold Pre Spud safety meeeting wI Greg Burley's Crew and all contractors. Discuss hazards of shallow gas and proper procedure for diverting if necessary, Orient MWD Flood conductor and check system for leaks Pre Spud meeting with New Crew and all contractors. Discuss shallow gas diverter procedures, Hole table top diverter drill to cover roles and responsibilitys, Tranfer 100 bbls of Kill Wt to pit #5 for" Contingency Kill Mud" Drill out Ice from 16" conductor 90' to 1 08' Orient UBHO sub to high side @ 101' Drlg 12.25" hole 108' to 191' MD - PR 130 SPM, 550 GPM, PP 950 PSI .-' Off Bttm, RPMs 60, Up wt 68k , DN wt 79k, RW 69k. Torq on bttm 2k, off bttm 1 k Std bk 1 std 5" HWDP - P/U 1 std NMCSDCs Drlg & Slide 12.25" hole 191' to 284' MD - PR 130 SPM, 550 GPM, PP 950 PSI Off Bttm, RPMs 60, Up wt 68k , DN wt 79k, RW 69k. Torq on bttm 2k, off bttm 1 k Run Ck Gyro @ 284' Drlg & Slide 12.25" hole 284' to 648' MD - PR 130 SPM, 550 GPM, PP 1000 PSI Off Bttm, RPMs 60, Up wt 69k, DN wt 78k, RW 70k. Torq on bttm 2k, off bttm 1 k @ 6:56 AM - The entire Kuparuk field went too Phase 3 weather conditions. We are unable to proceed with drilling due to loss of drilling support and safety concerns. After a discussion with drilling engineer and team leader it was decided to circu at surface until weather improves enought to continue drilling - Std bk BHA to 101' 14,50 WAlTON WOW SURFAC Circu slowly @ 2 BPM, 100 psi - Flow line temp 51 deg, Temp @ Midnight 59 deg, We will circu with charge pumps only to minimize tempreature increase. ....Weather.... Temp -16, WC - 44, Wind NE @ 25 kts wI gust to 33 Kts. 11,25 WAlTON WOW SURFAC Waiting for Phase 3 weather conditions to be lifted. 0.75 DRILL TRIP SURFAC TIH to 648' 12.00 DRILL DRLG SURFAC Drlg & Slide 648' to 2035' MD ( 1842' TVD) ART 4,2 hrs, AST 4.4 hrs, PR 140 SPM, 595 GPM, PP 1550, WOB 15-25K, Torq on bttm 6k, off bttm 4k, Up wt 97k, Dn wt 95k, Rot wt 93k Legal Well Name: 2P-449 Common Well Name: 2P-449 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Daté From-To Hours; Code SÜb<. Phasé. Code 2/9/2004 15:00 - 19:00 4,00 MOVE MOVE MOVE 19:00 - 23:00 4.00 MOVE MOVE MOVE 23:00 - 00:00 1.00 MOVE MOVE MOVE 2/1 0/2004 00:00 - 03:00 3,00 WELCTL NUND RIGUP 03:00 - 07:00 4.00 DRILL PULD RIG UP 07:00 - 08:00 1.00 DRILL RIRD RIG UP 08:00 - 09:00 1.00 DRILL RIRD RIGUP 09:00 - 12:00 3,00 DRILL PULD RIG UP 12:00 - 13:00 1.00 WELCTL OTHR RIGUP 13:00 - 17:00 4.00 ,DRILL PULD RIGUP 17:00 - 18:30 1,50 DRILL PULD RIGUP 18:30 - 20:30 2,00 DRILL RIRD RIGUP 20:30 - 21 :00 0.50 DRILL PULD RIG UP 21 :00 - 22:30 1.50 DRILL PULD SURFAC 22:30 - 23:00 0.50 DRILL SFTY SURFAC 23:00 - 00:00 1,00 DRILL PULD SURFAC 2/11/2004 00:00 - 00:30 0.50 DRILL RIRD SURFAC 00:30 - 01 :00 0.50 DRILL SFTY SURFAC 01 :00 - 01 :30 0.50 DRILL CIRC SURFAC 01 :30 - 01 :45 0.25 DRILL REAM SURFAC 01 :45 - 02:00 0,25 DRILL SURV SURFAC 02:00 - 03:15 1,25 DRILL DRLG SURFAC 03:15 - 03:30 0.25 DRILL PULD SURFAC 03:30 - 05:00 1.50 DRILL DRLG SURFAC 05:00 - 05:30 0.50 DRILL SURV SURFAC 05:30 - 08:30 3,00 DRILL DRLG SURFAC 08:30 - 09:30 1.00 DRILL CIRC SURFAC 09:30 - 00:00 2/12/2004 00:00 - 11: 15 11 : 15 - 12:00 12:00 - 00:00 Start: 2/8/2004 Rig Release: 2/22/2004 Rig Number: Spud Date: 2/9/2004 End: 2/22/2004 Group: D. e. scriptiqh ÒfOþ~ratiohs '. . . .".. ..."... . Move sub and complexes from 2P-419 to 2P-449 Spot sub over well. Spot complexes. Spot rock washer and 1/2 of the pipe shed. Rig Accept @ 00:01 Hrs 2/10104 - N/U Diverter System Load 228 jts 5" DP and 29 jts 5" HWDP into pipe shed C/O all handling tools f/4" to 5" - Load Mud products into pits Slip & Cut 54' drlg line - Start mixing spud mud M/U 5" DP in stds and stand back in derrick- Strap same Fuction Test Diverter system - Ck PVT system and test H2s and Methane gas detection, AOGCC rep Jeff Jones witnessed test Con't P/U 5" DP and std bk in derrick (Total 76 stds) P/U, M/U & Std bk 10 stds wI jars 5" HWDP Printed: 3/30/2004 10:31:14 AM ") ) 6.25 DRILL DRLG SURFAC Drlg 2035' to 2620' MD , PR 140 spm, 594 gpm, PP 1800, WOB 10-20k, RPMs 90, Torq on bttm 7k, off bttm 5k, Up wt 97, Dn wt 90k, Rot wt 93k ** Note** Had gas spikes @ 2127' MD ( 1899' TVD) 3560 units & 2312' MD ( 2007' TVD) 4400 units. Both spikes had C1 ,2,3,4,& 5s. See mud log 0500 hrs 2/13/04 Pump WtI Hi Vis sweep - Circu out. - @ BU 25% increase in cutting. Drlg 2620' to 2777' MD , PR 140 spm, 594 gpm, PP 1800, WOB 10-20k, RPMs 90, Torq on bttm 7k, off bttm 5k, Up wt 97, Dn wt 90k, Rot wt 93k Circu and repair Epoch Gas detector pump @ flow line, Drlg 2777' to 2935' MD (2302' TVD), PR 140 spm, 594 gpm, PP 1850, WOB 10-20k, RPMs 90, Torq on bttm 7k, off bttm 4k, Up wt 99, Dn wt 91 k, Rot wt 94k, For Tour: ART 5.1 hrs, AST 2,2 hrs Drlg 2935' to.3013' MD (2339' TVD) , PR 140 spm, 594 gpm, PP 1850, WOB 10-25k, RPMs 90, Torq on bttm 7k, off bttm 4k, Up wt 99, Dn wt 91 k, Rot wt 94k, - TD 9 5/8" esg point Pump WtI Hi vis sweep - Circu hole clean Pre-Cautionary hole monitor - Shut dn pumps for 15 mins to monitor well - Static CBU - Max gas @ BU 110 units Bk ream OOH to 1850' ( 55' above lowest point of ghost reamer) near drilling rates, 80 RPMs, 130 SPM, No problems or tight spots, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-449 2P-449 ROT - DRILLING n1334@ppco.com Doyon 141 ..... pate' From.JTo HoÜrsGbd$ðou:e Phase 2/13/2004 00:00 - 06: 15 06:15 - 07:00 0.75 DRILL CIRC SURFAC 07:00 - 08:45 1.75 DRILL DRLG SURFAC 08:45 - 10:00 1.25 DRILL CIRC SURFAC 10:00 - 12:00 2,00 DRILL DRLG SURFAC 12:00 - 13:00 1,00 DRILL DRLG SURFAC 13:00 - 14:00 1.00 DRILL CIRC SURFAC 14:00 - 14:15 0.25 DRILL CIRC SURFAC 14:15 - 15:00 0.75 DRILL CIRC SURFAC 15:00 - 16:00 1,00 DRILL TRIP SURFAC 16:00 - 16:30 0,50 DRILL CIRC SURFAC 16:30 - 18:00 1.50 DRILL TRIP SURFAC 18:00 -19:15 1,25 DRILL PULD SURFAC 19:15 - 20:00 0.75 DRILL SURV SURFAC 20:00 - 20:30 0.50 DRILL PULD SURFAC 20:30 - 21 :15 0,75 CASE RURD SURFAC 21 :15 - 21 :30 0,25 CASE SFTY SURFAC 21 :30 - 00:00 2.50 CASE RUNC SURFAC 2/14/2004 00:00 - 02:45 2,75 CASE RUNC SURFAC 02:45 - 03:45 1.00 CASE CIRC SURFAC 03:45 - 04: 15 0.50 CASE RURD SURFAC 04:15 - 07:00 2.75 CASE CIRC SURFAC 07:00 - 09:00 2.00 CEMENT PUMP SURFAC 09:00 - 09:45 0.75 CEMENT DISP SURFAC 09:45 - 10:30 10:30 - 13:00 13:00 - 15:00 0.75 CEMENT PULD SURFAC 2.50 CASE NUND SURFAC 2,00 WELLSR NUND SURFAC Start: 2/8/2004 Rig Release: 2/22/2004 Rig Number: Spud Date: 2/9/2004 End: 2/22/2004 Group: . . . . .." .. .. .. . . ....... .. : O~scription ofppeiatiÓhs· Circu hole clean - Large amount of clay to surface - Max gas @ BU 210 units. Observe well static - TOH to 196' - No problems - No tight hole UD BHA #1 Dn load MWD UD MWD & Motor R/U 9 5/8" csg tools Hold Pre-Job safety meeting with crew and contractors, Run 9 5/8" 40# L80 BTCM csg ( 22 jts in hole @ midnight) Con't to run 9 5/8" 40# L80 BTCM csg to 3008' - M/U hanger & Ln jt. Circu BU using Franks Fill tool - Stage pumps up slowly to 5 bpm = 350 psi UD franks tool - P/U Cmt head Circu and condition for Cmt Job - Hold safety meeting wI crew and all contractors while circulating. Cmt per plan - Pump 5 bbls CW100 - Test lines to 3500 psi - pump 35 bbls CW100 - Pump 40 bbls 10,5 ppg Mud push - Drop bttm plug - Pump 267 bbls 10.7 ppg lead - Pump 112 bbls 12.0 ppg lead Av pump rate 7 BPM & 650 psi - Drop top plug - Kick out plug wI 20 bbls H20- Turn over to rig for displacement Displace CMT with rig pumps - Displace @ 6 bpm, 700 psi, slow to 3 bpm for the last 10 bbls , Bumped plug with 1969 stks ( Calcu bump 2016 stks) @3 bpm = 410 psi. Pressure to 900 psi and hold 5 min - Bleed off - Floats held. CIP 9:25 AM - Full returns thru job - Recip csg thru complete job - Had 130 bbls 10.7 ppb cmt to surface. UD Cmt head & Lnd Jt - Clear rig floor of cmt equip NID Diverter system N/U, Orient and test well head, Test 1000 psi "OK" Printed: 3/30/2004 10:31:14 AM .) ) .... .. .. .. ..Ùofîoêò~hiIIiP:>iAI~$~á. ...... ·..O:p~r~~iøn~~:~nll1'1fJry·a~pÓ..t ......: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-449 2P-449 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 2/8/2004 Rig Release: 2/22/2004 Rig Number: Spud Date: 2/9/2004 End: 2/22/2004 Group: 'Date ·From~ToH()ürsCöde Sub. ,Code 2.00 WELLSR NUND SURFAC N/U BOPs & Surface lines. 5,00 WELCTL BOPE SURFAC R/U and Test BOPs. Test BOPs and all valves 250psi/5000 psi. Test Annular 250 psi/3500 psi. Number 1 valve on choke manifold failed and was replaced and retested. AOGCC rep Jeff Jones waived witness test. Install wear bushing M/U BHA #2 Con't P/U BHA Trouble shoot "short" detected in tools, Break and clean connections until found.The bad connection was found to be between the MPR & Density subs, Finish P/U & Orient BHA #2 TIH wi HWDP - Shallow test MWD tools - "OK" 2/14/2004 15:00 - 17:00 17:00 - 22:00 22:00 - 22:30 0.50 WELCTL BOPE SURFAC 22:30 - 00:00 1.50 DRILL PULD SURFAC 2/15/2004 00:00 - 00:30 0.50 DRILL PULD SURFAC 00:30 - 02:00 1.50 DRILL PULD SURFAC 02:00 - 03:00 1.00 DRILL PULD SURFAC 03:00 - 04:15 1.25 DRILL TRIP SURFAC 04:15 - 06:15 2.00 DRILL TRIP SURFAC 06:15 - 07:15 1.00 DRILL CIRC SURFAC 07:15 - 08:30 1.25 RIGMNT RSRV SURFAC 08:30 - 09:30 1,00 DRILL DEQT SURFAC 09:30 - 10:15 0,75 DRILL DRLG SURFAC 10: 15 - 11: 15 1.00 DRILL CIRC SURFAC 11:15 -12:00 0,75 DRILL FIT SURFAC 12:00 - 14:15 2.25 DRILL DRLG PROD 14:15 - 14:30 0.25 DRILL CIRC PROD 14:30 - 00:00 9,50 DRILL DRLG PROD 2/16/2004 00:00 - 11 :30 11.50 DRILL DRLG PROD 11 :30 - 12:00 0.50 DRILL TRIP PROD 12:00 - 13:15 1,25 DRILL TRIP PROD 13:15 - 13:30 0,25 DRILL CIRC PROD 13:30 - 15:00 1.50 DRILL TRIP PROD 15:00 - 16:45 1,75 DRILL TRIP PROD 16:45 - 17:00 0,25 DRILL REAM PROD 17:00 - 00:00 7.00 DRILL DRLG PROD . ..:. . .", ; DesCription ofqpëra.tipf'lS . TIH picking up 5" DP singles out of pipe shed to FC @ 2929', ( PU 60 jts total) Circu BU and clear air from system. PR 4 bpm = 400 psi. Keep pipe moving at all times. Slip & Cut drill line, (104' cut) - Full service top drive Test csg to 3500 psi on chart for 30 min. Drlg FC, Cmt, FS and 20' new hole fl 3013' to 3033' Circu hole clean - CIO to conditioned LSND 10.5 ppg mud system. When mud uniform out and in @ 10.5 ppg. Preform FIT to 18.0 ppg EMW, 10,5 ppg mud ,Shoe @ 2348' TVD, hold 911 psi @ surface. Pressure 840 psi after 10 min. Drlg 8,5" hole 3033' to 3237' MD, PR 130 spm, 552 gpm, PP 2200, WOB 10-20k, RPMs 90, Torq on bttm 10k, off bttm 8k. Circu and Establish ECD clean hole base line. CHBL 11.8 ppg, Drlg 8,5" hole 3237' to 3860' MD( 2748' TVD), PR 130 spm, 552 gpm, PP 2300, WOB 10-20k, RPMs 90, Torq on bttm 10k, off bttm 8k. Up wt 120k, Dn wt 88k, Rot wt 98k Drlg 3860' to 4630' MD (3123' TVD) ART 6,9 hrs, AST 1,1 hrs, PR 130 spm, 552 gpm, PP 2550 OB, RPMs 90, WOB 10-25k, Torq on bttm 4-10k, off bttm 6k, Up wt 120, Dn wt 85k, Rot wt 96k ***DD NOTE*** Drlg f/4570' to 4630' hole became "RATTY", slow ROP, erratic pump pressure, inconsistant WOB, Hole packing off when working pipe and on bttm, Suppect cutting bed may be avalanching?? After discussion with engineer and team leader a wiper trip to the shoe was decided may help, We will also pull out to the top of the HWDP and p/u the ghost reamer. It had been left out to see if these same problems seen on the last well "Were" because of the ghost reamer, It appeares the reamer was not the problem, Back Ream OOH to 4355' @ drill rates, 80 RPMs, PR 130 spm Back Ream OOH to shoe @ 3008' - No tight hole was noted CBU - Circu clean - Had an av increase of cutting at BU - Some fist size balls of clay TOH to top of HWDP @ 1105' - Large amount of clay was noted sticking 2'-3' under the tool joints to the DP. We pulled HWDP and cleaned to 830' where the clay disopated mostly, TIH - P/U Ghost Reamer @ 1109' - Cont TIH to 4540' Wash & Ream 4540' to 4630' Drlg 4630' to 5194' MD (3397' TVD) ART 4,7 hrs, AST 0.4 hrs, PR 130 spm, 552 gpm, PP 2700 OB, RPMs 100, WOB 10-20k, Torq on bttm Printed: 3/30/2004 10: 31 : 14 AM .) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') . >CdnOGoPhilliþSAlélsKá .·Øperati()ns..·SumrTIClry>ftøÞ~tt.. ... ........ 2P-449 2P-449 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 2/8/2004 Rig Release: 2/22/2004 Rig Number: Spud Date: 2/9/2004 End: 2/22/2004 Group: . ... .. D~sctiþti()Ö ()f¢)peråtiohS Date" Frorn ~ TòHoÜrs . Code ... Sqb· Phase Còdè 2/16/2004 17:00 - 00:00 2/17/2004 00:00 - 12:00 12:00 - 00:00 2/18/2004 00:00 - 12:00 12:00 - 12:30 7,00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 12,00 DRILL DRLG PROD 12,00 DRILL DRLG PROD 0.50 DRILL DRLG PROD 12:30 - 13:15 0,75 DRILL CIRC PROD 13:15 - 14:15 1,00 DRILL TRIP PROD 14:15 - 15:00 0.75 DRILL CIRC PROD 15:00 - 15:15 0.25 DRILL TRIP PROD 15:15 - 15:45 0,50 DRILL TRIP PROD 15:45 - 16:45 1.00 DRILL CIRC PROD 16:45 - 00:00 7,25 DRILL DRLG PROD 2/19/2004 00:00 - 03:30 03:30 - 04:15 04:15 - 12:00 3.50 DRILL DRLG PROD 0.75 DRILL CIRC PROD 7,75 DRILL DRLG PROD 6-10k, off bttm 6-9k, Up wt 141, Dn wt 95k, Rot wt 1 09k, BGG 40-70 units ""Note"" After bk reaming clean out and getting back on bttm we added mud treatment to help with clays the assy has been drilling with no problems that had presisted before? Drill fl 5,194' to 6,294' ART = 7.9 hrs AST = 0.5 hrs WOB 5/20K, RPM 100, 550 gpm @ 2750 psi, UP 145K, DN 91 K, ROT 11 OK, TO 8/13K on I 9/1 OK off, Ave, ECD's 12,0 to 12.5 ppg, Pumping Hi-vis weighted & unweighted sweeps every 3 to 4 stands, Mud wt, 10,5 ppg, Ave. BGG 35 units, Drill f/6,294' to 7,394' ART= 8.1 hrs AST= 0,9 hrs WOB 10/15K, RPM 100, 550 gpm @ 2800 psi, UP 195K, DN 103K, ROT 128K, TO 12/15K on I 15/17K off, Ave, ECD's 12.0 to 12.5 ppg, Pumping Hi-vis weighted & unweighted sweeps every 3 to 4 stands, Mud wt, 10,5 ppg, Ave, BGG 40 units, Max gas 370 units, Drlg 8.5" hole 7394' to 8257' MD ( 4832' TVD) ART 6.7 hrs, AST 1.8 hrs,PR 130 spm, 552 gpm, PP 3050 off bttm, RPMs 100, WOB 10-20k, T orq off bttm 14-15k, On bttm 14-17K, Up wt 185k, Dnwt 89k, Rot wt 125k, Mud wt 10,5 ppg, Vis 64, AV BGG 40-50 units.ECDs 12,2 to 12.6ppg, Pumping Wtlhi vis (2 ppg over) sweeps as needed to maintain clean hole every 3-4 stds,Running 3% lubes. Drlg 8,5" hole 7394' to 8257' MD (4832' TVD) ART 6.7 hrs, AST 1.8 hrs,PR 130 spm, 552 gpm, PP 3050 off bttm, RPMs 100, WOB 10-20k, Torq off bttm 14-15k, On bttm 14-17K, Up wt 185k, Dnwt 89k, Rot wt 125k, Mud wt 10.5 ppg, Vis 64, AV BGG 40-50 units,ECDs 12.2 to 12.6ppg. Pumping Wtlhi vis (2 ppg over) sweeps as needed to maintain clean hole every 3-4 stds.Running 3% lubes, Finish circu sweep from hole - Observe well - Static - ECDs 11.9 ppg Bk ream OOH tl7240' - PR 130 spm, 90 RPMs Circu hole clean Pull 5 stds on elevators - Pull good - No excess drag- Hole took proper fill TIH to 8350' Pump Sweep - Circu hole clean before drilling Cairm - ECDs 11.8 ppg Drlg 8,5" hole 8350' to 8907' MD (5142' TVD) ART 5,5 hrs, AST 0,6 hrs,PR 130 spm, 552 gpm, PP 3050 off bttm, RPMs 100, WOB 15-18k, T orq off bttm 15-18k, On bttm 18-21 K, Up wt 220k, Dnwt 11 Ok, Rot wt 141k, Mud wt 10.5 ppg, Vis 58, AV BGG 30-40 units,ECDs 12,1 to 12,3ppg, Pumping Wtlhi vis (2 ppg over) sweeps as needed to maintain clean hole every 3-4 stds.Running 2.5% lubes. Drlg 8.5" hole 8907' to 9213' MD (5287' TVD),PR 130 spm, 552 gpm, PP 3100 off bttm, RPMs 100, WOB 5-20k, Torq off bttm 19-20k, On bttm 19-23K, Up wt 204k, Dnwt 106k, Rot wt 143k, Mud wt 10.5 ppg, Vis 60, AV BGG 60-80 units,ECDs 12,1 to 12.3ppg, Pumping Wtlhi vis (2 ppg over) sweeps as needed to maintain clean hole every 3-4 stds,Running 2.5% lubes. Circu up Geo Sample - Fluorescences in sample - Geologist, Bill Morris picked Top T3 Bremuda @ 9137' (5250' TVD) Drlg 8.5" hole 8907' to 9213' MD (5287' TVD) ART 7.4 hrs, AST 0.5 hrs, PR 120 spm, 509 gpm, PP 2550 off bttm, RPMs 100, WOB 5-10k, Torq off bttm 19-20k, On bttm 19-23K, Up wt 205k, Dnwt 107k, Rot wt 145k, Mud wt 10,5 ppg, Vis 60, AV BGG 100-150 units.ECDs 11,6 to 11,8ppg. Pumping Wtlhi vis (2 ppg over) sweeps as needed to maintain Printed: 3/30/2004 10:31:14 AM ) ) Legal Well Name: 2P-449 Common Well Name: 2P-449 Spud Date: 2/9/2004 Event Name: ROT - DRILLING Start: 2/8/2004 End: 2/22/2004 Contractor Name: n1334@ppco.com Rig Release: 2/22/2004 Group: Rig Name: Doyon 141 Rig Number: .. Dåte Fron"l'-To . Hours iCøde Sub.. OescriþtiöHofOþèrcïtipns qOçJE! .. 2/19/2004 04:15 - 12:00 7.75 DRILL DRLG PROD clean hole every 3-4 stds.Running 2,5% lubes. 12:00 - 15:00 3.00 DRILL DRLG PROD Drlg 8,5" hole 9743' to 9946' MD ( 5656' TVD) ART 2,5 hrs, AST 0.0 ,/ hrs, PR 120 spm, 509 gpm, PP 2600 off bttm, RPMs 100, WOB 5-10k, Torq off bttm 19-20k, On bttm 19-23K, Up wt 215k, Dnwt 118k, Rot wt 155k, Mud wt 10,3 ppg, Vis 57, AV BGG 80 units,ECDs 11.5 to 11.8ppg. Pumping Wtlhi vis (2 ppg over) sweeps as needed to maintain clean hole every 3-4 stds.Running 2.5% lubes. 15:00 - 15:15 0,25 DRILL OBSV PROD Stop Pumps - Work Pipe - Monitor Well - Static 15:15 - 16:30 1.25 DRILL CIRC PROD Pump Wt I Hi Vis sweep - Circu hole clean 16:30 - 18:00 1,50 DRILL TRIP PROD Bk ream OOH to 8630' ( 210' above lowest point of ghost reamer. 18:00 - 19:00 1.00 DRILL CIRC PROD Circu BU 19:00 - 00:00 5.00 DRILL TRIP PROD TOH - UD BHA #2 , Observe well per procedure, observe @ shoe,HWDP & BHA into BOPs 2/20/2004 00:00 - 02:45 2,75 DRILL PULD PROD Can't UD BHA- UD NMCSDPs - Remove RA sourcesn- Dn Load MWD - Bk Bit - UD MWD,stab & Motor- Clear tools from floor 02:45 - 03:30 0,75 CASE RURD PROD Pull wear bushing - Pull BOP riser and remove built up clay ring 03:30 - 04:15 0.75 CASE RUNC PROD RU to run csg 04: 15 - 04:30 0.25 CASE SFTY PROD Pre - Job Safety meeting wI crew and all contractors 04:30 - 08:45 4.25 CASE RUNC PROD Run 5.5" X 3,5" mono bore csg conpletion to 2989' 08:45 - 09:30 0.75 CASE CIRC PROD Circu BU - Stage pumps up slowly to 4,6 bpm = 300 psi 09:30 - 11 :30 2,00 CASE RUNC PROD Run 5.5" X 3.5" mono bore csg conpletion to 5400' 11 :30 - 13:00 1.50 CASE CIRC PROD Circu BU - Stage pumps up slowly to 4 bpm = 500 psi 13:00 - 16:45 3.75 CASE RUNC PROD Run 5,5" X 3.5" mono bore csg conpletion to 9940' 16:45 - 17:30 0,75 CASE RURD PROD R/U long bails & CMT - Circu with head pin @ 2 bpm 480 psi 17:30 - 20:00 2,50 CEMENTCIRC PROD Circu & Condition - Stage pumps up slowly to 5 bpm = 600 psi Mud wt 10.3, Vis 43, PV13, YP13, Up wt 155k, Dn wt 84k 20:00 - 20:30 0,50 CEMENT SFTY PROD Pre-Job safety meeting wlcrew and all contractors, 20:30 - 21 :15 0,75 CEMENT PUMP PROD Batch Mix CMT 21 :15 - 23:00 1.75 CEMENT PUMP PROD Cmt Mono Bore Csg - Pump 10 bbls CW100, Test lines to 3500 psi, Pump 40 bbls Mud Push @ 12 ppg, pump 125 bbls tail slurry @ 15.8 ppg, Drop Mono wiper plugs Clipped together, AV cmt rate 5 bpm, Displace w 221,1 bbls 8.5 ppb Sea water. Bump plug wI 500 psi over to 1400 psi - Bleed off - Floats held, CI P 2300 hrs - Shoe @ 9940', Float Collar @ 9845' and Plug Catcher 9815' PBD 23:00 - 23:30 0,50 CEMENT PULD PROD Ck Floats - RID Cmt Head 23:30 - 00:00 0.50 CASE DEQT PROD Set A-75 FMC packoff *** Special Note*** Had HoT Oil come out and pump the annulus flush on 2P-419.Pumped 200 bbls water and freeze protected wI 80 bbls diesel ( 2830'). This had not been done when the Rig moved off because of the extreem cold temperatures. 2/21/2004 00:00 - 01 :00 1.00 CASE RURD PROD Clear csg tools from rig floor- CIO bails on top drive 01 :00 - 01 :30 0.50 CASE DEQT PROD Pull Pack off - unable to test - Order pack-off #2 01 :30 - 03:45 2.25 DRILL PULD PROD RlU & UD HWDP out of derrick - As long as very low ambient tempeature we do not wish to move with extra weight in derrick because of sub jacks. 03:45 - 04:30 0.75 CASE DEQT PROD Install & Test #2 packoff - Test 5000psi "OK" 04:30 - 13:00 8.50 DRILL PULD PROD Con't UD DP from derrick 13:00 - 13:45 0,75 CMPL TN RURD PROD R/U to run 3,5" 9,3# L80 EUEM 13:45 - 14:00 0,25 CMPL TN SFTY PROD Pre-Job safety meeting wI crew and all contractors 14:00 - 22:00 8.00 CMPL TN RUNT PROD Run completion per program. Ran 280 jts 3,5" 9.3# L80 EUEM Up wt 103k, Dn wt 60k 22:00 - 23:00 1,00 CMPL TN SOHO PROD Measure out for space out - Need 4,04" pup Printed: 3/30/2004 10:31: 14 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-449 2P-449 ROT - DRILLING n1334@ppco.com Doyon 141 ····bate· Fröm'-To HoUrs Code ð6Je:- .ÞhêlSé 2/21/2004 23:00 - 00:00 1,00 CMPL TN CIRC PROD 2/22/2004 00:00 - 01 :30 1.50 CMPL TN CIRC PROD 01 :30 - 02:30 1.00 CMPL TN SOHO PROD 02:30 - 04:00 1.50 CMPL TN DEQT PROD 04:00 - 04:15 0.25 CMPL TN PULD PROD 04:15 - 05:30 1,25 CMPL TN NUND PROD 05:30 - 07:00 1,50 CMPL TN NUND PROD 07:00 - 08: 15 1,25 CMPL TN FRZP PROD 08:15 - 10:00 1.75 CMPL TN NUND PROD 10:00 - 12:00 2,00 WELLSR PLGM PROD Start: 2/8/2004 Rig Release: 2/22/2004 Rig Number: Spud Date: 2/9/2004 End: 2/22/2004 Group: . . "' DeSëriptionof Operé3.ti~rl$ Circu out to clean sea water, Pumped 25 bbl spacer and then 520 bbls sea water,PR 5 bpm = 1800 psi - Work tbg while circu. *"" Note"" One of the truckes that brought the sea water had some diesel in his tank ( +1- 5 bbls) Heavy smell when pumped into pits. Con't to CIO to clean sea water. PR 5 bpm = 1800 psi, recip string at all times 8' to 10'· Pumped total 520 bbls sea water. M/U pup jt ( I full jt below hanger) M/U hanger m- P/U Landing jt - Land Tbg - RILDS R/U to test tbg - Test tbg to 3500 psi on chart for 30 min, Bleed tbg pressure to 1600 psi, R/U and test 5,5" X 3,5" annulas to 3500 psi on chart for 30 min. Test "OK" - Bleed pressure off tbg and sheer RP valve @ 8803' MD. Valve sheared at 2900 psi. UD landing joint - Install TWC NID BOPs NU adapter & tree· FMC test tree to 5000 psi f/1 0 min R/U Hot Oil to freeze protect well. Pump 50 bbls down 5.5" X 3.5" annulus. Well freeze protect to 2427' . 9.625 X 5.5" Ann - Rig pumped 200 water flush. Hot oil pumped 80 bbls freeze protect. Inject fluids - Finish sucking final fluids out of pits Set BPV - Secure tree - Clean cellar area ,/ Rig released @ 1200 hrs, 2/22/04 Printed: 3/30/2004 10:31: 14 AM ) 2P-449 Well Events ) Date Summary 02/29/04 DRIFT TBG TO 9536' RKB. IN PROGRESS.O [Tag] 03/01/04 REPLACED DCK WITH DV @ 8803' RKB. DRIFTED TBG W/ 24' X 2.5" DUMMY GUN TO 9539' RKB. TESTED TBG/IA TO 2500 PSI. GOOD TEST. 0 [T ag] 03/05/04 PERFORATED: 9392' - 9402', 6 SPF HJ, SBHP AFTER PERFORATING AT 8803' ,/ (GLM#5)= 1867.8 PSIA, TEMP= 127.7 DEGF AND SBHP AT 9397' (MID PERF)= 2013.9 PSIA, TEMP= 137.4 DEGF -- TAGGED BOTTOM AT 9354' (WITH 1.69" OD TOOLS) 0 [Perf, Pressure Data] 03/14/04 PUMPED MELTWATER FRACTURE TREATMENT, BREAKDOWN, SCOUR STAGE, DATAFRAC, BRACKETFRAC WITH 950 BBL PAD AND NO CHANGES TO THE PROPANT DESIGN. 0 NO TSO SEEN WITH 317 K 16/20 CARBO-LITE PUMPED 312 K 10.1 PPG IN PERFS AND 5K LEFT IN THE WELLBORE. 03/14/04 CLEANED OUT TO 95051CTMD LEFT WELL FREEZE PROTECTED FROM 2600' WITH 60/40 METH REST OH WELLBORE HAS SLICK DIESELO [FCO] 03/16/04 TAGGED @ 9231', EST. 171' FILL. SET 2.75" CATCHER SUB @ 8869'. ATTEMPTED PULL DV @ 8803', UNSUCCESSFUL. IN PROGRESS.O [Tag, GLV] 03/17/04 PULLED DV @ 8803' RKB. ATTEMPTED SET OV, UNSUCCESSFUL, LEFT NOSE CONE HOUSING IN WELL. CHASED TO CATCHER SUB @ 8869' RKB. IN PROGRESS.O [GL V] 03/18/04 BRUSHED TBG TO 8869'. RAN 2.6" MAGNET TO 8869', RECOVERED SHEAR RING FROM INT LATCH. SET 5/16" OV @ 8803' RKB. IN PROGRESS.O [GLV] 03/19/04 PULLED CATCHER @ 8869', RECOVERED NOSE CONE FROM BOTTOM LATCH. CHECK & SPRING FROM BOTTOM LATCH OV LOST IN TBG. 03/20/04 NITROFIED CLEANED OUT TO 9708'CTMD MAINTAINED 1 FOR 1 RETURNS. LEFT WELL SHUT IN AND FREEZE PROTECTED TO 3500' WITH N2 CAPO [FCO] 03/21/04 GAUGED TBG WITH 2.70" CENT; TAGGED @ 9626', EST. 224' RATHOLE.O [T ag] TUBING (0-8932, OD:3.500, ID:2.992) SURFACE (0-3008, OD:9.625, Wt:40.00) =>RODUCTION (0-8945, OD:5.500, Wt:15.50) Gas Lift MandrelNalve 5 (8803-8804, SLEEVE (8853-8854, OD:4.500) NIP (8869-8870, OD:4.490) XO (8945-8946, OD:5.670) FRAC (9392-9402) Perf (9392-9402) ) ) ,.Con_c-oPhUUpsAlåska" lne.~ ï¡¡¡illtr '¡r; I I; · I····: II';, '- ~. t ,~ . '····1· ......--- : .' . ~?;:Õ I" :' i '., i ~. ~i , ". 'Ir Q ..~ ¡I;. -- '\ -¡- -1-- T \ \"" ----;- -I: ~ --L \. KRU 2P-449 API: SSSV Type: NIPPLE Well Type: PROD Orig 2/22/2004 Completion: Last W/O: Angle @ deg @ Angle @ TD: 58 deg @ 9946 Rev Reason: TAG FILL Post FRAC Last Update: 3/22/2004 Annular Fluid: Reference Log: 28' RKB Last Tag: 9626 Last Date: 3/21/2004 Ref Log Date: TO: 9946 ftKB Max Hole 63 7802 Thread WELDED BTC BTCM 3.500 Perforations: Summary Interval I TVD 9392 - 9402 5374 - 5379 Stimulatiohs& TreatmentS Interval Date 9392 - 9402 3/13/2004 0-0 I Status Ft I SPF I Date I Type I Comment 10 6 3/5/2004 IPERF 60 deg phase, PJ Zone Type Comment FRAC PLACED St MD TVD Man Man Type Mfr 1 2693 2188 CAMCO KGB-2-9 2 5147 3371 CAMCO KGB-2-9 3 6761 4133 CAMCO KGB-2-9 4 7970 4690 CAMCO KGB-2-9 5 8803 5093 CAMCO KGB-2-9 ()tti'èr(pIÛgs;.··:êC:¡ÜI'p;!;!etc:).4J.EWEL~* Depth rvD Type 23 23 HANGER 465 465 NIP 8853 5117 SLEEVE 8869 5124 NIP 8914 5145 LOCATOR 8932 5154 SHOE V Mfr V Type VOD Latch DMY 1.0 BTM DMY 1.0 BTM DMY 1.0 BTM DMY 1.0 BTM OV 1.0 BTM Description Port TRO Date Vlv Run Cmnt 0.000 0 2/21/2004 0.000 0 2/21/2004 0.000 0 2/21/2004 0.000 0 2/21/2004 0.000 0 3/18/2004 ID 3.500 2.875 2.810 2.750 3.000 3.000 FMC TUBING HANGER CAMCO 'OS' NIPPLE CAMCO CMU SLIDING SLEEVE CAMCO 'D' NIPPLE G-22 LOCATOR Depth Description 8900 Check & Spring Comment JUNK LEFT IN TUBING - CHECK AND SPRING FROM 1" OV- BOTTOM LATCH GenerâlNótes Date Note 2/21/2004 TREE: FMC / GEN V / FMC 3-1/8" / 5 K TREE CAP CONNECTION: OTIS 9" Conoc~illips dotf- !J2(P Well bore Name 449 Well Name 449 Slot Name slot #449 Installation Name Drill Site 2P Field Name Meltwater GreatecJBv Comments ) ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska ) Wellbol~: 449 Well path: GSS<O-169'>MWD w/Sag<300-9946'> Date Printed: 1-Mar-2004 r'i. BAKER HUGHES INTEQ I Created 12-Feb-2004 I Last Revised 24-Feb-2004 Government ID 50-103-20486-00 I Last Revised ?4-Feb-?004 Grid NorthinQ 5868853.6700 I Grid EastinQ 443523.2900 I Latitude N70 3 8.4?81 I LonQitude W150 277.0314 I North 1025.99S lEast 1567.07F I Fastina Northina I Coord Svstem Name North Alianment 441964,238 5869891.466 AK-4 on NORTH AMERICAN DATUM 1927 datum True I Fastina J Northina 441964,?38 I Coord Svstem Name I North Alianment 5869891.466 AK-4 on NORTH AMFRICAN DATUM 19?7 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252,Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6866.21 Feet on azimuth 209.90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc~Phillips ) ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska ) Well bore: 449 Well path: GSS<O-169'>MWD w/Sag<300-9946'> Date Printed: 1-Mar-2004 r'i. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing rdeQ/100ftl 8ectionrftl 0.00 0.00 0.00 0.00 O.OON O.OOF 0.00 0.00 4435?3.?9 5868853.67 1 08.00 0.00 0.00 1 08.00 O.OON O.OOF 0.00 0.00 4435?3.?9 5868853.67 169.00 0.20 89.00 169.00 O.OON 0.11E 0,33 -0.06 443523.40 5868853.67 300.41 0.67 ?99.59 300.41 0.39N 0.33W 0.65 -0.15 4435?2.96 5868854.06 391.51 ?03 298.90 391.48 1.43N ?,?1W 1.49 -0.01 4435?1.09 5868855.11 484.01 5.05 297.94 483.79 4.13N 7.24W 3.27 0.42 443516.08 5868857,85 573.88 8.96 29?53 57?98 8.66N 17.?OW 4.41 1.97 443506.15 586886? .46 664.80 12.49 ?83.66 662.30 13.70N 33.30W 4.28 6.40 443490.09 5868867.6? 753,33 15.43 282.51 748.21 18.51N 54.11 W 3.34 13,55 443469.33 5868872.58 843.56 17.44 283.60 834.74 24.29N 78.97W ??5 ?2.08 443444.51 5868878.55 933.80 19.18 28?67 920.41 30.73N 106.58W 1.96 31.54 443416.95 5868885.18 1025.60 21.85 280.62 1006.38 37,18N 138.09W 3,01 43.07 443385.50 5868891.87 11 ?3,63 24.99 272.14 1096.35 41.32N 176.73W 4.69 60.41 443346.89 5868896.30 1216,66 27.10 265.84 1179.95 40.52N ?17.51W 3.74 83.06 443306.10 5868895.79 1310.21 28.04 263,12 1262.88 36.34N 260.60W 1.68 109.79 443262.99 5868891.93 1401.70 ?8.89 259,36 1343.31 ?9.68N 303.67W ?17 138.61 443?19.88 5868885.60 1495.84 31.58 ?54.?1 1424.65 18.77N 349.76W 3.97 172.63 443173.71 5868875.03 1588.11 33.93 249.21 1502.26 3,05N 397.10W 3.88 211.38 443126.26 5868859.66 1680.72 36.?8 ?48.53 1578.0? 16.16S 446.77W ?57 254.3? 443076.46 5868840.83 1775.52 39.06 ?50.37 1653.05 36.46S 501.01W 3.16 300.65 44302?07 58688?0.93 1867.34 42.01 249.44 1722,83 56,98S 557.04W 3,28 348,12 442965,89 5868800.83 1960.59 45.44 ?49.84 1790.21 79.398 617.47W 3.69 399.56 44?905.31 5868778.87 ?053.04 49.00 ?48.?8 185?99 1 03.66S 680.8?W 4.04 454.14 44?841.79 5868755.07 2146,27 52,06 245.69 1912.25 131.82S 747.02W 3.92 513.54 442775,38 5868727.40 ?238.71 55.54 ?45.?? 1966.84 162.818 814.87W 3.79 576.19 44?707.32 5868696.92 ?33?,04 58.67 242.78 2017.53 197.18S 885.27W 4.01 643.08 442636.67 5868663.07 2424.64 61.24 242,76 2063.89 233.86S 956,54W 2.78 712.38 442565.14 5868626.93 ?514.31 6?68 ?43.04 2106.04 269.918 10?6.99W 1.63 780.71 44?494.43 5868591.41 ?608.99 6?77 24?57 2149.43 308.37S 1101.84W 0.45 853.43 44?419.30 5868553.51 2702.02 62.07 242.93 2192,50 346.13S 1175.15W 0.83 924.74 442345.72 5868516,30 ?795.25 61.86 ?43.7? ??36.3? 383.078 1 ?48.68W 0.78 995.48 44??71.93 5868479.91 ?885.85 61.88 ?43.47 ??79.03 418.60S 13?0.?4W 0.24 1063.97 44??00.11 5868444.91 2937,96 61,76 243.43 2303.64 439.13S 1361.33W 0,24 1103.40 442158.87 5868424.69 3059.77 61.64 ?43.87 ?361.39 486.748 1457.44W 0.33 1195.?9 44?06? .43 5868377.80 315?50 6?19 ?43.05 ?405.05 5?3.?9S 1530.63W 0.98 1265.51 441988.98 5868341.79 3245.77 62.06 240.63 2448,66 562.20S 1603.31W 2,30 1337.45 441916,02 5868303.43 3337.67 61.16 ?37.91 ?49?36 603.50S 167? .80W ?78 1409.68 441846.?3 5868?62.65 3430.56 60.49 ?34.71 ?537.65 648.4 7S 1740.?7W 3.09 1483.92 441778.43 5868218.19 3523.42 60.17 232.39 2583.62 696.40S 1805.17W 2.20 1559.27 441713,19 5868170.74 3616.03 60.01 229.13 2629.81 747.17S 1867.33W 3.06 1635.53 441650,66 5868120.44 3709.38 61.18 ?24.00 2675.67 803.078 19?6.34W 4.95 1714.41 441591.?4 5868064.99 3802.87 61.29 219,93 2720,67 863.99S 1981.12W 3,82 1795.25 441536.01 5868004.48 3895.96 60.53 217.45 2765.93 927.4 7S 2031.97W 2.47 1876.13 441484.70 5867941.38 3988.04 61,35 215.33 2810.66 99? ,268 2079.71W 2.20 1956.43 441436.48 5867876.96 4081.31 61.76 209.85 2855.11 1061.32S 2123.86W 5.18 2038.40 441391.83 5867808.23 4174.74 61.53 204.99 ?899.51 1134.?78 2161.70W 4.58 2120,25 441353.45 5867735.57 4?66.90 61.33 ?03.37 ?943.58 1?08.108 2194.86W 1.56 2200.31 441319.75 5867661.99 4361,34 60,65 203.24 2989.38 1283,96S 2227.53W 0.73 2281.81 441286.52 5867586,39 4454.0? 60.15 203.01 3035.16 1358.078 2?59.18W 0.58 ?361.30 441?54.3? 586751?53 4545.91 60.59 ?03.44 3080.59 1431.478 ??90.68W 0.63 2440.10 441.??? .?9 5867439.37 4643.44 60.73 204,78 3128,38 1509.07S 2325.41 W 1,21 2524.19 441186.99 5867362.04 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252,Oft above mean sea level) Vertical Section is from O,OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6866,21 Feet on azimuth 209.90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc6Phillips ) ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska ) Wellbo. é: 449 Well path: GSS<O-169'>MWD w/Sag<300-9946'> Date Printed: 1-Mar-2004 r'¡. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing rdeQ/100ftl 8ectionrftl 4737.47 60.?1 204.11 3174.73 1583.558 2359.?7W 0.83 2605.18 441152.58 5861'87.8? 4828.7? 61.06 ?04.08 3.?19.47 1656.148 ?391.73W 0.93 ?683.83 441119.58 5867?15.47 4921.51 62.23 204.99 3263.54 1730.42S 2425,64W 1.53 2764.67 441085.12 5867141.45 5016.36 61.10 204.37 3308.56 1806.?8S ?460.50W 1.3? 2847.36 441049.70 5867065.86 5109.69 61.74 204.60 3353.?1 1880.87S ?494.47W 0.7? 29?8.50 441015.19 5866991.54 5201.72 62.15 204.98 3396.49 1954,60S 2528.53W 0,58 3008.96 440980,59 5866918.07 5295.30 61.40 ?04.?8 3440.75 ?0?9.558 ?56?89W 1.04 3090.6? 440945.68 5866843.38 5388.15 6?32 ?03.88 3484.54 2104.30S 2596.29W 1.06 3171.59 440911.72 5866768.89 5480.95 62.90 203,68 3527,23 2179,70S 2629.52W 0.65 3253,01 440877.94 5866693.74 5573.17 6?62 ~04.67 3569.44 ??54.508 2663.09W 1.00 3334.11 440843.82 5866619..?0 5664.05 61.83 203.68 3611,79 23?7.85S 2696.03W 1.30 3413.65 440810.35 5866546.10 5759.28 61,59 204,27 3656.93 2404.47S 2730.10W 0.60 3496.56 440775.71 5866469.74 5851.98 61.21 204.16 3701.30 2478.70S 2763.48W 0.42 3577.08 440741.78 5866395.77 5944.59 60.51 203.15 3746.40 2552.798 ?795.94W 1.22 3656.98 440708.78 5866321.93 6037.43 59,95 202.82 3792.49 2626.98S 2827.41W 0,68 3736.44 440676.76 5866247.99 6130.83 61.04 204.04 3838.49 ?701.56S ?859.73W 1.63 3816.68 440643.89 5866173.65 622? .11 61.83 204.?9 388?14 ?774.70S 289?55W 0.90 3895.98 440610.53 5866100.76 6315.01 61.33 205.03 3926.36 2848.95S 2926.64W 0.88 3976,90 440575.90 5866026.77 6407.75 61.88 203.46 3970.46 ?9?3.34S ?960.13W 1.60 4057.61 440541.85 586595?65 6501.33 6?55 ?03.05 4014.08 ?999.40S ?99? .8?W 0.81 4139.31 440508.61 5865876.84 6593.63 62.56 201.22 4056,63 3075,27S 3023,68W 1.76 4219.85 440477.19 5865801.20 6687.09 6?72 ?01.80 4099.58 315?.49S 3054.1?W 0.58 4301.30 440446.18 58657?4.?? 6780.27 6?73 200,94 414?28 32?9.6?S 3084.30W 0.8? 438?54 440415.44 5865647.32 6872.70 62.63 200,69 4184.70 3306.38S 3113.48W 0,26 4462,93 440385.69 5865570,79 6964.89 6?23 201.72 4.?,)7.37 338~.57S 3143.03W 1.08 4543.03 440355.57 5865494.83 7058.?4 62.69 201.10 4270.53 3459.63S 3173.25W 0.77 4624,23 440324.79 5865418.01 7151.15 62,51 201,18 4313,29 3536.568 3203.00W 0.21 4705,07 440294.48 5865341,30 7?44.03 6??4 200.58 4356.36 3613.45S 3?32.33W 0.64 4785.65 440264.58 5865264.64 7337.53 6?,69 201.14 4399.58 3690.928 3261.85W 0.72 4866.82 440?34.49 5865187.40 7429.68 62.44 201,30 4442.04 3767.16S 3291.45W 0,31 4947.00 440204,32 5865111.38 75??61 6?54 199.80 4484.97 3844.34S 33?0.38W 1.44 50?7.61 440174.82 5865034.43 7616.?1 62.75 197.66 45?7.98 39?3.06S 3347.07W ?04 5108.31 440147.55 5864955.9? 7708.98 62.75 193.82 4570.47 4002.42S 3369.44W 3,68 5187.22 440124.60 5864876.73 7801.70 63.09 190.47 461?69 4083.1 ?S 3386.80W 3.?4 5?64.55 440106.64 5864796.18 7893.64 6?8? 186.50 4654.51 4164.08S 3398.89W 3.86 5339.?7 440093.96 5864715.31 7986,58 61.33 185,15 4698.03 4245,77S 3407.23W 2.05 5412,58 440085.01 5864633.70 8079.98 59.90 183.37 4743.86 43.?6.928 3413.?8W ??6 5484.?1 440078.36 586455? .60 8173.58 59.8? 181.82 4790.86 4407.78S 3416.95W 1.43 5554.30 440074.10 5864471.78 8264.56 60.33 180.28 4836.25 4486.61S 3418.39W 1.57 5621.49 440072.07 5864392.97 8357.84 61.18 180.56 4881.8? 4568.00S 3418,99W 0.95 5690.38 440070.87 5864311.59 8450.39 60.81 180.19 4926.70 4648.948 3419.51W 0.53 5758.85 440069.74 5864?30.67 8543.92 61,83 179.77 4971.58 4730,99S 3419.49W 1.16 5827,96 440069.16 5864148.62 8635.79 6?.42 180.19 5014.54 4812,20S 3419.46W 0.76 5896.36 440068.59 5864067.4? 8728.31 62.06 180.04 5057.63 4894.088 3419.6?W 0.41 5965.42 440067.81 5863985,56 8823.24 61.48 179.47 5102.53 4977.718 3419,26W 0,81 6035.69 440067.55 5863901,93 8915.36 6?01 179,56 5146.14 5058.85S 3418,58W 0.58 6103.67 440067.64 5863820.80 9009.45 6?39 180.35 5190.0? 514?08S 3418.51W 0.85 6173.76 440067.08 5863737.58 9102.18 61,56 180.82 5233,59 5223.93S 3419.35W 1.00 6243.16 440065.64 5863655.74 9194.?3 61.?8 180.00 5277.63 5304.76S 3419.93W 0.84 6311.57 440064.46 5863574.93 9288.78 60.93 181.01 53?3.3? 5387.54S 34?0.66W 1.01 6381.69 440063.1 ? 586349? .17 9380.89 60.09 180.55 5368,66 5467.718 3421.75W 1.01 6449.82 440061.43 5863412.02 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212,60 degrees Bottom hole distance is 6866.21 Feet on azimuth 209.90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ ) ConocoPhillips ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska ,) Wellbore: 449 Wellpath: GSS<O-169">MWD w/Sag<300-9946'> Date Printed: 1-Mar-2004 "~i. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Easting Northing rdeQ/100ftl Sectionrftl 9474.09 59.45 179.74 5415.59 5548.?3S 34?1.95W 1.0? 6517.77 440060.63 5863331.51 9566.08 59.45 180.57 5462.34 56?7.45S 34?2.17W 0.78 6584.6? 440059.83 5863?5?30 9659,99 58.96 180.20 5510.42 5708.12S 3422.71W 0.62 6652.87 440058,69 5863171.65 975? .O? 58.91 180.?7 5557.91 5786.95S 34?3.03W 0.08 6719.46 440057.78 586309? .83 9843.48 58.35 179.76 5605.5? 5865.04S 3423.06W 0.78 6785.?5 440057.18 5863014.75 9946,00 58.35 179.76 5659.32 5952.31S 3422.69W 0.00 6858.58 440056.90 5862927.49 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Actual Datum 252,Oft above mean sea level) Vertical Section is from O,OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6866.21 Feet on azimuth 209,90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocÓPhillips ) ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska ) Well bore: 449 Well path: GSS<O-169'>MWD w/Sag<300-9946'> Date Printed: 1-Mar-2004 r'i. BAKER HUGHES INTEQ Comments . MDrttl ITVDrftl I Northrftl I Fastrftl I Comment 9946,od 5659.3j 5952.31~ 3422.69~Proiected Data - NO SURVEY Hole Sections Diameter Start nnl MDrftl 12 1/'. 81/? Start TVOrftl O.O~ 3013.0( Start Start Northrftl Fastrftl O.O~ 0.00,,"- ?339.1 ~ 468.55~ End End End Start MOrftl TVDrftl Northrftl Fastrftl O,OOE, 3013.0~ 2339.1~ 468.55~ 1420.51\1\449 14?0.51V\ 9946.0( 5659.3~ 595?31E 34??69V\ 449 Wellbore Casinas Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MOrftl TVOrftl Northrftl Eastrftl MDrftl TVOrftl Northrftl Eastrftl 16" Conductor O.Oc, O.Oc, 0.00t\. O.OOF 108.0C 108.01: 0.00f\, O.OOF 449 9 5/8" Casino O.OC O.OC 0.001\. O.OO~ 3007.0( ?336.3':: 466.21~ 1415.77V\ 449 51/2" x 31/2" XO O.O~ O,O~ 0,00,,"- O.OOE 8889.5~ 5134.0~ 5036,11 t, 3418.76\1\ 449 3 1/?in Casino 8889.5~ 5134.0~ 5036.11 E 3418.76V\ 9940.0( 5656.1i 5947.?OE 342?71V\ 449 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Actual Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6866.21 Feet on azimuth 209.90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 03/18/04 Schlumbel'ger NO. 3131 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color 3F-19A,1c 'l ~Ol Li 10696856 PERF RECORD & SBHP 03/10/04 1 _2P-419~r~ -011- 10696852 PERF RECORD & SBHP 03/06/04 1 2P-449~L.j ~r:;:".){/ 10696851 PERF RECORD & SBHP 03/05/04 1 2K-04 ,~- }\C~ 10696845 PRODUCTION PROFILE 02/28/04 1 2P-419JC.l/-'C:( 10696852 SCMT 03/06/04 1 3F-19Ä'9C>'/-(i} U 10696856 SCMT 03/10/04 1 Kuparuk '~' CD - ...........-,...."'--..:;~ -...--~ Wt-t at- ~ \/ r-i 1 . ...~~_~.;:'.;;;';';»'" cd....-............-.....-- SIGNE~:--\;-,(" l~ ,,~'\ "- C ,,<- ~/~ ~ , . . '-' r. Ó' A'" '" , r- ,.... "'UL~ ~'::''':I~-'~ L L-i.} , ~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. -¡2~~~!1 C~! (~Gas Gons, Ccmmi~¡n ,~_:¡~11fjrage '-=> . -...-, '--- . <==--- f'.- \j 'e> \\ '\ \..L> ) ) FRANK H. MURKOWSKI, GOVERNOR AItASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field 2P-449 ConocoPhillips Alaska, Inc. Permit No: 204-026 Surface Location: 1026' FNL, 1564' FWL, Sec. 17, T8N, R7E, UM Bottomhole Location: 1721' FNL, 1876' FEL, Sec. 19, T8N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t itness any required test. Contact the Commission's North Slope petroleum field ~ a 6~ - 07 (pager). ( 77¿;/ ~hn K. ~an Chair BY ORDER OJ' THE COMMISSION DATED this,b. day of February, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Conoc~Þhillips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com February 2, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Meltwater producer 2P-449 Dear Commissioners: ,,/' ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production well in the Bermuda sands of the Meltwater oil pool. Please find attached for the review of the Commission Form 10-401 and the information required by 20 Ace 25.005 for this well. ,/ The expected spud date is February 7, 2004 If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, 'è:.,~ ----\-"-\~ - \ .../ Randy Thomas Greater Kuparuk Area Drilling Team Leader RECEIVED FEB 0 2 2004 Alaska Oil & Gas Cons, COIf:ml$$IQn Anchorage ORIGINAL 1a. Type of Work: Drill 11] Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc, 3. Address: ) STATE OF ALASKA eJ("EI·VE"D ALASKA OIL AND GAS CONSERVATION COMM'S~~ PERMIT TO DRILL FEB 0 2 2004 20 AAC 25.005 ExploratoryU Alaska O~e&I~.Ç~,~Oinmí:',5ionMultiPle Zone D Service D Devel~OœO[] Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No, 59-52-180 2P-449 6. Proposed Depth: 12, Field/Pool(s): MD: 9940' TVD: 5621' Kuparuk River Field Redrill U 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a, Location of Well (Governmental Section): Surface: 1026' FNL, 1564' FWL, Sec. 17, T8N, R7E, UM Top of Productive Horizon: 1095' FNL, 1874' FEL, Sec. 19, T8N, R7E, UM ' Total Depth: 1721' FNL, 1876' FEL, Sec, 19, T8N, R7E, UM ' 4b. Location of Well (State Base Plane Coordinates): Surface: x· 443523 16. Deviated wells: Kickoff depth: 300 ft. 18. Casing Program Size Hole 42" Casing 16" 12.25" 9,625" 8.5" 8.5" 5.5" 3.5" 19 Total Depth MD (ft): Casing Structural Conductor Detailed Operations Intermediate Production Liner Perforation Depth MD (tt): 20. Attachments: Filing Fee 0 Property Plat D y- 5868854 Zone- 4 Maximum Hole Angle: 61,910 Specifications Weight Grade Coupling Length 62.5# H-40 Weld 80 40# L-80 BTC 3003 15.5# L-80 BTCM 8309 9.3# L-80 EUE8RDM 1603 PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) Length Size BOP Sketch U Diverter Sketch D Drilling Program 0 Seabed Report D 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name R. Thomas Signature '\~~ h¡3 7, Property Designation: , ADL 373112/389058 8. Land Use Permit: Meltwater Oil Pool 13. Approximate Spud Date: 217/2004 L32092 I 32409 9. Acres in Property: 5760 14. Distance to Nearest Property: 1095' @ Target 15. Distance to Neare~t'l"l . . I ,)V--i..íl.{" ,y.~ Well within Pool: ~8;~ AJo/1, 10. KB Elevation MD 28' 28' 252' AMSL feet 17. Anticipated Pressure (see 20 AAC 25.035) Max, Downhole Pressure: 2300 psig I Max, Surface Pressure: 1826 psig Setting Depth Quantity of Cement Bottom c. f, or sacks TVD (including stage data) 108' Preinstalled 2346 339 sx ASLite & 274 sx LiteCRETE 4867 890 sx GasBLOK 5621 (Included above) Top TVD 28' 28' MD 108' 3031 8337 9940 28' 8337 28' 4867 (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD TVD Perforation Depth TVD (ft): Time v. Depth Plot D Drilling Fluid Program 0 Date: Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 Contact Philip Hayden 265-6481 Title Kuparuk Drilling Team Leader . 'z..-/ -¿(é/ <"1 Phone '266 bð s Ò Date PreDared bv PhifiD Havden Commission Use Only , API Number: Permit APpro~al' t ! See cover letter 0- /lJ3.- ;ZL;)~E6 --C,O Date:;2., (¿:,,/O L for other requirements D Yes ~No Mud log re ired DYes 18' No D Yes IS'! No Directional survey required ,~Yes D No Permit to Drill ,; / ; _ Number: .2,C) y- OZ{;. Conditions of approval : . {~ge O~er: ~v j~\ , Approved by: BY ORDER OF THE COMMISSION z)Þ¡Oy K I GtNÄ[ Date: Submit in duplicate ) Apr "'1ion for Permit to Drill, Well 2P-449 l Revision No.O . Saved: 2-Feb-04 Permit It - Meltwater Well #2P-449 Application for Permit to Drill Document MOxil'nize Well Vglue Table of Contents 1. Well Name..... ...... .... .............. ... .... ....... ... ... ...... ..... ....... ...... ........... .......... ....... ........ .... 2 Requirements of 20 AAC 25.005 (f).. .......... .......... .......................... ............ ...... ........ .............. ...... .......... 2 2. Location Sum mary .... ... ........ ... .... ....... ...... ........... ..... .......... ............ ....... ....... ............ 2 Requirements of 20 AAC 25.005(c)(2) ...... ...... ........ ............................. ............ ............................ ..........2 Requirements of 20 AAC 25. 050(b).. .......... .......... ...................... ..... .................... ....... ............................3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ....... ............................... ...... ............ ............... ............ ................ 3 4. Dri II i ng Hazards Information .. ........... ... ... ...... ..... ..... .......... ....... ............ ....... ........ .... 3 Requirements of 20 AAC 25.005 (c)( 4) ...... .......... ...................... ...................... ........ .................... .......... 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ...... .......... ...................... ...................... .......... ............. ...............4 6. Casi ng and Cementing Program .............................................................................4 Requirements of 20 AAC 25.005(c)(6) .... ........ ................... ........ ...................... .......... ............................ 4 7. Diverter System Information.. .... ....... ...... ...... ....... .......... ... ..... ... ......... ............ ......... 4 Requirements of 20 AAC 25.005(c)(7) ...... ...... ........................... ...... ........................... .................. .........4 8. Dri II i ng FI uid Program ........ .... .... ....... ...... ........... .... .... ....... .... .............. ......... .... ....... 5 Requirements of 20 AAC 25.005(c)(B) ........ ..... ....... ........... ........ ...... .................................... .................. 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Production Hole Mud Program (LSND) ...... .......... ...... ............ .......... ............ ...... .................. .................. 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ......... ............... .............. ...... ................ .......... ....... ............... ...... 5 10. Seism ic Analysis ............ ................... .... ... ... ... ............ ..... ... ......... ........ ............ .... ..... 5 Requirements of 20 AAC 25.005 (c)(10) ...... ........................ ........ ....................... ............ ........ ...............5 11. Seabed Condition Analysis .....................................................................................6 8Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bond ing ..... ......... .......... ....... .................... ...... ... ........ ...... .......... .... ....... 6 ORIGINAL 2P-449 PERMIT IT,doc Page 1 of 7 Printed: 2-Feb-04 ") Ap'" ~,tion for Permit to Drill, Well 2P-449 , Revision No,Q i Saved: 2-Feb-04 Requirements of 20 AAC 25.005 (c)(12) .................... .............................. .............................. ................ 6 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ........................... ...... ................. .................. ................. ........... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) .. .................... ........ .......... .......... ................ ...... ................... ..... 7 15. A tta c h m e nts ............................................................................................................. 7 Attachment 1 Directional Plan (18 pages) ...... .............. ............... .......... ................ .................... ............. 7 Attachment 2 Drilling Hazards Summary (1 page) .................................................................................7 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 7 Attachment 4 Well Schematic (1 page) .. ................ ............. .......... .................... ............ ............ ............. 7 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 commi!:>"Sion 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 addli1g a suffix to the name designated for the well by the OperEitor and to the number assigned to the well by the commis~-¡on. The well for which this Application is submitted will be designated as 2P-449. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a PermIt to Dtill 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 proposed loc..'ation of the well at the surface, at the top of eaä7 objeäive formation, and at total depth" referenced to govemmental section lines. (8) the coordinates of the proposed location of the well at the swface" referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Adrmi1istration,,' (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,868,854 Eastings: 443,523 . 1026' FNL, 1564' FWL, Section 17, T8N, R7E, UM RKB Elevation 252' AMSL Pad Elevation 224' AMSL Location at Top of Productive Interval (Bermuda Sand) NGS Coordinates Northings: 5,863,532 1095' FNL, 1874' FEL, Section 19, T8N, R7E, UM Eastings: 440,064 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 9,230 5,287 5,035 Location at Total Depth NGS Coordinates Northings: 5,862,905 Eastings: 440,059 1721' FNL, 1876' FEL, Section 19, T8N, R7E, UM Measured Depth, RKB: 9,940 Total Vertical Depth, RKB: 5,621 Total Vertical Depth, 55: 5,369 and ORIGINAL 2P-449 PERMIT IT.doc Page 2 of 7 Printed: 2-Feb-04 ) Apr ....,'Vion for Permit to Drill, Well 2P-449 ) Revision No,O Saved: 2-Feb-04 (O) other information required by 20 MC 25.050(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application f'Or a Permit to Dnll (Form 10-401) must (1) include a plat, drawn to a suitable sCale" showing the patll of the proposed wellbore" including all adjacent wellbores within 200 feet of any portion of the propO!:ic:d well' Please see Attachment 1: Directional Plan and (2) for a/I we/I.r; within 200 feet of the prvposed wellbore (A) lI:r;t the names of the operators of those wells" to the extent that those names are known or dir;coverable in public records, and show that each named operator has been furnished a copy of the application by certified mall,' or (8) state that the applicant i.r; the only affected owner: The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dlill must be accompanied by each of the following item~~ except for an item already on tYe wHh the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (80PE) as required by 20 MC 25.035;, 20 MC 25.036" or 20 MC 25.037" as applicable,,- An API 13 5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 2P-449. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application far a Permit tv Drill mlJ.~t be accompanied by each of the fo/lowing item!.>~ exæpt for an item already on file with the cormnis.<:.ion and Identffìed in the application: (4) information on dlilling hazard~~ ineluding (A) the maximum downhole pressure that may be encountered" Cliteria used to determine it" and maximum potential slIIface pressure based on a methane gradient,,- The expected reservoir pressures in the Bermuda sands in the 2P-449 area vary from 0.30 to 0.44 psi/ft, ","' ~ or 5.8 to 8.4 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from existing wells on the field together with reservoir model forecasts. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Bermuda sand formation is 1826 psi, calculated as follows: MPSP = (5532 ft)(0.44 - 0.11 psi/ft) =1826 psi " (8) data on potential gas zones,,- Due to the presence of high annular pressures on some of the Meltwater wells (2P-431, 451 & 438) and ",' the occurrence of gas in some of the wells drilled to date in the current program there is the risk of encountering a pressured shallow zone. This interval may be encountered through the C-80 formation to the top of the Bermuda. The original high pressures recorded in these annuli were of concern but as can be seen from the following table a series of annular bleeds together with an observed natural decline in pressures have reduced the potential maximum pressure considerably: Oriqinal Latest Well Surface Fluid C-80 C-80 Equivalent Surface Fluid C-80 C-80 Equivalent Pressure Level Pressure Gradient (ppg) Pressure Level Pressure Gradient (ppg) 2P-431 1600 2387 1751 13.85 1200 193 1678 13.27 2P-451 1380 2160 1541 12.23 750 1392 1020 8.10 ORIGINAL 2P-449 PERMIT IT.doc Page 3 of 7 Printed: 2-Feb-04 ) Apr" -~ion for Permit to Drill, Well 2P-449 1 Revision No,Q , Saved: 2-Feb-04 I 2P-438 I 879 I 895 I 1245 9.83 800 I 768 I 1216 9.60 Using the latest annular pressures available the highest pressure that would be expected is approximately ¡." 1678 psi at 2441 ft TVD or 13.22 ppg EMW. Most of the previously drilled Meltwater wells have had an FIT/LOT of approximately 16 ppg thus indicating that this pressured interval, should it exist, can be safely controlled with standard well control methods. and (C) dat?l concerning potential causes of hole problems such as abnormally geo-pre!::",!:jvred !>trata/ lost ärculation zones, and zones t¡Jat have a propensity for dIfferential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application t"or a Pel7TJit to Oli/l must be aa"ompanied by each of the following items, except for an item already on lìle with the c.vmmission and identified in the application: (5) a description of'the procedure for conducting formation integl7ty tests, as required under 20 MC 25. 030{f); 2P-449 will be completed with 9 5/8" surface casing landed above the C-80 mudstone interval. The casing shoe will be drilled out and a leak off test will be performed in accordance with the "Leak Off Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item a/ready on file with the commission and identified in the app/kation: (6) a complete proposed ca:.ing and cementing program as requlÍ"ed by 20 MC 25.030, and a description of anys10tted linel; pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm CsgíTbg Size Weight Length MOíTVO MOfTVO 00 (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 5/8 12 V4 40 L-80 BTC 3003 28 / 28 3031 / 2346 Cement Program Prei nsta lied 3 V2 8 V2 9.3 L-80 EUE8RD Mod 1603 28 / 28 8337 / 4867 Cement to Surface with 339 sx ASLite Lead, 274 sx LiteCRETE Tail 8337/4867 Cement Top planned @ 9940 / 5621 8037' MD/,v'/ 4725' TVD. Cemented w/ 890 sx GasBLOK 5 V2 81/2 15.5 L-80 BTCM 8309 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a PermIt to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: {7} a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25. 035(17)(2); ORIGINAL 2P-449 PERMIT IT,doc Page 4 of 7 Printed: 2-Feb-04 ) App'" --:qion for Permit to Drill, Well 2P-449 , Revision No.O Saved: 2-Feb-04 A 21 1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 2P-449. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an Item already on file with the commission and identified in the application: (8) a dnlling fluid program, including a diagram and description of the drilling fluid sy..<;tem, as required by 20 AAC 25. 033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Initial Value Final Value Density (ppg) 8.6 ~9.2 Funnel Viscosity 250 250 (seconds) Yield Point 35-45 35-45 (cP) pH 9-9.5 9-9.5 API Filtrate 6 6 (cc / 30 min)} Chlorides (mg/I) <600 <600 *9.6 ppg if hydrates are encountered Production Hole Mud Program (LSND) 95/8" Casing Shoe to TD Initial Value Final Value 9.6 9.6 22-28 10-15 9-9.5 9-9.5 4-6 4 Density (ppg) Yield Point (cP) pH API Filtrate (cc /30 min)} HTHP @ 1scf (cc}) <12 <12 Base of Permafrost to 9 5/8" Casing Point Initial Value Final Value ~9.2* 10.5 150-200 55-65 30-35 12-15 9-9.5 9-9.5 4-6 4-6 <600 <600 ¡/ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (9) for an exploratory or stratigraphic test we/I" a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. . 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (10) for an exploratofY or stratigraphic test well, a seismic refraction or reflection analysis as reqUli'ed by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. ORIGINAL 2P-449 PERMIT IT,doc Page 5 of 7 Printed: 2-Feb-04 ) APr"'tion for Permit to Drill, We1l2P-449 , Revision No.O Saved: 2-Feb-04 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill mast be accompanied by each of the following itemS¡, except for an item already on lYe with the commission and Identified 1i7 the application: (11) for a well dnlled frvm an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling veS!.>""e1, an analysis of seabed conditions as required by 20 AAC 25.061(b}; Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identíl1ed in the application: (l2) eVidence showing that the requirements of 20 AAC 25.025 {Bondingjhave been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application far a Permit to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test (conductor has already been installed and cemented). 2. Spud and directionally drill 12 1/4" hole to casing point at 3031' MD / 2346' 1VD as per directional plan. Run MWD tools as required for directional monitoring and LWD tools (GR & resistivity) as required for data acquisition. '" 3. Run and cement 9 5/8", 40# L-80, BTC casing to surface. Displace cement with mud. Perform top job if required. 4. Remove diverter system and install wellhead and test. Install 13 5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 5. PU 8 1/2" bit and 6 '/4" drilling assembly, with MWD and LWD (GR, resistivity & neutron density). RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 6. Drill out cement and 20' of new hole. Perform LOT or FIT to 18.0 ppg EMW, recording results. 7. Directionally drill to 5 '12" x 3 1/2" casing point at 9940' MD / 5621' 1VD. 8. Run 5 '12", 15.5# L-80, BTC Mod x 3 1/2", 9.3# L-80, EUE8RD Mod casing to TD. Pump cement and displace with water and mud. Note that the cross over and seal bore extension for the completion will be .- positioned 200' MD above the Cairn interval, if present, as this is an interval that may be produced later in the life of the field. 9. Make up completion string as required and RIH to depth. Locate seal bore extension, space out and land completion. Pressure test completion and production casing to 3500 psi for 30 minutes and record results. Shear RP shear valve in gas lift mandrel. 10. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV 11. Freeze protect well with diesel by pumping into the annulus, taking returns from tubing and allowing to equalize. Carry out LOT and injection test on the outer annulus. Sweep the annulus with water and freeze protect. 12. Set BPV and move rig off. ORIGINAL 2P-449 PERMIT IT.doc Page 6 of 7 Printed: 2-Feb-04 ) APr!··,\tion for Permit to Drill, Well 2P-449 l Revision No,O . Saved: 2-Feb-04 13. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in gas lift mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). Perforate well and rig down wire line unit. 14. Carry out fracture stimulation. 15. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the £."Ommission and identified in t/7e application: (14) a general descn'ption of how the operator plans to dispose of drilling mud and cvttings and a statement of whether the operator intends- to request authorization under 20 AAC 25.080 for an annular disposal operation in tile well.,: Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 2P Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 2P Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on the pad in accordance with a permit from the State of Alaska. At the end of drilling operations, an application may be submitted to permit 2P-449 for annular disposal of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 Directional Plan (18 pages) Attachment 2 Drillíng Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematic (1 page) ORIGINAL 2P-449 PERMIT IT,doc Page 7 of 7 Printed: 2-Feb-04 ConocoPhillips Alaska, Inc. Mi. ..... Location: North Slope, Alaska Field: Meltwater Installation: Drill Site 2P Slot: slot #449 Well: 449 Well bore: 2P-449 Conoai'hillips ¢:: L.() -450 N N II E (,) -0 Q) ro (,) (/) 450 900 1350 - ~ --~_..-->-~--.--~.- INTEQ I RKB Elevation: 252' Created by : Planner Date plotted: 30-Jan-2004 Plot reference is 2P-449 . Ref well path is 2P-449 Vers#11.A. Coordinates are in feet reference slot #449. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 252.00 ft. Plot North is aligned to TRUE North. d 1800 ~ ~ 2250 ~ ~ 2700 ~ 3150 r-> " (,) 2 3600 .... KOP 6.00 BldlTrn 3/100 14.30 19.89 25.16 30.68 Base Permafrost DLS: 3.00 degl100ft C37 WELL PROFILE DATA Point MD Inc Azi TVD I North East deg/100rt V. Sect I Tie on 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -- End of Hold 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 End of BuildlTurn 633.33 10.00 290.00 631.64 9.92 -27.27 3.00 6.33 End of BuildlTurn 1003.99 20.00 270.00 989.44 20.97 -121.19 3.00 47.63 End of Build/Turn 1900.98 45.00 250.00 1741.89 -89.54 -581.07 3.00 388.50 End of BuildlTurn 2486.73 61.91 244.00 2089.61 -275.09 -1011.29 3.00 776.61 KOP 3145.97 61.91 244.00 2400.00 -530.05 -1534.03 0.00 1273.04 End of Turn 4342.01 61.91 203.13 2982.28 -1270.89 -2238.64 3.00 2276.79 End of Hold 7408.03 61.91 203.13 4425.83 -3758.40 -3301.14 0.00 4944.84 End of Turn 8087.16 61.91 180.00 4749.00 -4339.61 -3420.07 3.00 5498.55 Target 2P-449 Top Berm 9229.83 61.91 180.00 5287.00 -5347.70 -3420.07 0.00 6347.82 End of Hold 9750.20 61.91 180.00 5532.00 -5806.78 -3420.07 0.00 6734.56 T.D. & End of Hold 9940.20 I 61.91 1180.00 5621.46 -5974.40 I -3420.07 0.00 6875.78 I ~ 61.43 61.69 ~EOC 5112 X 3112 XO 5 1/2in Casing ~ T4.2 (Top Cairn) T4.1 T3 (Top Bermuda) Target T2 (Base Bermuda) ~ C35 (Top Albian) "S ¡ I TD, CS% PI. \ j2P-449 ¡ 3 1I2in asing , I 42.08 47.84 53.60 Base West Sak EOC ~ Turn 3/1 00 ~ DLS: 3.00 deg/100ft 9 5/8in Casing C8~b. 86 60.43 6063 61.26C50 EOC DLS: 3.00 degl100ft C40 I V 4050 4500 4950 5400 5850 6300 -450 0 450 Scale 1 cm = 225 ft 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650 8100 8550 9000 9450 Vertical Section (feet) -> Azimuth 212.60 with reference 0.00 N, 0.00 E from slot #449 r&l. BAKER HUGHES INTEQ Scale 1 em = 200 ft -5200 -4800 -4400 -4000 ---..-..------.-.---. "'--,.-.-.--.-."-- -------.---.- TARGET LOCATION: 1095'FNL,1874'FEL SEC. 19, T8N, R7E TD LOCATION: 1722' FNL, 1876' FEL SEC. 19, T8N, R7E .". -,--,---,.~----_._-_.. '-'--.--'''-.--''. ..--.,.. ConocoPhillips Alaska, Inc. _~"" ___._,"_~,_______.._.__"..__..__.._.___._n_"'.._" ._ _.'__"'_ ConocJPhillips Location: North Slope, Alaska Field: Meltwater Installation: Drill Site 2P -- -..-..-- ....--..".-..---------..- - - .------,----..--.-.--..- -3600 -3200 East (feet\ -> -2800 -24bo -2'000 -1600 _...._-_._----_.._~,,- ----,-~_.._" ,-...,.-.-.,. -,.'--- SURFACE LOCATION: 1026' FNL, 1563' FWL SEC. 17, T8N, R7E C40 C37 Turn 3/100 T7 j_l ~- EOC 5112 x 3112 XO 5 1/2in Casing T4.2 (Top Cairn) T4.1 o 00 ....... (J T3 (Top Bermuda) Target ... j l [2P-449 T2 (Base Bermuda) C35 (Top Albian) TO, Csg. Pt. 3 1/2in Casing Slot: slot #449 Well: 449 Wellbore: 2P-449 - -.-.-----------.---------.----..--..- ëreãlëa-6ÿ--:"'-'Pfàññ-êr .. "---'-- ..,.-----,,- Date plotted: 30-Jan-2004 ·ï5iõtreferericè-is2P:¡¡ïg·:···-- ---- ------~ -- Ref well path is 2P-449 Vers#11 A Coordinates are in feet reference slot #449. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 252.00 ft. Plot North is aligned to TRUE North. -1200 -800 o 400 -400 290 ÆZ Bld/Trn 3/100 -£) Base Permafrost .~,-_.. c:: .. 1, Base West Sak ~~ ~ EOC 1- ~ 9 5/8in Casing \j Turn 3/100 C80 400 KOP o -400 -800 - -1200 - -1600 - -2000 - -2400 ^ I -2800 Z o ;:I. - -3200::T ;; CD r+ -3600 - -4000 -4400 -4800 -5200 - -5600 en (") -6000 ~ (") 3 - -6400 II I\.) o o - -6800 ~ ORIGINAl 280 270 260 ConocoPhillips Alaska, Inc. slot #449 Well: 449 Wellbore: 2P-449 Location: field: Meltwater Installation: Drill Site 2P ï5ianner 30-Jan-2004 350 Ref well path is 2P-449 Vers#11.A. Coordinates are în feet reference slot #44fL True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 252.00 ft. Plot North is aligned to TRUE North. 4598 4500 290 250 240 210 150 200 160 190 170 180 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ConoeoPhillips Alaska, Ine.. "",/ Cono,coPhillips Location: North Slope, Alaska Field: Meltwater Installation: Drill Site 2P Slot: slot #449 Well: 449 Wellbore: 2P-449 Created by: Planner Date plotted: 2-Feb-2004 Plot reference is 2P-449 , Ref well path is 2P-449 Vers#11 ,A Coordinates are in feet reference slot #449. True Vertical Depths are reference Datum. Measured Depths are reference Rig Rig Datum: Planned Datum Rig Datum to mean sea level: 252,00 ft Plot North is aligned to TRUE North, Scale 1 em::: 10 ft -400 -380 -360 -340 -320 -300 -280 -260 -240 -220 1400 TVJì-------~------~ --------- ~ ~------~--~--- / Atk;;J y~ ~___________.J East (feet) -> -200 -180 -160 -140 -120 20 40 -100 -80 -60 -40 -20 o 11 00 TVD 900 TVD 800 TVD -~---- -- ~-____ 700 TVD ----~ 600 TVD Iì ~~TVD Jð!0 TVD 500 TVD300 TVl:$õo ~CZ9DTV V 800 TvbOO T _ _ woo TVrJ50 TVD / 900 TVD + 1100 TVO+ 700 TVD 1000 TVD . + 11 00 TVD - 1200 TYD ' 1 000 TVD- -r"'f\. ... + ~. .//~_ // 800 TVD fD \ \ r/<ç:/\ í /4 ~ ,) i t;,t;,'ò<:?- ) J$:)¡ ~-- ~~ ~/// (:1/ ~3.?~~--- 1300 TVD ~------ --------.---.--'.- -'~-- 180 160 140 120 100 80 ^ . z o 60 ;:;. :::r æ- 40 ~ - 20 0 (fJ -20 (1 ID CD (' -40 :3 II 0 -60 ;::I> 1800 TVD -100 -200 TVD -300 ^ , Z 0 -400 ;::¡. :::T - a' -500 <D r+ - -600 2100 TVD -700 (j) -800 " w ii) " -900 3 II (J'¡ 0 -1000 ;::!> ConoeoPhillips Alaska, Ine.. illips Location: Field: Installation: North Slope, Alaska Meltwater Drill Site 2P Slot: slot #449 Well: 449 Wellbore: 2P-449 Created by: Planner Date plotted' 2-Feb-2004 Plot reference is 2P-449 , Ref well path is 2P-449 Vers#11A Coordinates are in feet reference slot #449. True Vertical Depths are reference Rig Datum Depths are reference Ri9 Datum, Rig Datum: Planned Datum Rig Datum to mean sea level: 252.00 ft, Piot North is aiign~~TRUE North, Seale 1 em = 50 ft -2400 -2300 -2200 -2100 -2000 -1900 East (feet) -> -1400 -13ÒO -{200 -1100 -1000 -1800 -1700 -1600 -1500 -900 -800 -700 -600 -500 -400 -300 -200 3600 TVD 3900 TVD 4~ Tvd200T~D, . 5400 T~~8_0~ < ...~. ..-;// 451 /// ----:::/" // // // /' 2400TVD // /// 2700ND // #) \__/ 2400 TVD TVD 200 100 o Scale 1 em = 100 ft -4400 -4200 -4000 ~ -3800 4500 NO ConocoPhillips Alaska, Inc.. Field: Meltwater Installation: Drill Site 2P slot #449 Well: 449 Well bore: 2P-449 1ív/ ConocoPhmips Date Plot reference is 2P-449 Ref wellpath is 2P-449 Vers#11 A Coordinates are infeet reference slot #449> True Vertical Depths are reference Rig Datum Measured Depths are feference Rìg Datum. Rig Dat~m: Planned Datum Rig Datum to mean sea level: 252.00 ft. Plot North is aligned to TRUE North. -3600 -3200 East (feet) -> -3000 -~800 -2600 -2000 -1800 -1600 -1400 -1200 -3400 3900 NO 4100 NO 4300 ND / 4300 NO 4500 NO ~\ h\,J><~/ - ~/ //2500 NO (,bt~- //. 2;OÔn,~ = 2700 T\lO / ./ . 2900 NO ¿.//33~~ürWD ¡2'900 T\7D . !:~O ~ NO 35002:3500 ND 3100 NO . 700 NO 900 NO -2400 -2200 3700 NO 41 00 i'JòI1í'Vo 4500 NO NO 4700 NO 4900 NO 5300 NO 3900 NO 3900 NO 5500 NO 4300 NO 4100 NO 4500 NO 4700 NO 4900 TVO r- / 0) -¡ I ;¡: / ¡ff; / \/.--- 4100 TVO -400 -600 -800 -1000 -1200 -1400 -1600 -1800 -2000 ^ . Z -2200 0 ""II - :;:¡' - - -2400 CD CD - - -2600 -2800 -3000 -3200 -3400 -3600 (f) o -3800 * o 3 - -4000 II -'- a a -4200 ;:1! INTEQ Seale 1 em = 100 ft -4600 -4400 -4200 ConocoPhillips Alaska, Inc.. Alaska Slot: slot #449 Well: 449 Well bore: 2P-449 Field: Meltwater Installation: Drill Site 2P -4000 East (feet) -> -3400 -3200 -3000 -3800 -3600 4400 TVO 4800 TVO 5000 TVO 5200 TVO 5400 TVO 5600 TVO I -2800 -2600 -2400 1/;; Z~j 4000 TVO I I .¡::,.! , .¡::,.' \ eel ~ i~48AI 4200 TVO 5000 TVO ~/ ConocoPhillips Created by Planner Date plotted 2-Feb-2004 reference is Ref welipath is 2P-449 Vers#11 A CoordìnÇltes are in feet reference s!ot#449. Trtje Vertical Depths are reference Rîg Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum 'I Rig Datum to mean sea level: 252_00 ft Plot North is aligned to TRUE North_ -2200 -2000 -1800 5200 TVO 5400 TVO -2800 -3000 -3200 -3400 -3600 -3800 -4000 -4200 ^ , -4400 Z o '"'I .... - -4600::r ~ () .... -4800 - -5000 -5200 -5400 -5600 -5800 (f) 0 -6000 S,\) (i) 0 -6200 3 II 0 0 -6400 ;::¡, ConocóPhillips e ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska e PROPOSAL LISTING Page 1 Wellbore: 2P-449 Well path: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 ... BAKER HUGHES INTEQ Wellbore Name 2P-449 I Last Revised 30-Jan-2004 Well Name 449 Slot [North 1025.99S lEast 1567.07E Name slot #449 Installation Name Drill Site 2P I NorthinQ I Coord System Name I North AIiQnment 441964.238~ 5869891.466j AK-4 on NORTH AMERICAN DATUM 1927 datu~ True ' Field Name Meltwater [ EastinQ I Northina 441964.238~ I Coord System Name I North Alianment 5869891.466j AK-4 on NORTH AMERICAN DATUM 1927 datu~ True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL C~illips e ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska e PROPOSAL LISTING Page 2 Wellbore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 -.. BAKlR HUGHES INTEQ MD[ft] Inc[deg] Azi[deg] TVD[ft] Northing Easting Latitude Longitude Vertical Sectionlftl 0.00 0.00 0.00 0.00 , 5868853.6, 443523.2~ N70 3 8.4281 W150 27 7.0314 0.00 100.00 0.00 0.00 100.00 5868853.6, 443523.2~ N70 3 8.4281 W150 27 7.0314 0.00 200.00 0.00 0.00 200.00 5868853.6, 443523.2~ N70 3 8.4281 W150 27 7.0314 0.00 300.00 0.00 0.00 300.00 5868853.6, 443523.2~ N70 3 8.4281 W150 27 7.0314 0.00 400.00 3.00 290.00 399.95 5868854.5~ 443520.8' N70 3 8.4369 W150 27 7.1023 0.57 500.00 6.00 290.00 499.63 5868857.3. 443513.4~ N70 3 8.4633 W150 27 7.3146 2.28 600.00 9.00 290.00 598.77 5868861.8, 443501.2€ N70 3 8.5072 W150 27 7.6679 5.13 633.33 10.00 290.00 631.64 5868863.7! 443496.1C N70 3 8.5257 W150 27 7.8168 6.33 700.00 11.65 283.98 697.12 5868867.4! 443484.1€ N70 3 8.5612 W150 27 8.1617 9.74 800.00 14.30 277.64 794.57 5868871.71. 443462. H N70 3 8.6014 W150 27 8.7967 18.18 900.00 17.06 273.28 890.84 5868874.4' 443435.2~ N70 3 8.6257 W150 27 9.5712 30.58 1000.00 19.89 270.11 985.68 5868875.5. 443403.6~ N70 3 8.6343 W150 27 10.4831 46.90 1003.99 20.00 270.00 989.43 5868875.5: 443402.2i N70 3 8.6343 W150 27 10.5224 47.63 1100.0C 22.49 265.97 1078.92 5868874.5( 443367 .5~ N70 3 8.6216 W150 27 11.5230 67.43 1200.0C 25.16 262.60 1170.39 5868870.7. 443327.3' N70 3 8.5815 W150 27 12.6800 92.51 1300.0C 27.90 259.84 1259.86 5868864. H 443283. H N70 3 8.5140 W150 27 13.9508 122.06 1400.0C 30.68 257.55 1347.07 5868854.9' 443235.1€ N70 3 8.4193 W150 27 15.3320 156.01 1500.00 33.49 255.60 1431.79 5868842.9: 443183.4~ N70 3 8.2976 W150 27 16.8197 194.25 1600.00 36.34 253.93 1513.7a 5868828.2, 443128.1. N70 3 8.1494 W150 27 18.4100 236.69 1700.0C 39.20 252.46 1592.83 5868810.9~ 443069.3~ N70 3 7.9750 W150 27 20.0983 283.20 1800.0C 42.08 251.17 1668.7C 5868791.1C 443007 .3~ N70 3 7.7749 W150 27 21.8802 333.67 1900.0C 44.97 250.01 1741.2C 5868768.6~ 442942.2~ N70 3 7.5496 W150 27 23.7508 387.95 1900.98 45.00 250.00 1741.89 5868768.41 442941.6< N70 3 7.5473 W150 27 23.7694 388.50 2000.0C 47.84 248.78 1810.15 5868743.6! 442874.3. N70 3 7.2987 W150 27 25.7029 445.95 2100.0C 50.71 247.65 1875.3~ 5868716.0; 442803.7i N70 3 7.0219 W150 27 27.7294 507.56 2200.0C 53.60 246.61 1936.74 5868685.9' 442730.8' N70 3 6.7199 W150 27 29.8247 572.62 2300.0C 56.49 245.64 1994.03 5868653.2! 442655.61. N70 3 6.3935 W150 27 31.9829 640.94 2400.0C 59.39 244.74 2047.11 5868618.3( 442578.4i N70 3 6.0436 W150 27 34.1983 712.34 2486.73 61.91 244.00 2089.61 5868586.1' 442510.0~ N70 3 5.7219 W150 27 36.1613 776.61' 2500.0C 61.91 244.00 2095.86 5868581.01 442499.5~ N70 3 5.6714 W150 27 36.4644 786.61 2600.0C 61.91 244.00 2142.94 5868542.9, 442419.9€ N70 3 5.2909 W150 27 38.7482 861.91 2700.0C 61.91 244.00 2190.03 5868504.8! 442340.3~ N70 3 4.9104 W150 27 41.0321 937.21 2800.0C 61.91 244.00 2237.11 5868466.8' 442260.8. N70 3 4.5299 W150 27 43.3159 1012.52 2900.0C 61.91 244.00 2284.1E 5868428.7: 442181.2~ N70 3 4.1494 W150 27 45.5997 1087.82 3000.0C 61.91 244.00 2331.27 5868390.61 4421 01.6~ N70 3 3.7689 W150 27 47.8835 1163.12 3100.0C 61.91 244.00 2378.36 5868352.5, 442022.1' N70 3 3.3884 W150 27 50.1673 1238.42 3145.97 61.91 244.00 2400.0C 5868335.Of 441985.5~ N70 3 3.2135 W150 27 51.2171 1273.04 3200.0C 61.64 242.19 2425.55 5868313.81. 441942.9. N70 3 3.0015 W150 27 52.4397 1314.06 3300.00 61.21 238.81 2473.3~ 5868271.1 i 441866.H N70 3 2.5761 W150 27 54.6406 1391.66 3400.0C. 60.86 235.40 2521.82 5868224.2' 441792.4( N70 3 2.1087 W150 27 56.7559 1471.25 3500.0C 60.60 231.97 2570.72 5868173.0! 441721.n N70 3 1.6006 W150 27 58.7798 1552.63 3600.0C 60.43 228.53 2619.95 5868117.91 441654.4. N70 3 1.0531 W150 28 0.7068 1635.56 3700.0C 60.35 225.08 2669.37 5868058.91. 441590.6. N70 3 0.4679 W150 28 2.5317 1719.82 3800.0C 60.35 221.63 2718.86 5867996.2' 441530.5' N70 2 59.8464 W150 28 4.2493 1805.H 3900.0C 60.45 218.18 2768.26 5867929.91 441474.2~ N70 2 59.1904 W150 28 5.8550 1891.41 4000.0C 60.63 214.74 2817.46 5867860.3: 441422.0' N70 2 58.5017 W150 28 7.3444 1978.26 4100.0C 60.90 211.32 2866.31 5867787.51 441373.9. N70 2 57.7822 W150 28 8.7135 2065.5(' 4200.0C 61.26 207.92 2914.6€, 5867711.8( 441330.1. N70 2 57.0338 W150 28 9.9584 2152.8~ 4300.0C 61.70 204.54 2962.43 5867633.2! 441290.7. N70 2 56.2586 W150 28 11.0757 2240. H 4342.01 61.91 203.13 2982.2€ 5867599.51. 441275.5' N70 2 55.9255 W150 28 11.5063 2276.79 4400.0C 61.91 203.13 3009.59 5867552.61 441255.0i N70 2 55.4627 W150 28 12.0847 2327.25 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ConocJPhillips e ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska e PROPOSAL LISTING Page 3 Wellbore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 INTEQ MO[ft] Inc{deg] Azi[deg] TVO[ft] Northing Easting Latitude Longitude Vertical Sectionlftl 4500.0C 61.91 203.13 3056.67 5867471.71 441219.8. N70 2 54.6647 W150 28 13.0820 2414.27 4600.0C 61.91 203.13 3103.75 5867390.9. 441184.5i N70 2 53.8666 W150 28 14.0794 2501.2E 4700.0C 61.91 203.13 3150.8~ 5867310.0E 441149.3' N70 2 53.0685 W150 28 15.0767 2588.31 4800.00 61.91 203.13 3197.91 5867229.H 441114.0€ N70 2 52.2705 W150 28 16.0740 2675.3~ 4900.0~ 61.91 203.13 3245.0~ 5867148.3~ 441078.8' N70 2 51.4724 W150 28 17.0713 2762.35 5000.0C 61.91 203.13 3292.0f 5867067.4E 441043.5€ N70 2 50.6744 W150 28 18.0685 2849.37 5100.0C 61.91 203.13 3339.16 5866986.6C 441008.3' N70 2 49.8763 W150 28 19.0658 2936.3E 5200.0C 61.91 203.13 3386.24 5866905.n 440973.0€ N70 2 49.0783 W150 28 20.0630 3023.41 5300.0C 61.91 203.13 3433.32 5866824.8i 440937.8' N70 2 48.2802 W150 28 21.0602 311 0.4~ 5400.0C 61.91 203.13 3480.41 5866744.0C 440902.5€ N70 2 47.4821 W150 28 22.0573 3197.45 5500.0C 61.91 203.13 3527.4E 5866663.1~ 440867.3C N70 2 46.6841 W150 28 23.0545 3284.47 5600.00 61.91 203.13 3574.57 5866582.2i 440832.0~ N70 2 45.8860 W150 28 24.0516 3371.4E 5700.0C 61.91 203.13 3621.65 5866501.4' 440796.8C N70 2 45.0879 W150 28 25.0487 3458.51 5800.0C 61.91 203.13 3668.74 5866420.5~ 440761.5~ N70 2 44.2899 W150 28 26.0458 3545.5~ 5900.0C 61.91 203.13 3715.82 5866339.61 440726.3C N70 2 43.4918 W150 28 27.0429 3632.55 6000.0C 61.91 203.13 3762.9C 5866258.8. 440691.0~ N70 2 42.6937 W150 28 28.0399 3719.57 6100.0C 61.91 203.13 3809.9€ 5866177.9~ 440655.8C N70 2 41.8957 W150 28 29.0369 3806.59 6200.00 61.91 203.13 3857.07 5866097 .O~ 440620.5~ N70 2 41.0976 W150 28 30.0339 3893.61 6300.0C 61.91 203.13 3904.15 5866016.2. 440585.2~ N70 2 40.2995 W150 28 31.0309 3980.6~ 6400.0C 61.91 203.13 3951.23 5865935.3E 440550.0< N70 2 39.5014 W150 28 32.0279 4067.65 6500.0C 61.91 203.13 3998.31 5865854.4~ 440514.n N70 2 38.7034 W150 28 33.0248 4154.67 6600.0C 61.91 203.13 4045.4C 5865773.6: 440479.5~ N70 2 37.9053 W150 28 34.0217 4241.69 6700.0C 61.91 203.13 4092.48 5865692.7E 440444.2~ N70 2 37.1072 W150 28 35.0186 4328.71 6800.00 61.91 203.13 4139.56 5865611.9C 440409.0~ N70 2 36.3091 W150 28 36.0155 4415.7:1 6900.0~ 61.91 203.13 4186.64 5865531.0~ 440373.7~ N70 2 35.5110 W150 28 37.0124 4502.75 7000.0C 61.91 203.13 4233.72 5865450.1i 440338.5~ N70 2 34.7129 W150 28 38.0092 4589.77 7100.0C 61.91 203.13 4280.81 5865369.3' 440303.2f N70 2 33.9148 W150 28 39.0060 4676.79 7200.0C 61.91 203.13 4327.89 5865288.4< 440268.0:: N70 2 33.1168 W150 28 40.0028 4763.81 7300.0C 61.91 203.13 4374.97 5865207.51 440232.7f N70 2 32.3187 W150 28 40.9996 4850.8~ 7400.0C 61.91 203.13 4422.05 5865126.7' 440197.5~ N70 2 31.5206 W150 28 41.9963 4937.85 7408.03 61.91 203.13 4425.84 5865120.2. 440194.7C N70 2 31.4565 W150 28 42.0764 4944.84 7500.0~ 61.68 200.01 4469.31 5865045.m 440164.3~ N70 2 30.7152 W150 28 42.9332 5024.3f 7600.0~ 61.51 196.60 4516.8€ 5864961.8' 440136.1' N70 2 29.8939 W150 28 43.7275 5109.6C 7700.0C 61.43 193.19 4564.65 5864877.1C 440112.9C N70 2 29.0589 W150 28 44.3766 5193.2€ 7800.0C 61.43 189.77 4612.4f 5864791. H 440094.7€ N70 2 28.2125 W150 28 44.8787 5275.19 7900.0C 61.52 186.36 4660.24 5864704.3. 440081.8' N70 2 27.3570 W150 28 45.2325 5355.1C 8000.0C 61.69 182.96 4707.81 5864616.7. 440074.0. N70 2 26.4948 W150 28 45.4370 5432.8C 8087.16 61.91 180.00 4749.0~ 5864539.9i 440071.4i N70 2 25.7397 W150 28 45.4930 5498.55 8100.0C 61.91 180.00 4755.04 5864528.6< 440071.3~ N70 2 25.6283 W150 28 45.4929 5508.0E 8200.0~ 61.91 180.00 4802.13 5864440.4: 440070.7< N70 2 24.7606 W150 28 45.4917 5582.42 8300.0C 61.91 180.00 4849.21 5864352.2. 440070.0€ N70 2 23.8929 W150 28 45.4906 5656.7~ 8400.0C 61.91 180.00 4896.29 5864264.0' 440069.4~ N70 2 23.0252 W150 28 45.4895 5731.06 8500.0C 61.91 180.00 4943.37 5864175.8C 440068.7i N70 2 22.1575 W150 28 45.4883 5805.3f 8600.0C 61.91 180.00 4990.46 5864087.5~ 440068.1. N70 2 21.2899 W150 28 45.4872 5879.71 8700.0C 61.91 180.00 5037.54 5863999.31 440067.4i N70 2 20.4222 W150 28 45.4860 5954.0~ 8800.0C 61.91 180.00 5084.62 5863911. H 440066.8' N70 2 19.5545 W150 28 45.4849 6028.35 8900.0C 61.91 180.00 5131.7C 5863822.9( 440066.1€ N70 2 18.6868 W150 28 45.4838 6102.6€ 9000.0C 61.91 180.00 5178.7~J 5863734.7~ 440065.5C N70 2 17.8191 W150 28 45.4826 6177.0C 9100.0C 61.91 180.00 5225.87 5863646.5~ 440064.8~ N70 2 16.9514 W150 28 45.4815 6251.32 9200.0C 61.91 180.00 5272.95 5863558.3. 440064.2C N70 2 16.0837 W150 28 45.4804 6325.6~ 9229.8:1 61.91, 180.00 5287.0C 5863532.0C 440064.0C N70 2 15.8249 W150 28 45.4800 6347.8 All data is in Feet unless otherwise stated Coordinates are from Slot MOos are from Rig and TVO's are from Rig ( Planned Oatum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL Conoc6Phillips e ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska e PROPOSAL LISTING Page 4 Well bore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 INTEQ MO[ft] Inc[deg] Azi[deg] TVO[ft] Northing Easting Latitude Longitude Vertical Sectionlftl 9300.0C 61.91 180.00 5320.04 5863470.1 ' 440063.5¿ N70 2 15.2160 W150 28 45.4792 6399.97 9400.0C 61.91 180.00 5367.12 5863381.8! 440062.8~ N70 2 14.3484 W150 28 45.4781 6474.2~ 9500.0C 61.91 180.00 5414.2(, 5863293.61 440062.2~ N70 2 13.4807 W150 28 45.4769 6548.61 9600.0(, 61.91 180.00 5461.2€ 5863205.41 440061.5t N70 2 12.6130 W150 28 45.4758 6622.9l 9700.0(, 61.91 180.00 5508.37 5863117.2€ 440060.9. N70 2 11.7453 W150 28 45.4747 6697.26 9750.2C 61.91 180.00 5532.0C 5863072.91 440060.6C N70 2 11.3098 W150 28 45.4741 6734.56 9800.0C 61.91 180.00 5555.45 5863029.m 440060.21 N70 2 10.8776 W150 28 45.4735 6771.5€ 9900.0C 61.91 180.00 5602.5:1 5862940.~ 440059.6. N70 2 10.0099 W150 28 45.4724 6845.9C 9940.2C 61.91 180.00 5621.46 5862905.31 440059.3~ N70 2 9.6611 W150 28 45.4719 6875.7!! All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Planned Oatum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL e ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska eonocJ'Phillips e PROPOSAL LISTING Page 5 Wellbore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 8i. BAKER HUGHES INTEQ MOrft] TVOrft] Northrft] 300.00 300.00 633.33 631.64 1405.n 1352.0C 2225.94 1952.0C 2486.7~ 2089.61 3031.2~ 2346.0(, 3145.97 2400.0C 3232.45 2441.0C 4223.5~ 2926.0C 4342.01 2982.2E, 4887.26 3239.0C 5186.74 3380.0C 7408.0~ 4425.8< 7591.86 4513.0C 8087.16 4749.0C 8337.44 4866.8' 8537.44 4961.0C 8679.74 5028.0C 9229.8~ 5287.0C 9750.2(, 5532.0C 9809.66 5560.0C 9940.2C. 5621.46 Hole Sections Oiameter Start [in] MOrft] 121/4 8112 Start TVOrft] 0.00 3031.2~ Eastlft] O.OON 9.92N 1.535 182.02S 275.09S 485.69S 530.05S 565.14S 1176.56S 1270.89S 1713.26S 1956.23S 3758.40S 3910.40S 4339.61 S 4560.41S 4736.85S 4862.39S 5347.70S 5806.77S 5859.24S 5974.40S Comment O.OOE KOP 27.27W Bldrrrn 3/100 291.02\1\ Base Permafrost 810.53\1\ Base West Sak 1 011.29V\ EOC 1443.08V\ 9 5/8 CSG 1534.03V\ Turn 3/100 1601.58V\ C80 2194.42V\ C50 2238.64V\ EOC 2427.59V\ C40 2531.37V\ C37 3301.14V\ Turn 3/100 3356.50V\ T7 3420.07V\ EOC 3420.07V\ 5 1/2 x 3 1/2 XO 3420.07V\ T4.2 (Top Cairn) 3420.07V\ T4.1 3420.07V\ T3 (Top Bermuda) TarQet 3420.07V\ T2 (Base Bermuda) 3420.07V\ C35 (Top Albian) 3420.07V\ TO. CSQ. PI. Start Northrft] 0.00 O.OON 2346.0C 485.695 Start End End End Start Wellbore Eastlft] MOrft] TVOrft] Northrft] Eastlft] O.OOE 3031.28 2346.0C 485.69S 1443.08V\ 2P-449 1443.08V\ 9940.2C 5621.46 5974.40S 3420.07V\ 2P-449 ClasinlilfS Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MOrft] TVOrftl Northrft] Eastlft] MOrft] TVOrftl Northlft] Eastlft] 9 5/8in CasinQ 0.00 0.00 O.OON O.OOE 3031.28, 2346.0C 485.69S 1443.08V\ 2P-449 5 1/2in CasinQ 0.00 0.00 O.OON O.OOE 8337.4< 4866.84 4560.41S 3420.07V\ 2P-449 3 1/2in CasinQ 8337.44 4866.8' 4560.41S 3420.07V\ 9940.2(, 5621.46 5974.40S 3420.07V\ 2P-449 laltmets Name I Northrft] ~ Eastlft] 1 TVOrft] ~ Latitude 2P-449 Top Berm 5347.70 3420.07 5287.0 N70 2 TQt Rvsd30Jan04 I LonQitude 15.8249 W150 28 EastinQ J NorthinQ J Last Revised 440064.01 5863532.01 6-Jan-2004 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Planned Oatum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated () f1 ¡ fr" Î. r.'- .¡ A~ î Ur\IOH'J t_ ConocÓPhillips e ConocoPhillips Alaska, Inc.,slot #449 Drill Site 2P, Meltwater,North Slope, Alaska . PROPOSAL LISTING Page 1 Well bore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 '&1. BAKER HUGHES INTEQ I COOÍ'd Svstem Name . .North Alionment 5869891.466 AK-4 on NORTH AMERICAN DATUM 1927 datum True Coord SYstem Name I North Alionment 5869891.466 AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ConocóP'hillips ConocoPhillips AlaSka'c.,Slot #449 Drill Site 2P, Meltwater,North Slope, Alaska PROPOSAL LING Page 2 Wellbore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 r&iá. BAKER HUGHES INTEQ O.OC 0.00 o.oc o.oc 0.001\, O.OOE O.OC 0.00 100.0C 0.00 0.01) 100.0( 0.001\. O.OOF O.OQ 0.00 20D.O( O.OQ O.oc;, 200.0( 0.001\. O.OOF 0.00 0.00 300.0~ 0.00 O.OC 300.0~ 0.001\, O.OOE O.OC 0.00 400.0( 3.0c;, 290.0C 399.9~ 0.901\. 2.46W 3.01) 0.57 500.0C 6.0C 290.0(, 499.6~ 3.581\. 9.83V1¿ 3.0c;, 2.28 600.0C 9.00 290.0C 598.77 8.041\, 22.09V\ 3.0C 5.13 633.3~ 10.00 290.0( 631.6L.. 9.921\. 27.27V1 3.0c;, 6.33 700.0C 11.6!¡¡ 283.9E, 697.1¡ 13.531\. 39.24,^ 3.0C 9.74 800.0~ 14.30 277.6L 794.57 17.611\, 61.28V\ 3.0C 18.18 900.0C 17.01:11 273.2E. 890./3i" 20.091\. 88.1M 3.0C 30.5/j 1000.0C 19.89 270.1' 985.6E. 20.961\. 119.83'" 3.0c;, 46.9C 1003.9~ 20.00 270.0C 989.4::' 20.971\, 121.191/\ 3.0C 47.62 1100.0( 22.49 265.97 1078.9'- 19.681\. 155.93'" 3.0C 67.4:;' 1200.0( 25.11:11 262.6( 1170.3~ 15.60r--... 196.09'" 3.0C 92.51 1300.0( 27.90 259.8¿ 1259.8~ 8.731\, 240.211/\ 3.0C 122.0E 1400.0C 30.6131 257.5~ 1347.0i 0.90S- 288.15'" 3.01) 156.0' 1500.0C 33.49 255.6C 1431.7~ 13.26~ 339.80'" 3.01) 194.2~ 1600.0( 36.34 253.92 1513.7~ 28.335 395.01'" 3.00 236.6£ 1700.0C 39.20 252.4E 1592.8~ 46.06~ 453.62'" 3.0c;, 283.2( 1800.0( 42.0a 251.17 1668.7( 66.40~ 515.491/\ 3.01) 333.67 190D.O( 44.97 250.0' 1741.2( 89.305 580.42'" 3.0C 387.9E 1900.91 45.0Q 250.0C 1741.8~ 89.54~ 581.07V\ 3.01) 388.5C 2000.0( 47.84 248.7e 1810. H 114.80~ 648.20'" 3.0Q 445.9~ 2100.0( 50.71 247.6E 1875.3~ 142.945 718.55'" 3.00 507.5E 2200.0( 53.6c;, 246.6' 1936.7¿ 173.655- 791.29'" 3.0Q 572.6~ 2300.0C 56.4~ 245.6L 1994.0~ 206.825- 866.22'" 3.0C 640.9¿ 2400.0( 59.39 244.7L 2047.1' 242.395 943.141/\ 3.0C 712.3¿ 2486.7~ 61.91 244.0( 2089.6' 275.095- 1011.29'" 3.00 776.6' 2500.0C 61.91 244.0C 2095.8~ 280.23~ 1021.81'" 0.00 786.6' 2600.0( 61.91 244.0C 2142.9¿ 318.905 1101.11'" 0.00 861.9' 270D.O( 61.91 244.0(, 2190.0: 357.57~ 1180.40'" 0.00 937.2' 2800.0C 61.91 244.0(, 2237.1' 396.25~ 1259.69'" O.OC 1012.5, 290D.O( 61.91 244.0(. 2284.1~ 434.92~ 1338.991/\ O.OC 1087.8~ 3000.0C 61.91 244.0( 2331.2i 473.60~ 1418.28'" O.OC;, 1163.1, 3100.0C 61.91 244.0( 2378.3~ 512.27~ 1497.58'" 0.01) 1238.4, 3145.9i 61.91 244.0C 2400.0( 530.055 1534.03'" 0.00 1273.OL 3200.0( 61.64 242.1~ 2425.5f 551.59~ 1576.48'" 3.OQ 1314.0E 3300.0( 61.21 238.8' 2473.3~ 594.83~ 1652.90'" 3.0c;, 1391.6E 3400.0( 60.86 235.4C 2521.8~ 642.345 1726.351/\ 3.0C 1471.2E 3500.0( 60.6C 231.97 2570.7'- 693.995- 1796.63'" 3.00 1552.6~ 3600.0( 60.4~ 228.5~ 2619.9~ 749.635- 1863.54'" 3.00 1635.5(; 3700.0( 60.35 225.01: 2669.3i 809.12~ 1926.911/\ 3.0C 1719.8~ 3800.0C 60.3f1 221.62, 2718.8~ 872.295- 1986.56'" 3.0C 1805.1e 3900.0C 60 AfI 218.1E, 2768.2( 938.98~ 2042.33'" 3.0Q 1891.4' 4000.0( 60.63 214.7¿ 2817.4~ 1008.99~ 2094.061/\ 3.00 1978.2E 4100.0( 60.9C 211.3< 2866.3' 1082.13~ 2141,62'" 3.00 2065.5( 4200.0C 61.2Q 207.9" 2914.61 1158.21~ 2184.86'" 3.0C 2152.8~ 4300.0( 61.70 204.5¿ 2962.4~ 1237.02~ 2223.68'" 3.00 2240.1£ 4342.0' 61.91 203.1~ 2982.21 1270.89~ 2238.64'" 3.0Q 2276.7~ 4400.0C 61.91 203.1:;' 3009.5~ 1317.93~ 2258.74'" O.OQ 2327.2~ 4500.0( 61.91 203.1:;' 3056.6i 1399.07~ 2293.39'" 0.00 2414.27 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ConocJ'Phillips ConocoPhillips AlaSka!c.,Slot #449 Drill Site 2P, Meltwater,North Slope, Alaska PROPOSAL LING Page 3 Well bore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 r&ii. BAKER HUGHES INTEQ 4600.0~ 61.91 203.1~ 3103.7~ 1480.20~ 2328.04'1\ 0.00 2501.2~ 4700.0C 61.91 203.1~ 3150.8: 1561.33~ 2362.70'1\ 0.00 2588.3' 4800.0C 61.91 203.1~ 3197.9' 1642.46~ 2397.35'1\ O.OQ 2675.3~ 4900.0~ 61.91 203.1:; 3245.0~ 1723.59~ 2432.01'1\ 0.00 2762.3~ 5000.0C 61.91 203.1~ 3292.0~ 1804.72~ 2466.66'1\ O.OC;, 2849.3( 5100.0C 61.91 203.1~ 3339.1f 1885.86~ 2501.31'1\ O.OC 2936.3~ 5200.0~ 61.91 203.1 ~ 3386.2< 1966.99~ 2535.97V1 0.00 3023.4' 5300.0C 61.91 203.1 ~ 3433.3¡ 2048.12~ 2570.62'1\ 0.00 3110.4~ 5400.0C 61.91 203.1 ~ 3480.4' 2129.25~ 2605.28'1\ O.OQ 3197.4~ 5500.0~ 61.91 203.1:; 3527 .4~ 2210.38~ 2639.93'1\ 0.00 3284.47 5600.0C 61.91. 203.1 ~ 3574.5; 2291.51~ 2674.59'1\ 0.00 3371.4~ 5700.0C 61.91 ~03.1 ~ 3621.61 2372.65~ 2709.24'1\ O.OQ 3458.5' 5800.0~ 61.91 203.1 ~ 3668.7< 2453.78~ 2743.89\1\ 0.00 3545.5~ 5900.0C 61.91. 203.1 ~ 3715.8~ 2534.91~ 2778.55'1\ 0.00 3632.5~ 6000.OC 61.91. 203.1~ 3762.9~ 2616.04~ 2813.20'1\ 0.00 3719.57 6100.0~ 61.91 203.1 ~ 3809.9~ 2697.17~ 2847.86\1\ 0.00 3806.5~ 6200.0C 61.91 203.1 ~ 3857.0; 2778.30~ 2882.51'1\ O.OQ 3893.6' 6300.0C 61.91 203.1 ~ 3904.11 2859.43~ 2917.16'1\ O.OC 3980.6; 6400.0~ 61.91 203.1:; 3951.2~ 2940.57~ 2951.82'1\ O.OC 4067.6~ 6500.0C 61.91 203.1 ~ 3998.3' 3021.70~ 2986.47'1\ 0.00 4154.67 6600.OC 61.91 203.1 ~ 4045.4C 3102.83~ 3021.13'1\ O.OQ 4241.6~ 6700.0~ 61.91 203.1 ~ 4092.4~ 3183.96~ 3055.78'1\ O.OC 4328.7' 6800.0C 61.91. 203.1 ~ 4139.5f 3265.09~ 3090.43'1\ O.OC;, 4415.7~ 6900.0C 61.91 203.1 ~ 4186.6.1 3346.22~ 3125.09'1\ O.OC;, 4502.7~ 7000.0( 61.91 203.1 ~ 4233.7~ 3427.36~ 3159.74\1\ 0.00 4589.77 7100.0C 61.91. 203.1 ~ 4280.8' 3508.49~ 3194.40'1\ 0.0c;, 4676.7~ 7200.0( 61.91. 203.1 ~ 4327.8f 3589.62~ 3229.05'1\ O.OQ 4763.8' 7300.0~ 61.91 203.1:; 4374.9i 3670.75~ 3263.70'1\ 0.00 4850.8~ 7400.0( 61.91. 203.1~ 4422.0~ 3751.88~ 3298.36'1\ 0.00 4937.8~ 7408.m 61.91. 203.1~ 4425.8< 3758.40~ 3301.14'1\ O.OQ 4944.8< 7500.0( 61.68 200.0' 4469.3' 3833.76~ 3330.93'1\ 3.0C 5024.3E 7600.0C 61.51 196.6( 4516.8~ 3917 .25~ 3358.56'1\ 3.0c;, 5109.6{ 7700.0C 61.4~ 193.15- 4564.61 4002.14~ 3381.14'1\ 3.0Q 5193.2~ 7800.0~ 61.43 189.77 4612.4~ 4088.19~ 3398.62'1\ 3.00 5275.1~ 7900.0C 61.52- 186.3~ 4660.2< 4175.16~ 3410.95'1\ 3.00 5355.1( 8000.0C 61.69 182.9~ 4707.8' 4262.82~ 3418.09'1\ 3.0Q 5432.8( 8087.1( 61.91 180.0C 4749.0~ 4339.61~ 3420.07'1\ 3.0C 5498.5~ 8100.0C 61.91 180.0( 4755.0< 4350.93~ 3420.07'1\ O.OC;, 5508.0~ 8200.0C 61.91 180.0( 4802.1: 4439.15~ 3420.07'1\ O.OC;, 5582.4, 8300.0~ 61.91 180.0C 4849.2' 4527.38~ 3420.07VI O.OC 5656.7< 8400.0( 61.91. 180.0( 4896.2f 4615.60~ 3420.07'1\ 0.00 5731.0~ 8500.0( 61.91 180.0( 4943.3i 4 703.82~ 3420.07'1\ O.OQ 5805.3e 8600.0~ 61.91 180.0C 4990.4( 4792.04~ 3420.07VI O.OC 5879.7' 8700.0C 61.91. 180.0( 5037.5< 4880.27~ 3420.07'1\ 0.0c;, 5954.0~ 8800.0( 61.91 180.0( 5084.6~ 4968.49~ 3420.07'1\ 0.00 6028.3~ 8900.0~ 61.91 180.0C 5131.7~ 5056.71~ 3420.07VI 0.00 6102.6E 9000.0~ 61.91 180.0( 5178.7f 5144.93~ 3420.07'1\ 0.00 6177.0Ç 9100.0C 61.91.. 180.0( 5225.8; 5233.16~ 3420.07'1\ O.OQ 6251.3, 9200.0~ 61.91 180.0C. 5272.9~ 5321.38~ 3420.07'1\ O.OC 6325.6.1 9229.8: 61.91 180.0( 5287.0( 5347.70~ 3420.07'1\ 0.0c;, 6347.8, 9300.0( 61.91 180.0( 5320.0< 5409.60~ 3420.07'1\ O.OQ 6399.9( 9400.0( 61.91 180.0C. 5367.1~ 5497.82~ 3420.07'1\ 0.00 6474.2~ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR}GJ~tAL" con<>cÓPhillips ConocoPhillips Alask!C.,Slot #449 Drill Site 2P, Meltwater,North Slope, Alaska PROPOSAL LING Page 4 Well bore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 J&ií. BAKER HUGHES INTEQ 9500.0~ 61.91 180.0c, 5414.2~ 5586.05~ 3420.0711\ O.OC 6548.6' 9600.0C 61.9t 180.0( 5461.21 5674.27~ 3420.0711\ 0.0c. 6622.9< 9700.0C 61.91 180.0( 5508.3; 5762.49~ 3420.0711\ O.OC) 6697.2e 9750.2~ 61.91 180.0C, 5532.0~ 5806.77~ 3420.0711\ 0.00 6734.5E 9800.0C 61.91 180.0( 5555.4! 5850.71~ 3420.0711\ O.OC, 6771.5~ 9900.OC 61.91 180.0( 5602.5~ 5938.94~ 3420.0711\ O.OC, 6845.9( 9940.2( 61.91 180.0t 5621.4t 5974.40~ 3420.07\1\ 0.0c. 6875.7f All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIG'NALw Conoc~illips ConocoPhillips Alask!c.,Slot #449 Drill Site 2P, Meltwater,North Slope, Alaska PROPOSAL LING Page 5 Well bore: 2P-449 Wellpath: 2P-449 Vers#11.A Date Printed: 30-Jan-2004 "~Ii. BAKER HUGHES INTEQ 300.OC 633.3~ 1405.7~ 2225.9L 2486.7:;' 3031.21;. 3145.97 3232.4~ 4223.5~ 4342.0' 4887.2~ 5186.7L 7408.0~ 7591.8~ 8087.H 8337.4L 8537.4<" 8679.7<" 9229.8:'., 9750.2( 9809.6~ 9940.2C 300.OC 631.6¿ 1352.0( 1952.0\ 2089.6' 2346.0( 2400.0~ 2441.0( 2926.0~ 2982.2~ 3239.0~ 3380.0( 4425.~ 4513.0( 4749.0( 4866.8¿ 4961.0( 5028.0( 5287.0~ 5532.0( 5560.0( 5621.4( 0.001\ 9.921\, 1.53S 182.02~ 275.09~ 485.69~ 530.05S, 565.14~ 1176.56~ 1270.89~ 1713.26~ 1956.23~ 3758.40~ 3910.40~ 4339.61~ 4560.41~ 4736.85~ 4862.39~ 5347.70~ 5806.77~ 5859.24~ 5974.40~ O.OOE, KOP 27.27,^ BldfTm 3/100 291.02,^ Base Permafrost 810.53'" Base West Sak 1011.29\1\ EOC 1443.08\1\9518 CSG 1534.03\1\ Tum 3/100 1601.58\1\C80 2194.42V\C50 2238.64,^ EOC 2427.59V\C40 2531.371/\C37 3301.14,^ Tum 3/100 3356.50V\ T7 3420.07l/\EOC 3420.07V\ 5 1/2 x 3 1/2 XO 3420.071/\ T4.2 (Too Caim) 3420.071/\ T4.1 3420.07V\ T3 (Top Bermuda) TarQet 3420.07V\ T2 (Base Bermuda) 3420.07l/\C35 (Too Albian) 3420.071/\ TO, CSQ. Pt. 12 1/L 81/2 0.0c. 3031.21 0.00 2346.0C 0.001\ 485.69~ O.OOE 1443.08\1' 3031.21: 9940.2C 2346.0( 5621.4( 485.69~ 5974.40~ 1443.08\1\2P-449 3420.07V\2P-449 9 5/8in Casina 5 1/2in Casina 3 1/2in CasinQ 0.00 0.00 8337.4¿ 0.00 0.00 4866.8¿ O.OON O.OON 4560.41~ O.OOF O.OOF 3420.071/\ 3031.2~ 8337.4<" 9940.2C 2346.0( 4866.8<" 5621.4E. 485.69~ 4560.41~ 5974.40~ 1443.08V\2P-449 3420.07V\2P-449 3420.07l/\2P-449 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Planned Oatum 252.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 212.60 degrees Bottom hole distance is 6884.07 Feet on azimuth 209.79 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL .ker Hughes Incorporate. Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.0 ft Depth Range: 0.0 to 9940.1 ft Maximum Radius: 5280.0 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 1/21/2004 Validated: No Planned From To Survey ft ft 0.0 9940.1 Planned: 2P-449 Version#11.A V16 Version: 2 Toolcode Tool Name MWD+SAG MWD + Sag correction Summary 2P Pad 406 2P-406 V3 Plan: 2P-406 336.3 350.0 860.5 6.2 854.3 Pass: Major Risk 2P Pad 414 2P-414 V3 Plan: 2P-414 338.3 350.0 700.4 6.3 694.1 Pass: Major Risk 2P Pad 415 2P-415 VO 299.9 300.0 680.4 4.9 675.5 Pass: Major Risk 2P Pad 415 2P-415A VO 299.9 300.0 680.4 4.9 675.5 Pass: Major Risk 2P Pad 416 2P-416 V1 Plan: 2P-416 319.4 325.0 660.0 5.8 654.2 Pass: Major Risk 2P Pad 417 2P-417 VO 319.5 325.0 642.1 5.7 636.4 Pass: Major Risk 2P Pad 419 2P-419 V5 339.5 350.0 598.6 5.8 592.8 Pass: Major Risk 2P Pad 420 2P-420 VO 319.9 325.0 580.8 5.3 575.5 Pass: Major Risk 2P Pad 422 2P-422 V7 320.2 325.0 539.8 5.3 534.5 Pass: Major Risk 2P Pad 422 422A VO 320.2 325.0 539.8 5.3 534.5 Pass: Major Risk 2P Pad 424 2P-424 V5 341.0 350.0 500.5 5.8 494.7 Pass: Major Risk 2P Pad 424 2P-424A VO 341.0 350.0 500.5 5.8 494.7 Pass: Major Risk 2P Pad 427 2P-427 VO 321.0 325.0 440.3 5.4 434.9 Pass: Major Risk 2P Pad 429 2P-429 VO 321.3 325.0 401.5 5.6 395.9 Pass: Major Risk 2P Pad 431 2P-431 V1 343.2 350.0 358.8 6.0 352.8 Pass: Major Risk 2P Pad 432 2P-432 V12 343.5 350.0 340.4 6.3 334.1 Pass: Major Risk 2P Pad 434 2P-434 V4 366.3 375.0 299.2 6.3 292.9 Pass: Major Risk 2P Pad 438 2P-438 VO 345.6 350.0 219.9 6.0 213.9 Pass: Major Risk 2P Pad 441 2P-441 VO 346.7 350.0 160.5 6.1 154.4 Pass: Major Risk 2P Pad 443 2P-443 V4 Plan: 2P-443 347.5 350.0 120.6 6.4 114.2 Pass: Major Risk 2P Pad 445 2P-445 Vers#4 VO Plan: 348.3 350.0 80.5 6.4 74.1 Pass: Major Risk 2P Pad 447 2P-447 V6 373.7 375.0 38.7 6.4 32.3 Pass: Major Risk 2P Pad 448 2P-448 V2 374.4 375.0 19.8 6.6 13.2 Pass: Major Risk 2P Pad 448 2P-448A VO 374.4 375.0 19.8 6.6 13.2 Pass: Major Risk 2P Pad 448 2P-448PB 1 VO 374.4 375.0 19.8 6.6 13.2 Pass: Major Risk 2P Pad 451 2P-451 VO 1085.9 1075.0 50.3 26.7 23.6 Pass: Major Risk Meltwater North#1 MWN#1 MWN#1 VO 9937.0 4475.0 3934.8 268.7 3666.1 Pass: Major Risk Meltwater South #1 MWS#1 MWS#1 VO Out of range MWN#2 MWN#2 MWN#2 VO 300.0 300.0 4309.6 4.8 4304.8 Pass: Major Risk MWN#2 MWN#2 MWN#2A VO 300.0 300.0 4309.6 4.8 4304.8 Pass: Major Risk ORIGINAL e e MEL TW A TER - DRILLING HAZARDS SUMMARY 12 %" Open Hole & 9 5/8" Surface Casine Interval Event Broach of conductor Gas Hydrates Running sands & gravel Drill surface hole into shallow pressured interval- C-80 charged Hole swabbingfTight hole on trips Stuck surface casing Stuck pipe Lost circulation Risk Level Low Low Moderate Low Moderate Low Low Low / Mitigation Strategy I Contingency Monitor cellar continuously during interval If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Lecithin Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Do not exceed the surface hole TD as detailed in the individual well plans, ensure that all stands (in the derrick or in the hole) are accounted for at all times . Circulate hole clean prior to trip, proper hole filling (use of trip sheets), pumping out of hole as needed Clean the hole before running casing, pump high density high viscosity sweeps, wiper trip Keep hole clean, use high density high viscosity sweeps, keep pipe moving/rotating with pumps on whenever possible Keep hole clean. If losses occur - reduce pump rates and mud rheology, use LCM 8 Vi' Open Hole & 5 Iii' x 3 Iii' Production Casine Interval Event Drill through a shallow pressured interval: C-80 to C-37 Insufficient or undetermined LOT High ECD / Tight hole on trips/ Swabbing Differential sticking Barite sag Lost circulation Risk Level Moderate Moderate Moderate Moderate Low High Mitigation Strategy I Contingency Carry out well control drills. Kill fluid stored on location, contingency 7" casing string on location, heightened awareness Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 18 ppg MW equivalent Condition mud & clean hole prior to trips. Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever possible Good drilling practices as documented in well plan Pretreat mud before drilling reservoir section, keep hole clean - use PWD to monitor hole cleaning. If losses occur - reduce pump rates and mud rheology, use LCM ý ORIGINAL Meltwater Drilling Hazards Summary Prepared by Philip Hayden 1/31/2004 Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 1/30/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < Toe at Surface Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 108 ft. MD < Base of Permafrost at 1,406 ft. MD (1,352 ft. TVD) < Top of Tail at 1,616 ft. MD < 95/8",40.0#, L-80 grade BTC, AB Modified in 12 1/4" OH TD at 3,031 ft. MD (2,346 ft. TVD) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 225% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 210' below base of permafrost.) Lead Slurry (minimum pump time 200 min,) ArcticSet III Lite @ 10.7 ppg, - 4.43 ft3/sk 0.7632 ft3/ft x (108') x 1.00 (no excess) = 0.3132 ft31ft x (1406' - 108') x 3.25 (225% excess) = 0.3132 ft31ft x (1616' -1406') x 1.45 (45% excess) = 82.4 ft? + 1321.2 ft3+ 95.4 ft3 = 1499 ft3/ 4.43 ft3/sk = Round up to 339 sks 82.4ft3 1321.2 ft3 95.4 ft3 1499 ft3 338.4 sks Have 230 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 162 min.) LiteCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3132 ft3/ft x (3031' -1616') x 1.45 (45% excess) = 0.4257 ft31ft x 80' (Shoe Joint) = 642.6 ft3 + 34.1 ftj = 676.7 ft3/ 2.47 ft3/sk = Round up to 274 sks 642.6 ft3 34.1 ft3 676.7 ft3 274 sks SHST = 5rF, Estimated SHCT = 74°F. (SHST calculated using a gradient of 2 SF/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 40 8.0 8.0 Drop Bottom Plug 4.0 12.0 MudPUSH II 7 40 5.7 17.7 Lead Slurry 7 267 38.1 55.8 Tail Slurry 5 121 24.2 80.0 Drop Top Plug 3.0 83.0 Displacement 7 204 29.1 112.1 Bump Plug 3 20 6.7 118.8 MUD REMOVAL Recommended Mud Properties: 9.6 ppg and as thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-20, Ty ? 20-25 Centralizers: Recommend 2 per joint on shoe track & 1 per joint for lower 70CY MD. ORIGINAL Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: ConocoPhillips Alaska, Inc. Revision Date: 1/30/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 ernail: martin13@slb.com Previous Csg. < 9 S/8", 40.0#, L-80 grade BTC, AB Modified at 3,031 ft. MD Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing Cairn formation. Tail Slurry (minimum thickening time 149 min.) GasBLOK w/ Class G + 053, D600G, 0047, 0065 and B155 retarder as per lab testing @ 15.8 ppg, 1.17 ft3/sk 0.2291 ft3/ft x 300' x 1.75 (75% excess) = 0.3272 ft3/ft x (9940' - 8337') x 1.75 (75% excess) = 0.0488 ft3/ft x 60' (Shoe Joint) = 120.3 ft3 + 917.9 ft3 + 2.9 ft3 = 1041 .1 ft3/ 1.17 ft3/sk = Round up to 890 sks 120.3 ft3 917.9 ft3 2.9 ft3 1041.1 ft3 889.8 sks BHST = 139°F, Estimated BHCT = 119°F. (BHST calculated using a gradient of 2 SF/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative < S 112", 1S.S#, L-80 grade Stage (bpm) Volume (min) Time BTC, AB Modified (bbl) (min) in 8 1/2" OH CW100 5 40 8.0 8.0 Drop Bottom Plug 3.0 11.0 MudPUSH II 6 40 6.7 17.7 Tail Slurry 7 185 26.4 44.1 Drop Top Plug 3.0 47.1 Displacement 8 197 24.6 71.7 < Top ofT ail at Bump Plug 3 15 5.0 76.7 8,037 ft. MD < X-over at 8,337 ft. MD < Top of Caim Fm. at 8,S37 ft. MD < 3 1/2", 9.3#, L-80 grade EUE, 8rd Modified in 8 1/2" OH TD at 9,940 ft. MD (S,621 ft. TVD) Mark of Schlumberger MUD REMOVAL Recommended Mud Properties: 10.2 ppg and as thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv ? 19-22, Ty ? 22-29 Centralizers: Recommend 1-W per joint 300 feet above the top of the 51;2" and 31;2" casing ORIG1No4L Meltwater 2P-449 P"ucer Proposed Completion Schematic 3-1/2" Completion String 30" x 16" 62.6# @ +1- 108' MD (Insulated) Depths are based on Doyon 141 RKB Surface csg. 9 5/8" 40.0# L-80 BTC +1- 3031' MD 12346' TVD r I I ~ I ~ I I ~ II I ~ II I I ~ I I I I 2 I I J' 5 %" 15.5# L-80 BTCM x 3 W 9.3# L-80 EUE8RD Mod crossover at +1- 8337' MD I 4867' TVD Future Perforations Production csg 5 W 15.5# L-80 BTCM x 3 W' 9.3# L-80 EUE8RD Mod +1- 9940' MD I 5621' TVD I --- I ~ I ~ I ~ I ~ I ~ I~I I I a I ~ I ~ I ~ I ~ ~ ~ " ~ I I ~ ~ III ~ ~ " I ~ I ~ I ~ --- ~ I I ~ ~ y , , , , , , , , , , , ..J. I I I 1 1 : 211 ; II I I 1 z I 1 '- I I I I I '- l +- ~ ·m~iflfps r I I I I I I I ~ 3 W' FMC Gen 5 Tubing Hanger, 3 %" L-80 EUE8RD Mod pin down 3 W 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3 W 9.3# L-80 EUE8RD Mod Tubing to Surface 3 %" Cameo 'DS' nipple wi 2.875" No-Go Profile. 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at +1- 500' MD 3 %" 9.3# L-80 EUE8RD Mod tubing to landing nipple 4 x 3 %" x 1" Cameo 'KBG-2-9' mandrels 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 %" x 1" Cameo 'KBG-2-9' mandrel wi shear valve, pinned for 3000 psi shear (casing to tubing differential), 3 W x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 W Baker 'CMU' sliding sleeve wi 2.813" Cameo DS profile, EUE8RD Mod box x pin. 3 %" x 6' L-80 EUE8RD Mod handling pup installed above 3 %" Cameo 'D' nipple wi 2.75" No-Go profile. 3 %" x 12' L-80 EUE8RD Mod spaeaeout pup installed above, 3 %" x 6' handling pup installed below 3 %" Baker 80-40 GBH-22 casing seal assembly wi 15' stroke, 3 %" L-80 EUE8RD Mod box up, 3 %" x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 W BTCM x 3 W EUE8RD Mod SBE set at +1- 200' MD above the top of the Bermuda interval (or 200' MD above the Cairn if present) ORfGI~JAL 01/31/2004 N ~ {) SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ATO 1530 / / . ",-I 700GSTREET DATE h::p,-(.J~ f--(2 2L~:::¡4/311 ANCHORAGE AK 99501 / - 6~~~~ ¿~E .Sf/lft; c f A Lft?tl1- / !4 Œz (' ~ .- (1é. tUt~l~J ~!¿..~-; ~,--'c¡ /I-C'/;0 1042 I $ 100CO _ DOLLARS fÌ1 C" CHASE Chase Manhallan Bank USA, N.A. Valid Up To 5000 Dollars , 2QOWhlte Clay Center Dr., Newark. DE 19711 ..... .' f'- _,_'AA~ ,. /V 1//· 2L, I~'; 1 . .0 D . ~ ~ ': 2 . 8 ~ ? . ''10 ? q 2~~r:¡:~/~dií>Ç1i-¿ d"z-. e e e e TRANSMlT AL LETTER CHECKLIST CIRCLE APPROPRJAT:[;LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME k/2!(f zp t/t/I 2L-/ C¡" - 0 U PTD# r(,()ð~ u \\ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new wenbore segment of existing well Permit No, API No. Productionsbould continue to be reported as a function of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for wen (name on permit). PU,OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates Tbe permit is approved subject to full compliance with 20 AAC 25.055. Approval to periorate and produce is contingent upon issuance of a conservation order approving a spacing exception. {Company Name) assumes the liability of any protest to tbe spacing . exception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from beJow tbe permafrost or from wbere samples are first caugbt and J 0' sampJe intervals through target zones. PTD#: 2040260 Administration D D Appr Date SFD 2/2/2004 Engineering Appr Date TEM 2/3/2004 !Pl. Geology Appr Date SFD 2/2/2004 Geologic Commissioner: IST\S Field & Pool KUPARUK RIVER, MELTWATER OIL - 490140 Well Name: KUPARUK RIV U MELT 2P-449 Program DEV Well bore seg Company CONOCOPHILLlPS ALASKA INC Initial ClassfType DEV / PEND GeoArea 890 Unit On/Off Shore .on Annular Disposal 1 P13rmiUee attache_d_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y13S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Leas13nIJmberappropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_n[qIJe wellnamJ3_a!1d lJl!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . . . _ _ _ _ . . _ _ _ Y13S _ . . _ _ _ _ _ _ _ . _ . _ _ _ . . . . . . . . . . . . . . . . _ . _ . . _ _ _ . _ . _ . . . . . . . . . . . . . . . _ _ . _ . . . . . . _ _ _ _ _ . 4 WellJQcat13d [nadefrneJ:Lpool _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ . 5 WeJIJQcated prßper.d[stancefromdriJling unitb_ound.ary_ _ _ . . . _ Y13S _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 6 WeJIJQcat13d pr_oper _distance. from otber weUs_ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y13S _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 7 _Sutficient .acreage_ayailable [ndJillilJg unjL _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ Yes _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . 8 Jtd13viated, js weJlbore platincJuded _ _ _ . . _ _ _ _ _ .. . _ _ _ _ . . _ _ _ _ _ _ . _ _ _ Y13S _ _ _ _ _ _ _ . _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ _ _ . _ . . _ _ . _ _ _ 9 .Operator 0111)' affected party _ _ _ _ _ _. _ _ _ _ . _ . _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ 10 .Operator bas.appropr[ate.Qond [nJorce . . _ . . . . . . . . . _ _ _ _ . . . . . . _ . . . . . . . . _ _ Y13S. . . . . _ _ _ _ . . _ _ . . . . . . . _ _ . . . . . . . . . . . . . . . _ . . _ _ . . . . . . . .. . . . . . . _ . _ . _ . .. ." _ . . . . _ 11 P13rmit c_ao be [sSl!ed witbout co_nserva.tiOI1 order _ . . . _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ . Y13S _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . _ _ _ . _ . _ _ _ _ _ _ _ _ _ . 12 P13rmit~o be [ssl!ed witbout ad_ministrati",e.approvaJ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Y13S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 13 Can permit be approved before 15-day wait Yes 14 WellJQcated within area and.strata _authorized by_lojectiolJ Ord13r # (pIJtlO# ¡n.çommeots).(For. NA _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 AllweUs_within.1l4.mile.area.ofreyiewid13lJt[fied(ForservjÇßwell only). .. _..... _.. _ _ _ _NA..... _ _ _. _... _........ _. _. _ _.. _........ _ _ _ _........... _ _.. _ _ _ _. _.... _ _ _ _ _ _. 16 Pre-produ_ced injector; duration_of pre-production l13sS than_:3 mOl1tbs (For_service well Qnly) _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ 17 ACMPFïl1ding.of Con_sLstenGy.has bee_nJssued forJbis project _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _NA _ _ W.ßIJ dr[lled from exjsiilJg pa_d, _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ 18 _C_olJductor stril1g_PJov[dJ3d _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _Y13S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ . 19 _Surfac13_casingpJotectsallknownUSDWs _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _Allaquifen¡ex13mpt13d,AO_CFR102(b)(3). . _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _. . _ _ _ _ _. 20 _CMT v_ol adequateJo circ_ulateon _cond_uctol' & SUJtC$g _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ Y13S _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _CMT v_pI adeql!ateJo tie-inJQngstriog to_SIJrf csg_ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ Al1nular disp_osal may be propo_sed. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwill coyeraJl knownprQdlJctiye borizon_s_ _ . . . _ _ _ _ _. . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ Y13S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ 23 _C_asiog desigos ad.equate fßr C,_T" B&_ perroafl'ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ Y13S _ _ _ _ _ _ _ _. _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 24 _A.dequ.ateJankage one.serve pit _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _... . Y13S_.. _ _ _Rigis_e_qIJippe_dw:ith$t13epits._NoJøseJ",e.pjtplanned, Waste.toal1approyedannulus;or.dispos.alwell._ __ 25 Jf.aJe-drilL has_a 10-403 for abandol1ment be13lJ apPJovød _ _ _ _ _ _ _ _ _ _ _ _ . NA _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ 26 Adequate_w:ellboreseparatio.n_propos;ed. _ . . . . . . . . _ _ . . . _ _ _ . . . . . . . . _ . . _ _ . . Y13s. . . . . . .l?rOJJ:imi.t)'an.alysiS perto(l1]e_d, G]o$e approache.sJdentjfiJ3d.. TravelilJgcylinderplotinclude<t . _ . . . . . . . _ . . . 27 Jf.divørter Jeq_uired, does it meet reguJa.tions. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ Y13S _ _ _ _ _ _ _ _ _ _ _ _ _ . .. _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _. _ _ _ _ _ . .. _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ 28 _DJillilJg fJuidprogram schemaUc_& equip Jistadequale_ . _ _ _ . _ _ _ _ _ . . _ _ _ _ . _ _ _ . _ _ _ Y13s. _ _ _ _ _ _ Expected SHF' in.B13(11Juda 5._8:8.4. EMW, Planne.d_MW _9,6. .Risk_of shaUowør higher pres;sureJdentifi.ed. _ _ _ 29 .BOPEs,_dß_they meelreguJa.tion _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ . Y13S . _ _ _ _ Sl!rface shoe integrity [s.gJ3lJeJally grealer thaI115_.Q EMWindjc.atin-9_sia_ndard well control applies.. _ _ . 30 BOPEpress raiilJgappropriate;.testlo_(pu.tpsigLn_comments)_ _ _ _ _ _ _ _ _ _ _ _ _ Y13S _ _ _ _ _ _W\SE'çalculate.dJorBJ3rmu_da.1626.p_si.350Qpsiappropriate._CE'AluSl!aJl)'tJ3ststo5_00QpsL _.. _ _ _ _ _. __ 31 _Choke_manifold compJies w/APl Rp-5:3 (May 84) _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ YJ3S _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ 32 Work willocc_ur withoutoper<ltionshutdow:n. _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ . . _ _ _ YJ3S _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ 33 Js preseoce_Qf H2S gas_probable_ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ . . . _ _ _ _ _ _ No_ _ _ Rig is_equippe_d_w:ith $ensor$_aod alarm$._ . . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 34 Mecha_n[c<lcondjUooßfwellsw[thiI1AORYerified(For_s_ervicewølJoI1ly)_ _ _ _ _ NA _. _ _ _ _ _ _ _. _ _ _ _ _.. _ _ _ _ _ _ _ _ _. _ _. _ _ _ _ _ _ _ _ _ _ _. _ _ _ _. _ _ _ _ _ _ _ _.. __ 35 PJ3rmil ~o be [sSl!ed w!o_ hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ Y13S _ _ _ _ _ . _ _ _ . . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 _D_atapJesented on pote.ntial pveJpres_sIJreZOl1e$ _ _ _ _ _ _ _ _ _ _ _ Y13S _ _ _ E'otentialJor _eoco_uotørjll9_shallow _abnormal p[e$sure ~o_ne;.discus_sed in_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 37SJ3ism[c_analysjs_ ohbaJlow gas_zßoes_ _ _ _ . . _ . _ _ _ _ _ _ . _ _ _ _ _ . . _ _ _ _ . _ _ _NA _ _ _ _ _ _ Drjlling Hazards.loformaiion s;ection_ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ 38 .SJ3abed _conditiPIJ survey (if off-shwe) . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ NA _ _ . _ _ _ _ Expected reservojr pre$Sl!re between_5,8.and 8.4 _ppg EMW; w[ll.be drill.ßd with 9.6 ppg mud. _ _ . _ _ _ _ _ _ _ _ _ _ 39 _ Conta_ct l1amelphOl1eJor.weøkly progres;sreports [exploratpry _onlYl _ _ _ _ _ _ . NA _ _ _ _ _ _ _ _ _ . . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ e e Date: Engineering Commissioner: Date Public Commissioner Date ~j e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) ') REceiVED **** REEL HEADER **** LDWG 04/04/16 l (')fì 2 1 2004 AWS 01 '",¡d~ii¡i .(1,' 'i ')'<l~" , .';r',~\ **** TAPE HEADER **** LDWG 04/04/16 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER MELTWATER UNIT MWD/MAD LOGS #: WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: #: JOB DATA LDWG File Version 1.000 Extract File: LISTAPE.HED 2P-449 501032048600 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 16-APR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 S. TUFTON D. GLADDEN MWD RUN 2 2 G. SUTING D. GLADDEN MWD RUN #: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 17 8N 7E 252.00 224.00 :: WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 12.250 PRODUCTION STRING 8.500 16.000 9.625 108.0 3007.0 9946.0 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE cJ& C¡~t/ G ç /ZÇ,s RECEIVED A.PR 2 1 2004 AlaslœOilaGaaCons.Can.... Arcal~ . 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: N 70 DEG 03' 8.428" LONG: W150 DEG 27' 7.031" LOG MEASURED FROM D.F. AT 252.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a Multiple Propagation Resistivity (MPR) and Gamma Ray with Near Bit Inclination services from 108 - 3013 feet MD (108 - 2339 TVD). (2) Baker Hughes INTEQ run 2 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD) , Caliper Corrected Neutron (CCN), along with Drill Collar Pressure (DCP) and MPR Resistivity services from 3013 - 9946 feet MD (2339 - 5659 TVD) . (3) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) Depth of 9 5/8" Casing Shoe - Logger: 3011 feet MD (2338 TVD) Depth of 9 5/8" Casing Shoe - Driller: 3007 feet MD (2336 TVD) (2) The interval from 2959 to 3013 feet MD (2314 - 2339 TVD) was not logged due to the presence of the 9 5/8" casing. (3) The interval from 9905 to 9946 feet MD (5638 - 5659 TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 77 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 108.0 STOP DEPTH 9946.0 # ') ) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 108.0 2959.0 MERGE BASE 2959.0 9946.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN 2p-449 5.xtf LCC 150- CN ConocoPhillips Alaska WN 2P-449 FN Meltwater Unit COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F MSB 18655 8.25 MPR MEMORY 13-FEB-04 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : STOP DEPTH 2959.0 START DEPTH 90.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 1 .2500 2 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOll.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 1084 records... Tape Subfile: 2 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 108.000000 9946.000000 0.500000 1036 Total Data Records: 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 ) ) 3013.0 90.0 2959.0 o TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # .0 62.8 BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # TOOL NUMBER DHA 8021 MPR 8017 SRIG 5269 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: # # 12.250 108.0 Spud 9.50 .0 .0 200 .0 .000 .000 .000 .000 86.0 .0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # .00 .000 .0 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): o REMARKS: # BIT RUN 1 (MWD Run 1). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN 2p-449.xtf LCC 150 CN ConocoPhillips Alaska WN 2P-449 FN Meltwater Unit COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 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: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 605 Tape File Start Depth 90.000000 ) ) Tape File End Depth Tape File Level Spacing Tape File Depth Units 2959.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 3 704 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 2959.0 STOP DEPTH 9946.0 # 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: 19-FEB-04 MSB 18655 6.75 TC MEMORY 9946.0 2959.0 9946.0 o 58.4 63.1 #= TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RES IS. GAMMA RAY TOOL NUMBER DHA 90427 CCN 29572 ORD 28636 MPR 67280 SRIG 5078 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3007.0 # BOREHOLE CONDITIONS MUD TYPE: LSND 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: # 10.50 .0 .0 200 .0 .000 .000 .000 .000 139.0 .0 .0 .0 Sandstone .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/MPR/ORD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN 2p-449.xtf LCC 150 CN ConocoPhillips Alaska WN 2P-449 FN Meltwater Unit COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL GRAM RPCL RPSL GRAM RPD RPM 0.0 0.0 0.0 ) ) RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD ( TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 Total Data Records: 1997 Tape File Start Depth 2959.000000 Tape File End Depth 9946.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet **** FILE TRAILER **** Tape Subfile: 4 2107 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** LDWG 04/04/16 01 **** REEL TRAILER **** LDWG 04/04/16 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: 8 bytes 4124 bytes 2 records... 132 bytes 132 bytes