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201-182
ORIGINATED TRANSMITTAL DATE: 6/26/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4738 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Meltwater PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4738 2P-420 501032039100 Tubing Punch 23-Mar-2024 RECIPIENTS Conoco Phillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 201-182 T39055 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 15:15:19 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com 0 201-182 T38909 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 14:47:30 -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" H-40 108' 7-5/8" L-80 2351' 5-1/2" L-80 5428' 3-1/2" L-80 5857' 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 9.875" 9 cu yds High Early surface 260 sx AS III Lite/ 140 sx Lite C included above6.75" TUBING RECORD 255 sx Class G6.75" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 5/26/2024 201-182/ 324-162/ 324-223 50-103-20391-00-00 KRU 2P-420 ADL0373112 892' FNL, 2128' FWL, Sec. 17, T8N, R7E, UM 1465' FNL, 763' FEL, Sec. 17, T8N, R7E, UM 10/15/2001 6860' MD/ 5863' TVD Surface/ Surface P.O. Box 100360, Anchorage, AK 99510-0360 444088 5868984 1335' FNL, 1212' FEL, Sec. 17, T8N, R7E, UM 10/28/2001 9. Ref Elevations: KB: 25.5' 5868527 1454' MD/ 1454' TVD SETTING DEPTH TVD 5868393 TOP HOLE SIZE AMOUNT PULLED 446027 446475 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Abandoned N/A 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, CASING WT. PER FT.GRADE CEMENTING RECORD 9.3# surface 6156' 2351'surface surface 15.5# Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 6156' 6850' surface 5428' 62.5# 29.7# 108' surface 2141-2413' 4207-5953' Plugged and Abandoned 6156' MD/ 5428' TVD (Seal Assy) If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6157'3-1/2" SIZE DEPTH SET (MD) 41'-2135' 93.6 bbl 15.7 ppg Cement Cemented Perfs: 6272-6320' MD and 5502-5533' TVD 6324-6352' MD and5535-5553' TVD 6361-6374' MD and 5559-5567' TVD 6386-6422' MD and 5575-5598' TVD PACKER SET (MD/TVD) 42" Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 23.2 bbl 16.5 ppg Cement 31 bbl 15.8 ppg Cement By Grace Christianson at 1:33 pm, Jun 11, 2024 Abandoned 5/26/2024 JSB RBDMS JSB 061824 xGDSR-7/9/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1454' 1454' Top of Productive Interval 6266' 5498' 6271' 5501' 6562' 5685'N/A 6563' 5685' 31. List of Attachments: Schematics, Summary of Operations, Photos 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Sydney Long Digital Signature with Date:Contact Email: sydney.long@conocophillips.com Contact Phone:(907) 265-6312 Senior RWO/CTD Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Bottom Meltwater If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Abandoned 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. Authorized Title: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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). T3 Formation Name at TD: Top MeltWater 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. N/A - Abandoned Authorized Name and T2 Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Tagged TOC) 4,207.0 2P-420 3/30/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: 5/25/24 Well marker plate information verified by AOGCC Bob Noble. 4' 1" below OG 2P-420 5/27/2024 mouser Notes: General & Safety Annotation End Date Last Mod By NOTE: 5/25/24 Well marker plate information verified by AOGCC Bob Noble. 4' 1" below OG (TUNDRA) 5/27/2024 mouser NOTE:************ WELL REQUIRES 2.88" NOGO RING ON LOCK*********** 3/31/2019 aappleh NOTE: MILL OBSTRUCTION @ 6291' -6344' w/3.6" JUNK MILL, 50+% OF PERFS STILL COVERED 8/13/2005 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.1 108.0 108.0 62.50 H-40 WELD SURFACE 7 5/8 6.87 41.1 2,351.4 2,351.3 29.70 L-80 BTCM PROD 5 1/2 4.95 41.1 2,135.0 2,134.9 15.50 L-80 BTCM PROD 5.5"x3.5" @ 6177' 5 1/2 4.95 2,413.4 6,850.8 5,857.9 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 2,645.0 Set Depth … 6,156.8 Set Depth … 5,428.4 String Max No… 3 1/2 Tubing Description Tubing - Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,045.1 5,357.1 49.90 GAS LIFT 4.688 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,094.6 5,388.8 50.34 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813 6,110.6 5,399.0 50.49 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,155.0 5,427.2 50.47 LOCATOR 4.500 BAKER LOCATOR BAKER 2.980 6,155.8 5,427.8 50.47 SEAL 4.000 BAKER GBH-22 SEAL ASSY BAKER GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 41.0 41.0 0.00 MARKER PLATE 30" Marker plate 1/4" thick 5/25/2024 0.000 2,440.0 2,439.9 0.44 CIBP Bridge plug set for P&A ALPHA CIBP 4/15/2024 0.000 5,950.0 5,295.3 49.09 TUBING PUNCH 3' TUBING PUNCH, 1.56", 3 GRAM, 6 SPF, 18 0.43" HOLES 3/25/2024 2.992 6,053.0 5,362.2 49.97 TUBING PUNCH 3' TUBING PUNCH, 1.56", 3 GRAM, 6 SPF, 18 0.43" HOLES OWEN 3/24/2024 2.992 6,060.0 5,366.7 50.03 TUBING PUNCH 3' TUBING PUNCH, 1.56", 3 GRAM, 6 SPF, 18 0.43" HOLES OWEN 3/23/2024 2.992 6,250.0 5,487.9 50.22 PLUG Set 2.63" TTS CIBP 10/5/2023 0.000 6,720.0 5,780.4 53.27 PLUG CEMENT PLUG 11/2/2001 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 41.1 41.1 0.00 PRODUCTION 5.500 4.950 2,413.4 2,413.2 0.44 PRODUCTION 5.500 4.950 6,156.8 5,428.4 50.46 LOCATOR 6.000 4.950 6,157.9 5,429.1 50.46 CSR 5.500 4.000 6,177.4 5,441.5 50.42 XO reducing 5.500 XO reducing 5.5x3.5 (9.3#,l- 80,EUE,2.992) 3.500 6,187.9 5,448.2 50.40 PRODUCTION 3.500 2.992 6,224.3 5,471.4 50.31 PROD w/Landing pte 3.500 2.992 6,723.8 5,782.7 53.29 PRODUCTION 3.500 2.992 6,756.4 5,802.1 53.50 PRODUCTION 3.500 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,272.0 6,320.0 5,501.9 5,532.8 T-3, 2P-420 12/23/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,324.0 6,352.0 5,535.3 5,553.2 T-3, 2P-420 12/23/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,361.0 6,374.0 5,559.0 5,567.2 T-3, 2P-420 12/22/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,386.0 6,422.0 5,574.8 5,597.6 T-3, 2P-420 12/22/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 2P-420, 6/10/2024 1:29:12 PM Vertical schematic (actual) PROD 5.5"x3.5" @ 6177'; 2,413.4-6,850.8 PLUG; 6,720.0 IPERF; 6,386.0-6,422.0 IPERF; 6,361.0-6,374.0 IPERF; 6,324.0-6,352.0 IPERF; 6,272.0-6,320.0 PLUG; 6,250.0 Cement Plug; 6,155.0 ftKB TUBING PUNCH; 6,060.0 TUBING PUNCH; 6,053.0 GAS LIFT; 6,045.1 TUBING PUNCH; 5,950.0 Cement Plug; 4,207.0 ftKB Cement Plug; 4,207.0 ftKB CIBP; 2,440.0 SURFACE; 41.1-2,351.4 Cement Plug; 2,141.0 ftKB PROD; 41.0-2,135.0 Cement Casing; 41.1 ftKB CONDUCTOR; 41.1-108.0 MARKER PLATE; 41.0 Plug – Plug Back / Abandonment Plug; 41.1 ftKB Casing 1; 0.0 KUP INJ KB-Grd (ft) 37.30 RR Date 11/2/2001 Other Elev… 2P-420 ... TD Act Btm (ftKB) 6,860.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039100 Wellbore Status INJ Max Angle & MD Incl (°) 54.00 MD (ftKB) 6,860.01 WELLNAME WELLBORE2P-420 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 41.1 2,351.0 41.1 2,350.9 Cement Casing Pipe movement: ReciprocatingDrag down (lbs): 65Drag up (lbs): 106Time started reciprocating: 14:26Time stopped reciprocating: 16:25Cement Found Between Shoe and Collar (Y/N): YCement found on liner tool (Y/N): NAnnular flow after cement job (Y/N): NCirculating BHT (F): 70Static BHT (F): 68Pressure before cementing (psi): 400Hours circulated between stages: 3Method used to measure density: ScaleReturns (pct): FullTime cementing mixing started: 14:48 10/19/2001 6,155.0 6,250.0 5,427.2 5,487.9 Cement Plug Dump bailed cement with Slickline on top of CIBP 10/7/2023 4,207.0 5,953.0 4,110.9 5,297.3 Cement Plug 4,207.0 5,953.0 4,110.9 5,297.3 Cement Plug 3/27/2024 2,141.0 2,413.0 2,140.9 2,412.9 Cement Plug 4/18/2024 41.1 2,135.0 41.1 2,134.9 Plug – Plug Back / Abandonment Plug 4/20/2024 2P-420, 6/10/2024 1:29:13 PM Vertical schematic (actual) PROD 5.5"x3.5" @ 6177'; 2,413.4-6,850.8 PLUG; 6,720.0 IPERF; 6,386.0-6,422.0 IPERF; 6,361.0-6,374.0 IPERF; 6,324.0-6,352.0 IPERF; 6,272.0-6,320.0 PLUG; 6,250.0 Cement Plug; 6,155.0 ftKB TUBING PUNCH; 6,060.0 TUBING PUNCH; 6,053.0 GAS LIFT; 6,045.1 TUBING PUNCH; 5,950.0 Cement Plug; 4,207.0 ftKB Cement Plug; 4,207.0 ftKB CIBP; 2,440.0 SURFACE; 41.1-2,351.4 Cement Plug; 2,141.0 ftKB PROD; 41.0-2,135.0 Cement Casing; 41.1 ftKB CONDUCTOR; 41.1-108.0 MARKER PLATE; 41.0 Plug – Plug Back / Abandonment Plug; 41.1 ftKB Casing 1; 0.0 KUP INJ 2P-420 ... WELLNAME WELLBORE2P-420 Page 1/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/1/2024 06:00 4/1/2024 12:00 6.00 MIRU, MOVE MOB P Change out saver sub, R/D ST80, clear rig floor subs and equipment. 0.0 0.0 4/1/2024 12:00 4/1/2024 18:00 6.00 MIRU, MOVE MOB P Prep and lower cattle shute, raise cellar, Prep derrick to scope down. Change out valves and seats on mud pumps. 0.0 0.0 4/1/2024 18:00 4/2/2024 00:00 6.00 MIRU, MOVE MOB P Critical crane lifts, remove ST80, BOP's and MPD equipment. Clean BOP deck and bridle up and scope down derrick. 0.0 0.0 4/2/2024 00:00 4/2/2024 06:00 6.00 MIRU, MOVE RURD P Shovel snow out from stompers and load casing shed with spear parts for MOB. 0.0 0.0 4/2/2024 06:00 4/2/2024 12:00 6.00 MIRU, MOVE RURD P Critical lift with crane. Set BOP in transport cradle and secure. Install grabber on Top drive. Spool off drill line and secure energy track. 0.0 0.0 4/2/2024 12:00 4/2/2024 18:00 6.00 MIRU, MOVE RURD P Lower weight bucket to rig floor. Prep derrick to lay over. Shovel snow away from modules and prep for move. Purge air from moving systems. 0.0 0.0 4/2/2024 18:00 4/3/2024 00:00 6.00 MIRU, MOVE RURD P Shovel snow away from modules and prep for move. Change out butterfly valves in pits. Rig equipment inventory. 0.0 0.0 4/3/2024 00:00 4/3/2024 06:00 6.00 MIRU, MOVE RURD P Shovel snow away from modules and prep for move. Change out demco valve in pump room. 0.0 0.0 4/3/2024 06:00 4/3/2024 12:00 6.00 MIRU, MOVE RURD P Inspect valves in pits and conduct MP2's on mud pumps. Swap to rig enerators at 08:00hrs 4-3- 24. 0.0 0.0 4/3/2024 12:00 4/3/2024 15:00 3.00 MIRU, MOVE MOB P Pull ball mill away from pump module. Reposition casing module away from pipe module. 0.0 0.0 4/3/2024 15:00 4/3/2024 18:00 3.00 MIRU, MOVE RURD P Continue to remove snow and ice from stomper paths in wheel wells. Clean and organize rig floor. Drop cattle shute into pipe shed. Remove interconnections. 0.0 0.0 4/3/2024 18:00 4/3/2024 22:00 4.00 MIRU, MOVE RURD P Continue with interconnections and prepping modules for move. Blow down steam and raise C section. 0.0 0.0 4/3/2024 22:00 4/4/2024 00:00 2.00 MIRU, MOVE RURD P Prep, skid rig floor and lay over derrick. 0.0 0.0 4/4/2024 00:00 4/4/2024 06:00 6.00 MIRU, MOVE RURD P Unpin and Stomp pipe shed from sub. Stomp sub off well center. Off well center at 03:00hrs. Continue Prep for MOB. 0.0 0.0 4/4/2024 06:00 4/4/2024 12:00 6.00 MIRU, MOVE RURD P R/D and prep for rig MOB to 2P location. Waiting on ICE road. 0.0 0.0 4/4/2024 12:00 4/4/2024 18:00 6.00 MIRU, MOVE RURD P R/D and prep for rig MOB to 2P location. Waiting on ICE road. 0.0 0.0 4/4/2024 18:00 4/5/2024 00:00 6.00 MIRU, MOVE RURD P R/D and prep for rig MOB to 2P location. Waiting on ICE road. 0.0 0.0 4/5/2024 00:00 4/5/2024 06:00 6.00 MIRU, MOVE RURD P R/D and prep for rig MOB to 2P location. Waiting on ICE road. 0.0 0.0 4/5/2024 06:00 4/5/2024 07:30 1.50 MIRU, MOVE MOB P Stomp pipe shed out from SUB and stage in direction for MOB. 0.0 0.0 4/5/2024 07:30 4/5/2024 12:00 4.50 MIRU, MOVE MOB P Stomp and make 50' turn on SUB and stage in direction of MOB. 0.0 0.0 4/5/2024 12:00 4/5/2024 18:00 6.00 MIRU, MOVE MOB P Changing out Hillman roller on pit module. 0.0 0.0 4/5/2024 18:00 4/6/2024 00:00 6.00 MIRU, MOVE MOB P Continue changing out Hillman roller on pit module. Place pits and motor modules on suspension. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 2/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/6/2024 00:00 4/6/2024 06:00 6.00 MIRU, MOVE RURD P R/D and prep for rig MOB to 2P location. Waiting on ICE road. 0.0 0.0 4/6/2024 06:00 4/6/2024 13:00 7.00 MIRU, MOVE RURD P Continue prep modules for arrival of haul trucks. 0.0 0.0 4/6/2024 13:00 4/6/2024 18:30 5.50 MIRU, MOVE RURD P Truck and equipment arrived at 13:00hrs. Mate up trucks to modules, prep for MOB. 0.0 0.0 4/6/2024 18:30 4/7/2024 00:00 5.50 MIRU, MOVE MOB P PJSM, Start MOB from MT7 pad to A21 Pad. Off MT7 pad at 19:00hrs with 6 package convoy, Casing shed, SUB, pipe module, pit module, pump module and motor module. ETA: 02:00hrs 4-7- 24. 0.0 0.0 4/7/2024 00:00 4/7/2024 02:30 2.50 MIRU, MOVE MOB P Rig modules are at A21 pad, Crew change and waiting on fuelers. 0.0 0.0 4/7/2024 02:30 4/7/2024 14:00 11.50 MIRU, MOVE MOB P Subbase and Casing shed are traveling Heavy Haul ice road at mile 10.2 Casing shed is currently detained at Mile 10.2 from Alpine Checkpoint. 14:00 – 18:30: Crews are working to matting up casing shed to recover integrity of Ice road. 0.0 0.0 4/7/2024 14:00 4/7/2024 18:30 4.50 MIRU, MOVE MOB P Crews are working to matting up casing shed to recover integrity of Ice road. Move casing module out of punch through, Ice road crews repair road and lay mats. 0.0 0.0 4/7/2024 18:30 4/7/2024 19:00 0.50 MIRU, MOVE MOB P Continue with casing module to 6 mile cut off area. 0.0 0.0 4/7/2024 19:00 4/8/2024 00:00 5.00 MIRU, MOVE MOB P Ice road crews repairing ice road. 0.0 0.0 4/8/2024 00:00 4/8/2024 01:30 1.50 MIRU, MOVE MOB P Continue work to stabilize the road, Ice road crews repairing ice road. 0.0 0.0 4/8/2024 01:30 4/8/2024 02:30 1.00 MIRU, MOVE MOB P Transport rig mats from 2P pad and lay mats on ice road 0.0 0.0 4/8/2024 02:30 4/8/2024 04:00 1.50 MIRU, MOVE MOB P MOB Sub-base to mile marker, join with casing module 0.0 0.0 4/8/2024 04:00 4/8/2024 04:30 0.50 MIRU, MOVE MOB P Fuel up rig modules, let traffic clear per Security 0.0 0.0 4/8/2024 04:30 4/8/2024 11:00 6.50 MIRU, MOVE MOB P MOB casing and sub-base to 2N pad 0.0 0.0 4/8/2024 11:00 4/8/2024 12:00 1.00 MIRU, MOVE MOB P NES truck return to K-Pad alpine 0.0 0.0 4/8/2024 12:00 4/8/2024 13:30 1.50 MIRU, MOVE MOB P NES prep pits and Pipe shed modules 0.0 0.0 4/8/2024 13:30 4/8/2024 14:00 0.50 MIRU, MOVE MOB P Wait on security to close Ice Road and prep to move 0.0 0.0 4/8/2024 14:00 4/8/2024 19:00 5.00 MIRU, MOVE MOB P Move pits and pipe shed to CRIB, then to Colville mine site area 0.0 0.0 4/8/2024 19:00 4/8/2024 20:00 1.00 MIRU, MOVE MOB P Mechanic working on NES overheated Truck 0.0 0.0 4/8/2024 20:00 4/8/2024 22:00 2.00 MIRU, MOVE MOB P Move Pipe Shed and Pit Module from Colville Mine Site to 6 Mile 0.0 0.0 4/8/2024 22:00 4/8/2024 23:00 1.00 MIRU, MOVE MOB P Refuel NES Trucks 0.0 0.0 4/8/2024 23:00 4/9/2024 00:00 1.00 MIRU, MOVE MOB P Depart with Pipe Shed and Pit Module from 6 Mile to L Pad Gaurd Shack. 0.0 0.0 4/9/2024 00:00 4/9/2024 00:30 0.50 MIRU, MOVE MOB P Continue to move pipe shed, and pit module from 6 mile Pad guard shack. 0.0 0.0 4/9/2024 00:30 4/9/2024 01:30 1.00 MIRU, MOVE MOB P Stage at L pad guard shack and wait for Pad operator shift change. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 3/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/9/2024 01:30 4/9/2024 02:30 1.00 MIRU, MOVE MOB P Move from L Pad guard shack to 2N pad. Stage pit and pipeshed complexes at 2N. Unhook NES trucks, and equipment form modules. 0.0 0.0 4/9/2024 02:30 4/9/2024 04:00 1.50 MIRU, MOVE MOB P NES trucks go from 2N to A21 Pad. 0.0 0.0 4/9/2024 04:00 4/9/2024 13:30 9.50 MIRU, MOVE MOB P Mobilize module from A21 to 2L guard shack. 0.0 0.0 4/9/2024 13:30 4/9/2024 17:00 3.50 MIRU, MOVE MOB P Begin to move modules from 2L to 2P. At mile marker 16 enroute to 2P pump module had a flat tire. 0.0 0.0 4/9/2024 17:00 4/9/2024 21:45 4.75 MIRU, MOVE MOB T Wait on tire crew to arrive to change flat tire on the pump module. 0.0 0.0 4/9/2024 21:45 4/9/2024 23:00 1.25 MIRU, MOVE MOB T Change tire on Pump module. 0.0 0.0 4/9/2024 23:00 4/10/2024 00:00 1.00 MIRU, MOVE MOB P Resume rig move to 2P 0.0 0.0 4/10/2024 00:00 4/10/2024 01:00 1.00 MIRU, MOVE MOB P Continue moving pump module and motor module to 2P. 0.0 0.0 4/10/2024 01:00 4/10/2024 01:30 0.50 MIRU, MOVE MOB P Rig down NES trucks from pump, and motor modules. Refuel trucks. 0.0 0.0 4/10/2024 01:30 4/10/2024 04:30 3.00 MIRU, MOVE MOB P Mobilize trucks and other rig move equipment from 2P to MT7 0.0 0.0 4/10/2024 04:30 4/10/2024 07:30 3.00 MIRU, MOVE MOB P Rig up trucks to ball mill, and shop. Prep to move both to 2P 0.0 0.0 4/10/2024 07:30 4/10/2024 20:00 12.50 MIRU, MOVE MOB P Move ball mill and shop from MT7 to 2L Kuparuk check point. 0.0 0.0 4/10/2024 20:00 4/10/2024 21:15 1.25 MIRU, MOVE MOB P Refuel rig move equipment. Inspect tires, and moving system. Allow traffic to pass. 0.0 0.0 4/10/2024 21:15 4/11/2024 00:00 2.75 MIRU, MOVE MOB P Continue to move from 2L check point down the spine road to 2P. 0.0 0.0 4/11/2024 00:00 4/11/2024 01:00 1.00 MIRU, MOVE MOB P Continue to move Ball Mill and Rig shop to 2P. Spot rig shop and stage Ball Mill. 0.0 0.0 4/11/2024 01:00 4/11/2024 01:30 0.50 MIRU, MOVE MOB P Mobilize trucks and equipment from 2P to 2N. 0.0 0.0 4/11/2024 01:30 4/11/2024 03:00 1.50 MIRU, MOVE MOB P Rig up on Pipe Module and reposition for clearance around Sub. Continue rigging up trucks on Sub Base, and Pit Module. 0.0 0.0 4/11/2024 03:00 4/11/2024 07:00 4.00 MIRU, MOVE MOB P Move Sub Base and Pit Module from 2N to 2P Pad. 0.0 0.0 4/11/2024 07:00 4/11/2024 08:00 1.00 MIRU, MOVE MOB P Remove Jeep off of Pit module. Pull Jeep on mats and unhook from NES truck. 0.0 0.0 4/11/2024 08:00 4/11/2024 09:30 1.50 MIRU, MOVE MOB P Pull Sub on Mats, and line up to back over well. 0.0 0.0 4/11/2024 09:30 4/11/2024 10:00 0.50 MIRU, MOVE MOB P Remove Jeep from Sub base. 0.0 0.0 4/11/2024 10:00 4/11/2024 11:00 1.00 MIRU, MOVE MOB P Turn Sub base and align and crab over the well. 0.0 0.0 4/11/2024 11:00 4/11/2024 13:00 2.00 MIRU, MOVE MOB P Level and shim sub base. 0.0 0.0 4/11/2024 13:00 4/11/2024 17:00 4.00 MIRU, MOVE MOB P Pull pipe shed onto mats. Unhook truck, align and stomp pipe shed towards sub. Shim up sub for stomping in the pipe shed in to sub. 0.0 0.0 4/11/2024 17:00 4/11/2024 20:00 3.00 MIRU, MOVE MOB P Stomp pipe shed into sub base, and pin in place. 0.0 0.0 4/11/2024 20:00 4/11/2024 22:00 2.00 MIRU, MOVE MOB P Raise derrick, and Skid rig floor. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 4/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/11/2024 22:00 4/12/2024 00:00 2.00 MIRU, MOVE MOB P Stomp in pumps. Hook up interconnects. But pits butt up pumps to pits. 0.0 0.0 4/12/2024 00:00 4/12/2024 02:00 2.00 MIRU, MOVE MOB P Stomp motor module, Install interconnections to Pump module. 0.0 0.0 4/12/2024 02:00 4/12/2024 03:30 1.50 MIRU, MOVE RURD P Continue hook up interconnections from motor to pump modules. Hook up interconnections to pits, Energize air to rig floor.Swap from moving gens to rig generators. SIMOPS: Lay Hurculite and mats for DC1 camp SIMOPS: MOB DC1 camp to 2P pad, Arrived at 06:00hrs. SIMOPS: MOB crane to 2P pad. Arrived at 03:00hrs. 0.0 0.0 4/12/2024 03:30 4/12/2024 05:00 1.50 MIRU, MOVE RURD P Lower cellar and Prep to install BOP's. 0.0 0.0 4/12/2024 05:00 4/12/2024 06:30 1.50 MIRU, MOVE RURD P PJSM, Critical lift, Pick BOP's and install in BOP cradle. 0.0 0.0 4/12/2024 06:30 4/12/2024 08:00 1.50 MIRU, MOVE RURD P Lower C section, Spool on drill line. Remove top drive pins and install scoping lines. 0.0 0.0 4/12/2024 08:00 4/12/2024 09:00 1.00 MIRU, MOVE RURD P Scope up derrick and secure, R/D scoping equipment. 0.0 0.0 4/12/2024 09:00 4/12/2024 10:00 1.00 MIRU, MOVE RURD P Install ST-80 on rig floor with crane. 0.0 0.0 4/12/2024 10:00 4/12/2024 11:00 1.00 MIRU, MOVE RURD P Raise cattle shute, energize steam to pits and BOP deck. 0.0 0.0 4/12/2024 11:00 4/12/2024 12:00 1.00 MIRU, MOVE RURD P Lower derrick ladder and install C- Section cushions. Install kelly hose. 0.0 0.0 4/12/2024 12:00 4/12/2024 18:00 6.00 MIRU, MOVE RURD P Continue M/U kelly hose, Prep pits to take on fluid, Lay mats and stomp casing module, Spot Ball Mill, Remove rig move doors on pipe module. 0.0 0.0 4/12/2024 18:00 4/12/2024 23:00 5.00 MIRU, MOVE RURD P M/U Koomey lines to BOP's, Install kill HCR, set grating in cellar, P/U handling equipment to rig floor. NOTE: Rig acceptance at 23:00hrs 4-12 -24 0.0 0.0 4/12/2024 23:00 4/13/2024 00:00 1.00 MIRU, WELCTL RURD P R/U hard line to manifold, Set choke skid and run hard line to cellar. NOTE: Tiger tank noted to arrive on location at ~02:00hrs. SIMOPS: Clean work areas and save rig move tools and equipment. TBD: 0psi IA: 0psi OS: 240psi 0.0 0.0 4/13/2024 00:00 4/13/2024 02:30 2.50 MIRU, WELCTL RURD P Continue Clean work areas and save rig move tools and equipment, Staging high pressure risers while WO tigher tank. ULDS: 35.80' LLDS: 38.05' 0.0 0.0 4/13/2024 02:30 4/13/2024 03:30 1.00 MIRU, WELCTL RURD P Off load tiger tank and hook up service lines. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 5/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/13/2024 03:30 4/13/2024 04:00 0.50 MIRU, WELCTL SVRG P Service rig, Trouble shoot Mud Pump drives. (VFD Alarms) 0.0 0.0 4/13/2024 04:00 4/13/2024 05:30 1.50 MIRU, WELCTL RGRP T Trouble shoot Mud Pump drives. (VFD Alarms) 0.0 0.0 4/13/2024 05:30 4/13/2024 08:00 2.50 MIRU, WELCTL PRTS P Test lines to 250/2500psi. Low torque valve leak, Blow down and change out valve. Flood lines and retest 250/2500psi. Leaks found pump room interconect, Pump room Demco, and injection Demco valve. 0.0 0.0 4/13/2024 08:00 4/13/2024 09:30 1.50 MIRU, WELCTL CIRC P Test lines to 250/2500psi Displace well with 57bbls 9.8ppg NaCI take returns to tiger tank, Pump down tubing and take returns up IA at 4bpm, final circ pressure 600psi. 0.0 0.0 4/13/2024 09:30 4/13/2024 10:30 1.00 MIRU, WELCTL RURD P Blow down service lines, R/D high pressure lines on rig floor and cellar. OWFF (Static) 0.0 0.0 4/13/2024 10:30 4/13/2024 12:00 1.50 MIRU, WHDBOP OWFF P N/D tree and remove tubing adaptor. Inspect tubing hanger threads (Good shape) 0.0 0.0 4/13/2024 12:00 4/13/2024 14:30 2.50 MIRU, WHDBOP NUND P Measure space out and make up high pressure risers. 0.0 0.0 4/13/2024 14:30 4/13/2024 22:30 8.00 MIRU, WHDBOP NUND P Continue N/U BOP's, Kill/Choke lines, Cut to fit new trip nipple riser, Seal Joes box, install fill hose and flow line. 0.0 0.0 4/13/2024 22:30 4/13/2024 23:00 0.50 MIRU, WHDBOP NUND P M/U 3-1/2" test joint, Function test BOP's. 0.0 0.0 4/13/2024 23:00 4/13/2024 23:30 0.50 MIRU, WHDBOP NUND P Swap control lines on annular. 0.0 0.0 4/13/2024 23:30 4/14/2024 00:00 0.50 MIRU, WHDBOP PRTS P R/U lines and equipment. Purge air form BOP's and Choke manifold. 0.0 0.0 4/14/2024 00:00 4/14/2024 02:00 2.00 MIRU, WHDBOP RURD P Purge air form BOP's and Choke manifold. 0.0 0.0 4/14/2024 02:00 4/14/2024 08:00 6.00 MIRU, WHDBOP BOPE P Test BOPE all test T/ 250 low for 5 min and 3,000 high for 5 min charted. Manual operated & super choke tested T/2,000 psi charted, W/ 3-1/2" and 5.5" test JT test annular, 3-1/2 X 5-7/8" UPR, Test choke valves 1-15, manual operated & super choke, Choke & kill manuals, HCR's, 4" valves on kill line, Upper and lower IBOP on TD; Blind/shear rams; Perform KOOMEY drawdown, ACC = 2950 PSI. MANIF. = 1500 PSI. ACC = 1800 PSI After all functions on bottles, 12 sec for 200 psi. Build W/ 2 Elec. pumps, 69 sec T/ Build full system. Pressure W/ 2 Elec. & 2 Air pumps, Closing times, Annular = 26 sec. UPR = 5 sec. Blind / Shears = 5 sec. LPR = 6 sec. Choke HCR = 2 sec. Kill HCR = 2 sec; Test PVT G/L and flow out alarms, Test LEL and H2S alarms. Waived Witness by AOGCC Brian Bixby 4/12/24 12:30hrs 0.0 0.0 4/14/2024 08:00 4/14/2024 09:30 1.50 MIRU, WHDBOP RURD P Remove blank plug and R/D test equipment. Blow down surface equipment. 0.0 0.0 4/14/2024 09:30 4/14/2024 10:30 1.00 COMPZN, CSGRCY THGR P R/U 4" drill pipe and 3-1/2" EUE X/O, M/U to top drive and tubing hanger. 0.0 2,645.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 6/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/14/2024 10:30 4/14/2024 11:00 0.50 COMPZN, CSGRCY THGR P BOLD, P/U string 63k, Line up and circulate through cut at 2,645' MD. DPM at 4bpm 268psi. Pumped 825 stks 70bbls. 2,645.0 2,645.0 4/14/2024 11:00 4/14/2024 11:30 0.50 COMPZN, CSGRCY RURD P L/D double 4" and L/D hanger, Blow down top drive. 2,645.0 2,611.0 4/14/2024 11:30 4/14/2024 14:30 3.00 COMPZN, CSGRCY PULL P POOH and L/D 3-1/2" EUE production tubing. 2,611.0 0.0 4/14/2024 14:30 4/14/2024 15:00 0.50 COMPZN, CSGRCY RURD P R/D 3-1/2" tubing equipment. 0.0 0.0 4/14/2024 15:00 4/14/2024 15:30 0.50 COMPZN, CSGRCY OWFF P OWFF, (Static) 0.0 0.0 4/14/2024 15:30 4/14/2024 16:00 0.50 COMPZN, CSGRCY OTHR P M/U pack off running tool, J into pack off (no issues) Observed 275psi on OA. L/D retrieving tool. 0.0 0.0 4/14/2024 16:00 4/14/2024 18:00 2.00 COMPZN, CSGRCY OTHR P R/U to tiger tank bled off OA in 100psi increments from 275psi to 0psi. 3bbls returned. 0.0 0.0 4/14/2024 18:00 4/14/2024 18:30 0.50 COMPZN, CSGRCY OWFF P OWFF (Static) 0.0 0.0 4/14/2024 18:30 4/14/2024 20:30 2.00 COMPZN, PLUG RURD P R/U and space out 9-5/8" Dutch riser. RILD on riser adapter. PJSM with SLB wire line. 0.0 0.0 4/14/2024 20:30 4/15/2024 00:00 3.50 COMPZN, PLUG ELNE P R/U Schlumberger 0.32" E-Line and equipment, RIH with 4.24" ALPHA CIBP. 0.0 0.0 4/15/2024 00:00 4/15/2024 01:30 1.50 COMPZN, PLUG ELNE P Continue RIH with 4.24" ALPHA CIBP on SLB CPST-A. Correlate and set on depth 2440.2' WLM - Middle element 2439.42' top of CIBP. (Collars at 2430' and 2386'). Line tension before set 654# / 400# after set. P/U to 2400'. S/O and tag CIBP at 2440' WLM. POOH L/D setting tools. 0.0 0.0 4/15/2024 01:30 4/15/2024 02:00 0.50 COMPZN, PLUG ELNE P R/D SLB CPST-A running tools. 0.0 0.0 4/15/2024 02:00 4/15/2024 03:00 1.00 COMPZN, PLUG CIRC P Close BSR test CIBP to 1000psi 10min (good test). Pumped/returned 1bbl. 0.0 0.0 4/15/2024 03:00 4/15/2024 06:00 3.00 COMPZN, PLUG ELNE P RIH with Welltec 5.5" mechanical cutter. Correlate and set cutter on depth 2,413'' WLM. Cut casing at 2413' ELM. Noticed returns on OA from fluid U-TBG. CIRC out OA. Pressure up IA to 100psi, noticed increase in OA pressure from 100-150psi (confirm cut). Circulate out diesel from OA. Pump 50bbls Deepclean and chase with 9.8ppg NaCI. Circ 1-4bpm on open choke to Tiger Tank 1000-700psi return OA 70-120psi. 0.0 0.0 4/15/2024 06:00 4/15/2024 07:00 1.00 COMPZN, PLUG ELNE P POOH with cutting tools and L/D. Good indication cutters fully extended. R/U packoff and Dutch riser. 0.0 0.0 4/15/2024 07:00 4/15/2024 09:00 2.00 COMPZN, PLUG WWSP P P/U landing joint and packoff retrieving tool. RIH and J into packoff with 10k. Check pressures (static). BOLD, L/D packoff. RIH with landing jt with X/U to 4". Pull 5.5" casing with 102k. 0.0 0.0 4/15/2024 09:00 4/15/2024 10:00 1.00 COMPZN, PLUG CIRC P Circulate at 4bpm 70psi 2872stks. SIMOPS: PJSM with cement crews. 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 7/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/15/2024 10:00 4/15/2024 12:00 2.00 COMPZN, PLUG CMNT P Pump 3bbls water. Test lines to 3000psi. Pump 8bbls 10.5ppg Mud Push II spacer at 2bpm 200psi. Drop ball. Mix and Pump 23 BBLS of 16.5ppg cement @ 2.5 BPM. Pump 12bbls 10.5ppg Mud Push II space cement unit. Swap to rig pumps and displace at 4bpm 33psi. Displace with 30bbls with rig pump. FCP - 33psi. Full returns throughout job. No losses. Cement in place @ 12:00hrs, 4/16/24. 0.0 0.0 4/15/2024 12:00 4/15/2024 12:30 0.50 COMPZN, PLUG RURD P R/D cement lines and equipment (well static). 0.0 0.0 4/15/2024 12:30 4/15/2024 13:30 1.00 COMPZN, PLUG PULL P POOH and L/D 5.5" casing from 2413' MD to 2139' MD. PU: 71k 2,413.0 2,139.0 4/15/2024 13:30 4/15/2024 14:00 0.50 COMPZN, PLUG CIRC P Circulate out cement and spacer from 2139' MD at 4.5bpm 140psi. 2,139.0 2,139.0 4/15/2024 14:00 4/15/2024 14:30 0.50 COMPZN, PLUG PULL P POOH and L/D 5.5" casing from 2139' MD to 2095' MD. PU: 65k 2,139.0 2,095.0 4/15/2024 14:30 4/16/2024 00:00 9.50 COMPZN, PLUG WOC P WOC, Monitoring well and move pipe every 6hrs. WOC till 4-16-24 @ 1400hrs to reach 500psi (24:48hrs). 2,095.0 2,095.0 4/16/2024 00:00 4/16/2024 13:00 13.00 COMPZN, PLUG WOC P WOC, Monitoring well and move pipe every 6hrs. WOC till 4-16-24 @ 1400hrs to reach 500psi (24:48hrs). 2,095.0 2,095.0 4/16/2024 13:00 4/16/2024 14:30 1.50 COMPZN, PLUG TRIP P Make up X/O from 5.5" L-80 BTC to 4" XT39, Wash in hole pumping at 1bpm 60psi. Tagged stringer at 2,116' MD. Tagged hard cement at 2,162' MD with 16k. AOGCC Brian Bixby witnessed tag. 2,095.0 2,162.0 4/16/2024 14:30 4/16/2024 15:30 1.00 COMPZN, PLUG PRTS T Space out at 2131' MD. R/U for test. Made three attempts to test without sucess. 1st: 760psi/ 250psi drop 15min 2nd: 760psi/ 250psi drop 15min 3rd: 1600psi/ 300psi drop 15min AOGCC Brian Bixby witnessed test. 2,162.0 2,131.0 4/16/2024 15:30 4/16/2024 20:30 5.00 COMPZN, PLUG OWFF T POOH L/D 5.5" L-80 BTC casing. Total 55 joints 1 cut joint. (tally 2414.70') Good cut, 2413' ELM +/- 1/2" section not fully cut. (Cutters were stalled when cut was made) Possible in compression. 2,131.0 0.0 4/16/2024 20:30 4/17/2024 00:00 3.50 COMPZN, PLUG WAIT T Pipe management, strap 5.5" casing, Lay out 4" drill pipe and strap while waiting on Baker 7.625" Model J Retrievamatic test packer. 0.0 0.0 4/17/2024 00:00 4/17/2024 03:30 3.50 COMPZN, PLUG TRIP T Single in hole with Baker 7.625" Model J Retrievamatic test packer. Set packer at 2089' MD element depth. 0.0 2,101.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 8/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/17/2024 03:30 4/17/2024 06:00 2.50 COMPZN, PLUG PRTS T Attempt to test balanced cement plug with pkr set at 2089' MD. 1st test: Pressure up to 1525psi 5min leaked down to 1300psi. 2nd test: Pressure up to 1700psi 10min leaked down to 1400psi. 3rd test: Pressure test backside to 1650psi 30min 1625psi (good test). Unseat packer, RIH and tagged at 2144' MD. Reset packer at 2117' MD element depth. 4th test: Pressure up to 1700psi 10min leaked down to 750psi. 2,101.0 2,117.0 4/17/2024 06:00 4/17/2024 08:00 2.00 COMPZN, PLUG TRIP T POOH with Baker test packer from 2117' MD, 2,117.0 0.0 4/17/2024 08:00 4/17/2024 08:30 0.50 COMPZN, PLUG OWFF T OWFF (Slight drop). Change out air boot on Joes box. 0.0 0.0 4/17/2024 08:30 4/17/2024 17:00 8.50 COMPZN, PLUG WAIT T Wait on drilling tools. 0.0 0.0 4/17/2024 17:00 4/17/2024 17:30 0.50 COMPZN, PLUG BHAH T M/U 6-3/4" bit and BHA, 17.55'. 0.0 18.0 4/17/2024 17:30 4/17/2024 18:00 0.50 COMPZN, PLUG PUTB T Single in with 4" drill pipe to 301' MD. 18.0 301.0 4/17/2024 18:00 4/17/2024 19:00 1.00 COMPZN, PLUG TRIP T TIH from 301' MD to 2080' MD. 301.0 2,080.0 4/17/2024 19:00 4/17/2024 19:30 0.50 COMPZN, PLUG CIRC T Break circulation at 2080' MD. GPM: 240 PSI: 225psi 2,080.0 2,080.0 4/17/2024 19:30 4/17/2024 20:00 0.50 COMPZN, PLUG WASH T Wash in hole and tagged cement at 2162' MD with 10k. 2,080.0 2,162.0 4/17/2024 20:00 4/17/2024 21:45 1.75 COMPZN, PLUG DRLG T Drilling cement from 2162' MD to 2216' MD. 2162' MD 7k WOB 145'/hr 2188' MD 10k WOB 140'/hr 2200' MD 10k WOB 106'/hr GPM: 240 PSI: 225psi RPM: 60 TRQ: 2k 2,162.0 2,216.0 4/17/2024 21:45 4/17/2024 22:15 0.50 COMPZN, PLUG CIRC T Shaker screens bilnding off. Circuate at 2215' MD while changing shaker screens. GPM: 164 PSI: 118psi 2,216.0 2,216.0 4/17/2024 22:15 4/17/2024 23:30 1.25 COMPZN, PLUG DRLG T Drilling cement from 2216' MD to 2381' MD. (Note: 18' Below surface shoe with D25 elevation correction) 2250' MD 10k WOB 95'/hr 2300' MD 10k WOB 140'/hr 2350' MD 10k WOB 103'/hr 2380' MD 10k WOB 130'/hr GPM: 240 PSI: 225psi RPM: 60 TRQ: 2k 2,216.0 2,381.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 9/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/17/2024 23:30 4/18/2024 00:00 0.50 COMPZN, PLUG CIRC T Circulate BTM's up at 2281' MD. GPM: 250 PSI: 252psi RPM: 60 TRQ: 2k ROT: 80k 2,381.0 2,348.0 4/18/2024 00:00 4/18/2024 00:30 0.50 COMPZN, PLUG PRTS T Pumped at 1/4bpm reached 382psi and broke down. Continue pumping at 1/4bpm - pumping in at 340psi. Increased rate to 1bpm pumping in at 376psi. 2,348.0 2,348.0 4/18/2024 00:30 4/18/2024 01:00 0.50 COMPZN, PLUG CIRC T CIRC BTM's up at 2348' MD at 250gpm, 252psi. 2,348.0 2,348.0 4/18/2024 01:00 4/18/2024 01:30 0.50 COMPZN, PLUG OWFF T OWFF (Static). 2,348.0 2,348.0 4/18/2024 01:30 4/18/2024 03:00 1.50 COMPZN, PLUG TRIP T POOH from 2281' MD. L/D Baker BHA. 2,348.0 0.0 4/18/2024 03:00 4/18/2024 03:45 0.75 COMPZN, PLUG RURD T R/U 5.5" casing running equipment. 0.0 0.0 4/18/2024 03:45 4/18/2024 08:00 4.25 COMPZN, PLUG PUTB T PJSM. Run 5.5" 15.5ppf L-80 BTC casing to 2371' MD. 0.0 2,371.0 4/18/2024 08:00 4/18/2024 08:30 0.50 COMPZN, PLUG RURD T Change out handling equipment to 4". Wash down at 1bpm 70psi. Wash in hole from 2371' MD and tag at 2375' MD DPM with 10k. Stage rate to 5bpm 145psi (full returns). 2,371.0 2,375.0 4/18/2024 08:30 4/18/2024 11:00 2.50 COMPZN, PLUG CIRC T R/U cement equipment. Continue circulating at 2375' MD 4bpm 125psi. PJSM with cement crew. 2,375.0 2,375.0 4/18/2024 11:00 4/18/2024 12:00 1.00 COMPZN, PLUG CMNT T Pump 3bbls water. Test lines to 3500psi. Pump 8bbls 10.5ppg Mud Push II spacer at 2bpm 200psi. Drop ball. Mix and Pump 23 BBLS of 16.5ppg cement @ 2.5 BPM. Pump 12bbls 10.5ppg Mud Push II spacer with cement unit. Swap to rig pumps and displace at 4bpm 33psi. Displace with 29bbls with rig pump. FCP - 33psi. Full returns throughout job. No losses. Cement in place @ 12:00hrs, 4/18/24. 2,375.0 2,375.0 4/18/2024 12:00 4/18/2024 13:00 1.00 COMPZN, PLUG TRIP T POOH with 5.5" casing from 2375' MD to 2094' MD at 30'/min. (Fluid level, balanced and viewed at surface) 2,375.0 2,094.0 4/18/2024 13:00 4/18/2024 13:30 0.50 COMPZN, PLUG CIRC T CIRC at 2094' MD at 168gpm ICP 400psi. FCP 100psi. 2,094.0 2,094.0 4/18/2024 13:30 4/18/2024 14:00 0.50 COMPZN, PLUG TRIP T OWFF (Static). POOH from 2094' MD to 1836' MD. 2,094.0 1,836.0 4/18/2024 14:00 4/19/2024 00:00 10.00 COMPZN, PLUG WOC T WOC. Close annular stage up pressure. 100psi Static, increase to 200psi, Bled down to 80psi. Continue monitoring pressure SIP. Slowly break over pipe every hr. Surface sample hard @ 2100hrs. WOC till 4-19-24 @ 1400hrs to reach 500psi (21:55hrs). 1,836.0 1,836.0 4/19/2024 00:00 4/19/2024 13:00 13.00 COMPZN, PLUG WOC T WOC. Continue monitoring SIP - 15psi. Slowly break over pipe every hr. WOC till 4-19-24 @ 1400hrs to reach 500psi (21:55hrs). 1,836.0 1,836.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 Page 10/10 2P-420 Report Printed: 5/28/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/19/2024 13:00 4/19/2024 14:30 1.50 COMPZN, PLUG TRIP T Bled off 15psi OA pressure. Open annular. Circulate at 4bpm,100psi. Pumped 20bbl/15ppb medium nutplug pill at 2135' MD. 1,836.0 2,135.0 4/19/2024 14:30 4/19/2024 16:00 1.50 COMPZN, PLUG CIRC T R/U 4" handling equipment. TIH from 2135' MD to 2141' MD. Tagged with 10K. R/U and pressure test cement to 758psi for 10min, 1625psi for 30min, final 1600psi. R/D test equipment. AOGCC: Sean Sullivan witness tag/test. 2,135.0 2,141.0 4/19/2024 16:00 4/19/2024 16:30 0.50 COMPZN, PLUG TRIP P POOH with 4" drill pipe from 2141' MD to 1834' MD. 2,141.0 1,834.0 4/19/2024 16:30 4/19/2024 17:00 0.50 COMPZN, PLUG PUTB P RIH with 5.5" L-80 BTC casing. from 1834' MD to 2093' MD. 1,834.0 2,093.0 4/19/2024 17:00 4/19/2024 17:30 0.50 COMPZN, PLUG PUTB P Drain stack, Run and land hanger at 2135' MD with 80K. 2,093.0 2,135.0 4/19/2024 17:30 4/19/2024 19:00 1.50 COMPZN, PLUG WWSP P R/U and set pack off. RILDS and test packoff to 5k for 10min (good test). Well static. 0.0 0.0 4/19/2024 19:00 4/19/2024 20:00 1.00 COMPZN, PLUG THGR P R/U and run tubing hanger. RILDS. 0.0 0.0 4/19/2024 20:00 4/19/2024 21:00 1.00 COMPZN, PLUG PRTS P R/U and purge air from system. Close UPR and test tubing hanger to 3000psi for 10min (good test). 0.0 0.0 4/19/2024 21:00 4/19/2024 23:30 2.50 COMPZN, WHDBOP PULD P L/D 4" drill pipe from derrick. SIMOPS: Breaking connections on BOP's and prep to N/D. 0.0 0.0 4/19/2024 23:30 4/20/2024 00:00 0.50 COMPZN, WHDBOP RURD P Continue N/D BOP's. Pull master bushings. 0.0 0.0 4/20/2024 00:00 4/20/2024 01:30 1.50 COMPZN, WHDBOP NUND P Continue N/D BOP's. Clean Joes box. Pull trip nipple. Skid BOP's. 0.0 0.0 4/20/2024 01:30 4/20/2024 02:30 1.00 DEMOB, MOVE NUND P Retrieve and L/D high pressure risers. 0.0 0.0 4/20/2024 02:30 4/20/2024 03:30 1.00 DEMOB, MOVE NUND P N/U tree, Install flanges and gauges. Secure tree. SIMOPS: test tbg adapter to 3500psi. SIMOPS: Blow down steam, 0.0 0.0 4/20/2024 03:30 4/20/2024 06:00 2.50 DEMOB, MOVE RURD P R/U cement lines from IA to cement truck in court yard. return line from OA to pits. SIMOPS: Remove kelly hose on top drive, Installing scoping bridle, Scope down derrick. Remove bridle lines. 0.0 0.0 4/20/2024 06:00 4/20/2024 09:00 3.00 DEMOB, MOVE CMNT P Pump 3bbls water, Test lines to1500psi, Pump 20bbls 10.5ppg Mud Push II spacer at 4bpm 200psi. Mix and Pump 93.6 BBLS of 15.7ppg cement @ 4.3 BPM. 9bbls cement returns 0.0 0.0 4/20/2024 09:00 4/20/2024 12:00 3.00 DEMOB, MOVE RURD P Clean pits and surface equipment. SIMOPS: Shut in IA & OA, Remove 1502 flanged and install gauges (well secured) (OA 0psi, IA 0psi, No tubing) SIMOPS: Raise C section, disconnect interconnections. Release off 2P-420 well at 1200hrs 4-20 -24 0.0 0.0 Rig: DOYON 25 RIG RELEASE DATE 4/20/2024 DTTMSTART JOBTYP SUMMARYOPS 3/20/2024 CHANGE WELL TYPE (SECURE) T-DDT TO 0 PSI (PASSED), BLEED IA TO 0 PSI (COMPLETE). 3/23/2024 CHANGE WELL TYPE SHOOT TUBING PUNCHER FROM 6060'-6063', CCL-TS=4', CCL STOP DEPTH=6056', LOG CORRELATED TO TUBING TALLY DATED 11/02/2001, SAW TUBING PRESSURE DROP FROM 800 TO 600 PSI AFTER FIRING PUNCHER, LRS PRESSURED UP TUBING TO 2500 PSI WITH NO RESPONSE ON IA (UNABLE TO PUMP INTO WELL), JOB IN PROGRESS. 3/24/2024 CHANGE WELL TYPE SHOOT TUBING PUNCHER FROM 6053'-6056', CCL-TS=6.8', CCL STOP DEPTH=6046.2', LOG CORRELATED TO TUBING TALLY DATED 11/02/2001. NO CHANGE IN IAP PRESSURE, ATTEMPT TO PUMP DOWN TUBING & IMMEDIATLY PRESSURE UP W/ NO RESPONSE ON IA. JOB IN PROGRESS 3/25/2024 CHANGE WELL TYPE SHOOT TUBING PUNCHER FROM 5950'-5953', CCL-TS=4', CCL STOP DEPTH=5946.0', LOG CORRELATED TO TUBING TALLY DATED 11/02/2001, PRE-SHOT T/IA=1800/0, POST-SHOT T/IA=50/125. JOB IS READY FOR CEMENTING. 3/25/2024 CHANGE WELL TYPE RIG UP LRS PUMP UNIT TO TBG, PUMP 15 BBLS DOWN TBG @ 2BPM, 1000 PSI PUMP PRESSURE THROUGH PERFERATIONS AND UP IA TO TANK, U-TUBE. JOB COMPLETE, RIG DOWN. 3/26/2024 CHANGE WELL TYPE (SECURE) BLEED OA FOR BUR (COMPLETE) 3/27/2024 CHANGE WELL TYPE PUMPED 50 BBL CHEM WASH, 110 BBLNaCl FOLLOWED BY 31 BBL15.8 # CEMENT@ 2BPM @ 235 PSI, DISPLACED WITH 39 BBL 9.8 NaCl. .5 BBL FREEZE PROTECT ON SURFACE 3/29/2024 CHANGE WELL TYPE SHOOT TUBING PUNCHER FROM 2000' - 2003. CIRCULATE 50 BBLS OF DIESEL DOWN TUBING UP IA AT 2.0 BPM @ 200 PSI. VERFIED DIESEL AT TANK. READY FOR SW TAG & TEST 3/30/2024 CHANGE WELL TYPE TAG TOP OF CEMENT ( STATE WITNESSED, KAM ST JOHN ) @ 4207' RKB. PERFORMED PASSING CMIT TO 1709 PSI. JOB COMPLETE, WELL READY FOR E-LINE. 3/31/2024 CHANGE WELL TYPE CUT 3.5" TUBING WITH WELLTEC MECHANICAL CUTTER AT 2626' RKB. TATTLETALE SHOWED BLADE EXTENSION TO 4.43". JOB COMPLETE, READY FOR RIG 4/1/2024 RECOMPLETION R/D and prep for rig MOB to 2P location. 4/2/2024 RECOMPLETION R/D and prep for rig MOB to 2P location. Waiting on ICE road. 4/3/2024 RECOMPLETION R/D and prep for rig MOB to 2P location. Waiting on ICE road. Disconnect interconnections, move casing module and ball mill into position to MOB. Skid rig floor and lay over derrick. 4/4/2024 RECOMPLETION R/D and prep for rig MOB to 2P location. Waiting on ICE road. Stomp motor, pump and pit modules. Unpin and stomp pipe shed module out from sub. Stomp sub from well center and and position for MOB. 4/5/2024 RECOMPLETION R/D and prep for rig MOB to 2P location. Waiting on ICE road. Stomp pipe shed out from SUB and stage in direction for MOB. Stomp and make 50' turn on SUB and stage in direction of MOB. Changing out Hillman roller on pit module. Place pits and motor modules on suspension. 4/6/2024 RECOMPLETION R/D and prep for rig MOB to 2P location. Waiting on ICE road readiness at 1800 hrs 4/6/24. Begin MOB modules to A21/K pad. 4/7/2024 RECOMPLETION Continue mobilize Rig to 2P-420. Move 6 modules to A21, Crew change and fuel up, Sub and Casing shed continue on to Heavy haul road, Casing shed detained at mile 10.2 from Alpine Checkpoint, continue with casing shed. Continue to move shed to 6 miles from cut-off. Ice road crews repairing road 4/8/2024 RECOMPLETION Continue to move Casing Shed and Sub Module to 2N pad. Transfer Haul Trucks and Dozer Equipment to A21 Pad. Rig up on Pipe Shed and Pit Modules, Begin moving to 2N Pad. 4/9/2024 RECOMPLETION Continue to move modules towards 2P. Pump module tire went flat at mile marker 16 while enroute to 2P. Change tire and continue move. 4/10/2024 RECOMPLETION Finish moving Pump module to 2P and stage. Mobilize trucks from 2P to MT7 to retrieve the ball mill, and shop. move Ball mill, and shop towards 2P 2P-420 Plug and Abandon Summary of Operations 4/11/2024 RECOMPLETION Set and spot Rig Modules in place on 2P-420. Raise derrick and skid rig floor. 4/12/2024 RECOMPLETION Stomp modules and install interconnects. Scope up derrick. Critical lift for installing BOPs and ST-80. Stomp Casing module. Continue rigging up and rig acceptance. R/U hard line and choke skid to tree. 4/13/2024 RECOMPLETION Continue Clean work areas and save rig move tools and equipment while WO tiger tank, Spot tank and install service line. Trouble shoot mud pump drives, Circulate out freeze protect, OWFF, N/D tree, N/U BOPs 4/14/2024 RECOMPLETION Purge air from system, Test BOPs. R/U and pull hanger, CIRC SS, Pull and L/D 3-1/2" EUE tubing. R/U dutch riser, R/U SLB E-Line, RIH with 4.24" ALPHA CIBP. 4/14/2024 SUPPORT OTHER OPERATIONS ELINE SUPPORTING DOYON 25. MOBILIZE EQUIPMENT AND SPOT IN. RIG UP PCE, ASSEMBLE AND TEST TOOLS. RIH WITH 4.25" PESI CIBP 4/15/2024 SUPPORT OTHER OPERATIONS SET PESI 4.25" CIBP, SET DEPTH = 2440.19', CCL TO MID ELEMENT = 10.19', CCL STOP DEPTH = 2430'. CUT 5.5' CASING WITH WELLTEC CUTTER, CUT DEPTH = 2413', CCL TO CUTTER = 20.5', CCL STOP DEPTH = 2392.5'. JOB COMPLETE. 4/15/2024 RECOMPLETION Continue RIH with 4.24" ALPHA CIBP, Correlate and set on depth 2440.2' WLM (Collars at 2430' and 2386'), Line tension before set 654# / 400# after set. POOH, M/U mechanical cutter and cut casing at 2,413' MD. CIRC 50bbls deep clean and displace with 9.8ppg NaCI to tiger tank, POOH R/D SLB wire line. R/U and pull pack off, R/U and pull hanger and 5.5" casing. Reland casing and R/U and set bal cement plug. POOH to ~ 2139'. CIRC out CMT/Spacer. WOC 4/16/2024 RECOMPLETION WOC. TIH and tag at 2162' MD with 16k. R/U and attempt to test (Unable to achieve test). POOH and L/D 5.5" casing. P/U Baker test packer. 4/17/2024 RECOMPLETION RIH with Baker 7.625" Model J Retrievamatic test packer. Set and attempt to pressure test cement plug, (test failed). W.O. Orders. POOH with 4" drill pipe/Baker packer. M/U 6-3/4" Bit and TIH to 2080' MD. Break circulation. Wash in hole and tag cement at 2162' MD. Drill CMT to 2381' MD. (Note: 18' Below surface shoe with D25 elevation correction). CBU. 4/18/2024 RECOMPLETION Injection test at 1bpm 370psi. CBU. OWFF. POOH and L/D BHA. Run 5.5" casing. CIRC and set balanced cement plug. Pull out of cement. CIRC out Cement/Spacer. Shut in and hold ~80psi. WOC for 25HRS. 4/19/2024 RECOMPLETION WOC. TIH and tag/test balanced plug. M/U hanger and land. Set packoff/test. Install TBG hanger/test. L/D 4" drill pipe. SIMOPS N/D BOP's. 4/20/2024 RECOMPLETION N/D BOP's. Install tree. R/U and CMT IA/OA. R/D and MOB to 2P-415. 4/21/2024 RECOMPLETION 5/11/2024 SUPPORT OTHER OPERATIONS (P&A) INSTALLED HEATER INTO WELL CELLAR AREA. VERIFIED NEGATIVE PRESSURE ON IA/OA VALVES. BLED NEGATIVE PRESSURE THROUGH BOTH VALVES FOR 1 HOUR. MONITORED IA/OA FOR PRESSURE OR VACUUM BUILD UP FOR ONE HOUR. ZERO PRESSURE (POSITIVE OR NEGATIVE) NOTED. WELLHEAD DDT (PASSED). ****NEXT STEP; VALVE AND TREE REMOVAL, VERIFY TOC, INSTALL TAPPED BLINDS.***** 5/12/2024 SUPPORT OTHER OPERATIONS (P&A) PREP- IN PROGRESS, REMOVED IA/OA & TREE, REPLACED WITH BLIND FLANGES. TOC @ SURFACE., ****NEXT STEP: OBTAIN ACWR**** 5/19/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS. NES MOBILIZED EQUIPMENT TO LOCATION, BEGAN DEWATERING OF AREA.( 78 BBLS) ***NEXT STEPS: CUT REMOVE WELL HEAD.*** 5/20/2024 SUPPORT OTHER OPERATIONS (P&A) PREP- CUT AND REMOVED 73" OF WELLHEAD AND CONDUCTOR. 2' ABOVE ORIGINAL GROUND. TOC OF 5" KILL STRING IS 21' APPROXIAMETLY 1/2 BARREL FUV. SENT NOTICE TO AOGCC FOR OPPORTUNITY TO VIEW TOC. SET SHORE CAN AROUND STEEL CELLAR. **NEXT STEP - AOGCC APPROVAL NEEDED FOR CEMENT TOP JOB. *** 5/21/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS- AOGCC INSPECTOR ADAM EARL VIEWED TOC- PERMISSION GIVEN TO TOP-OFF 21 FOOT VOID. POORBOY 1/2 BBL OF 15.8# PORTLAND TYPE I/II, CLASS G CEMENT INTO 5' CASING. WELDERS PREPARED SHORE CAN FOR MISTRAS INSPECTION. CUT REMOVED STEEL CELLAR. ***NEXT STEP- EXCAVATE INSIDE OF SHORE CAN, TD 14 BELOW TOP OF CAN.*** 5/22/2024 SUPPORT OTHER OPERATIONS (P&A) PREP- EXCAVATE TO 11' INSIDE OF SHORE CAN. TARGET DEPTH 14' FROM TOP OF SHORE CAN. ***NEXT STEP- COMPLETE EXCAVATION AND PREPARE WELL STUB FOR REMOVAL.*** 5/23/2024 SUPPORT OTHER OPERATIONS (P&A PREP) IN PROGRESS- EXCAVATED TO 13' FROM TOP OF SHORE CAN. CUT/REMOVED INSULATED JACKET 6" ABOVE EXCAVATION GROUND. ***NEXT STEP: CUT/ REMOVE WELL STUB AND PREP FOR MARKER PLATE. SUBMIT AOGCC REQUEST.*** 5/24/2024 SUPPORT OTHER OPERATIONS (P&A) PREP- CUT AND REMOVED 73" OF WELL STUB FOR MARKER PLATE INSTALLATION. TOC ~ 4' 1" BELOW ORIGINAL GROUND. NOTICE SENT TO AOGCC FOR OPPORTUNITY TO VIEW TO AND MARK PLATE INFORMATION PRIOR TO WELDING AND BACKFILL OPERATIONS. ***NEXT STEPS: VERIFY MARKER PLATE INFORMATION WITH AOGCC, WELD MARKER PLATE, BACKFILL AND EXTRACT SHORE CAN.*** 5/25/2024 SUPPORT OTHER OPERATIONS (P&A) AOGCC INSPECTOR BOB NOBLE WITNESSED, MARKER PLATE INFORMATION AND TOC OF WELL STUB. MARKER PLATE 4' 1" BELOW ORIGINAL GROUND (TUNDRA). WELDED MARKER PLATE TO WELL STUB, BACKFILLED SHORE CAN AND EXTRACTED. ***NEXT STEP - REQUEST SITE CLEARANCE FROM AOGCC AND DEMOB EQUIPMENT.*** 5/26/2024 SUPPORT OTHER OPERATIONS (P&A) AOGCC INSPECTOR BOB NOBLE WAIVED SITE CLEARANCE, REQUESTED SITE PHOTOGRAPHS TO BE TAKEN.. DEMOBED EQUIPMENT. P&A COMPLETED. 201-182 T38909 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.12 14:47:52 -08'00' 2024-0525_Surface_Abandon_KRU_2P-420_bn Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 5/30/2024 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment - Final Petroleum Inspector KRU 2P-420 ConocoPhillips Alaska Inc. PTD 2011820; Sundry 324-162 5/25/2024: I traveled to KRU 2P-420 to inspect the surface abandonment. When I arrived, I met with CPAI representative Roger Mouser. I went over the sundry with him then inspected the excavation and found the well cut off 4 feet 1 inch below tundra level. The well has 30-inch structural pipe, 16-inch conductor pipe, 7-5/8 inch surface casing and 5-½ inch production casing. The annular space between the 30-inch and the 16- inch conductor was full of hard foam (insulated conductor); all other stings were full of good hard cement. The ¼-inch x 30-inch marker plate had all the correct information. Attachments: Photos (2) 2024-0525_Surface_Abandon_KRU_2P-420_bn Page 2 of 2 Surface Abandonment – KRU 2P-420 (PTD 2011820) Photos by AOGCC Inspector B. Noble 5/25/2024 2024-0521_Surface_Abandon_KRU_2P-420_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 5-22-2024 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector KRU 2P-420 CPAI PTD 2011820; Sundry 324-162 5/21/2024: I traveled out to KRU 2P-420 to witness the surface abandonment progress. Cement in the 5.5-inch tubing did not reach surface during initial pumping operation and I was at location to verify how far down the top of cement was in the tubing – found at 251 inches below the surface tubing cut (1-inch shy of 21 feet). Approval was given to proceed with topping the tubing with cement. All other well spaces were full of cement. I departed location prior to them cementing the tubing. A follow-up inspection is warranted. Attachments: Photos (2) 2024-0521_Surface_Abandon_KRU_2P-420_ae Page 2 of 2 Surface Abandonment – KRU 2P-420 (PTD 2011820) Photos by AOGCC Inspector A. Earl 5/21/2024 Originated: Delivered to:19-May-24 Alaska Oil & Gas Conservation Commiss 19May24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24 3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24 3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24 2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24 MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24 MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24 3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24 2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24 1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24 1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24 1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24 3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24 2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Eset # T38800 T38801 T38802 T38803 T38816 T38817 T38818 T38819 T38820 T38821 T38822 T38824 T38823 T38825 2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 12:41:13 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:17 Township:8N Range:7E Meridian:Umiat Drilling Rig:Doyon 25 Rig Elevation:39.45 ft Total Depth:6860 ft Lease No.:ADL0373112 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:7 5/8"O.D. Shoe@ 2351 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:5 1/2" x 3 1/2"O.D. Shoe@ 6821 Feet Csg Cut@ 2450 Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 6157 Feet Tbg Cut@ 2610 Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bridge plug 2460 ft 2141 ft 9.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1625 1610 1600 IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Jonathan Benedict Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Traveled to KRU 2P-420 for tag and pressure test of intermediate cmt plug for P&A. Doyon 25 was on location for abandonment operations. Solid tag of cement top @ 2141 ft MD; 200 ft above the surface casing shoe with 10k lbs down weight. No issues with the MIT. April 19, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-420 Conoco Phillips Alaska PTD 2011820; Sundry 324-223 Well Schematic Test Data: P Casing Removal: rev. 3-24-2022 2024-0419_Plug_Verification_KRU_2P-420_ss KRU 2P-420 (PTD 2011820) P&A Well Schematic 4/19/2024 Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Change Approved ProgramPull TubingOther StimulatePerforateSuspend Other: ___________________Alter CasingPerforate New Pool Re-enter Susp WellPlug for Redrill 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoYes 10. Field:9. Property Designation (Lease Number): 11. Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): None6860' CollapseCasing Structural Conductor Surface Intermediate Production Liner Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:Wellbore schematicProposal Summary12. Attachments: ServiceDevelopmentExploratory StratigraphicBOP SketchDetailed Operations Program 15. Well Status after proposed work:14. Estimated Date for WDSPLOIL WINJCommencing Operations:Suspended SPLUGGSTORWAGGAS16. Verbal Approval: AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name: Contact Email: Contact Phone: Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Location ClearancePlug Integrity BOP Test Mechanical Integrity Test Other Conditions of Approval: Post Initial Injection MIT Req'd? NoYes APPROVED BY Date:THE AOGCCCOMMISSIONERApproved by: Sr Res EngSr Pet GeoSr Pet EngComm.Comm. 3-1/2" Packer: Baker GBH-22 Seal Assy. SSSV: None Perforation Depth MD (ft): L-80 2323' 6272-6320', 6324-6352', 6361- 6374', 6386-6422' 6825' 5502-5533', 5535-5553', 5559- 5567', 5575-5598' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 108' 2351' 5858'6851' 16" 7-5/8" 80' 6157' MD 108' 2351' ConocoPhillips Alaska, Inc. SizeLength Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned BurstTVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 201-182 P.O. Box 100360, Anchorage, AK 99510 50-103-20391-00-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing MD (ft):Tubing Grade: 6156' MD and 5428' TVD N/A Sydney Long Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: Plugs (MD):MPSP (psi): 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: sydney.long@conocophillips.com (907) 265-6312 Senior RWO/CTD Engineer KRU 2P-420 6250', 6720'28595488'6250'5863' 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 Victoria Loepp 4/17/2024 Date:04/17/2024 By Grace Christianson at 3:32 pm, Apr 17, 2024 SFD 4/18/2024 AOGCC inspection required after cutoff and before remedial cementing X VTL 4/19/24 BOP test to 2500 psig; Annular preventer test to 2500 psig. A variance to 20 AAC 25.112(a)(1)(A) is granted. Cement is not required from 100' below the base of the C-80 to 100' above the top of the C-80. The variance is granted to allow an equally effective plug which includes the placement of a cement plug from ~50' MD below the surface casing shoe in the open hole to 150' MD into the surface casing. (20 AAC 25.112(i)) A variance to the cement logging required in Other Order 196 is granted. Cement logging is not required.10-407 X X JLC 4/19/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.04.19 17:03:42 -04'00'04/19/24 RBDMS JSB 042324 2P-420Plug and Abandonment Background & Objective 2P-420 was an injectorthat has been shut in since September 2021. This well is in the process of being suspended with a CIBP and cement placed (as of 3/7/2024). The remaining steps to P&A this well include threemore cement plugs: an intermediate plug across the tubing, a plug across the surface casing shoe after the tubing and production casing has been pulled, and then a final plug to surface. Well Data Meltwater Formation: x Reservoir pressure 7/29/2023 = 2859psi (5144 TVD) x MASP = 2507psi C-80 Formation: x OAP = 277psi (11/5/2022)(fluid packed with diesel) x MASP = 862psi(0.1 PSI/FT gradient) Intermediate Plug –Wireline & Pumping Prepared by: Katherine O’Connor Estimated Start Date: 3-21-24 Procedure 1. Punch tubing at ±6050’ RKB 2. Pump the following schedule taking returns up the IA: a. ±40 bbls surfactant wash b. ±150 bbls 9.8 brine c. ±31 bbls cement d. ±39.5 bbls 9.8 brine displacement 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 4550’ MD 4. RIH and tag TOC and perform pressure test to 1500 psi (AOGCC Witnessed) 5. Cut tubing at ±2,610’ RKB Surface Casing Plugs – Rig Prepared by: Sydney Long Estimated Start Date: 4-22-2024 MIRU 1. MIRU on 2P-420. (No BPV due to abandonment of all perforations.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed oƯ IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead before proceeding. 3. ND Tree and NU BOPE. Test rams and annular to 250/3,000 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 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 by picking up casing. 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 11 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ 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’ inside the surface casing shoe based on space out of a casing collar at the Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe ii. Pump cement plug across the shoe through the tubing. PU and circulate the base of the tubing clear b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon bearing zones. It is our intention to recover 50’ of production casing from the open hole section. c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to drill out the cement plug once pumped. 6. WOC 7. Tag cement and PT to 1,500 PSI with state witness a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to increasing pressure to full 1,500 PSI for 30-min state witness b. Observe pressure leak oƯ during test. Pull 5-1/2” casing out of the well. ConƱrm surface casing integrity before proceeding with a test packer 8. PU milling BHA and clean out the cement plug to below the surface casing shoe and until injectivity is achieved. POOH and LD DP. 9. PU and RIH with cementing string 10. Place the cementing string at the milled depth and pump a balanced plug. Pull the string slowly up through the cement to above the TOC. Perform a light hesitation squeeze and place pressure on the TOC. Target a Ʊnal TOC ±150’ inside the surface casing shoe. 11. WOC 12. Tag cement and PT to 1,500 PSI with state witness 2P-420 Surface Shoe Plug Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 54.5 bbls of 15.8# Class G Cement Calculated TOC @ 3,978' KB 1 3 5 4 Production Casing: 5.5" x 3.5" @ 6,177' KB, 15.5# x 9.3#, L-80 BTCM Set @ 6,850.8’ KB T-3 Peforations: @ 6,272'– 6,422' KB (150') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,351.4' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,156.8' KB 6 Item Depth - tops (KB) 1 Casing Hanger 25.5' 2 Cast Iron Bridge Plug 2450.0' 3 Baker CMU Sliding Sleeve 6,094.6' 4 Camco D Nipple 6,110.6' 5 Baker Locator 6,155' 6 Baker GBH-22 Seal Assembly 6,155.8' 7 Cement Plug 6,720' 7 Plug #1 – Reservoir TOC ±6220' RKB C80 @ 2460' KBC80 @ 2460' KB Plug #3 – Surface Shoe TOC 2200' RKB BOC @ ±2450' RKB 2 Plug #2 – Intermediate TOC ±4550' RKB BOC @ ±6050' RKB Execute Final Abandonment Plug 8. Land workstring in casing hanger proƱle. 9. NFT for 30 minutes 10. ND BOPE. NU dry hole tree. 11. Circulate cement surface to surface until full cement returns observed on surface. See table below for cement volumes. RDMO 12. ND BOPE. NU dry hole tree. 13. RDMO. Cement Plug TOC BOC Section ID BBL/FT Volume Notes Surface Shoe 2401 2451 Open Hole 6.75 0.03867 1.9 Displacement of Prod Casing Stub Included in BBL/FT calc 2351 2401 Open Hole 6.75 0.04426 2.2 2201 2351 Surface Casing 6.87 0.04026 6.8 11.0 Total Volume of Plug Surface Casing 23 2201 Surface Casing 6.87 0.04026 87.3 Displacement of Prod Casing Included in BBL/FT calculation Execute Final Abandonment Surface Excavation 14. DHD to perform drawdown test on tubing, IA, and OA 15. Remove well house. 16. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system. 17. Remove tree in preparation for excavation and casing cut. 18. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 19. Cut oƯ wellhead and all casing strings at 4 feet below original ground level. 20. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 21. Send the casing head with stub to materials shop. Photo document. 22. 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-420 c. PTD #: 201-182 d. API #: 50-103-20391-00-00 23. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground level. 24. Obtain site clearance approval from AOGCC. RDMO. 25. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location condition after work is completed 2P-420 Final P&A Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 54.5 bbls of 15.8# Class G Cement Calculated TOC @ 3,978' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 6,177' KB, 15.5# x 9.3#, L-80 BTCM Set @ 6,850.8’ KB T-3 Peforations: @ 6,272'– 6,422' KB (150') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,351.4' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,156.8' KB 6 Item Depth - tops (KB) 1 Casing Hanger 25.5' 2 Cast Iron Bridge Plug 2450.0' 3 Baker CMU Sliding Sleeve 6,094.6' 4 Camco D Nipple 6,110.6' 5 Baker Locator 6,155' 6 Baker GBH-22 Seal Assembly 6,155.8' 7 Cement Plug 6,720' 7 Plug #1 – Reservoir TOC ±6220' RKB C80 @ 2460' KBC80 @ 2460' KB Plug #3 – Surface Shoe TOC 2200' RKB BOC @ ±2450' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2200' RKB 2 1 Plug #2 – Intermediate TOC ±4550' RKB BOC @ ±6050' RKB 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.£ 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. [EXTERNAL]RE: 2P-420 Repump Surface Shoe Plug APPROVAL Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Wed 4/17/2024 11:10 AM To: Long, Sydney <Sydney.Long@conocophillips.com> £ Sydney, Approval is granted to proceed with procedure to mill/repump surface casing shoe plug as outlined below. Could you please revise the current change of approved program sundry to include these steps and resubmit asap to the permiƫng site. Thank you, Victoria From: Long, Sydney <Sydney.Long@conocophillips.com> Sent: Wednesday, April 17, 2024 8:18 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; AOGCC Permiƫng (CED sponsored) <aogcc.permiƫng@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Germann, Shane <Shane.Germann@conocophillips.com> Subject: 2P-420 Repump Surface Shoe Plug Good morning, The surface shoe cement plug on 2P-420 was pumped Monday to plan with no losses or concerns. A WOC of +24 hours was performed before having AOGCC at the rig to witness the tag and test yesterday afternoon. Good cement was tagged at 2,150' RKB, which would place TOC 201' above the surface shoe, with a 15 klb set down. It was then attempted to pressure test - unsuccessfully. The pressure bled off slowly (~10 psi per minute linearly) and the test failed. At this point we pulled the 5-1/2" casing to surface and ran in with a test packer to confirm whether the leak was at the TOC or in the surface casing. It was determined that the plug was leaking (casing test held). We are currently pulling out of hole with the test packer. Our recommended plan forward is as follows: 1. Continue to POOH with the test packer and lay down 2. Pick up a cement milling BHA. Mill out the cement plug until below the surface shoe and injectivity is achieved. 3. POOH with the milling BHA and lay down drill pipe 4. Pick up and RIH with cementing string 5. Place the workstring at the milled depth and pump a balanced plug. Pull the workstring slowly up through the cement to above the top. Perform a light hesitation squeeze and place pressure on the TOC. 6. WOC 7. Tag and test the TOC per AOGCC with witness 8. Proceed with the approved sundry Please let me know if you have any questions or concerns. You are welcome to call my cell if you have any questions. Thank you, £ Sydney Long Senior Rig Workover Engineer £ATO-1490 | O: (907) 265-6312 | C: (907) 227-5800 £ £ 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:Doyon 142 Rig Elevation:Total Depth:6,860 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:P&A:XXX Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:7 5/8"O.D. Shoe@ 2351 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:5 1/2" x 3 1/2"O.D. Shoe@ 6851 Feet Csg Cut@ 2450 Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 6,157 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Casing Stub Bridge plug 2,460 ft 2,162 ft 9.5 ppg brine Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1600 1300 IA 1600 1300 OA 1600 1300 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Good tag - 15K lbs on the plug with the drill string. The pressure test failed - pressure loss exceeded 10%. April 16, 2024 Brian Bixby Well Bore Plug & Abandonment KRU 2P-420 ConocoPhillips Alaska Inc. PTD 2011820; Sundry 324-162 none Test Data: F Casing Removal: Rob Reinhardt Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2024-0416_Plug_Verification_KRU_2P-420_bb 1 Conklin, Amy A From:Long, Sydney Sent:Tuesday, April 16, 2024 11:13 AM To:Loepp, Victoria T (OGC) Cc:Hobbs, Greg S; Taylor, Jenna; Conklin, Amy A Subject:Re: [EXTERNAL]RE: 2P-420 Change to Final Cement Procedure Request APPROVAL Thank you very much! I'll get started on that paperwork for you. Thank you, Sydney Long Senior Rig Workover Engineer From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, April 16, 2024 11:00 AM To: Long, Sydney <Sydney.Long@conocophillips.com> Subject: [EXTERNAL]RE: 2P-420 Change to Final Cement Procedure Request APPROVAL 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. Sydney, Approval is granted for the change. Please submit a change of approved program as soon as possible. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Long, Sydney <Sydney.Long@conocophillips.com> Sent: Monday, April 15, 2024 12:59 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; Coberly, Jonathan <Jonathan.Coberly@conocophillips.com> Subject: 2P-420 Change to Final Cement Procedure Request Victoria, 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 I called and left a message earlier but would like to follow up about the procedure on 2P-420 for the pumping of the final surface-to-surface cement plug. This is after the plug is set and tested with AOGCC witness at the surface shoe. The current approved procedure is: We have realized there is a significant improvement to operations if the rig up of the cementing unit is changed. The current approved sundry has the cement pumped through the landing joint down the 5-1/2" casing and taking returns out the OA valve. This is creating a challenge for how to flush surface lines and the BOPE - and has significant risk to cement contamination in the surface well control equipment. It would be our request that after the state witness tag and test, the operations are changed as follows: 1. Land workstring in the casing hanger profile 2. NFT for 30 minutes a. Barrier 1: State witnessed tag and test of cement plug b. Barrier 2: KWF 3. ND BOPE and NU Tree 4. Circulate cement surface to surface until full returns are observed on surface via the IA valve and taking returns out the OA valve. 5. RDMO The final condition of the well will not change. The request is to change from pumping the cement with the BOPE on the well to pumping the cement with the tree on the well. If this is something you are willing to consider, I can submit the Change to Approved Sundry documentation. We anticipate this operation happening tomorrow. Thank you for your consideration, Sydney Long Senior Rig Workover Engineer ATO-1490 | O: (907) 265-6312 | C: (907) 227-5800 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:17 Township:8N Range:7E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:6860 ft MD Lease No.:ADL 373112 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:7 5/8"O.D. Shoe@ 2351 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:5 1/2" x 31/2"O.D. Shoe@ 6851 Feet Csg Cut@ Feet Liner:O.D. Shoe@ Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 6157 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 6155 ft 4207 ft 6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1709 1644 1627 IA 1709 1645 1628 OA 300 277 268 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Good hard tag at 4207 ft MD and got a good cement sample from bailer. Bbls in 0.3 bbls, out 0.2 with a good test. March 30, 2024 Kam StJohn Well Bore Plug & Abandonment KRU 2P-420 ConocoPhillips Alaska LLC PTD 2011820; Sundry 324-162 Photos (2) Test Data: P Casing Removal: rev. 3-24-2022 2024-0330_Plug_Verification_KRU_2P-420_ksj 2024-0330_Plug_Verifica�on_KRU_2P-420_photos_ksj Page 1 of 1 Plug Verification – KRU 2P-420 (PTD 2011820 Photos by AOGCC Inspector K. StJohn 3/30/2024 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 108' 7-5/8" L-80 2351' 5-1/2" L-80 5428' 3-1/2" L-80 5858' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: 255 sx Class G Flow Tubing SUSPENDED 6272-6320'MD and 5502-5533' TVD 6324-6352' MD and 5535-5553' TVD 6361-6374' MD and 5559-5567' TVD 6386-6422' MD and 5575-5598' TVD Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information 15.5# 6850' Surface 5428' 62.5# 29.7# 108' Surface 6156' SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 42" CASING WT. PER FT.GRADE 10/28/2001 CEMENTING RECORD 5868527 1454' MD / 1454' TVD SETTING DEPTH TVD 5868393 TOP HOLE SIZE AMOUNT PULLED 446027 446475 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A Kuparuk River Field/ Meltwater- Suspended 50-103-20391-00-00 KRU 2P- 420 ADL0373112 892' FNL, 2128' FWL, Sec. 17, T8N, R7E, UM 1465' FNL, 763' FEL, Sec. 17, T8N, R7E, UM 10/15/2001 6860' MD/5863' TVD 6155' MD / 5427' TVD 25.5' P.O. Box 100360, Anchorage, AK 99510-0360 444088 5868984 1335' FNL, 1212' FEL, Sec. 17, T8N, R7E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 3/17/2024 201-182 BOTTOM 9.875" 9 cu yds High Early Surface 260 sx AS III Lite, 140 sx LiteCRETE 9.3# Surface 6156' 2351'Surface Surface If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 6.75" TUBING RECORD 6.75" 6156'3-1/2" Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 6155- 6250' 14 gallons Cement on Top of CIBP @ 6250' By James Brooks at 8:01 am, Mar 19, 2024 323-450 JSB Suspended 3/17/2024 JSB RBDMS JSB 040424 DSR-4/23/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1454' 1454' 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: N/A - Suspended N/A - Suspended INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Authorized Title: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and 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 Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this documentLocation: Date: 2024.03.18 16:00:45-08'00'Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,299.0 2P-420 10/4/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag, set CIBP, dump bail cement 2P-420 10/7/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE:************ WELL REQUIRES 2.88" NOGO RING ON LOCK*********** 3/31/2019 aappleh NOTE: View Schematic w/ Alaska Schematic9.0 11/19/2010 ninam NOTE: MILL OBSTRUCTION @ 6291' -6344' w/3.6" JUNK MILL, 50+% OF PERFS STILL COVERED 8/13/2005 WV5.3 Conversio n 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 WELD SURFACE 7 5/8 6.87 27.9 2,351.4 2,351.3 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 6177' 5 1/2 4.95 25.5 6,850.8 5,857.9 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.5 Set Depth … 6,156.8 Set Depth … 5,428.4 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 TUBING HANGER 3.500 487.9 487.9 0.70 NIPPLE 4.563 CAMCO DS NIPPLE CAMCO DS 2.875 6,045.1 5,357.1 49.90 GAS LIFT 4.688 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,094.6 5,388.8 50.34 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813 6,110.6 5,399.0 50.49 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,155.0 5,427.2 50.47 LOCATOR 4.500 BAKER LOCATOR BAKER 2.980 6,155.8 5,427.8 50.47 SEAL 4.000 BAKER GBH-22 SEAL ASSY BAKER GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,250.0 5,487.9 50.22 PLUG Set 2.63" TTS CIBP 10/5/2023 0.000 6,720.0 5,780.4 53.27 PLUG CEMENT PLUG 11/2/2001 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) 6,045.1 5,357.1 49.90 1 GAS LIFT DMY BTM 1 0.0 3/24/2016 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,272.0 6,320.0 5,501.9 5,532.8 T-3, 2P-420 12/23/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,324.0 6,352.0 5,535.3 5,553.2 T-3, 2P-420 12/23/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,361.0 6,374.0 5,559.0 5,567.2 T-3, 2P-420 12/22/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,386.0 6,422.0 5,574.8 5,597.6 T-3, 2P-420 12/22/2001 6.0 IPERF Powerjet Chgs, 60 deg phase Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,155.0 6,250.0 5,427.2 5,487.9 Cement Plug Dump bailed cement with Slickline on top of CIBP 10/7/2023 2P-420, 3/18/2024 3:16:33 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6177'; 25.5-6,850.8 PLUG; 6,720.0 IPERF; 6,386.0-6,422.0 IPERF; 6,361.0-6,374.0 IPERF; 6,324.0-6,352.0 IPERF; 6,272.0-6,320.0 PLUG; 6,250.0 Cement Plug; 6,155.0 ftKB GAS LIFT; 6,045.1 SURFACE; 27.9-2,351.4 NIPPLE; 487.9 CONDUCTOR; 28.0-108.0 Casing 1; 0.0 KUP INJ KB-Grd (ft) 37.30 RR Date 11/2/2001 Other Elev… 2P-420 ... TD Act Btm (ftKB) 6,860.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039100 Wellbore Status INJ Max Angle & MD Incl (°) 54.00 MD (ftKB) 6,860.01 WELLNAME WELLBORE2P-420 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP DTTMSTART JOBTYP SUMMARYOPS 7/29/2023 ACQUIRE DATA DRIFTED TBG W/ 2.80" CENT TO 2.75" D-NIPPLE @ 6110' RKB, MEASURED SBHP @ 6110' RKB (MAX = 2858 PSI), DRIFTED TBG W/ 15' X 2.70" DMY CIBP DRIFT TO 6275' RKB. JOB COMPLETE. 10/4/2023 CHANGE WELL TYPE BRUSH AND FLUSH TBG & LINER FOCUSING ON CIBP SET DEPTH @ 6250' RKB. TAGGED TD @ 6299' RKB, IN PROGRESS. 10/5/2023 CHANGE WELL TYPE LOAD WELL W/ 10.2# BRINE. FREEZE PROTECT 20 BBLS OF DIESEL. SET TTS 2.63" CIBP MID ELEMENT @ 6250' RKB, MIT-T TO 2500 PSI. READY FOR SLICKLINE TO DUMP BAIL CEMENT. 10/6/2023 CHANGE WELL TYPE DUMP BAIL APROX 12 GAL OF CEMENT ON TOP OF CIBP @ 6250 RKB, JOB IN PROGRESS 10/7/2023 CHANGE WELL TYPE DUMP BAIL 2 GAL OF CEMENT @ 6201' RKB. TAG TOC @ 6206' RKB W/ S. BAILER, TAG 2.75" D NIPPLE @ 6110' RKB FOR C/F, PRESSURE TBG TO 2000 PSI, RE TAG TOC @ 6206' RKB. READY FOR SW TAG & TEST. 2/17/2024 CHANGE WELL TYPE MIT-IA TO 2000 PSI. (PASSED) @ 2000 PSI 3/1/2024 CHANGE WELL TYPE (SUSPENDED WELL) FT LDS/GN'S (COMPLETED), T POT (PASS) T PPPOT (PASS), IC POT (PASS), IC PPPOT (PASS). 3/17/2024 CHANGE WELL TYPE STATE WITNESS (AUSTIN MCLEOD) TAG TOC @ 6155' RKB, STATE WITNESS MITT TO 1730 PSI (PASSED). READY FOR NEXT STEPS. 2P-420 Suspend Summary of Operations MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:17 Township:8N Range:7E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:6860 ft MD Lease No.:ADL0373112 Operator Rep:Suspend:X P&A:NA Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ NA Feet Surface:7-5/8"O.D. Shoe@ 2351 Feet Csg Cut@ NA Feet Intermediate:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Production:5-1/2"x3-1/2"O.D. Shoe@ 6851 Feet Csg Cut@ NA Feet Liner:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing:3-1/2"O.D. Tail@ 6157 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 6250 ft 6155 ft 8.6/6.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1730 1680 1660 IA 520 525 525 OA 290 290 290 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Brent Rogers Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to KRU 2P to witness the tag and pressure test of the bottom, zone isolating cement plug that had been dumped bailed on 10/7/2023 on top of a cast iron bridge plug (CIBP) inside the wells 5-1/2-inch production string. CIBP was set at 6250 ft MD putting it 22 feet above the top perforation. They ran in the hole with generic 2-1/2 inch slickline bailer string and tagged at 6155 ft MD (53° inclination) with multiple jars down. At surface we found cement in the bailer. Then achieved a passing mechanical integrity test of the plug/production string. No issues with this inspection. March 17, 2024 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-420 ConocoPhillips Alaska, Inc. PTD 2011820; Sundry 323-450 none Test Data: P Casing Removal: rev. 3-24-2022 2024-0317_Plug_Verification_KRU 2P-420_am Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request: Change Approved ProgramPull TubingOther StimulatePerforateSuspend Other: ___________________Alter CasingPerforate New Pool Re-enter Susp WellPlug for Redrill 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoYes 10. Field:9. Property Designation (Lease Number): 11. Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): None6860' CollapseCasing Structural Conductor Surface Intermediate Production Liner Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch 15. Well Status after proposed work:14. Estimated Date for WDSPLOIL WINJCommencing Operations:Suspended SPLUGGSTORWAGGASDate:16. Verbal Approval: AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name: Contact Email: Contact Phone: Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Location ClearancePlug Integrity BOP Test Mechanical Integrity Test Other Conditions of Approval: Post Initial Injection MIT Req'd? NoYes APPROVED BY Date:THE AOGCCCOMMISSIONERApproved by: Sr Res EngSr Pet GeoSr Pet EngComm.Comm. (907) 265-6312 Senior RWO/CTD Engineer KRU 2P-420 6250', 6720'28595488'6250'5863' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Plugs (MD):MPSP (psi): 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: sydney.long@conocophillips.com AOGCC USE ONLY Tubing MD (ft):Tubing Grade: 6156' MD and 5428' TVD N/A Sydney Long STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 201-182 P.O. Box 100360, Anchorage, AK 99510 50-103-20391-00-00 Kuparuk River Field ConocoPhillips Alaska, Inc. SizeLength Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned BurstTVD 6157' MD 108' 2351' 108' 2351' 5858'6851' 16" 7-5/8" 80' 2323' 6272-6320', 6324-6352', 6361- 6374', 6386-6422' 6825' 5502-5533', 5535-5553', 5559- 5567', 5575-5598' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 3-1/2" Packer: Baker GBH-22 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 Current Pools: Meltwater Oil Pool - Suspended 3/21/2024 By Grace Christianson at 9:23 am, Mar 13, 2024 X DSR-3/14/24 X A.Dewhurst 14MAR24 VTL 03/21/2024 10-407 X AOGCC inspection required after cutoff and before remedial cementing BOP test to 2500 psig; Annular preventer test to 2500 psig. A variance to 20 AAC 25.112(a)(1)(A) is granted. Cement is not required from 100' below the base of the C-80 to 100' above the top of the C-80. The variance is granted to allow an equally effective plug which includes the placement of a cement plug from ~50' MD below the surface casing shoe in the open hole to 150' MD into the surface casing. (20 AAC 25.112(i)) A variance to the cement logging required in Other Order 196 is granted. Cement logging is not required. JLC 3/22/2024 2P-420Plug and Abandonment Background & Objective 2P-420was an injector that has been shut in since September 2021. This well is in the process of beingsuspended with a CIBP and cement placed (as of 3/7/2024). The remaining steps to P&A this well include threemore cement plugs: an intermediate plug across the tubing, a plug across the surface casing shoe after the tubing and production casing has been pulled, and then a final plug to surface. Well Data Meltwater Formation: Reservoir pressure 7/29/2023 = 2859 psi (5144 TVD) MASP = 2507 psi C-80 Formation: OAP = 277 psi (11/5/2022) (fluid packed with diesel) MASP = 862 psi (0.1 PSI/FT gradient) Intermediate Plug Wireline & Pumping Prepared by: Katherine OConnor Estimated Start Date: 3-21-24 Procedure 1. Punch tubing at ±6050 RKB 2. Pump the following schedule taking returns up the IA: a. ±40 bbls surfactant wash b. ±150 bbls 9.8 brine c. ±31 bbls cement d. ±39.5 bbls 9.8 brine displacement 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 4550 MD 4. RIH and tag TOC and perform pressure test to 1500 psi (AOGCC Witnessed) 5. Cut tubing at ±2,610 RKB Surface Casing Plugs Rig Prepared by: Sydney Long Estimated Start Date: 4-22-2024 MIRU 1. MIRU on 2P-420. (No BPV due to abandonment of all perforations.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed o 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 250/3,000 PSI. a. Will not set BPV due to two tested cement plugs below providing two barriers to formation. b. BOPE Con guration: Annular / Variable Bore Rams / Blind 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 con rm casing is free from cut by picking up casing. 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 shing 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 11 BBL of cement, plus excess, to target a nal TOC ±150 inside the surface casing shoe. Slightly under displace cement and pull 5-1/2 casing slowly to above nal TOC - allowing cement to ll the space vacated by the casing displacement. Ensure base of 5-1/2 casing is between 150 200 inside the surface casing shoe based on space out of a casing collar at the oor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe ii. Pump cement plug across the shoe through the tubing. PU and circulate the base of the tubing clear b. A Variance is requested to 20 AAC 25.112 requiring cement 100 below hydrocarbon bearing zones. It is our intention to recover 50 of production casing from the open hole section. c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to drill out the cement plug once pumped. 6. WOC 7. Tag cement and PT to 1,500 PSI with state witness a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak o prior to increasing pressure to full 1,500 PSI for 30-min state witness 2P-420 Surface Shoe Plug Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 54.5 bbls of 15.8# Class G Cement Calculated TOC @ 3,978' KB 1 3 5 4 Production Casing: 5.5" x 3.5" @ 6,177' KB, 15.5# x 9.3#, L-80 BTCM Set @ 6,850.8 KB T-3 Peforations: @ 6,272' 6,422' KB (150') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,351.4' KB Production Tubing: 3 ½, 9.3# L-80 EUE-8rd Set @ 6,156.8' KB 6 Item Depth - tops (KB) 1 Casing Hanger 25.5' 2 Cast Iron Bridge Plug 2450.0' 3 Baker CMU Sliding Sleeve 6,094.6' 4 Camco D Nipple 6,110.6' 5 Baker Locator 6,155' 6 Baker GBH-22 Seal Assembly 6,155.8' 7 Cement Plug 6,720' 7 Plug #1 Reservoir TOC ±6220' RKB C80 @ 2460' KBC80 @ 2460' KB Plug #3 Surface Shoe TOC 2200' RKB BOC @ ±2450' RKB 2 Plug #2 Intermediate TOC ±4550' RKB BOC @ ±6050' RKB Execute Final Abandonment Plug 8. Land workstring in casing hanger pro le. 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. 11. RDMO. Cement Plug TOC BOC Section ID BBL/FT Volume Notes Surface Shoe 2401 2451 Open Hole 6.75 0.03867 1.9 Displacement of Prod Casing Stub Included in BBL/FT calc 2351 2401 Open Hole 6.75 0.04426 2.2 2201 2351 Surface Casing 6.87 0.04026 6.8 11.0 Total Volume of Plug Surface Casing 23 2201 Surface Casing 6.87 0.04026 87.3 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 o T/I/O to ensure all pressure is bled o 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 lose ground from falling into the excavation. 17. Cut o 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-420 c. PTD #: 201-182 d. API #: 50-103-20391-00-00 21. Remove cellar. Back ll cellar with gravel/ll as needed. Back ll remaining hole to ground level. 22. Obtain site clearance approval from AOGCC. RDMO. 23. Report the nal P&A has been completed to the AOGCC. Photo document nal location condition after work is completed 2P-420 Final P&A Schematic Conductor: 16" Conductor 108' KB Production Casing Cement: 54.5 bbls of 15.8# Class G Cement Calculated TOC @ 3,978' KB 1 2 3 5 4 Production Casing: 5.5" x 3.5" @ 6,177' KB, 15.5# x 9.3#, L-80 BTCM Set @ 6,850.8 KB T-3 Peforations: @ 6,272' 6,422' KB (150') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,351.4' KB Production Tubing: 3 ½, 9.3# L-80 EUE-8rd Set @ 6,156.8' KB 6 Item Depth - tops (KB) 1 Casing Hanger 25.5' 2 Cast Iron Bridge Plug 2450.0' 3 Baker CMU Sliding Sleeve 6,094.6' 4 Camco D Nipple 6,110.6' 5 Baker Locator 6,155' 6 Baker GBH-22 Seal Assembly 6,155.8' 7 Cement Plug 6,720' 7 Plug #1 Reservoir TOC ±6220' RKB C80 @ 2460' KBC80 @ 2460' KB Plug #3 Surface Shoe TOC 2200' RKB BOC @ ±2450' RKB Plug #4 Surface TOC 23' RKB BOC @ ±2200' RKB 2 1 Plug #2 Intermediate TOC ±4550' RKB BOC @ ±6050' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,299.0 2P-420 10/4/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag, set CIBP, dump bail cement 2P-420 10/7/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE:************ WELL REQUIRES 2.88" NOGO RING ON LOCK*********** 3/31/2019 aappleh NOTE: View Schematic w/ Alaska Schematic9.0 11/19/2010 ninam NOTE: MILL OBSTRUCTION @ 6291' -6344' w/3.6" JUNK MILL, 50+% OF PERFS STILL COVERED 8/13/2005 WV5.3 Conversio n 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 WELD SURFACE 7 5/8 6.87 27.9 2,351.4 2,351.3 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 6177' 5 1/2 4.95 25.5 6,850.8 5,857.9 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 25.5 Set Depth 6,156.8 Set Depth 5,428.4 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 TUBING HANGER 3.500 487.9 487.9 0.70 NIPPLE 4.563 CAMCO DS NIPPLE CAMCO DS 2.875 6,045.1 5,357.1 49.90 GAS LIFT 4.688 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,094.6 5,388.8 50.34 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813 6,110.6 5,399.0 50.49 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,155.0 5,427.2 50.47 LOCATOR 4.500 BAKER LOCATOR BAKER 2.980 6,155.8 5,427.8 50.47 SEAL 4.000 BAKER GBH-22 SEAL ASSY BAKER GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,206.0 5,459.7 50.37 OTHER Dump bailed cement on CIBP 10/7/2023 0.000 6,250.0 5,487.9 50.22 PLUG Set 2.63" TTS CIBP 10/5/2023 0.000 6,720.0 5,780.4 53.27 PLUG CEMENT PLUG 11/2/2001 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) 6,045.1 5,357.1 49.90 1 GAS LIFT DMY BTM 1 0.0 3/24/2016 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,272.0 6,320.0 5,501.9 5,532.8 T-3, 2P-420 12/23/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,324.0 6,352.0 5,535.3 5,553.2 T-3, 2P-420 12/23/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,361.0 6,374.0 5,559.0 5,567.2 T-3, 2P-420 12/22/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,386.0 6,422.0 5,574.8 5,597.6 T-3, 2P-420 12/22/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 2P-420, 10/8/2023 8:03:57 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6177'; 25.5-6,850.8 PLUG; 6,720.0 IPERF; 6,386.0-6,422.0 IPERF; 6,361.0-6,374.0 IPERF; 6,324.0-6,352.0 IPERF; 6,272.0-6,320.0 PLUG; 6,250.0 OTHER; 6,206.0 GAS LIFT; 6,045.1 SURFACE; 27.9-2,351.4 NIPPLE; 487.9 CONDUCTOR; 28.0-108.0 Casing 1; 0.0 KUP INJ KB-Grd (ft) 37.30 RR Date 11/2/2001 Other Elev 2P-420 ... TD Act Btm (ftKB) 6,860.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039100 Wellbore Status INJ Max Angle & MD Incl (°) 54.00 MD (ftKB) 6,860.01 WELLNAME WELLBORE2P-420 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from katherine.oconnor@conocophillips.com. Learn why this is important From:Davies, Stephen F (OGC) To:O"Connor, Katherine Cc:Loepp, Victoria T (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]RE: KRU 2P-415A (Permit 201-226; Sundry 324-144) - Question Date:Monday, March 18, 2024 1:17:37 PM Thank you, Katherine. The erroneous calculated cement top of 5,782 MD is based on 62-1/2 barrels of cement, 6-3/4 hole diameter, 30% hole washout, and a production casing string consisting of only 5-1/2 pipe (forgetting that a significant portion of that production casing string actually consists of 3-1/2 pipe). Could you please check the calculated TOCs on schematic drawings that accompany all future Sundry Applications? Thanks for your help, Steve Davies AOGCC From: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Sent: Monday, March 18, 2024 12:54 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 2P-415A (Permit 201-226; Sundry 324-144) - Question Hi Steve I just pulled the drilling record, and confirmed there was 62.5 bbls of cement pumped. Using that and the 6-3/4 hole size, I calculate TOC outside the casing being ~7000 KB depending on how many digits I carry through in my calcs. So unsure how whomever made the schematic got to 5782 KB. Thanks Katherine Katherine OConnor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, March 18, 2024 12:09 PM To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: KRU 2P-415A (Permit 201-226; Sundry 324-144) - Question CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Katherine, Im reviewing CPAIs revised Sundry Application for KRU 2P-415A. This is a minor point, but to ensure that AOGCCs well records are accurate could you please confirm the calculated top of cement for the 5.5 x 3.5 production casing string that is shown on the wellbore schematic drawing as 5,782 MD? Cheers and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field & Processed 20ͲNovͲ23 0 1 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field & Processed 21ͲNovͲ23 0 1 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field & Processed 7ͲJanͲ23 0 1 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 72PͲ415A 50Ͳ103Ͳ20383Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 7ͲOctͲ23 0 1 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲOctͲ23 0 1 10 2VͲ05 50Ͳ029Ͳ21051Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 19ͲJulͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 1C-22 PTD:202-222 T38179 2.1D-38 PTD: 200-077 T38180 3. 1J-107 PTD: 207-107 T38181 4. 1L-03A PTD: 199-037 T38182 5. 2L-313 PTD: 198-219 T38183 6. 2M-24 PTD: 192-050 T38184 7. 2P-415A PTD: 201-226 T38185 8. 2P-417 PTD: 201-069 T38186 9. 2P-420 PTD: 201-182 T38187 10. 2V-05 PTD: 183-176 T38188 12/1/2023 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲ Final 5ͲOctͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:25:47 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6860'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. W ell 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 9/10/2023 3-1/2" Packer: Baker GBH-22 Seal Assembly SSSV: None Perforation Depth MD (ft): L-80 2323' 6272-6320', 6324-6352', 6361- 6374', 6386-6422' 6825' 5502-5533', 5535-5553', 5559- 5567', 5575-5598' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 108' 2351' 5858'6851' 16" 7-5/8" 80' 6157' MD 108' 2351' 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 201-182 P.O. Box 100360, Anchorage, AK 99510 50-103-20391-00-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6156' MD and 5428' 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-420 5863' 6720' 5357' 2318 6720' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:26 am, Aug 10, 2023 323-450 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: 2023.08.07 15:28:57-08'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor MDG 8/23/2023 X 10-407 DSR-8/14/23 12/31/2024 X VTL 08/11/2023*&: 08/24/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.08.24 10:14:56 -08'00' RBDMS JSB 082923 2P-420 Suspension Date WriƩen: 13 June 2023 ExecuƟon Date: Sept 10, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & ObjecƟve 2P-420 was an alternating gas or MI injector that was shut in September 2021. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 7/29/2012 = 2858 at 5399’ TVD MASP = 2318 psi Last MITIA 8/16/22 to 3210 psi (passed) Last tag 6275’ RKB on 7/29/2023 with 2.5” bailer Known casing damage 6290’ KB – 6344’ KB Procedure Wireline & Pumping 1. Tag TD. If unable to get within 50’ of perforations, contact Katherine O’Connor 2. Fluid pack tubing with KWF and freeze protect 3. Set CIBP @ ±6,250’ RKB (must be set within 50’ of the top of perforations) 4. Perform MIT-T to 2500 psi, record results 5. Dump bail at least 30’ of cement on top of CIBP 6. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 7. RIH and tag TOC, approx. 6220’ RKB (MUST BE AOGCC WITNESSED) 8. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 9. Perform DDT and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,275.0 2P-420 7/29/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update Tag Depth 2P-420 7/29/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE:************ WELL REQUIRES 2.88" NOGO RING ON LOCK*********** 3/31/2019 aappleh NOTE: View Schematic w/ Alaska Schematic9.0 11/19/2010 ninam NOTE: MILL OBSTRUCTION @ 6291' -6344' w/3.6" JUNK MILL, 50+% OF PERFS STILL COVERED 8/13/2005 WV5.3 Conversio n 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 WELD SURFACE 7 5/8 6.87 27.9 2,351.4 2,351.3 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 6177' 5 1/2 4.95 25.5 6,850.8 5,857.9 15.50 L-80 BTCM Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.5 Set Depth … 6,156.8 Set Depth … 5,428.4 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.5 25.5 0.00 HANGER 8.000 TUBING HANGER 3.500 487.9 487.9 0.70 NIPPLE 4.563 CAMCO DS NIPPLE CAMCO DS 2.875 6,045.1 5,357.1 49.90 GAS LIFT 4.688 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,094.6 5,388.8 50.34 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813 6,110.6 5,399.0 50.49 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,155.0 5,427.2 50.47 LOCATOR 4.500 BAKER LOCATOR BAKER 2.980 6,155.8 5,427.8 50.47 SEAL 4.000 BAKER GBH-22 SEAL ASSY BAKER GBH-22 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,720.0 5,780.4 53.27 PLUG CEMENT PLUG 11/2/2001 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) 6,045.1 5,357.1 49.90 1 GAS LIFT DMY BTM 1 0.0 3/24/2016 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,272.0 6,320.0 5,501.9 5,532.8 T-3, 2P-420 12/23/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,324.0 6,352.0 5,535.3 5,553.2 T-3, 2P-420 12/23/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,361.0 6,374.0 5,559.0 5,567.2 T-3, 2P-420 12/22/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 6,386.0 6,422.0 5,574.8 5,597.6 T-3, 2P-420 12/22/2001 6.0 IPERF Powerjet Chgs, 60 deg phase 2P-420, 8/7/2023 3:01:27 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6177'; 25.5-6,850.8 PLUG; 6,720.0 IPERF; 6,386.0-6,422.0 IPERF; 6,361.0-6,374.0 IPERF; 6,324.0-6,352.0 IPERF; 6,272.0-6,320.0 GAS LIFT; 6,045.1 SURFACE; 27.9-2,351.4 NIPPLE; 487.9 CONDUCTOR; 28.0-108.0 Casing 1; 0.0 KUP INJ KB-Grd (ft) 37.30 RR Date 11/2/2001 Other Elev… 2P-420 ... TD Act Btm (ftKB) 6,860.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039100 Wellbore Status INJ Max Angle & MD Incl (°) 54.00 MD (ftKB) 6,860.01 WELLNAME WELLBORE2P-420 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP 1 Regg, James B (OGC) From:Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent:Wednesday, August 17, 2022 10:00 AM To:Regg, James B (OGC); Wallace, Chris D (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Subject:CPAI 2P-Pad shut in tests 08-16-22.xlsx Attachments:MIT KRU 2P PAD SI TESTS 08-16-22.xlsx All Attached is the 10 426 form for the shut in tests performed on 2P pad on the 16 th of Aug 2022. Please let me know if you have any questions or concerns. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040170 Type Inj N Tubing 2605 2620 2610 2610 Type Test P Packer TVD 5209 BBL Pump 3.2 IA 470 3590 3500 3480 Interval V Test psi 2900 BBL Return 3.1 OA 203 360 310 290 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011820 Type Inj N Tubing 827 827 828 828 Type Test P Packer TVD 5428 BBL Pump 1.0 IA 460 3210 3145 3130 Interval V Test psi 2900 BBL Return 0.9 OA 277 363 319 309 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020180 Type Inj N Tubing 808 1001 980 953 Type Test P Packer TVD 5456 BBL Pump 2.3 IA 410 3200 3090 3075 Interval V Test psi 2900 BBL Return 2.0 OA 277 576 515 484 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011020 Type Inj N Tubing 875 876 876 876 Type Test P Packer TVD 5219 BBL Pump 2.1 IA 390 3200 3110 3100 Interval V Test psi 2900 BBL Return 1.8 OA 236 569 539 531 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2020910 Type Inj N Tubing 1091 1091 1091 Type Test P Packer TVD 5177 BBL Pump 3.2 IA 450 3200 2105 Interval V Test psi 2900 BBL Return OA 278 405 345 Result F Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031530 Type Inj N Tubing 886 887 887 887 Type Test P Packer TVD 5141 BBL Pump 1.6 IA 470 3210 3110 3090 Interval V Test psi 2900 BBL Return 1.6 OA 254 356 321 312 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2010820 Type Inj N Tubing 112 288 298 294 Type Test P Packer TVD 5274 BBL Pump 1.7 IA 950 3210 3110 3100 Interval V Test psi 2900 BBL Return 1,6 OA 211 428 303 253 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2031540 Type Inj N Tubing 882 882 882 882 Type Test P Packer TVD 5234 BBL Pump 2.0 IA 210 3210 3110 3110 Interval V Test psi 2900 BBL Return 1.8 OA 438 444 444 443 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 2P-438 2P-447 MITIA every 2 yr to max anticipated injection pressure per AIO 21C.002 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-429 2P-432 2P-434 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-427 Notes:MITIA every 2 yr to max anticipated injection pressure per AIO 21C.001 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 ConocoPhillips Alaska Inc, Kuparuk / KRU / 2P Pad Witness Waived by Guy Cook Beck / Borge 08/16/22 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Tubing plug set at 8110' MD Notes: Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 2P-419 2P-420 Form 10-426 (Revised 01/2017)2022-0816_MIT_KRU_2P-pad_8wells 2P-420 MEMORANDUM TO: Jim Regg 17 017-07-1 P.I. Supervisor Ke FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 6, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2P-420 KUPARUK RIV U MELT 2P420 Src: Inspector Reviewed By: P.I. Supry TF Comm Well Name KUPARUK RIV U MELT 2P-420 API Well Number 50-103-20391-00-00 Inspector Name: Guy Cook Permit Number: 201-182-0 Inspection Date: 8/1/2020 Insp Num: mitGDC200803110957 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2P-420 Tt2g Io - tzso - PTD 201 1820 - IType Test', sPT (Test psi z9oo Ip 575 3220 3150 also BBL Pumped: _I BBL Returned: - -- -I--- OA 375 377 377 j 377 - - Interval RsQvnR P/F ' P Notes: MIT -IA every 2 years to max anticipated surface injection pressure per AIO 21C rule 4. Testing was completed with a Little Red Services pump truck and calibrated gauges. Thursday, August 6, 2020 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS .,o..... - AUG 1 G 2013 A 1. Operations Abandon Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ 71Wa5bI7,VuWwn LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: WAG Injection startup ❑� 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: DevelopmentEx ❑ p lorato ry❑ Straligraphic ❑ Service ❑� 201-182 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 6. API Number: 50-103-20391-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: Surface: ADL 373112 KRU 2P420 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10, Field/Pool(s): NA Ku aruk River Field/Meltwater Oil Pool 11. Present Well Condition Summary: Total Depth measured 6860 feet Plugs measured 6720 feet true vertical 5863 feet Junk measured None feet Effective Depth measured 6,422 feet Packer measured 6156 feet true vertical 5,598 feet true vertical 5428 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' Surface 2324' 7.625" 2351' 2351' Intermediate Production 6825 5.5" 6851' 5858' Liner Perforation depth Measured depth 6272-6422' feet True Vertical depth 5502-5598' feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 SEAL ASSY: MD- 6156' TVD - 5428' Packers and SSSV (type, measured and true vertical depth) Packer - BAKER GBH -22 SEAL ASSY 6156' 5428' SSSV:None 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 3580 0 930 PSI 2060 PSI Subsequent to operation: 1 0 3900 1750 PSI 560 PSI 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service E] Straligraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG E] GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-455 Authorized Name: Sayeed Abbas Contact Name: Sayeed Abbas Authorized Title: Staff Petroleum Engineer Email: Sayeed.abbas(o)ponocophllllps.com {Contact '+ Authorized Signature: ` mi Date: " 5- Z0(7 Contact Phone: 907-265-1109 (ITL// 9 Form 10-404 Revised 412017 0�4 3BDMS-t0UG 15 2019 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 August 5th, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. has completed changing the service of the Kuparuk River Unit (Meltwater) Well 2P-420 from Gas Injection to Water Alternating Gas Injection. Enclosed you will find a 10-404 report of Sundry Well Operations for ConocoPhillips Alaska, Inc. If you have any questions regarding this matter, please contact me at 907-265-1109. Sincerely, V Sayeed Abbas Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Report of Sundry Well Operations Daily report of Well Operations Well Schematic 2P-420 DAILY REPORT WELL OPERATIONS 7/37/2079: 2P-420 started water injection as part of the process to change the well from Gas Injection (GINJ) designation to Water -Alternating -Gas (WAG) designation KUP INJ WELLNAME 2P-420 WELLBORE 2P-420 c(TPh''Iips%01C1S1S1VwtRDP Well Attributes Max Angle &MD TD LV��� Pleska.lrlc.MELTWATER item rvame weuM,e wpuuwl wellCo,e sums ncu•1 MD inns) 5 010 3 2 039100 MJ 6.00 6860L1 ACI BIm InR6) 6,860.0 1ppml Gale AnnoYliun Entl Dele KAGnd Va Rq Release DaM Last WO: 3].30 11YL2001 2PR2Av4ngd9 06aa Au, Last Tag VereoY uarrutic(Muell AnnoYlis deep (PoIBj EnE Dal¢ VNllbare "Massey LAST TAG: RKB 6,311.0 217-020 iappleh ...................._..... cesi,gnoo-_-.........- Last Rev Reason Annobllon E,M DeIa Wellwm —1 Mo]By .G.A. Eb Rev Reason: Pulled A Injection VtiN ))22)2819 217-02D fel9V5p Casing Strings Casing Gescnptian 00(m) mpn) TCpmrcel Degn ulKel sol Depth (TVD).wid"n D -Grade Trap ThRatl CONDUCTOR 16 15.06 280 108.0 1108p 6250 H40 WELD Casing description depnl IDpn) Top(XKSI SNianat eI Set Oegh RVD)....en g—jetrMe Tep TnrW SURFACE 7518 6.87 279 2,3514 2,3513 29.70 L-80 BTCM Casing dascepeonOd hill Top IXKB) sNdepen Me) Real DepM Ilia—WILLen IL.GnJe Tep Thrutl Indent PRODUCTION 5.5k3.5" 5112 495 25.5 6.8508 5,857.9 15.50 L-80 BTCM @6177 Tubing Strings CONDVCTOR',ID61 p9.0 Tubing Description sbing Ma... ld(in) Top lnKRl Set Depth M..Set Depth NAD(... W11NX1 G,atle Top ConnmllCn TUBING 3112 299 25.5 6,156.8 5,4284 9.30 L-80 EUE-8rd Completion Details T.; D) Topmol Nominal NIPPY: b]g Top MB)IXKB) L m IdDas Co. ID (in) 25.5 25.5 000 HANGER TUBING HANGER 3.500 4879 48].9 JO NIPPLE CAMCO DS NIPPLE 2875 6094.fi 5,388.8 50.34 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 6,110fi 5,399.0 504 NIPPLE CASCO D NIPPLE 2750 6,155.0 5,6272 5047 L CATOR BAKER LOCATOR 2.980 6.1558 5,42).8 SO4J SEAL BAKER GBH -22 SEAL ASSY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) roplrvDl Top mcl SURFACE: V 9.2%Ia TopinKe) (edDe (•1 Des Co. Run Gaff ID(Id 6720.0 I 5IbUs 5327 PLUG JCEMENTPLUU 11122001 0000 Perforations & Slots Shot Dens Top OVD) Ban GVD) (shown Wa.117 adapt TepeM°a) Ran mile) mile) MR) Unless! Zone DM I Tree Co. 6,2720 6,320.0 5,5019 5,532.8 T-3,20.420 182312001 60 IPERF Possojet Crags, 6O deg phase 63240 6.3520 5,5353 5,553.2 T3, 2P420 1223312001 6.0 IPERF Pmerjet Chile, 60 deg phase 6,3610 6,374.0 5,559.0 5,567.2 T-3,28420 1231222001 6.0 IPERF PosserjetChge,6 deg phase S.E. B..6 6386.0 6422.0 5,574.8 5,5976 T-3,28420 12282001 60 IPERF damages gs, deg phase NWPIF: 8,1148 Maneral Inserts sl all on iopinKel Tap MD)Klw pas.) Make 1 mons.ODpn) 9ery Type Lstn Type posS. (In) TRORon Ips) Run Oate Com 1 6,065.1 5,357.1 CASCO KB - - 1 GAS LIFT OMY BTM 0.000 0.0 312412016 11 9 Notes: General & Safety Fila dam Annoullon EDCATOR:6,IRd 811312005 NOTE. MILL OBSTRUCTION @6291'-6344'.136"JUNK MILL,50n% OF PEEPS STILL COVERED SEAL', alsse 1111912010 NOTE: view Schematic amt Alaska Schemadc90 313112019 NOTE.••"•""'•'WELL HEMLINES 2.88" NOGO RING ON LOOK •••••••'••' IPERF 4ZR.... IPERP:ea2a.o.e.ss2.d� IPFFF:e.alda.n4o- RVv:6.M0e.a22.0� luG: g.rm0 PRODUCTION 5sros a_ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �® DATE: Monday,August 22,2016 P.I.Supervisor i e- �� (1(o SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2P-420 FROM: Brian Bixby KUPARUK RIV U MELT 2P-420 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry R— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U MELT 2P-420 API Well Number 50-103-20391-00-00 Inspector Name: Brian Bixby Permit Number: 201-182-0 Inspection Date: 8/20/2016 Insp Num: mitBDB160821043350 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2P-420 • 'Type Inj C'' TVD 5428 ' Tubing 2425 - 2425 - 2425 - 2425• PTD` 2011820 Type Test SPT;Test psi 2900 - IA 1300 3300 - 3230 - 3230 - Interval REQVAR P/F P ✓ ' OA 90 92 _ 92 - 92 Notes: AIO-21B SCANNED MAY 2U `� Monday,August 22,2016 Page I of 1 • • Wallace, Chris D (DOA) From: Lyons, Kelly A <Kelly.A.Lyons@conocophillips.com> Sent: Saturday, April 23, 2016 11:08 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of IA pressure anomaly Meltwater injector 2P-420 (PTD 201-182) follow-up 3-12-16 update 4-23-16 Attachments: MIT KRU 2P-420 non witnessed 03-24-16.xlsm Chris, As proposed below,the well was circ'ed out and MITIA passed on 3/24/16. During the follow-up 30-day monitor period on gas injection, the IA has been fluctuating. However the IA pressure readings appear tied to thermal fluctuations of the gas injection. At this point CPAI believes the well is no longer demonstrating signs of TxIA communication and is being returned to its 'normal' injection status,to be governed under AIO 21B. If any indications of communication are observed in the future,they will be reported at that time. Please let us know if you disagree with the plan forward. Attached are the MIT and latest 90 day TIO plot. SCANNED MAY 0 2 2016 Well Name 2P-420 Notes: Start Date 1/24/2016 Days 90 End Date 4/23/2016 y� Annular Communication Surveillance 4000 - _.. __. - 100 WHP IAP - 550 OAP 11YNT ViNdf\m‘ei 2 00 - 70 NV".1416j - 60 _ .N _,.,.,. 5D Q. - 40 1E00 - sD - 20 500 - 10 0 Jan-16 Jan-16 Jan-16 Feb-16 Feb-16 Mar-16 Mar-16 Mar-16 Mar-16 Apr-16 Apr-16 Apr-16 r-3E -a 3337 ; p:337 1:33 1373• Flf‘En Jan-'6 Jan-16 Jan-16 Feb-"6 Feb-16 War-1E Mar-16 Mar-16 Mar-16 Apr-16 Apr-16 Apr-16 Date Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 From: NSK Problem Well Supv Sent: Saturday, March 12, 2016 8:22 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> 2 0 411) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoodalaska.aov; AOGCC.InspectorstS alaska.aov; phoebe.brooks@alaska.gov chris.wallacei8 alaska.00v OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/2P DATE: 03/24/16 OPERATOR REP: Ahern AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2P-420 Type Inj. W TVD 5,428' Tubing 1,250 1,400 1,400 1,400 Interval O P.T.D.2011820 Type test P Test psi 1500 Casing 425 3,025 3,000 2,995 P/F P Notes: Diagnostic OA 100 100 100 100 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 2P-420 non witnessed 03-24-16.xlsm • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, March 12, 2016 8:22 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler Subject: RE: Report of IA pressure anomaly Meltwater injector 2P-420 (PTD 201-182) follow-up 3-12-16 Chris, Initial diagnostics were done including packoff testing and an MITIA. The tubing and inner casing packoffs all passed as well as a passing MITIA. The IA was bled down at that time for pressure monitoring. The IA pressure continued to slowly build up however the buildup rate was slower following the bleed. The well was shut in and will await further diagnostics. It is ConocoPhillips intention to set a plug in the tubing, open the CMU and circulate in clean fluid into the IA. The CMU will be closed and an MITIA performed again prior to returning to injection. If the MITIA still passes, the well will be returned to gas injection restarting the 30 day monitor period. If there is a continued increase in the IA pressure, the well will be shut in at that time and a plan forward developed as there is no water injection capability out at 2P pad. Please let me know if you disagree with this plan. Attached is a 14 day TIO plot for reference. SCANNED APR 0 8 2016 s WELL TRENDS 2P 420 plot duration : -2 we CHOKE 13 . INJ RATE 0 . INJ PRES 3450 . ORIF DP 2 . INJ TEMP 56 . INJ VOL 0 . IGV/OGV CPRIME WH PRES 3450 SCHLE WELL STATUS 3800 OFF 3800 . OPEN/SI 120 . 3420 r iEVENT AT 3800 . PICK TIME 100 . 3040 - GENERAL PURPOSE 200 . UEVENT AT 2660 PICK TIME 1000 . - _ ____ _ — 2280 CREATE WELL AUTOSCALE __ — IN NOTE AT i- ' 2 g 4 8 =" r_ - PICK TIME _w...�. 1900 =` L IliORIFICE 0 + Ei 1520 r- FREEZE GET G R _,-===-: PROTECTION 1140 SAVE EOM IN WELL HEAD 760 - = sIll _ - ': VIEW SDL 0 . 00 380 _iw4.c.......r.-WALI....►I.... -__ --,---- 20 . II CREATE SDL 0 . 00 0 ' [LOU ; VIEW EPDDL 0 .00 I EP SC?A LE DESC r T CK VALUE III CREATE EPDDL 0.00 I Por CIMKT-:. 12 . 5 I ' INJ PRES 3452 . 1111 ANNCOM PROBLEMS IIlir INJ TEMP 55 . Flags: Ipm, WH PRES 3452 . TBG: II illir INJ RATE 0 . IA: TsIA on gas I low ORIF-DP 2 . OA: OA open shoe 1 Por IA PRES 832 . OOA/Tree: 1 ir OA PRES 95 . Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 41IWELLS TEAM Cps 2 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, March 02, 2016 1:26 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly Meltwater injector 2P-420 (PTD 201-182) 3-2-16 Attachments: 2P-420 schematic.pdf Chris, Meltwater gas injector 2P-420 (PTD 201-182) is experiencing an unexplained IA pressurization while on gas injection. An IA bleed was performed on 2/26/16 when the IA pressure was noticed by the operator to have begun rising (it was not near the DNE limit of 2400psi). Because there had been a recent relative increase in injection temperature and simultaneous OA bleed, it was suspected to be a thermal issue because gas injectors tend to respond much more rapidly to minor changes in wellbore conditions. With continued surveillance of the well however,the IA is continuing to demonstrate repressurization. The well will be left online and initial diagnostics with DHD will be scheduled as soon as possible to include MITIA/IA drawdown test with extended bleeds as necessary/packoff testing. It will go on a 30 day monitor. An update will be provided at the conclusion of the diagnostics period. Please let me know if you disagree with the plan. Attached are the schematic and 90 day TIO plot. SCANNED AUG 0 4 2016 Well Name 2P-420 Notes: Start Date 12/3/2015 Days 90 End Date 31212016 'CCC - — b'JHP Annular Communication Surveillance — 1= 2ECC — — 1: — 12 2CCC — 11 1ECC IC N — vC $2"1CCC — ?C — 7C ECC — C EC tic.-1E Cec-1E Cec-1E Dec-15 Jan-16 Jan-16 Jan-16 Jan-16 Feb-16 Fel;-1€ Mar-16 Mar-1E t1c;-1E Cec-1E Cec-1E Cec-1E Jan-1_ Jan-1: Jan-1: Jan-1E Feh-16 Feb-16 Mar-16 Mar-1E Date Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 2 STATE OF ALASKA AL A OIL AND GAS CONSERVATION CON ,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed Suspend r Perforate r Other StimulateAlter Casing 9 r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well rRe-enter Susp Well r Other:LoggingFe- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r Exploratory r 201-182 3 Address: 6 API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20391-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0373112 KRU 2P-420 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s): TMD3D Water Flow log Kuparuk River Field/Meltwater Oil Pool 11.Present Well Condition Summary: Total Depth measured 6860 feet Plugs(measured) 6720 true vertical 5863 feet Junk(measured) none Effective Depth measured 6720 feet Packer(measured) none true vertical 5780 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108 108 SURFACE 2324 7.625 2351 2151 PRODUCTION 6825 5.5 6851 5858 SCANNED JUL U 2 8 2 01'.{. q`r tic; ottIE E` JUN 19 LSI' Perforation depth: Measured depth: 6272-6320, 6324-6352,6361-6374,6386-6422 -N o---, - True Vertical Depth: 5502-5533, 5535-5553, 5559-5567, 5575-5598 t"=`N- Aw= Tubing(size,grade,MD,and TVD) 3.5, L-80, 6157 MD, 5428 TVD Packers&SSSV(type,MD,and TVD) no Packer NIPPLE-CAMCO DS NIPPLE @ 488 MD and 488 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbi Gas-Mcf Water-Bbi Casing Pressure Tubing Pressure Prior to well operation 9900 Subsequent to operation 7000 14 Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations Id Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ ri SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt 314-643 Contact Kasper Kowalewski 265-136 Email Kasper.Kowalewski c(r�cop.com Printed Name Kasper Kowalewski , Title Sr. Drillsite Petroleum Engineer Signature 7 Phone:265-1363 Date 6 /g15 VrL- 1114115 RBDIV4A JUN Y. 5 2015 r'et Form 10-404 Revised 5/2015 Submit Original Only �^ t KUP INJ 2P-420 i.0110�P!IIIIIp$ Well Attributes Max Angle&MD TD Alaska,irtc Wellbore API/UWI Field Name Wellbore Status ncl(") MD(kKB) Act Blm(ftKB) Cnrne,vtvlkps''.` 501032039100 MELTWATER INJ 54.00 6,860.01 6,860.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) -Rig Release Date 2P-420,5/3/201510:55:28AM SSSV:WRDP Last WO: 37.30 11/2/2001 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,300.0 3/27/2015 Rev Reason:RESET INJ VALVE hipshkf 5/3/2015 casing 1;0.0 HANGER;25.5 I __ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 108.0 108.0 62.50 H-40 WELD - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 27.9 2,351.4 2,351.3 29.70 L-80 BTCM 1 Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen)i...Grade Top Thread PRODUCTION 5.5"x3.5" 512 4.950 25.5 6,850.8 5,857.9 15.50 L-80 BTCM @ 6177' Tubing Strings , Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection € TUBING 31/2 2.992 25.5 6,156.8 5428.4 9.30 L-80 EUE-8rd CONDUCTOR;28.0-108.0 1 Completion Details H- Nominal ID Top(ftKB) Top(ND))ftKB) Top Incl(") Item Des Com (in) 25.5 25.5 0.00 HANGER TUBING HANGER 3.500 NIPPLE;487.9 487.9 487.9 0.70 NIPPLE CAMCO DS NIPPLE 2.875 VALVE;487.9 Ulf',. 6,094.6 5,388.8 50.34 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 6,110.6 5,399.0 50.49 NIPPLE CAMCO D NIPPLE 2.750 6,155.0 5,427.2 50.47 LOCATOR BAKER LOCATOR 2.980 6,155.8 5,427.8 50.47 SEAL BAKER GBH-22 SEAL ASSY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 487.9 487.9 0.70 VALVE 2.875"C-LOCK W/A-1 INJ VLV(.910 BEAN, 5/2/2015 0.913 OAL=71") SURFACE;27.9-2,3514 6,720.0 5.780.4 53.27 PLUG CEMENT PLUG 11/2/2001 0.000 I Perforations&Slots i Shot Dens T GAS LIFT;6.045.1 '.® otstf Top(ftKB) Btm(ftKB) Top(ftKB) (ftKB) Bt(8K(ND) Zone Date (s t) Type Corn I. 6,272.0 6,320.0 5,501.9 5,532.8 T-3,2P-420 12/23/2001 6.0 IPERF Powerjet Chgs,60 deg I phase 6,324.0 6,352.0 5,535.3 5,553.2 T-3,2P-420 12/23/2001 6.0 IPERF Powerjet Chgs,60 deg phase 6,361.0- 6,374.0 5,559.0 5,567.2 T-3,2P-420 12/22/2001 6.0 IPERF Powerjet Chgs,60 deg phase SLEEVE;6,094.8 6,386.0 6,422.0 5,574.8 5,597.6 T-3,2P-420 12/22/2001 6.0 IPERF Powerjet Chgs,60 deg phase Mandrel Inserts NIPPLE;6,110.6- E St ffiI N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com a f 6,045.1 5,357.1 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 9/1/2010 9 Notes:General&Safety End Date Annotation 8/13/2005 NOTE:MILL OBSTRUCTION @ 6291'-6344'w/3.6"JUNK MILL,50+%OF PERFS STILL COVERED LOCATOR,6,155.0 11/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL;6,155.8 NO EL I m' IPERF;6,272.0.6,320.0 IPERF;6,324.0-6,352.0 - IPERF,6,361 0-6,374,0 - IPERF;6.3860-6,422.0 - I I PLUG;6,720.0 PRODUCTION 5.5-x3.5"Q 6177';25.5-6.850.8 2P-420 WELL WORK SUMMARY DATE SUMMARY 3/27/2015 PULLED 3.5"A-1 INJ VALVE @ 469' SLM. TAGGED @ 6300' SLM. READY FOR E- LINE. 4/15/2015 PERFORMED A WATERFLOW SURVEY WITH STATIONS AT 6272, 6232, 6100, 6000, 5875, 5750, AND 5500 WITH 500 PSI INJECTION PRESSURE ON THE TUBING. PERFORMED STATIONS AT 6272, 6232, AND 6100 WITH 750 PSI INJECTION PRESSURE ON THE TUBING. FOUND A SMALL UPWARD FLOW RATE (-7 FPM) FROM 6100 STOPPING BETWEEN 5750 AND 5875. JOB WILL CONTINUE ON 16-APR-15 TO FINISH LOGGING PROGRAM. 4/16/2015 FINISH LOG FROM THE PREVIOUS DAY WITH STATION IMPULSE TESTS AT 5875 AND 6100 AT 750 PSI WHIP AND 6100, 6232, AND 6272 AT 980 PSI WHIP. JOB COMPLETE. 5/2/2015 SET 2.875" C-LOCK W/ A-1 INJ VALVE (.910 BEAN) @ 488' RKB (GOOD CLOSURE TEST). JOB COMPLETE WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. cPo! / íf;}- Well History File # Digital Data Added to LaserFiche File 0 CD's - # 0 DVD's - # - 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions Or information requests regarding this file. OF T • . 0.1. 1%%, s, THE STATE Alaska i and Gas - ==_ ofAL A s KA Conservation Commission wh GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ;;' Q. Anchorage, Alaska 99501-3572 -ALAS Y' Main: 907.279.1 433 Fax: 907.276.7542 Thomas Nenahlo Drillsite Petroleum Engineer SCANNED ConocoPhillips Alaska, Inc. P.O. Box 100360 c 0 1^ 1 $(g— Anchorage, AK 99510 Re: Kuparuk River Field, Meltwater Oil Pool, 2P-420 Sundry Number: 313-565 Dear Mr. Nenahlo: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster ®�� Chair, Commissioner DATED this o T d of November, 2013. Encl. SIW OIL AND GASTCONSERVATION COMM19!lfON ! ,\� OCT 20 APPLICATION FOR SUNDRY APPROVALS \`,'�C 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r After casing r Other:Logging Is 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development r 201-182 3.Address: Stratigraphic r Service 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20391-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2P-420 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0373112 Kuparuk River Field/Meltwater Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6860 5863 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 108' 108' SURFACE 2324 7.625 2351' 2151' PRODUCTION 6825 5.5 6851' 5858' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6272-6320,6324-6352,6361-6374, 5502-5532,5535-5553,5558-5667,5574- 6386-6422 5598 3.5 L-80 6157 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SEAL-BAKER GBH-22 SEAL ASSY MD=6156 TVD=5428 PLUG-CEMENT PLUG MD=6720 TVD=5780 12.Attachments: Description Summary of Proposal pr 13. Well Class after proposed work: Detailed Operations Program BOP Sketch r Exploratory r Stratigraphic r Development r Service p 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/1/2014 Oil r Gas r VVDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ p VVAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tommy Nenahlo Email: Thomas.L.Nenahlo(a)cop.com Printed Name Thomas ahlo c� Title: Drillsite Petroleum Engineer Signature 7. g0.14/..aV' Pho ne:265-6934 Date:10/25/2013 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3k3^'SCQS Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Weft 'to ce24- , nn acc c c e w i it, kto zt a.do3 Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: / 4 v ` APPROVED BY / �i Approved by: COMMISSIONER THE COMMISSION Date: [/pCf®I NCV 15 A roved application is valid for 12 months trom the date of approval. +(1v !V1 Form 10-403(Revised 10/2012) /`) (0/31113 Submit Form and Attachments in Duplicate Vr/I/(0/i3 ORIGINAL �J • • RE .: OCT 17 2013 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 17th, 2013 Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 SUBJECT: Requests for Administrative and Sundry Approvals for Meltwater Surveillance Initiatives Dear Mr. Wallace: As discussed in the meeting held on September 26th, 2013, between the Alaska Oil and Gas Conservation Commission(AOGCC) and ConocoPhillips Alaska, Inc. (CPAI), the Meltwater team is pursuing a number of surveillance initiatives to aid in the characterization and understanding of the Meltwater shallow gas issue while collecting further data for the evaluation of development options. Attached within this communication are the technical justifications for the necessary administrative and sundry approvals to achieve the objectives of these surveillance initiatives. The surveillance initiatives that are currently being pursued are as follows: • An extended outer annulus bleed at well 2P-431 o Pertaining to this initiative, please find a request for Administrative Approval via Rule 10, Area Injection Order 21A(Amended), for Meltwater production well 2P-431 (PTD 202-053) in regard to Rule 3 (annular pressure limits). Also enclosed is an Application for Sundry Approval (10-403) for authorizing annular flow from 2P-431. • Video and Spectra-Flow® logging at wells 2P-419, 2P-420, 2P-427, 2P-429, 2P- 434, 2P-447 o Pertaining to this initiative, please find a request for Administrative Approval via Rule 10, Area Injection Order 21A(Amended), for Meltwater injection wells 2P-419 (PTD#204-017), 2P-420 (PTD# 201- 182), 2P-427 (PTD#202-018), 2P-429 (PTD#201-102), 2P-434 (PTD# 203-153), 2P-447 (PTD# 203-154) in regards to Rule 7 (authorized injection pressure) and Rule 8 (authorized fluids for injection). Please call Tommy Nenahlo at 265-6934, or me at 265-1464 if you have any questions. • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Sincerely, :?,a.d Jerry Dethlefs ConocoPhillips Well Integrity Director &. 2/14 Tommy Nenahlo ConocoPhillips Meltwater Drill Site Petroleum Engineer Enclosures: Technical Justification for Administrative Relief Requests Application for Sundry Approval Welibore Schematic • • ConocoPhillips Alaska,Inc. Kuparuk River Unit Meltwater Pool Injection Wells Technical Justification for Administrative Relief Request,AIO 21A,from Rules 7 and 8 Purpose ConocoPhillips Alaska,Inc. (CPAI)requests that the AOGCC approve this Administrative Relief as per Area Injection Order(AIO)21A(Amended),Rule 10,for temporary relief from criteria set forth in Rules 7 and 8 that defines the authorized pressure and fluids for injection,respectively. CPAI requests temporary relief from these rules to conduct video and Spectra Flow®logging on six Meltwater injectors, 2P-419(PTD#204-017),2P-420 (PTD#201-182),2P-427(PTD#202-018),2P-429(PTD#201-102),2P- 434(PTD#203-153),and 2P-447(PTD#203-154). By conducting video logging on these injectors,the Meltwater team is looking to inspect possible collapsed liner,as has been indicated by recent and historic well work. By conducting Spectra Flow®logging,the Meltwater team is looking to determine if there is fluid movement around the production casing cement shoe over a range of sand face injection pressures. Video Logging Campaign Summary During recent and historic well work,indications of potentially collapsed liner in injectors 2P-419,2P- 420,2P-429,2P-434, and 2P-447 have arisen. In a number of these injectors it is believed that these potential collapsed liner locations are limiting our injection into the Bermuda formation. To aid in characterizing and understanding these potential collapsed liner locations, as well as to formulate a plan to remediate this issue, it is necessary to run video logs to inspect the locations. To safely execute a video log on a miscible injectant(MI)injector it is necessary to adequately displace the near wellbore formation to ensure that MI returns are not taken to surface. Therefore, it is recommended that the near wellbore formation be displaced with a minimum three tubing volumes of hot diesel. Upon adequately displacing the near wellbore formation,the video log will be run while injecting filtered sea water to allow for the optimum video resolution to inspect these potential collapsed liner locations. The ability to provide a sufficient injection rate at Meltwater is critical as it is necessary to ensure that adequate lift gas temperatures are maintained at the Meltwater's Drill Site,2P. Drill Site 2P is located approximately twelve miles from the nearest drill site,2N. This distance provides a significant amount of time for cooling of the MI that is used as injection fluid as well as a lift gas for the producers. During winter months and low injection rate periods,the temperature of the lift gas has historically become low enough to cause rapid paraffin deposition in the upper wellbore of the producers and can choke flow to a point at which the well would need to be shut in. If enough production is shut in the temperature of the Meltwater produced oil line could become low enough to require it to be shut in and de-inventoried to mitigate the potential for the line to freeze. In 2012,modeling was completed to determine the minimum MI gas delivery temperature at Meltwater to ensure that this issue can be mitigated. As anticipated,the variable with the greatest effect on the MI gas delivery temperature at Meltwater is the MI injection rate. By completing video logs on these potential collapsed liner locations to aid in developing a remediation strategy it is believed that this risk of low lift gas temperature and a produced oil line freezing scenario can be reduced. To successfully complete this video logging campaign,temporary relief from AIO 21A(Amended) Rules 7 and 8 is requested to adequately displace the formation and conduct these video logs. CPAI Well Integrity Director 10/17/2013 1 • • • Spectra Flow®Logging Campaign Summary To successfully complete this Spectra Flow®logging campaign,temporary relief from AIO 21A (Amended)Rule 8 is requested to allow for the temporary injection of sea water into the Bermuda formation. Sea water is not an authorized injection fluid in AIO 21A(Amended). The Halliburton® Spectra-Flow logging technology is capable of identifying fluid movement around the production casing shoe by identifying the presence of oxygen. Sea water will provide the oxygen in the injection fluid to ensure the logging campaign can be completed successfully. To achieve the most information from the logging campaign,temporary relief from AIO 21A(Amended) Rule 7 is requested for exceeding the established pressure limit during injection of sea water into the Bermuda formation while logging. The Meltwater team would like to vary the injection pressures of the sea water while performing Spectra Flow®logging runs to complete the following objectives: 1. To confirm there is not fluid movement around the production casing shoe when injecting within the sand face injection pressure limit established by Rule 7 in AIO 21A(Amended). 2. To determine if MI migration is a result of historic sand face injection pressures at Meltwater prior to the issuance of AIO 21A(Amended). The second objective stated above is intended to further the Meltwater team's understanding of the MI migration mechanism. As discussed in the November 2012 hearing with the AOGCC,the Meltwater team proposed two potential MI migration mechanisms. One of these migration mechanisms includes the possibility of MI migration around the production casing cement shoe. By completing the aforementioned objectives,the Meltwater team will be able to make more informed decisions to ensure the field is operated safely and effectively. Video and Spectra Flow®Logging Procedure Outline The following is an outline of the procedure for the proposed Spectra Flow®Logging campaign to be performed on each of the six injectors. 1. Displace the near wellbore formation with a minimum three tubing volumes of hot diesel to mitigate the risk of taking MI returns at surface during well work operations. o Injection pressure at surface not to exceed 2,495 psig with diesel(4475 psig at perf depth assuming 0.36 psi/ft gradient and 5,500 ft TVD to mid-perfs) 2. Rig up E-Line with Spectra-Flow®Logging tools and IPROF string to monitor bottomhole conditions. 3. Little Red Services(LRS)to pump sea water down on well using a step rate approach as defined below. During each step,the Spectra-Flow®logging tool will be passed up and down to identify the possible height of injected fluid above the perforations. a. Step 1: 500 psi WHIP (2975 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) b. Step 2: 750 psi WHIP (3225 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) c. Step 3: 1,000 psi WHIP (3475 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs)\ d. Step 4: 1,250 psi WHIP(3725 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) e. Step 5: 1,500 psi WHIP (3975 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) CPAI Well Integrity Director 10/17/2013 2 • • f. Step 6: 1,750 psi WHIP(4225 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) g. Step 7: 2,000 psi WHIP(4475 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD to mid-perfs) 4. Upon completion of the step rate logging runs,E-Line and LRS will rig down and move off the well. 5. Injection of seawater will cease on each individual well after the logging runs are completed. 6. The well bores will then be freeze protected with the injection of hot diesel with the injection pressure at surface not to exceed 2,495 psig(4475 psig at perf depth assuming 0.36 psi/ft gradient and 5,500 ft TVD to mid-perfs) Administrative Approval Request: CPAI requests temporary relief from(AIO)21A(Amended),Rules 7 and 8 to conduct Video and Spectra Flow®logging on six Meltwater injectors: 2P-419(PTD#204-017), 2P-420(PTD#201-182), 2P-427(PTD#202-018), 2P-429(PTD#201-102), 2P-434(PTD#203-153), 2P-447(PTD#203-154). 1. Temporary relief from AIO 21A(Amended)Rule 7 is requested for exceeding the pressure limit during injection of sea water into the Bermuda formation during the logging operations only. The approval is requested for a period of six months from the date of the AOGCC approval. 2. Temporary relief from AIO 21A(Amended)Rule 8 is requested to allow for injection of sea water into the Bermuda formation for the purposes of performing the logging operations only. The approval is requested for a period of six months from the date of the AOGCC approval. CPAI Well Integrity Director 10/17/2013 3 • • ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 25th, 2013 Chris Wallace Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Response to Questions Regarding Requests for Administrative and Sundry Approvals for Meltwater Surveillance Initiatives Dear Mr. Wallace: Thank you for your reply regarding our requests for Administrative and Sundry Approvals for the Meltwater surveillance initiatives. Please find below the responses to your questions in your emails that were sent October 22nd, 2013. Injected Volumes and Duration Per the plan developed by the Meltwater team, it is expected that no more than 6,000 barrels of Beaufort seawater will be required to be injected at each injector to complete the video and Spectra-Flow®logging initiatives. This estimate of 6,000 total barrels includes the procedures to complete the miscible injectant displacement, video logging, and Spectra-Flow® logging procedures. Below is a high level breakdown of this estimate for clarity: • Displacement volume estimate: 1,000 BBLs of seawater per well o This is volume that we may need during the video and/or Spectra-Flow®logging campaign to mitigate the potential for having miscible injectant present in the wellbore. • Video Logging volume estimate: 1,600 BBLs of seawater per well o To minimize the turbidity of the fluid, and thus increase our video resolution at the potential collapsed liner locations, filtered seawater will be used to displace the wellbore and ensure it remains displaced throughout the video logging procedure. • Spectra-Flow®Logging volume estimate: 3,400 BBLs of seawater per well o This estimated volume of 3,400 BBLs is planned to be split evenly amongst the seven pressure stages outlined in the Technical Justification for Administrative Relief Request, AIO 21A(Amended), from Rules 7 and 8, that was submitted to the AOGCC on October 17th, 2013. o It is preferred that seawater be used for the Spectra-Flow®logging as upright tanks will be on location at Drill Site 2P to store the seawater that will support the aforementioned video logging. Operationally, it is preferred that Kuparuk produced water be kept separated from seawater due to corrosion concerns. The above logging initiatives may require up to 168 hours(7 days)to complete, per well. • • ConocoPhiIIips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 B eau fort Seawater Compatibility Study A Meltwater field fluid sensitivity and stimulation study was completed in March of 2001. This study utilized core samples from the Meltwater North#1 and Meltwater North#2 wells that included an investigation into the sensitivity of preserved reservoir samples to the proposed flood waters. These proposed flood waters included a Kuparuk produced water blend and a 75% Kuparuk produced water/25% Beaufort seawater blend. The investigation into the sensitivity of the Meltwater North#1 and Meltwater North#2 core samples to the proposed flood waters concluded that there were no adverse reactions to the75% Kuparuk produced water/25% Beaufort seawater blend identified. The Meltwater team plans to inject 100% Beaufort seawater to minimize the turbidity of the fluid while conducting video logging. Although we do not have fluid sensitivity studies completed with 100% Beaufort seawater, the salinities of the Kuparuk produced water and the Beaufort seawater are similar, and no appreciable compatibility problems for either the Meltwater formation or its confining zones are expected. If injectors do incur damage from sea water injection the damage will be contained within a small radius of the wellbore due to the small volume of fluid required to complete the logging initiatives. Any damage to the near wellbore formation that may arise can be reversed by employing remedial treatments. Sundry Requests Attached you will find six Application for Sundry Approvals, one for each of the six wells that we are requesting approval to conduct video and Spectra-Flows logging. If you require any further information, please do not hesitate, I would be more than happy to address them for you. Thanks, ��e�izte/t4 Tommy Nenahlo Drill Site Petroleum Engineer 2T (Kuparuk&Tabasco)&2P (Meltwater) North Slope Operations& Development ConocoPhillips Alaska Anchorage: (907) 265-6934 Mobile: (720)273-2685 Enclosures: Applications for Sundry Approval (Quantity 6) Wellbore Schematics (Quantity 6) • • KUP 2P-420 COnocoP fillips Well Attributes .-. , , Max Angle&MD TD ,..„-, .n. i Wel!bore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) Alaska,Inc. 501032039100 MELTWATER INJ 54.00 6,860.01 6,860.0 Carlocof4lal�ps Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:WRDP Last WO: 37.30 11/2/2001 Well Confiq:-2P-420,12/5/2012 8:39:21 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod... End Date Last Tag:SLM 6,285.0 9/1/2010 Rev Reason:SET INJ VALVE ninam 12/5/2012 Casing 2,0 -._-- -- Casing Strings Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)...--String Wt.. String... String Top Thrd CONDUCTOR 16 15.062 28.0 108.0 108.0 62.50 H-40 WELD HANGER,26 � Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd SURFACE 7 5/8 6.875 27.9 2,351.4 2,351.3 29.70 L-80 BTCM Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd PRODUCTION 5 1/2 4.950 25.5 6,850.8 5,857.9 15.50 L-80 BTCM ! . :: r 5.5"x3.5"@ 6177' Tubing Strings _ Tubing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(ND)... String Wt... String... String Top Thrd TUBING 31/2 2.992 25.5 6,156.8 5,428.5 9.30 L-80 EUE-8rd Completion Details CONDUCTOR, ii, Top Depth Nomi... 28-108 (ND) Top Inc! Top(ftKB) (ftKB) (`) Item Description Comment ID(In) II25.5 25.5 -1.83 HANGER TUBING HANGER 3.500 VALVE,488 487.9 487.9 0.78 NIPPLE CAMCO DS NIPPLE 2.875 NIPPLE,488 6,094.6 5,388.8 50.34 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 IF6,110.6 5,399.0 50.49 NIPPLE CAMCO D NIPPLE 2.750 INIP 6,155.0 5,427.4 50.57 LOCATOR BAKER LOCATOR 2.980 6,155.8 5,427.9 50.56 SEAL BAKER GBH-22 SEAL ASSY 3.000 ,/ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Inc! Top(ftKB) (ftKB) 11 Description Comment Run Date ID(In) 488 487.9 0.78 VALVE 3.5"A-1 INJECTION VALVE ON 2.875"CS-LOCK(S/N: 11/14/2012 0.913 HRS-238,OAL=48") SURFACE, 28-2,351 6,720 5,780.0 53.05 PLUG CEMENT PLUG 11/2/2001 0.000 Perforations&Slots fir Shot Top(ND) Btm(ND) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment GAS LIFT, I 6,272 6,320 5,502.0 5,532.4 T-3,2P-420 12/23/2001 6.0 IPERF Powerjet Chgs,60 deg phase 6,045 6,324 6,352 5,535.0 5,553.1 T-3,2P-420 12/23/2001 6.0 IPERF Powerjet Chgs,60 deg phase 6,361 6,374 5,558.9 5,567.2 T-3,2P-420 12/22/2001 6.0 IPERF Powerjet Chgs,60 deg phase 6,386 6,422 5,574.8 5,597.6 T-3,2P-420 12/22/2001 6.0 IPERF Powerjet Chgs,60 deg phase INotes:General&Safes End Date Annotation SLEEVE,6,095 8/13/2005 NOTE:MILL OBSTRUCTION @ 6291'-6344'w/3.6"JUNK MILL,50+%OF PERFS STILL COVERED 11/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE,6,111 1 Il I• I --- A I LOCATOR, 6,155 SEAL,6,156 ' - kil IPERF, 6,272-6,320 - IPERF, 6,324-6,352 IPERF, 6,361.6,374 IPERF, Mandrel Details 6,386-6,422 l Top Depth Top ' Port (ND) Inc! OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... I1 6,045.1 5,357.0 49.90 CAMCO KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 9/1/2010 PLUG,6,720 Ilr PRODUCTION 5.5"x3.5"5 • A 6177,26-6,851 TD,6,860 Hunt, Jennifer L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, June 26, 2013 12:39 PM To: NSK Fieldwide Operations Supt Cc: Hunt, Jennifer L (DOA) Subject: RE: Meltwater SSSV Testing I missed that one... thanks.Transposed with 2P-419 PTD too. Here is updated corrected wells and PTD's. So a total of six wells. Well PTD 2P-447 203-154 2P-419 204-017 2P-434 203-153 2P-427 202-018 r 2P- 2P-420 201-1 ) 429 201-102 SCANNED 2014 Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: NSK Fieldwide Operations Supt [mailto:NSKFieldwideOperationsSupt @conocophillips.com] Sent: Wednesday, June 26, 2013 12:30 PM To: Schwartz, Guy L (DOA) Subject: RE: Meltwater SSSV Testing Guy, We also have well 2P-447 as a WAG injector. I don't have the PTD number handy, but I do have the API number— 501032046800. Thanks, Larry Larry Baker/Glynn Jones NSK Fieldwide Operations Superintendent N2072[c�ConocoPhillips.com 907-659-7042 Pager 659-7000 x604 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz©alaska.gov] Sent: Wednesday, June 26, 2013 10:59 AM To: NSK Fieldwide Operations Supt Cc: Regg, James B (DOA); Ferguson, Victoria L (DOA); Hunt, Jennifer L(DOA) Subject: [EXTERNAL]RE: Meltwater SSSV Testing Larry, 1 After further discussion and thought it would be best to reclassify the WAG injection wells on the Meltwater pad to GINJ (gas injector). The wells should be included in the upcoming SVS testing to be done in July. At some point in future if water is again available for injection on Meltwater the status can be reverted back to WAGIN. The wells in our database that need to have status changed from WAGIN to GINJ are: Well PTD 2P-419 203-154 2P-434 203-153 Pg77 202-018 2P-420 201-182) 2P-429 201-102 We will change status in our database today... Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: NSK Fieldwide Operations Supt [mailto:NSKFieldwideOperationsSuptconocophillips.com] Sent: Tuesday, June 25, 2013 4:35 PM To: Schwartz, Guy L (DOA) Subject: Meltwater SSSV Testing Guy, We talked several months ago about the well classification status of the Meltwater(DS-2P) injectors and whether they should remain as WAG injectors or if we should change the well classification to GINJ. At that time you replied that it was your preference to leave the well as a WAG well status even though it will stay on MI for an indefinite period. We are going to perform the SVS testing for DS-2P in July and I just wanted to verify that you still wanted the well classification to remain as WAG. Please confirm that DS-2P should remain classified as a WAG injector. As a SSSV test is not required for a WAG injector, we also ask you to please confirm that we are not required to perform a SSSV test or report SSSV testing for DS-2P during the July pad SVS testing. I look forward to hearing back from you soon. Please feel free to call me at 659-7042 if you have any questions. Thanks, Larry Larry Baker/Glynn Jones NSK Fieldwide Operations Superintendent N2072(a�ConocoPhillips.com 907-659-7042 Pager 659-7000 x604 2 Hunt, Jennifer L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, June 26, 2013 11:26 AM To: Hunt, Jennifer L (DOA) Subject: meltwater wells status change WAGIN to GINJ Put this in comments for 5 Meltwater wells: Well status change to GINJ: No injection water available on Meltwater pad for foreseeable future. Well needs to have SSSV tested every 6 months. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,June 26, 2013 10:59 AM To: 'NSK Fieldwide Operations Supt Cc: 'Regg,James B (DOA) (jim.regg @alaska.gov)'; Ferguson,Victoria L(DOR); Hunt,Jennifer L(DOA) Subject: RE: Meltwater SSSV Testing Larry, After further discussion and thought it would be best to reclassify the WAG injection wells on the Meltwater pad to GINJ (gas injector). The wells should be included in the upcoming SVS testing to be done in July. At some point in future if water is again available for injection on Meltwater the status can be reverted back to WAGIN. The wells in our database that need to have status changed from WAGIN to GINJ are: Well PTD 2P-419 203-154 2P-434 203-153 2P-427 202-018 2P-420 201-182) 2P-429 201-102 ,pHNED FEB 2 0 2014 We will change status in our database today... Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: NSK Fieldwide Operations Supt [mailto:NSKFieldvvic eOperationsSup[ y conocopt[iip.,.com] Sent: Tuesday, June 25, 2013 4:35 PM To: Schwartz, Guy L(DOA) Subject: Meltwater SSSV Testing Guy, We talked several months ago about the well classification status of the Meltwater(DS-2P) injectors and whether they should remain as WAG injectors or if we should change the well classification to GINJ. At that time you replied that it was your preference to leave the well as a WAG well status even though it will stay on MI for an indefinite period. We are going to perform the SVS testing for DS-2P in July and I just wanted to verify that you still wanted the well classification to remain as WAG. Please confirm that DS-2P should remain classified as a WAG injector. As a SSSV test is not required for a WAG injector, we also ask you to please confirm that we are not required to perform a SSSV test or report SSSV testing for DS-2P during the July pad SVS testing. I look forward to hearing back from you soon. Please feel free to call me at 659-7042 if you have any questions. Thanks, Larry Larry Baker/Glynn Jones NSK Fieldwide Operations Superintendent 1 Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139 @conocophillips.com] _ VSc. Sent: Thursday, January 27, 2011 9:09 AM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); Colombie, Jody J (DOA); NSK Prod Engr & Optimization Supv; NSK Fieldwide Operations Supt; Bradley, Stephen D Subject: FW: RE: Request for Approval Attachments: Kuparuk Gas Injector Flow back Volumes.xls Tom, Attached you will find the Kuparuk Gas Injector Flowback information per your request. .� Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. FEB 8 2011, Kuparuk Office: 907.659.7535 Kuparuk Pager: 659.7000; #924 CPAI Internal Mail: NSK -69 This email may contain confidential information. If you receive this e-mail in error ' lease notify the sender and delete this email immediately. From: Maunder, Thomas E (DOA) jmailto :tom.maunder@alaska..gov] Sent: Tuesday, January 25, 2011 9:09 AM To: NSK Prod Engr & Optimization Supv Subject: RE: Request for Approval Gary/Denise, Following up on my brief conversation with Gary the other day, could one of you provide some information with regard to the flowback of these WAG injectors while TAPS was unavailable. Please copy everyoned as before with your response. Thanks in advance, Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. CaII or message with any questions. 1/27/2011 Page 2 of 3 s • Tom Maunder, PE AOGCC X From: NSK Prod Engr & Optimization Supv fmailto :n2046(aconocophillips.comJ Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto_tom.maunder ©alaska.goy] Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC Q From: NSK Prod Engr & Optimization Supv [mailto n2046(aconocophills.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1 &2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D 1/27/2011 Page 3 of 3 • Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ilowback PTD# Adjacent PTD# Estimated Prod as Injector SI Producer (Mscfd) aP -420 201 -182 2P -422A 202 -067 4,500 a4P -447 203 -154 2P -448A 202 -005 2,000 , U-03 185 -006 2U -02 185 -005 3,500 S -09 202 -205 3S -08C 207 -163 7,500 3S -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/27/2011 2P -420 2P -447 3S -09 2P -420 2P -447 3S -09 PROD MTR- MTR- MTR- PROD MTR- MTR- MTR- PROD MTR- MTR- MTR - DATE -TIME HRS 2P- 420 -OIL 2P- 420 -H2O 2P- 420 - FORM_GAS HRS 2P -447 -OIL 2P- 447 -H2O 2P- 447 - FORM_GAS HRS 3S -09 -OIL 3S- 09 -H2O 3S- 09- PROD_GAS ii BBLS BBLS MSCF BBLS BBLS MSCF BBLS BBLS MSCF 01 /09/11 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 01/10/11 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 01/11/11 0.6 0.7 100.1 74.7 11.3 900.3 0.0 5975.3 10.8 2.3 865.9 01 /12/11 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 8.9 1.7 0.0 866.4 0.0 01/13/11 6.9 8.1 1250.6 1056.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 01 /14/11 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Totals 7.5 8.8 1350.7 1131.3 11.3 900.3 0.0 5975.3 19.7 3.9 0.0 1732.3 • Page 1 of 2 • • Maunder, Thomas E (DOA) From: Roby, David S (DOA) Sent: Monday, January 10, 2011 5:21 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: Request for Approval All, Seems like a reasonable plan to me. There shouldn't be any impacts to ultimate recovery as the volumes of gas that would be removed from these injectors should be negligible in the grand scheme of things, assuming the proration does not go on indefinitely. III' On a side note. Should we require, or at least strongly encourage, all operators to develop contingency plans that we can pre- approve to handle situations like this in the future so that they and us don't have to jump through a bunch of hoops to try to get something approved in a very short period of time? Dave Roby (907)793 -1232 A JAN 1 8 nil rom: Maunder, Thomas E (DOA) - ' t: Monday, January 10, 2011 4:38 PM To: . Prod Engr & Optimization Supv Cc: Foers - , Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: R . tequest for Approval Gary, I acknowledge your req t. Do you have any best estimate of when this could be needed? Will there be any modificati• of the pilot settings on the new producers "? Sundries will not be necessary. aving to ability to test is appropriate for allocation purposes. I have copied this to my colleague- o they may make necessary assessments. I do not have the authority for this alp. •val, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046 ' onocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; N ieldwide Operations Supt; CPF1 &2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if need ; to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so shout• gelp ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evol As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowbac o production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of - - 1/11/2011 • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mailto :n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval 1/11/2011 Page 2 of 3 Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ? lowback Adjacent Estimated Prod . .;as Injector PTD# SI Producer PTD# (Mscfd) —v. 4P -420 201 -182 2P -422A 202 -067 4,500 a;P -447 203 -154 2P -448A 202 -005 2,000 alU -03 185 -006 2U -02 185 -005 3,500 3S -09 202 -205 3S -08C 207 -163 7,500 - 9S -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/11/2011 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, September 03, 2010 1:56 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: RE: 2P-420 (PTD 201-182) Request to restart gas injection Tom, Thank you, I will let CPF2 know they can bring it back on injection. I didn't get anything about a new form, 1 will look it up on the web site. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~:: ~ ~' ~-~ 1 ~ j ~ ~'; From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, September 03, 2010 1:50 PM To: NSK Problem Well Supv Subject: RE: 2P-420 (PTD Z01-182) Request to restart gas injection Brent, I do not know of any reason that injection cannot be resumed. The MIT appears satisfactory. Did you get an email that there has been a form revision? It is available on the web site. I think additional columns for 45 minute and maybe 60 minutes have been added. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, September 03, 2010 12:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: 2P-420 (PTD 201-182) Request to restart gas injection Tom, Jim, Guy ConocoPhillips is requesting permission to restart injection on 2P-420 (PTD 201-182). Previously the well was shut in due to a failed MITIA. Slickline has worked on the well and a passing MITIA has been performed (see attached form). Currently there is not water injection capability to 2P pad, the request is to restart gas injection. Once the well has thermally stabilized, the North Slope inspectors will be contacted to schedule a witnessed MITIA. Please let me know if this would be acceptable. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/7/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phoebe.brooks@alaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: FIELD (UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 2P 09/01 /10 Watkins - HES Packer Pretest Init~l 15 Min. 30 Min. We11 2P-420 T In'. N TVD 5,428' Tubi 1,500 1,500 1,500 1,500 Interval O P.T.D. 2011820 T test P Test 1500 400 2,500 2,405 2,405 P!F P Notes: Diagnostic MITIA OA 240 380 300 300 Well T In'. TVD Tut>i Interval P.T.D. T test Test P/F Notes: OA Well T In . TVD Tub Interval P.T.D. T test Test Corsi P!F Notes: OA Well T In . TVD Tu ' Interval P.T.D. T test Test C PfF Notes: OA Well T In . TVD T Interval P.T.D. T test Test - Corsi P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas 1= Indusfial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Moridoring P =Standard Pressure Test R = IMemal Radioactive Tracer Survey A = Temperature Anomay survey D = Dfierential Temperature Test INTERVAL Cordes I = Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes} MIT Report Form BFL 11/27/07 KRU 2P-42009-01-10 (2).xls u MEMORANDUM TO: Jim Regg P.I. Supervisor X22 ~7~13~1p FROM: Bob Noble Petroleum Inspector L~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2P-420 KUPARUK RIV U MELT 2P-420 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. SuprvJ~~_ Comm Well Name: KUPARUK RIV U MELT 2P-420 Insp Num: mitRCN100809171522 Rel Insp Num: API Well Number: s0-103-20391-00-00 Inspector Name: Bob Noble Permit Number: 201-182-0 Inspection Date: 8/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2P-a2o ' Type Inj. ~ TVD sans IA Isso P.T.D 2ous2o~ TypeTest SPT Test psi Isoo pA 29I Interval aYRTST p~ F Tubing Soso Notes: Failed to pressure up after pumping 13 barrels ,- ~~ ~urt'r~'.Glfs~ d1o~~C~ ~ ~~~~le r Tuesday, August 10, 2010 Page 1 of 1 • ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] 1 Sent: Monday, August 09, 2010 1:32 PM ~~~ ~I~~l~o To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2P-420 PTD # 201-182 report of failed MITIA Attachments: 2P-420.pdf _ Jim,Tom,Guy, ~~.~ C~~S -~`J~C'l~rz Cr~cfe. ) Meltwater injector 2P-420 (PTD# 2014182) failed an MITIA on 8/8/10 as witnessed by Bob Noble. The well will be, shut in as soon as reasonably possible. T'f~e well will also added to the monthly injector report. Initial diagnosics will be performed with slickline to identify source of failure and repair if possible. Attached is a wellbore schematic and 90 day TIO plot. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 8/9/2010 KRU 2P-420 PTD 2011820 8-9-10 Till D..ooo»rno ph+ = CHC)KF 3000 2500 2000 n- 1500 1000 500 0 01-Jun-10 D1-Jul-10 01-Aug-1Q Date 200 150 a d 100 Y 0 t v 50 0 TIVO Plot - 2P~20 ~^-''~ ~ KUP ~ 2P-420 COtIOGU~~11~~Ip 5 1 Attributes An le 8 Ml) TD Wellbore APIAIWI Fie ld Name Well Status Prod/Inj Type Inc! (° ) MD (ftKB) Act Btm (flK8) It.a'~Kd''.~1 ^. /i 501032039100 MELTWATER INJ MI 54.00 6,860.01 6,860.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "'"" SSSV: NIPPLE LastWO: 37.30 11/2/2001 wen cony:-zP-42o 1r2i zgo91ro33o nM Schematic-A ctual Annotation Depth (flK8) End Date Annotation End Date Last Tag: 6 ,297.0 7/62007 Rev Reason: FORMAT UPDATE 1/2/2009 Casin Strin s String OD String ID Set Depth Set Depth (TVD) String Wt String ~- Casing Description (in) (in) Top (flK8) (flK8) (flK8) (IbsHt) Grade String Top Thrd CONDUCTOR i 6 15.062 0.0 108.0 108.0 62.50 H-40 WELD ~ ' SURFACE 75/ 8 6.875 0.0 2,351.0 2,350.9 29.70 L-80 BTCM coNDUCroR. PRODUCTION 51/ 2 4.950 0.0 156.0 6 5.428.0 15.50 L-80 BTCM 106 , I LINER 31 2 2.992 6,156.0 6,850.0 5,857.4 9.30 L-80 EUE8RD Tubin Strin s String OD String ID Set Depth Set Depth (ND) String Wt String _ ^ Tubing Description lin) (in) Top (ftKB) (ftKB) (flK8) (Ibc/ft) Grade String To Thrd NIPPLE, 488 ~ : TUBING 31/ 2 2.992 0.0 6,156.0 5,428.0 9.30 L-80 EUE8RD ,_E tc Other In Hole All Jewei :Tubin Run 8 Retrievable Fish e : 1 Top Depth (ND) lop Inc! ~ Top (flK8) (flK8) (°) Description Comment Run Date ID (in) suRFACE, ~ ~ 488 0 488 0 78 N 0 IPPLE CAMCO'DS' NIPPLE W2.875" PROFILE 11!2/2001 2.875 2,351 . . . 1 6,045.0 5,357.0 49.89 G AS LIFT CAMCO/KBG-2-9/1/OV/INT1.313//Comment: STA 1 722005 2.900 6,095.0 5,389.0 50.35 S LEEVE BAKER'CMU' SLIDING SLEEVE 71/2/2001 2.813 6,111.0 5,399.3 50.49 N IPPLE CAMCO'D' NIPPLE W/2.75 PROFILE 112/2001 2.750 6,155.0 5,427.4 50.57 L OCATOR XO LOCATOR 11/212001 2.980 6,156.0 5,428.0 50.56 S EAL BAKER GBH-22 SEAL ASSEMBLY 11/22001 3.000 - 6,720.0 5,780.0 53.05 P LUG CEMENT PLUGS 112/2001 0.000 GAS uFr• 6,045 [=~ perforations Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (flK8) (ftKB) Zone Date (ch^~ Type Comment 6,272.0 6,320.0 5,502.0 5,532.4 12232001 6.0 IPERF Powerjet Chgs, 60 deg phase r .~ ~ 6,324.0 6,352.0 5,535.0 5,553.1 12232001 6.0 IPERF Powerjet Chgs, 60 deg phase SLEEVE, 6,095 F~ .- 1 6,361.0 6,374.0 5,558.9 5,567.2 12/222001 6.0 IPERF Powerjet Chgs, 60 deg phase . , 6,386.0 6,422.0 5,574.8 5,597.6 12222001 6.0 IPERF Powerjet Chgs, 60 deg phase Notes: General 8 Safe End Data Annotation 8/132005 NOTE: MILL OBSTRUCTION @ 6291' -6344' w/3.6" JUNK MILL, 50+% OF PERFS STILL COVERED NIPPLE, 6,111 -- OCATOR, I ft F fti_-. 6,155 PRODUCTION, i, 6.156 ~ SEAL. 6,156 ~~ ~ IPERF, 6.272-6,320 - -.- IPERF, 6,324-6,352 _ IPERF, 6,361-fi,374 - IPERF, 6,386G,622 - PLUG, 6,720 I I LINER, 6,850 TD. 6,860 Page 1 of 2! h Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 10, 201010:09 AM To: 'NSK Problem Well Supv' Cc: Regg, James B (DOA) Subject: RE: 2P-420 PTD # 201-182 report of failed MITIA Brent, Jim and I discussed this and although we really don't want to specify the plot type, the jpeg style in the second message more immediately conveys the information. I had to do a tittle experimentation with printing options, but if I use the "full page fax' print in the wizard none of the information is cut off. So, it would be appreciated K you send future TIO plots using the jpeg formal Thanks for your help here. Call or message with any questions. Tom Maunder, PE AOGCC __ __ _ _ _ From: NSK Problem Well Supv [maiito:n1617@conocophillips.com] Sent: Tuesday, August 10, 2010 8:55 AM • - •• To: Maunder, Thomas E (DOA) Subject: RE: 2P-420 PTD # 201-182 report of failed MITIA Tom, Nere is a different 90 day TIO plot. Just for my reference, would you prefer this TIO plot as to the one previously sent? Brent Rogers/Martin Walters Problem Wells Supervisor ConowPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] SeM: Tuesday, August 10, 2010 8:13 AM To: NSK Problem Well Supv Subject: RE: 2P-420 PTD # 201-182 report of failed MITIA I opened the MIT sheet and can see that the OA is about 300 psi From: Maunder, Thomas E (DOA) Sent: Tuesday, August 10, 2010 8:03 AM To: 'NSK Problem Weil Supv' Subject: RE: 2P-420 PTD # 201-182 report of failed MITIA Morning Brent, Is 2P-420 also have elevated OA pressures due to the charging issue out there? Sort of difficult for me to sort out the different colors with light weight lines. Thanks, Tom From: NSK Problem Well Supv [maifto:n1617@conocophillips.com] Sent: Monday, August 09, 20101:32 PM To: Maunder, Thomas E (DOA); Regg, lames B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2P-420 PTD # 201-182 report of failed M1TIA Jim,Tom,Guy, Meltwater injector 2P-420 (PTD# 201-1$2) failed an MITIA on 8/8/10 es witnessed by Bob Noble. The well will be shut in as soon as reasonably possible. The well will also added to the monthly injector report. Initial diagnosics will be performed with slidcline to identify source of failure and repair if possible. Attached is a wellbore schematic and 90 day TIO plot. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 859-7224 Pager (907)659-7000 pgr. 909 8/10/2010 ~!'Yk1 lWYN~ ~~~ 3: !"4~~~L~~ 1 4 lb~.'+.~.~V~1 l~ ~i ~~I iLl tf 3000 3 . 3000 ~` [~ 0 . .3000. 3CIU[l 2700 3~~; .,, 3000. 200 • 2100 0. 0. CI . 0_ 0. 0. tl , • tl. 1800 1500 1200 900 600 300 0 ';z: K(1V-ZF'-~20C-POS SCRATCH 92 SCRATCH_92 SCRATCtI_92 SCRATCH 92 UF:ti(~~t Y F1' f ~3N FLOW TUBING CHOKE FLOW TUBING PRESSURE FLOW TUBING TEMP INNER Al11J131.U~ t't2E OUTER ANNULUS PRES P~e~ T~>~E ~~-t-u~-ra i~.s~. i : ,t 1 IIE I.ATFST ,;~,t~~? ?~~~~~~ ??????? ~?"l77?7 77?7?77 ??????? ~?????? 7???777 PREY WELL DRILLSITE WELL 2p 42U NEXT WELL FN"t`I2Y "1 Y E'E OPERATOR OPERATOR VERIFIED 3Y~TEM AUTO E1+1TRY BOTH YLi1~l S"1"~R-1` 'I'IMF: MINOR TIME 12-MAY-10 08:37 MAJOR TIME WEEK • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, August 09, 2010 1:32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2P~20 PTD # 201-182 report of failed MITIA Attachments: 2P-420.pdf Jim,TOm,Guy, Meltwater injector 2P-420 (PTD# 201-182) failed an MITIA on 8/8/10 as witnessed by Bob Noble. The well will be shut in as soon as reasonably possible. The well will also added to the monthly injector report. Initial diagnosics will be performed with slickline to identify source of failure and repair if possible. Attached is a wellbore schematic and 90 day TIO plot. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager (907)659-7000 pgr.909 T/UO Plot - 2P~20 3000 2500 2000 d 1500 1000 500 0 l\. ~- 200 •~~ d~ . 01-Jun-10 01-Jul-10 Date 01-Aug-10 150 a E as 100 d Y O t V 50 0 8/10/2010 MEMORANDUM . State of Alaska _ Alaska Oil and Gas Conservation CommissP TO: Jim Regg P.I. Supervisor -"/ ()f ""j-' I ~ êff 1) Xi l!lp DATE: Wednesday, August 30,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2P-420 KUPARUK RIV U MELT 2P-420 Src: Inspector C6~ 'JP\~ \ Reviewed By: P.I. SuprvSF>¡Z- Comm FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV U MELT 2P-420 API Well Number 50-103-20391-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060829 130709 Permit Number: 201-182-0 Inspection Date: 8/18/2006 Rei Insp N um Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2P-420 Type Inj. G TVD 5428 IA 0 1620 1610 1610 P.T. 2011820 TypeTest SPT Test psi 1500/ OA 300 350 320 320 Interval 4YRTST P/F P / Tubing 3380 3380 3360 3360 Notes 1.3 BBLS diesel pumped, I well house inspected; no exceptions noted, SCANNED SEP 0 82006 Wednesday, August 30, 2006 Page I of I e Conoc~illips Afaska e '\'.' 1'-, - '80 ~ ;>, 2· C J¡.....1~ u_ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 31 ¡~lfìtho!íage June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 -. . ~ J'"l £ .".,. /Þ."".v.-" ' \J:.~~ ~(.~W"'';µl' (. r t: ' Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, Royfi1l404B, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on May 05, 2006. Schlumberger Well Services mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner on May 18th, 19th and 31 S\ 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. Sincerely, \~.s~--d- A~ C::>6/~ 0 lð6 ~ Perry Klein ConocoPhillips Problem Well Supervisor Attachment 901-{ ~& f e e ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Well Name PTD# Vol. of cement Final top of Cement top um ed cement off date bbls ft Corrosion inhibitor/ sealant date 5/19/2006 · ConocJ:)hiiii ps Alaska ~i"')CC: ,.:'l? l-ø- .J ¡j ~~I''t, 'e· & Gu G¡i)î:lS, Anchor~ge P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 {)D j - Jgì~~ June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 f"'" 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, 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 18t\ 19th and 31 S\ 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. ConocoPhillips Problem Well Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Vol. of cement Final top of Cement top urn ed cement off date bbls ft Corrosion inhibitor/ sealant date 5/19/2006 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFich~\CvrPgs _ Inserts\Microfihn _ Marker.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 302-002/304-040 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/6/2004 Volume (bbls): Number of days disposal occurred Previous 9479 100 totals (bbls): 2004 I 1 st 3661 100 2004 I 2nd 0 0 2004 I 3rd 0 0 2004 14th 0 0 2005/1st 0 0 6. Permit to Drill Number: 7. Well Name: 8. API Number: 201-182 2P-420 50-103-20391-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ---' 150 9729* 20 4/26/2002 5/19/2002 2P-427, Heavenly 0 3761 4 2/27/2004 3/1/2004 2P-406 0 0 0 0 0 0 0 0 0 J 0 0 0 '-' Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth quarter. 12. Remarks and Approved Substances . .. . SCANNER, ,1\ R~ <': Descnptlon(s). *includes freeze protect volumes & LOT volumes and volumes from sundry 302-002 dated 1/15/200i . , ,L: hYK 1 8 2005 I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,~. Total Ending Volume (bbls): 13140 200 150 13490 Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader IN6 I KU(, IIUN6 ON Kt:Vt:K\.::It: \.::IIUt: rorm lU-4L,j Kev. LILUU4 24 r...r( (z. (63 Phone Number: (907) 265-6830 6UDmlt. In uupllcate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 100 150 9729* 20 4/26/2002 5/19/2002 2P-427, Heavenly 100 0 3761 4 2/27/2004 3/1/2004 2P-406 0 0 0 0 0 0 0 0 0 0 0 0 ~ 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): *includes freeze protect volumes & LOT volumes and volumes from sundry 302-002 dated 1/15/2002 SCANNED JAN 1 -12UD5 I hereby certify that the foregoing is true and correct to the best of my knowledge. r \ <--.J ( \ ~ 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG0 GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 302-002/304-040 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/6/2004 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 9479 2004/1st 3661 2004 / 2nd 0 2004 / 3rd 0 2004 / 4th 0 Total Ending Volume (bbls): 13140 200 150 13490 Step Rate Test D Signature: Date: Printed Name: Randy Thomas Kuparuk Drilling Team Leader Title: Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 201-182 2P-420 8. API Number: 50-103-20391-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~' 24 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \,(¡ 1O.r Phone Number: (907) 265-6830 Submit in Duplicate !~ Previous totals (bbls): 2004/1st 2004 / 2nd 2004 / 3rd 2004 / 4th ~ Total Ending Volume (bbls): Signature: Printed Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAG 0 GINJ 0 WINJ D WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 302-002/304-040 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/6/2004 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 201-182 2P-420 1. Operator: . ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 8. API Number: 50-103-20391-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 9479 100 150 9729* 20 4/26/2002 5/19/2002 2P-427 Heavenly 3661 100 0 3761 4 2/27/2004 3/1/2004 2P-406 0 0 0 0 0 0 0 0 0 0 13140 200 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): *includes freeze protect volumes & LOT volumes and volumes from sundry 302-002 dated 1/15/2002SCANNED NOV 04 I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Randy Thomas Cnrrn 1 n_A,)-:¡ CO" ')/')nnA 150 13490 Step Rate Test D Date: Title: Kuparuk Drilling Team Leader IN~T :lIIr.TI{)N~ {)f\I I:II::\I¡:::R~¡::: ~Jn¡::: 24 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 2004 \ ó (( c:;. (c C( Phone Number: (907) 265-6830 Submit in Duclicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG0 GíNJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 302-002 / 304-040 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/6/2004 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 201-182 2P-420 8. API Number: 50-103-20391-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: Previous 9479 100 150 9729* 20 4/26/2002 5/19/2002 2P-427, Heavenly totals (bbls): 2004 / 1 st 3661 100 0 3761 4 2/27/2004 3/1/2004 2P-406 2004 / 2nd 0 0 0 0 0 2004 / 3rd 2004 / 4th - Total Ending Report is due on the 20th Volume 13140 200 150 13490 24 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth quarter. 12. Remarks and Approved Substances Description(s): *includes freeze protect volumes & LOT volumes and volumes from sundry 302-002 dated 1/15/2002 I hereby certify that the foregoing is true and correct to the best of my knowledge. ~\~ Signature: Printed Name: Randy Thomas ::nrm 1 n-.I1"~ QC\I .,/.,1111.11 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 7 ("'8 fa 7 Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): *includes freeze protect volumes & LOT volumes and volumes from sundry 302-002 dated 1/15/2002 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ ~ ? Printed Name: ~"..A.) C"1...-.. ~""J' Title: 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation [2] or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic 0 Service [2] Development D Exploratory D 4b. Well Status: Oil 0 Gas 0 WAG[2] GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: Sb. Sundry approval date: 302-002 / 304-040 (h)(3) Other Commission approved substances (include descriptions in block 12) 2/6/2004 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 100 150 9729* 9479 20041 1st 3661 100 3761 0 2004 1 2nd 2004 1 3rd 2004 14th Total Ending Volume (bbls): 200 150 13490 13140 Step Rate Test 0 Date: ~~....l~ l-e----- L~",,-J Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 201-182 2P-420 8. API Number: 50-103-20391-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 20 4/26/2002 5/19/2002 2P-427, Heavenly 4 2/27/2004 3/1/2004 2P-406 24 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ~ /(6 160/ Phone Number: Z 6S- 6-6)0 Submit in Duplicate ( Note to File (" 2 P-420 (201-182...304-040) Kuparuk River Unit Meltwater Pool ConocoPhillips Alaska, Inc ConocoPhillips has made application to re-approve annular disposal for the subject well. Annular disposal had been previously approved 1/15/02 (302-002) for this well and a total of 9729 bbls has been disposed as of May 2002. CPA is not requesting to increase the allowable disposal volume. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No remarkable events were reported while drilling the surface hole of the well, although there was some tite hole experienced. --Surface casing was cemented to surface. Cement was not circulated and a top job was performed from 200'. A "hard tag" is reported with the 1" pipe. It is reported that the pipe was reciprocated and that lost returns was not experienced. --On the initial leak off test, 16.1 ppg EMW was reached after pumping 6 strokes. During the observation period, the pressure held steady. --The production hole was fitfully drilled to TO. Actual drilling went reasonably well, but numerous tool failures were experienced. Some lost circulation was experienced, as was "breathing" . --The 5-1/2' x 3-1/2" tapered casing string was run and successfully cemented. Minor lost returns were experienced, but were successfully treated with LCM and lowering the mud weight. --A subsequent injectivity test was done down the 7-5/8" x 5-1/2" annulus. The pressure smoothly increased to 550 psi where it breaks. This is 14.2 EMW. The open formations readily accepted fluid at 13.8 EMW. When pumping was stopped, the pressure dropped to 300 psi and held steady. This is similar to other Meltwater wells. --CPA provided a listing of all surface casing shoes within % mile of 2P-420. All wells have been examined in the cement calculation spreadsheet and no anomalies have been identified that would preclude granting CPA's request. The surface casing shoe of 2P-417 is less than 100' distant from 2P-420, it would be prudent to monitor the OA of 2P-417 while pumping into 2P-420. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request to reauthorize annular disposal for the subject well. A~ '111~ Tom Maunder, PE,. -, Sr. Petroleum En~iineer February 5, 2004 C:f"p. ~~~QE' If"',j it" E D'" -n ~ 2004 1~:J}\Vd''''\M~~'' ~'\"QI~.w r J~ ~~ ( Conoc~hillips ( Post Office Box 100360 Anchorage, Alaska 99510-0360 Philip Hayden Phone (907) 265-6481 Fax: (907) 265-1336 Email: philip.hayden@conocophillips.com February 4, 2004 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillin1! Waste on well 2P-420 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that 2P-420 be re-permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. This well had previously been permitted for annular injection with Sundry Number 302-002 effective 1/15/2002 and expired 1/15/2003. According to our records a total volume of 9729 bbls has been disposed of in the annulus of this well during the initial permit period. We would like to re-permit this well for annular disposal for a total volume of 35000 bbls. It is intended to begin annular disposal operations on 2P -420 approximatel yMarch 15, 2003. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Translnittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surtàce casing shoe) with Daily Drilling Report. 6. Production Casing Description 7. Production Casing Celnenting Report & Daily Drilling Report during cement job. 8. Formation LOT on 7-5/8" x 5-1/2" casing annulus with Daily Drilling Report. 9. Plan View of Existing Adjacent Wells/ '", 10. Details on al!)Vells within ~)nile of2P-420 at the surface casing shoe; 2P-451, 2P-441, 2P-438, 2P-434, 2P- 432(2P-422Á and 2P-417. V For wells 2P-441, 2P-422A and 2P-417 we make reference to our previous application for annular disposal for well 2P-422X dated 10/03/2003 while for well 2P-438 we make reference to our previous application for annular disposal for we1l2P-429 dated 12/02/2003. With reference to point (8) above, this deeper LOT occurred at a lower equivalent mud weight than the casing shoe test. Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. ,.. . If you have any questions or require further information, please contact Philip Hayden at 265-6481, or Randy Thomas at 265-6830. Sl,'ncere¿rlY' , P. Philip Hay n Drilling Engineer f~t:(=~EIVED Ft"1 0 5 2004 0 D I (' ! ~\ , A L "~" ~ ~ ~1 j ~", ~ . t' ", "" ~ \¡ . Alaska 011& Gas Con$" Commí;\sion Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown D D D ( 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: Suspend D Repair well D Pull Tubing D ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 28' RKB, 252' AMSL 8. Property Designation: ADL 373112/ L 32092 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 10548 5930 10548 Casing Length Size Structural Conductor 80' 16" Surface 2323 7 5/8 Intermediate Production 6128 5.5 Liner 694 3.5 Perforation Depth MD (ft): 6272-6422 Packers and SSSV Type: Baker GBH-22 seal assembly, Cameo OS nipple for SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: ( ~~~ t ~ D Annular Dispos.0 D Plug Perforations Perforate D Stimulate D Other D Variance Time Extension Perforate New Pool Re-enter Suspended Well 0 5. Permit to Drill Number: 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service 0 201-182 6. API Number: 50-103-20391-00 9. Well Name and Number: 2P-420 10. Field/Pools(s): Ku aruk River Field / Meltwater Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 5930 MD TVD Collapse Burst 108 2351 108 2351 6890 4790 5422 7000 4990 5853 10160 10530 Tubing Size: Tubing Grade: Tubing MD (ft): 3.5 L-80 6156 6156 6850 Perforation Depth TVD (ft): 5502 -5598 Packers and SSSV MD (ft): 3/15/2004 Date: 6156,488 13. Well Class after proposed work: Exploratory 0 Development D 15. Well Status after proposed work: oilD GasD WAG 0 GINJ D Service 0 Plugged 0 WINJ D Abandoned D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name R. Thomas -~ Signature Contact Philip Havden @ 265-6481 Title Kuparuk Team Leader Phone 265-6830 COMMISSION USE ONLY Date ¿ I ~ Ie.) f:, Conditions of approval: Notify Commission so that a representative may witness .. . REr'J=~\lF::'r) " . . Other: 'N~'\CL ù~ \f' +'-'r¿ VR~~3"n=;- 9~\~k C?~~ ët\>-l.\\,\ ,,:>~.lJ 'ü-,= ~~() \' '0\-" . . 'S'S~\-«c; .~~~,j~\g~cl~~~\ \~ð ~ I ,\O\~ \CJ'-~d'_J Subseque orm qui red ..., . ':).~ Plug IntegrityD BOP Test D Mechanical Integrity TestD Approve 1 3 200~ Sundry Number: 201~ 01-D Location Clearance 0 Alaska ŒI & Gmi ¡A n~, L-il!mi1ission Anchorage BY ORDER OF COMMISSIONER THE COMMISSION AnnuIJ:~ Jisposal Transmittal Form - ~.~ ..L 2P-420 AOGCC Re~ulations, 20 AAC 25.080 (b) 1 Desi~nation of the well or wells to receive drillin~ wastes: 2P-420 2 The depth to the base of freshwater aquifers and permafrost, if No Aquifers 1 Base Permafrost = +1- 1352' TVD RKB present. 3 A stratigraphic description of the interval exposed to the open From the 7-5/8" shoe to the cement top all that is open is annulus and other information sufficient to support a interbedded claystone, siltstone and shale with occasional commission finding that the waste will be confined and will minor non-hydrocarbon bearing sands. not come to the surface or contaminate freshwater. 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin~ waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum total volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate waste under (h)(3) of this section. 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 1956 psi. See attached calculation calculations showine: how this value was determined. pae:e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT 1 FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casing shoe. 11 Identification of the hydrocarbon zones, if any above the N/A depth to which the inner casine: is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or 2P-449, 2P-443, 2P-416, 2P-406 will be generated. 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why compliance would be imprudent. 16 Any additional data required by the commission to confirm N/A containment of drilling waste. Well Date 2P-420 2/3/2004 ; ; Co:) Co:) bl) = .~ U = = tr¡ ar) ( f Pressure Calculations for Annular Disposal TOC Est. @ 5,550' MD 5,036' TVD 4 1I2"Tbg 5 ,857 TVD Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas Gradient is Header Pressure 1,500 psi 12 ppg 0.4525 psi/ft 0.11 psi/ft 0 psi Maximum Fluid Densitv to Burst Surface Casine Pburst85% = PHydrostatic + P Applied - PFormation MW max 5,857 = ( 2,351 * 0.052 * MWmax ) + 1500 - (0.4525 * 2,351) = 44.3 ppg Surface Casine Strine Size Weight Grade PburstlOO% Pburst85% Depth of Shoe FIT/LOT @ Shoe FIT/LOT for Annulus Max Surf. Pressure 7.625 in 29.7 ppf L 80 6,890 psi 5,857 psi 2,351 ft 16 ppg 14.2 ppg 1,500 psi or 1,956 psi Maximum Fluid Densitv to Collapse 2nd Casine Strine PcollapSe85% = PHydrostatic + P Applied - PGasGradient - PHeader MW max 4,242 = ( 5,036 * 0.052 'i< MW max ) + 1,500 - ( 0.1100 * 5,036) - 0 Maximum Allowable Pressure at Surface Casine Shoe P max allowable = P max allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT P max allowable = ( 2,351 * .052 * 16 ) 1,956 psi 12.6 ppg 2nd Casine Strine Size Weight Grade P collapse 1 00% P collapse85% Top of Cement Gas Gradient Max Surf. Pressu Header Press 5.5 15.5 L 80 4,990 4,242 5,036 0.11 1,500 0 in ppf psi psi ft psi/ft psi psi , I ,6, SUlY3idiaJÌ" of PHilLIPS PET¡:pJlEUt',..1 C;()t',..1P.6Jf( TUBI~IG 21>420 (0~6156, API 501032039100 Well Type: IINJ Angle 'OJ TS: deo @ 003500, SSSV Type: Nipple Orig 111/2/2001 Angle @ TO 54 deg @ 6860 102992) Completion: Annular Fluid' LastW/O Rev Reason: Tag, set gauges by SURFACE ImO (0~2351 Reference Loo: Ref Log Date Last Update 9/30/2002 007.625 Last Tao: 6395 RKB TO 6860 ftKB Wt29.70) Last Tao Date: 9/29/2002 I Max Hole An91e 54 deg @ 6860 CasihqStrinQ.ALL Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16,000 0 108 108 62,50 H~40 WELD SURFACE 7,625 0 2351 2351 29,70 L-80 BTCM PRODUCTION 5,500 0 6156 5428 15,50 L-80 BTCM LINER 3,::'00 6156 6850 5857 9,30 L-80 EUE8RD rUBiNG ::;OOUCT ION Size Top I Bottom I TVD I Wt I Grade I Thread (0-6156 3,500 0 I 6156 I 5428 I 9,30 I L-80 I EUE8RD 005.500 Ft SPF Wt15,50) Interval TVD Zone Status Date Type Comment 6272 - 6320 5502 5533 48 6 12/23/2001 IPERF Powe~etChgs,60deg phase 6324 6352 5535 5553 28 6 12/23/2001 IPERF Powe~etChgs,60deg phase 6361-6374 5559 - 5567 13 6 12/22/2001 IPERF Powe~etChgs,60deg phase 6386 - 6422 5575 - 5598 36 6 12/22/2001 IPERF Powerjet Chgs, 60 deg SLEEVE phase ¡Ga:Liff (60956096 St MD TVD Man Man V Mfr I V T~I Latch I Port I TRQ I Date I Vlv 004.500) Mfr Tvpe Run Cmnt 1 6045 5357 CAMCO KBG-2-9 I DMY 1,0 I BTM I 0000 I 0 P/13/20011 A.....in :At<' ¡¡::\M¡:: '¥ Depth TVD Tvpe Description ID 488 488 NIP CAMCO 'OS' NIPPLE W/2875" PROFILE 2,875 6095 5389 SLEEVE BAKER 'CMU' SLIDING SLEEVE 2,813 6111 5399 NIP CAMCO '0' NIPPLE W/2,75 PROFILE 2.750 6111 5399 GAUGES SET DUAL SPARTEK GAGUES ON BOMP HANGER SET 9/29/2002 0000 6155 5427 LOCATOR XO LOCATOR 2,980 r,IP 6156 5428 SEAL BAKER GBH-22 SEAL ASSEMBLY 3.000 (611'~6112 6720 5780 PLUG CEMENT PLUGS 0000 003.750) SEAL (6156-6157 004000) LINER (6156-6850 003.500 WIS.?;]) Perf - (62n6320) - Perf - (6324-6352) - - Perf - (6361~6374) - - Pel'! (6386-6422) - ( Casi ng Detail 7 5/8" surface casing { ( PHilliPS Alaska, Inc. WELL: 2P-420 DATE: 9/17/01 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LDS = 27.90. TOPS Above Rotary 6.701 75/8" Landing Joint (35.20 total) RKB to LR 27.90 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.85 27.90 30.75 30.75 jts 3-55 75/8",29.7# L-80 BTCM 2232.01 30.75 Gemeco Float Collar 1.33 2262.76 jts 1-2 7 5/8", 29.7# L-80 BTCM 85.82 2264.09 Gemeco Float Shoe 1.51 2349.91 BTM OF SHOE @-----»»> 2351.42 TO 9 7/811 Hole 23581 Csg Hanger goes in the top of Joint # 55 12 TOTAL, Gemeco Bow Spring Centralizers - 3 Stop Rings 3- Centralizers in center of jts.1, 2 & 3 over stop rings 9 - Centralizers over collars of jts,4-12 ** Fill using IIFranks" fill tool - Remove tool on Joint before Hanger ** Baker Lok all connections from the Top'of FC down ** Monitor returns closely ** Remove air from slips for first 10 jts ## Torque first 10 and average-Torque to AVG - Watch Diamonds Remarks: String Weights with Blocks: 96k Up, 94k Dn, 34k TD & Blocks. Ran 55 joints of casing. Drifted casing with 6.750/1 plastic rabbit. Use Jet Lube Lead free thread compound on all connections. Doyon 141 Drilling Supervisor: Dearl W. Gladden Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Prima 9.625 (in) 2,351 (ft) 10/18/2001 Surface Casing 7.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Hole Size: sa TMD: (ft) sa Date: sa Type: Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Steven Doughten Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Cmtd. Csg: Pipe Movement: Reciprocating Type: Cement Casing Volume Excess %: 2.50 Meas. From: Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 252 (gpm) Mud Circ Press: 400 (psi) Start Mix Cmt: 14:48 Start Slurry Displ: : Start Displ: 16:02 End Pumping: 16:25 End Pump Date: 10/19/2001 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.00 (bbl/min) Y 550 (psi) 1,050 (psi) 5 (min) Y Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: Scale Slurry Data Fluid Type: LEAD Slurry InteNal: (ft) Water Source: Description: AS Lite Class: G To: 1,474.00 (ft) Cmt Vol: 206.0 (bbl) Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Slurry Vol:260 (sk) Water Vol: 128.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 2/3/2004 11:13:45 AM Li uidConc; Units Slurry Data Fluid Type: TAIL Slurry Interval: (ft) Water Source: Rig To: (ft) Description: LiteCRETE Cmt Vol: 64.4 (bbl) Slurry Vol:140 (sk) Class: Density: 12.00 (ppg) Yield: 2.40 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: TAl L Mix Water: (gal) Foam Job: N Test Data Thickening Time: 3.42 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 16.00 (ppge) Tool: N Open Hole: 37 (ft) Hrs Before Test: Liner Lap: Pas Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: No CMT to surface TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Y Number of Remedial Squeezes: 1 Printed: 2/3/2004 11: 13:45 AM Pumped 5 bbl GW100 @ 8.4 ppg , Test Lines, 35 bbls GW1 00 @ 8.4 ppg , Drop Bttm Plug, 30 Bbls Mudpush XL @ 10.5 (wI Dye) , 207 bbls Lead GMT 10.7ppg wI D124 50.00%, D053 30.00%, D079 1.5%, S001 1.5%, D046 .600%, D065 .500%, 61 bbls Tail GMT@ 12.00ppg wI D962 Gem PLUS Blend, D046 0.200 %, D065 1.00%, D079 1.00% (Note )Bow Spring Gentrilizers used on first 12 joints. There are 3 on stop rings in the middle of joints 1,2,&3 . They are run across collars on jts 3 thru 12 ,o,oNote,o,o Preformed Top Job. Ran 200' 1" Hyd Tbg down along side 7 5/8" csg. Flushed by pumping 88 bbl h20 (8.4+ h20 to surface) - GMT by pumping 151 bbls 10.7 ppg lead GMT. Had 10.7+ GMT to surface Printed: 2/3/2004 11: 13:45 AM (' ii' ... ..... .... .... ...... ... ...',' ... .. ... ,'.. ...., .. ... ' ...... .... .. ..... .. ... .. .. .> ... ... .... ... ... ...... > . .....cxL.o.l ..... _..0...'.' .1 .... ... I___c,' .r"è1gl;:ll...UI ... ..Inc. I . ..... .. ... ....,' .>...,.- .C.. ft-.:I...._uoo ..... .... .8. .. .. .... ... ..,UII,..... ......I~...~.I""_.L.. . ..' .. .. ...... ....... ....... .......... .. ..,. . . .., ... ., ... .. ... ,,'... .,'. ........ WELL NAME I JOB NUMBER I EVENT CODE 24 HRS PROG TMD I TVD DFS I REPT ~O. DATE 2P-420 ODR 2,358.0 2,358.0 7.00 10/18/2001 SUPERVISOR RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD IDAILYTAN~ CUM. TANG Dearl W. Gladden Dovon 141 Meltwater 6,741.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD CUM INTANG WI MUD N/U BOPs 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD N/U BOPs - Test BOPs - P/U BHA #2 - Drill Out 10/18/2001 227,998 639,341 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP I LEAKOFF AFE AUTH. AK0203 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 10/16/2001 2,295.70 0.260 308.430 7.625 (in) @ 2.351.0 (ft) (in) @ (ft) DE~SITY(ppg) 9.80 Ippl IECD I MUD DATAl. DAILY COST I 0 CUM COST 0 Fvl PWvp I GELS WUHTHP . . FCrr.SOL . ...OIUWAT %~arïdIMBT. .1. ... Ph/pM I Pf/Mf.. ..1. ... CI I Ca t H2S ,'14IMi: ES 46 14/19 I 8112 6.21 I I n.o I 9.41 I 1870 I I I I I I>. ........ ........... .>.... . ...... ... ..... .' ,.., ..,' . OPERATIONS SUMMARY .... . ... .. ......) ... ..... ',,'. ". ... ,. " ,, ', .., FROM. TO .. HOURS CODE... TROUBLE ... sUe> PHÂSE I' ., '." .." ." .. . . ... .. ... . DESCRIPTION .,... )....,...<',.....,'... ..... ..'.,. 00:00 01:00 1.00 DRILL P TRIP SURFAC Con't TOH 01:00 03:00 2.00 DRILL P PULD SURFAC UD BHA - UD 3 flex wt DCs - Dn Load MWD & UD same. Brk Bit - UD Motor 03:00 04:30 1.50 CASE P SFTY SURFAC R/U to run 7 5/8"29.7# L-80 BTCM csg 04:30 05:00 0.50 DRILL P SFTY SURFAC Hold PJSM with crew & GBR csg crew 05:00 08:30 3.50 CASE P RUNC SURFAC Run Csg - Hit Bridge @ 2288' ( ck float equip) 08:30 10:45 2.25 CASE P RUNC SURFAC Wash from 2288' to 2358' (BTTM) 10:45 13:30 2.75 CASE P CIRC SURFAC Circu & Condition hole thru Franks Fill tool - Recip csg 10'-12' - Pump @ 6 bpm @ 200 psi - Hole clean no excess drag - Up wt 96K , Dn wt 94K 13:30 14:00 0.50 CASE P CIRC SURFAC RID Franks Fill Tool - R/U Schlum CMT head (Plugs Loaded) 14:00 15:00 1.00 CEMENT F CIRC SURFAC Circu & Prime Up CMT unit 15:00 16:30 1.50 CEMENT F PUMP SURFAC CMT Csg- Shoe @ 2351' - Pump 5 bbl CW100 - Test CMT lines to 3500 psi- Con't pump 35 bbls CW1 00 - Drop Bttm Plug - Pump 30 bbl Mudpush XL @ 10.5 ppg (w'Red Dye) - 207 bbls Lead CMT @ 10.7 ppg - 56 bbls Tail CMT @ 12 ppg - Drop Top plug - Pump 5 bbls water - Switch over to Rig for displacement - Rig pumping mud displace wI 981 stks (99.08 bbls) Bumped plug wI 500 psi. Pumped to 1000psi - Shut in for 5 min - Bleed off - Floats Held **** Note** NO CMT TO SURFACE *** CIP 16:30 hrs 16:30 17:30 1.00 CASE P NUND SURFAC RID Schlum - UD Landing jt - UD Csg Tools 17:30 18:30 1.00 CASE P NUND SURFAC N/D Riser & Flow Lines 18:30 19:30 1.00 CASE P NUND SURFAC Flush & Clean Diverter System 19:30 21:30 2.00 CASE P NUND SURFAC N/D Diverter System and remove from cellar 21:30 22:00 0.50 CASE P SFTY PROD PJSM for CMT Top Job 22:00 00:00 2.00 CASE Np OTHR PROD M/U 1" Hydril tbg and run in to 16" X 7 5/8" Ann to 200' "Hard Bttm" - R/U to circu 24 HR SUMMARY: Run Csg - Cmt Csg - Preform Top Job .. ... ... ....... ......... .. .. '.. ' '., .." > .. . . . ".... PERS.ONNEl.DATÄ. .... ..... ..... .. ... ..., .... ',' ,. >.. ......... .... .......... ..'..,....< ,... ". ".",'..,.,,:, ".: .',,' ". ' .. . ..... ".", .,'.. ,', ,".' ,".'" ' ,',. ,:......... .,' ............... SERV.ICE.. .. ,.......... ... .. NO. HOljRS ..... ...ë()M~.ðtNY> .. .. ... .. I. .......... Se:RVICE. .. .......... .,. ... NO... '. HOURS. ... ... ÇOMPANY .. Doyon 28 Service Personnel 14 ConocoPhillips Company 1 DUS 5 .. ... .'....... ........: .. ..,., .., ....< .. ..> MATERIAL.S ICON8UMP110N... ....... .. > . ..','.'...,. .."..,... ...'. . "....., . .. . ,>, .. ",.',. , " . .. ....ITEIIII... . ,', . .UNITS ... ..... .,. USAGE . . . . ON HAND .. ..L ... .rrt:M. .,.'... ... :" ..UNITS ...... USAGi: .,. I......... ON H.AND. ...» . .. .. Rig Fuel gals 1,358 8,278 Rig Water bbls 470 70 Camp fuel gals 84 2,648 Camp Potable Wate bbls 101 -81 Printed: 2/3/2004 11: 16:42 AM RESERVOIR NAME 2P-417 DS 4 G&I 3R-11 2P-420 2P-420 2P-420 Printed: 2/3/2004 11 :16:42 AM -. ........ ~~II<lnc. .. ....,~.,< , .r\_=I. ,... ..... .<-... . .... ..,UII' .1-'11111119. ..1"":".. ... .... . .... ..\ IJOB NUMBER ¡EVENT CODE 124 HRS PROG TMD I TVD IDFS 2P-420 ODR 2,358.0 I 2,358.0 8.00 SUPERVISOR I RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG Dearl W. Gladden Dovon 141 Meltwater 6,741.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Preform LOT 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 10/19/2001 160,504 LEAKOFF AFE 16.00 , (i .... . ,.... WELL NAME , ... 24 HR FORECAST LITHOLOGY Preform LOT - Drlg JAR HRS OF SERVICE I BHA HRS SINCE INSP INC AZIM ¡LAST CASING 0.260 308.430 7.625 (in) @ LAST SURVEY: DATE TMD 10/16/2001 2,295.70 NEXT CASING 2,351.0 (ft) 5.500 (in) @ , , , ......... ........ .. IREPT NO. I DATE 9 110/19/2001 I CUM. TANGO CUM INTANG WI MUD 0 CUM COST WI MUD 799,845 AUTH. AK0203 LAST BOP PRES TEST 6741.0 (ft) 10/19/2001 ICUMCOST 0 CII cal H2S LlMEIES I I 1 I OENSITY(ppg) 10.00 IpP Ecol ¡MUD DATA OAILYCOST 1 0 FVPV¡YPGELS WL/HTfiP I FCrr~S()L I OIUWAT I %SàndIMBT Ph/pM 1 Pf/Mfl 60 16/27 9/12 5.01 I I I 16.0 1 9.3/ 1 1870 I BHAIHOL.ECONDITIONS ,.. ,.>< . .... ... < . STRING WT.ON ... ... ..1. .. STRINGWT.' ROT. .1.'....' TORQUE / UNITS 1 1 ; NOJTS . 1 1 1 1 1 1 1 3 1 6 1 29 . .. .,.. , . ,.... .. ,.. . ..' .. .... . . ... ." .. ,... ..... ..,.<... ....> ...8ITS .... ...... .'.... ...... ..,. ... ,... .. .. ... ... . ...... BIT/RUN SIZE.,.. MÅNl.jI::.. .ilTYPE ISERIÄÎ.NO. .,... JETSØRTFA .!bEPTHINDATEIN .. I:O",O;'L~a~G..ø-.R .'...... 2 I 1 6.750 HUGHES-CHR I dp0283 11904074 13/13/13/1311 2,358.0 10/19/200110-32,484-CT-A-0-I-JD-D1 ... ..,.. ...,......< .. . .,. .... ....,..'....' .....' .......... . ..... .,BITÖPERATïöNS ..... .....,. ... ,....., ,.'.'.., ,..'. ..... ,....... .... .........., ..BITI~UN ..' I.. woe. .1. .. .åPM ..., ...GPM .: ¡PRESS .'.p arr. .1 <.....HRS ..... 1,24HrDIS1' '124l-1rR()pIC~M ti~s I c:ÚMQ~PTHJ ëUM ROP ,.......... ............' '.... '... .... ..'.. .......' ....... .. ..,....'..OPERA"tIONSSUMMARY ..,.......,..... ..'........'...'...... ,...:.'..' '..'.."'."..... ... ..,.... ,.... \ ... F.ROM TO HOÜRS POD!: . tROUBLE' . SUB. PHASE: . <.. ....", ., ........ ... ..DESCRIPTIÓN ..' ..'. ... .) ..,...,.. ....'....'. 00:00 03:00 3.00 CEMENT ~ ~H OTHR SURFAC Con't CMT Top Job(Have 1" Hyd Tbg run to 200') - Flush Ann pumping 88 bbls H2O - CMT pumping 151 bbls 10.7 ppg Lead - Rate 2 bpm @ 600psi - Flush and UD Tbg SURFAC RID and blowout all CMT equip - Clean all Top Job tools from floor PROD Install & Orient FMC Gen V Csg head - Test 1000psi - Hold 10 min PROD N/U BOPs - C/O Bttm pipe rams to 4" - Modify flow riser PROD Install test plug - R/U Test lines PROD Test BOPs & Choke Manif - Test 250psi 15000 psi high - Test Ann 250/3500 psi- Test Gas detectors - AOGCC rep Lou Grimaldi witnessed test BOPE PROD Install Wear bushing - RILDS PULD PROD P/U BHA #2 - Orient & Program MWD - Load RA sources TRIP PROD TIH wI SWDP BIiANØ.1 2 I... ,. . ...\ .. > <.., EJHA WT.BELOW .J~Rs.1 . STRING VIT. ÙÞ.. .: I . .<., .<.. ..,. .. ItEI\IIOESþRIP1'1()N........ ...... .'..., .....'.. ,..... ...... Bit Mud Motor Stabilizer - Non Mag Crossover Sub - Bottom Hole Orienting LWD MWD Drill Pipe - Non-Mag 4 Comp Serv Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt 03:00 03:30 03:30 05:00 05:00 11 :00 11 :00 12:00 12:00 17:30 CEMENT ~ ~H WELLSR F WELLSR F WELCTL F WELCTL F OTHR NUND NUND BOPE BOPE 0.50 1.50 6.00 1.00 5.50 17:30 18:00 0.50 WELCTL F 18:00 22:00 4.00 DRILL P 22:00 22:30 0.50 DRILL P ... ,.. . LENGTH 0.90 30.98 5.70 3.00 2.16 34.51 22.66 92.33 3.64 184.84 30.01 893.69 O.D. 6.750 4.750 4.750 4.750 4.750 4.750 4.750 4.750 4.750 4.880 5.250 4.880 .'... .".. to." 1.500 1.500 2.250 2.500 2.500 2.500 2.500 2.250 2.250 2.500 2.250 2.500 . ..1 .. BIT NO.> I 2 'I . B, H,A", L,,', ÉNGTH< ,. <, "",', ,.', .' < 1 1 ,304.42 ...... CONN SIZE CONN TYPE F Printed: 2/3/2004 11:17:21 AM FROM TO 22:30 23:00 23:00 23:30 23:30 00:00 . TROUBLE SUB DEOT TRIP CIRC OPERATIONS SUMMARY PHASE PROD Shallow Test Smart Tools PROD TIH - Tag @ 2262' PROD Circu out Contaminated Mud for Csg Test 24 HR SUMMARY: Run Csg - Cmt Csg - Preform Top Job RESERVOIR NAME , - 2P-417 DS 4 G&I 3R-11 2P-420 2P-420 2P-420 Printed: 2/3/2004 11: 17:21 AM CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P-420 Date: 10/20/2001 Supervisor: Dearl W, Gladden Reason(s) for test: ~ Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 75/8" 29,7# L-80 BTC-M Casing Setting Depth: 2,351' TMD Hole Depth: 2,388' TMD Mud Weight: 10,0 ppg Length of Open Hole Section: 37' ....... : ,......... #= 1/ : ......... ............... ~_II . , ..... M ......... .......... ........ t- 8 , 'II I If" -~ ~:::~EAK'OFF TEST Ii I -~ II" I CASING TEST =,~= I/' ' i=::~OT SHUT IN TIME -;- CASING TEST SHUT IN TIME -~ I -~ J ' . 500 p;; p;; 200 p;; " , 'Co , STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE SHUT IN TIME CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY .. ......., <.,.. . "11 .ë-- -':1- <. > II _..-':.... .' _. ~~.1 ...> ..,.~I<IJ._.''''''~ ..." ... .. ... '.,. ....' . ,.,,'..' .....' '.,. '. "'" .".. ." .'.'" .<' .<.. .'.' ,.. I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD IDFS I REPT NO. DATE 2P-420 I ODR 1 370.0 2,728.0 I 2,727.0 9.00 I 10' 10/20/2001 SUPERVISOR IRIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG CUM. TANG Dearl W. Gladden Doyon 141 Meltwater 6,741.0 0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD Run Reverse Basket 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Make C/O run w/ Globe Reverse Bsk - DrlQ - Wiper Trip 10/20/2001 120,468 920,313 LITHOLOGY JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAKOFF AFE AUTH. I 16.00 AK0203 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING LAST BOP PRES TEST 10/20/2001 2,946.40 10.720 101.710 I 7.625 (in) @ 2,351.0 (ft) 5.500 (in) @ 6741.0 (ft) 10/19/2001 DENSITY(ppg) 10.00 I PP ECDI INlUD CÄTA!DAILYCOST 1 0 I CUM COST 0 FV PVIYP GELS' WUHTHP FCIT.SOL ÖIIJ'NÄT ".1' %SantflMBT.1 PhlPIIA . .,' ,'1..'. 'PflMf CI.. J c:ä .. J ,. H2$ . .¡LIME I.ES 54 15/27 1 7/12 4.7/ / / I /6.0 9.3/ /870 I I I I .BHANO; 3 I L" "".. ..<:,.. ,..:...., ',. ". '.' BfiÄI HOLECONDITIÔNSL< '... .". ""', "',. ". ,.IBl'fNO. BIiAWT.BELpWJÂRS F' ,.STFtINGWT.UP "STRINGW'1'.DN "'1< StFtINGWf.Rþt(I'."TOFtQUi:IUNlrs ".' I.BHAÚ~~Gt~. ".". I I I 1,212.64 .'.. ..'. <: ...> '.'. "...:' trEMDE$CRIP1ÏON ...... . .'.. ... ., < .:.. ,. . " NOJ,.S.. ,,<LENGTH .. '.. 'Ö.D. ,... . '..., tD."..... I CONN.SIZE CONN. TYPE Venturi Junk Basket 1 6.62 4.750 2.500 Sub - Float 1 1.51 4.750 2.500 Drill Pipe - Non-Mag 4 Comp Serv 3 92.33 4.750 2.250 Crossover 1 3.64 4.750 2.250 Drill Pipe - Heavy Wgt 6 184.84 4.880 2.500 Jars 1 30.01 5.250 2.250 Drill Pipe - Heavy Wgt 29 893.69 4.880 2.500 (' .'.' '."'" ."'."'<'.."(,....,,:.'" ,.,.,...,<" ..., "." , """'.. ...' ".. ...,.., ....,' WELL NAME <. .<'...." '.' ." , , ",,'.' , ''',' ... .iI, .- a.~o " ."H '..".' ., '..,.'....., "'.'.'.""'.'..' ..,' ....."'," .,."", ... '"BITS. ,.<\« ',. .... .... "..'...".. '. .' ......... """.'" ..' "'.....,.'. ,BIT/RUN< ".SIZE 1 <' MANÜF. ,T'fPE SEFUÂLNO; T ,. '.' JE,.S ORTFA ..'. ,.1 DEP,.HIN D~1'E IN '. I, I-O.D.L.B~G.O-R "'," ..' 2/ 1 6.750 1 HUGHES-CHR Idp0283 /1904074 I 13/13/13/13// I 2,358.0 10/19/2001 0-32,484-CT-A-0-I-JD-D" ""'.','... ."..'..'.'."'.'..., " ,. '.' ...'.'........',.< ........'...BITÖPERATIONS'. .."'.,.' '. ...""..' ....'. .,'.,. "..'. "..".".,..' ,. ... ~ '{¡ÄUN'" ,.., Wó~f¡I,ÄPM IGPM PRES$fPBIJIHRS 24IirPISt¡.24HfROpICLÏMI-IRSIC:UMDEP"HCUMROP I'¡.' .". :" .. "'.. .,...., ...., '."'¡. ...' .,. '.'.' ...'.. ".. "'... '.."".,,,". .."".", "'.,. ".'.. 'SlJRVEYDÄTA ", ,.,. ,'.. '., "..<' ,...."..,' ,.,.',.. .., .'.. ' ",..,.'.. ..., '. '. ,.> .' IM.í).'INCl... . AZII\IIUTH. .. TN.D; , N/~~Ut,,1 ElVfCIjM.SEpnON ..¡.iVI.D. .... INþL~ '..' ..AZINiU1'H . "TN.p.. N/SCUM ElWCUMSEC,.ION. 2,371.30 0.440 340.200 2,371.15 -2.98 -5.37 -4.52 2,754.76 6.240 86.600 2,753.86 -3.43 13.14 13.58 2,467.70 0.440 0.810 2,467.55 -2.26 -5.49 -4.80 2,848.90 8.960 98.550 2,847.17 -4.21 25.50 25.77 2,563.20 3.080 103.120 2,563.01 -2.48 -2.99 -2.32 2,946.40 10.720 101.710 2,943.23 -7.18 41.89 42.40 2,644.60 4.830 95.740 2,644.21 -3.32 2.55 3.26 ",/,>,.)'<>< . '...'. "..." '.. ...'.,' "., FROM "'TO' .. HOURS. CODE" TROUBL.E;..... SUB... 00:00 02:00 2.00 WELLSR F DEOT 02:00 05:00 3.00 DRILL P DRLG 05:00 06:00 1.00 DRILL P CIRC 06:00 06:30 0.50 DRILL P FIT 06:30 15:30 9.00 DRILL P DRLG 15:30 16:00 0.50 DRILL Np DH CIRC 16:00 18:00 2.00 DRILL Np DH TRIP 18:00 19:30 1.50 DRILL Np DH TRIP 19:30 20:00 0.50 DRILL Np EOIP OTHR F C>Þ.ERATIONSSÜMMARY ..<... .,.,. '. "., ,.",.., ..'...' ...,........ ,.,.. ..."....,.> .. PH~SE ...... .... '...< .. > <.. .. [)ESCRIP'T1ÒN .. . ' .. .... .. "<',..,,, PROD Test 7 5/8" Csg to 2500 psi on chart - Hold 30 min PROD Drlg FC ,CMT & FS - New hole 2358' to 2588' MD PROD Circu & Condition - Circu out CMT contaminated mud PROD Preform FIT to 16.0 EMW - W/10.0 ppg mud @ 2388' MD -Pump to 745 psi surface pressure Dir Drlg 2388' to 2728' MD (2726' TVD) - MWD Failed Circu hole clean TOH Remove RA Sources - Dn Load MWD - Inspect Bit "Bit has extensive damage" PROD Evaluate Bit damage - Discuss options with Team Leader PROD PROD PROD PROD Printed: 2/3/2004 11 :18:04 AM ( l .......... ,c..i .....c ......... '...... .cc.............c.............c.c ,.cC... ... --::c .................... ..,..... .... c.. .., ..... .'.<c .. ...,.. .,c. ,., <p~nA? ."...c..._I~'! II~, ~ .1". 'w ..c..f .cl" I.. LI~ ... ._- c.. ......,.. 'c' c. ,.c - . - --- ... .---... ,_. .....c..". ' , .1:11""'11 It. c ....c......c").. ... ....... .....C.. -... ...:'~' .'.~.;J.'Vt'''I.. ' ..c, ,.c c.... .. ,.. ... ... ,.. , " WELL NAME I JOB NUMBER EVENT CODE 24 HRS PROG TMD ITVD DFS I REPT NO. DATE 2P-420 ODR 370.0 2,728.0 2,727.0 9.00 10 10/20/2001 ... ..c> OPERATIONS SUMMARY FROM TO HOURS CODE !TROUBLE SUB ! PHASE DESCRIPTION 20:00 20:30 0.50 DRILL Np EOIP PULD PROD Lay dn failed MWD ( failure found to be coupling plud between SDN & MPR) 20:30 21:30 1.00 DRILL Np EOIP PULD PROD UD motor, stab & remaining MWD 21:30 23:30 2.00 WAlTON N ¡EOIP EOIP PRQD Waiting on Globe Reverse Basket & BTC operator 23:30 00:00 0.50 FISH Np EOIP MILL PROD P/U Globe Reverse Junk Basket 24 HR SUMMARY: Test Csg - Drill out 30' new hole - Preform FIT - Drlg 'c ' .... ".'" 'C',.' ".,c ,"'C ,,'c. c.c.PERSONNELDATA C' ". , ...c "" c, '". '. , C,' .' <'. ., '.", '" : '".cC,. cc.. "..... COMPAfJY c....." . ..cc ..., ... ,... . SERVICE.. .... .... .. ..NO.c .c. ' HOURS .... ..... CqMPANY ,. c .c ..,... SERVICE C.c ..NP; ...... HOURS. 'c " c' ., Doyon 29 Service Personnel 10 ConocoPhillips Company 1 DUS 5 ;c,C, : " ;.:. .:...... cc ..c.. ... ..,iT. C..c MATERIALS/CONSUMPTION .,' .c c... '....:. ' ......::. c. :..... c, . ......... .. .,....,. .....' ..c:...... ,", '. ITEM'...".... .....c:,..'.UNITS... .', .. USAGE ...' ..". :ONHANDC. ,>ITEM c. ...c.........1 UNITS ; ;1. USAGE ::, ON HAND ....... ,. ". Rig Fuel gals 1,633 4,706 Rig Water bbls 300 130 Camp fuel gals 2,488 Camp Potable Wate bbls 76 65 ,c, ,. .,., . c " . , .... c ccc.; .:. c:SUPPORT CRAFT ..c C. .. ... c. , .. T ,... ... ...c.. ..,:. . ' ,'. .cc;, C,". :. , c, :c' ': c '. " ,,' '" .c ;tYpe:.:....:.... : ;. :.t-Jö. ... ... ,'.,c... .... .... ,; REMARKS ... .c. ,..:,.. .. i.. ...:...TVPE :. >.... . NO.. ...; c c. .:.,..cc. REMARKS '. .'. :":. " < " 2P-417 2P-420 3R-11 560 2P-420 DS4 G&I 14 2P-420 . ...< ...c :... ... .,.. ;.... ,; ... c ..c;, ' ' .RESERVOIFÎiANDINTERVAL DATA.. . .,. 'C .C'."" .,' , ' .', C', c. ,c,' , ,c,' : c: c: ,' <" ..... .., '." .. .RESERVåiRNAIII1E:. ...... .. ..:.,.. ..ZON~ ,c,':,' c ... TOP.c.,. . BASE ; " . .... ..COfJIMENTS. ',: ",'; .,' ." cc ; ., cC, '.,' ,c ,:. '" .' .C." '.. 2P-417 2P-420 0 DS4 G&I 2P-420 14 3R-11 2P-420 560 Printed: 2/3/2004 11 :18:04 AM ~>, Drift (in) . CASING HANGER & PU 5.500 15.50 L-80 4.825 BTC 1 2.84 25.55 Y VETCO ~EW FMC Gen V 5 1/2"CASING - PRODU 5.500 15.50 L-80 4.825 BTC 144 6,118.32 28.39 ATLAS BRADFOR EW 4.950 5.5" L-80 15.5# B SBE WITH PUP 5.500 L-80 4.825 BTC 1 10.09 6,146.71 BAKER EW 4.950 5.5" L-80 15.5# B SEAL LOCATOR SUB 6,000 4,825 1 1.16 6,156.80 BAKER CSR ASSEMBLY 5.500 4.000 19.43 6,157.96 BAKER EW 4.0001 I ~ 1 CROSS OVER 5.500 15.50 L-80 2,867 EUE 1 0.57 6,177.39 PPCo EW 2,992 5.5" x 3,5" CASING - PUP JT 3,500 9.30 L-80 2,867 EUE 1 9.97 6,177.96 ARMCO EW 2,992 3.5" L-80 9.3# E 3 1/2"CASING - PRODU 3.500 9.30 L-80 2.867 EUE 1 30.41 6,187.93 ARMCO EW 2.992 3.5" L-80 9.3# E CASING - PUP JT 3.500 9.30 L-80 2.867 EUE 1 6.02 6,218.34 ARMCO EW 2.992 3.5" L-80 9,3# E 3 1/2"CASING - PRODU 3.500 9.30 L-80 2.867 EUE 16 499.50 6,224.36 ARMCO EW 2.992 3,5" L-80 9.3# E LANDING PLATE 3.500 1 6,723.86 Y PESI 3 1/2"CASING - PRODU 3.500 9.30 L-80 2.867 EUE 1 31.43 6,723.86 Y ARMCO 1 r'J EW 1 I 2.99213.5" L-80 9.3# E FLOAT COLLAR 3.500 EUE 1 1.14 6,755.29 Y WEATHERFORD 3 1/2"CASING - PRODU 3.500 9.30 L-80 2.867 EUE 3 93,18 6,756.43 Y ARMCO I r'JEW 1 I 2.992/3.5" L-80 9.3# E FLOAT SHOE 3.500 EUE 1 1.22 6,849,61 Y WEATHERFORD Printed: 11/2/2001 10:49:29 AM ...... . . . PHILLIPSALA$KAING~ . . on . no .Q~siØgRøþ()rt Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING "-'0 Casing went in hole with no excess drag or tight spots. Filled pipe every jt with mud and broke circ. every 2000'. After getting to bottom and starting to circulate, we lost partial retums. We had to use LCM sweeps and put 6 to 10 ppb LCM in system to regain good circulation. We then lowered mud weight from 10 to 9.8 ppg and regained full circ.. Cement was then pumped and had corT'4Jlete returns through out the job. Ran 21 jts. 3 1/2" L-80 9.3# EUE Tubing Ran 144 jts. 5 1/2" L-80 15.5# BTC Mod Casing 16 - 31/2" Bow Spring Centralizers 5 - 3 1/2" Straight Blade Centralizers 19 - 5 1/2" Bow Spring Centralizers 18 - 5 1/2" Centering Guides 26 - 3 1/2" Lock collars -..- Printed: 11/212001 10:49:29 AM Hole Size: 6.750 (in) Hole Size: Hole Size: Hole Size: TMD Set: 6,850 (ft) SO TMD: (ft) TMD Set: Top Set: (ft) Date Set: 11/2/2001 SO Date: Date Set: BTM set: (ft) Csg Type: Production Casing SO Type: Csg Type: Plug Date: Csg Size: (in.) SO TMD: Plug Type: SO Date: Drilled Out: Cmtd. Csg: Production Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Kevin Anderson Pipe Movement: Reciprocating Type: Cement Casing Volume Excess %: 50.00 Meas. From: caliper Time Circ Prior To Cementing: 10.00 Mud Circ Rate: 130 (gpm) Mud Circ Press: 500 (psi) Start Mix Cmt: 00:01 Start Slurry Displ: 00:27 Start Displ: 00:08 End Pumping: 01 :22 End Pump Date: 11/2/2001 Top Plug: Y Bottom Plug: Y 3.00 (bbl/min) 3.00 (bbl/min) Y 1 ,158 (psi) 1,800 (psi) 1,800 (min) Y Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: batch Density Meas By: Scale Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: Slurry Data Fluid Type: TAIL Description: ARCTIC SET Class: G Slurry Interval: 5,600.00 (ftJTo: 6,850.00 (ft) Cmt Vol: 54.5 (bbl) Density: 15.80 (ppg) Yield: 1.20 (ft3/sk) Water Source: Trucked Slurry Vo/:255 (sk) Water Vol: 18.6 (bbl) Other Vol: 0 Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: 132 (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: ZONAL ISOL Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 2/3/2004 11 :14:07 AM Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Report #: Start: 2 10/15/2001 Stage No: 1 Slurry No:1of1-Additives Trade Name Concentration Units D-065 D-047 D-053 D-110 D-800 D-600G D-29 CELLOPHANE DISPERSANT DEFOAMER GYPSUM RETARDER RETARTER GASBLOK L.C.M. Test Press: 3,000 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) H rs Before Test: Cement Found on Tool: N Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: After casing was on bottom, we lost returns, after circ. 10 hrs. and adding LCM to the system we regained full returns. We mixed and pumped 30 bbls Dowell Mud Push at 10.5 ppg, followed with 255 sx (54.5 bbls) cement mixed at 15.8 ppg, dropped plug and displaced with fresh water, bumped plug right on calc. displacement. Floats held ok. Had full returns through out cement job and well stayed static after job was complete. Printed: 2/3/2004 11 :14:07 AM -. .:...''''''.'.::1 .~ I ,I. .- 1111"t"~<: ,Inc. . ~!..~_n..~ .~ :.:..:. ... ...:..J~"~ ........:.~I""'-.., "'''.., ..... :..: ...:.::> .........:,' I JOB NUMBER I EVENT CODE 24 HRS PROG TMD ITVD IDFS I REPT NO. ¡DATE 2P-420 I I ODR 6,860.0 5,863.0 21.00 I 22 11/1/2001 I RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG ¡CUM. TANG I Doyon 141 Meltwater 6741.0 0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD RIH with 3 1/2" production string 0 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD Run 3 1/2" completion tubina, Space out, N/U tree, freeze pr 11/1/2001 88,584 2,394,068 LITHOLOGY JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAKOFF AFE AUTH. I 16.00 AK0203 LAST SURVEY: DATE TMD INC AZIM ¡LAST CASING NEXT CASING LAST BOP PRES TEST 10/27/2001 6,797.20 53.790 103.820 7.625 (in) @ 2,351.0 (ft) 5.500 (in) @ 6.741.0 (ft) 10/26/2001 DENSITY(ppg) 10.00 PP I I ECD I I MUD DATA DAILVCOSTI 0 <cuMcaSTI 0 FV .,pwVP .GELS WUHTHP FCIT.SOL .'OILJ\YATJ%S~ndIMBTlph/pMIPf/Mfl . cll .:. Ca ... J H2S IlIME ES 54 16/22 8/16 4.2/ / / I /5.0 I 9.5/ I I I I I I .BHA/HOLE CONDITIONS. ¡:.. .. ... .......:1 BrrNo.j 4 STRiNG WT. ON STRING WT.ROT I"O~QUEI UNiTs . ... BHA LEN~TH .. I I 1,302.09 LENGTH ..:.. '..:.0.0: . :.. . tD. . CONN SIZE CONNTYPE 0.88 6.750 1.500 30.83 4.750 1.500 5.70 4.750 2.250 3.00 4.750 2.500 34.51 4.750 2.500 22.66 4.750 2.500 92.33 4.750 2.250 3.64 4.750 2.250 184.84 4.880 2.500 30.01 5.250 2.250 893.69 4.880 2.500 . , { .. ..... , , ... ........( WELL NAME SUPERVISOR Don Presnell CURRENT STATUS BH~tiI().1 5 I.: .... .......:.:.. :.,:::.. ...... : .'.: ':::.' '..': BHAWT;BEL()WJAR$ :: STRINGWT.UP .....¡.I I I . ".'. . ITEM DESCFUPTION . .. .: . .. :... ',. . . »: ..:.: Bit Mud Motor Stabilizer - NonMag Crossover LWD MWD Drill Pipe - Non-Mag 4 Comp Serv Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt NO JTS 1 1 1 1 1 1 3 1 6 1 29 '. , ..:... ...'.:.. .... ... .:. ...... .:.....: : ...... ..:...:. ,.'.: :... . ..':. . .: ..., . " ... :.... :.. '.. BITS. ..... ...... . ,. ..'.. '. ...:.... ........:...... .:..... ,.. . '.... .:.. . ,..... ... ... SITlRUN .,. SIZE :... 'MANUF~ . . TYPE I SERIAL. NO. I .. .. ...:JETSORTFA ...... DEPTHIN bÅÏ'ÈIN11~0~D~L~B~G~O-R. .. 4/ I 6.750 SMITH S75PX Ijs2424 I 13/13/13/13/13/ I 4,515.0 10/23/2001 0-0------ .,' . '.:.' :..... .. :.. ....'¡ .. ..'.. :.......:'..:. ..,. ,. ..::. :.'.... ..:Brr oÞERATIONS ..,.. ... .. > ..... '.'...".:.',...'.......'...... ...:.......:, ....... ': ,. ....¡.. ...'....... . BIt/RÜN.... ....:1 .WOB.... .....:¡.I ,. ..RPM.¡. .I..'....GPM.....' .¡ PRESS. '.. .J~BIT.....I... HAS.... :.. .24I;frDls'r..!24HrROP ,.ICÜMHRS' CUMDEPTti CÜMROP ......) .. .,.': ... ........¡< ..:.. /» '..., >'.'.OPERATIONSSUMIVIARY ......:..:. '< ............. .:...... .'.. ....:."..'. .'... .:.. ..'..¡..... ............: ...'..' ... ,.'.. FROM TO .HOURS.CÓÖE. TROUBL.ESUB .. PHASE I. ..........¡. ........' ..ÖES.CRIPTION .....'....'.." '....'.. ....... ...¡. ..'" ...'... .... ..., 00:00 02:30 2.50 CASE P RUNC PROD Run 21 jts. 3 1/2" casing and float equip. 02:30 04:30 2.00 CASE P RURD PROD R/D 3 1/2" casing equip., R/U to run 5 1/2" casing, had a broblem with the casing pup jt on top of the seal bore extension. The PuP jt. was a 6" OD, threaded with 51/2" BTC and the elevators or casing slips wouldn't work. Things had to be modifid for one connection 04:30 06:00 1.50 CASE Np OPER RURD PROD Change out guide bowl and grabber dies on top drive, the OD of the Franks Fill Up tool HT -38 box was to big to go into the top drive guide and grabber dies, had to change out to larger guide and dies. RUNC PROD Run 5 1/2" casing to 2475' RGRP PROD Repair pipe handling skate, Had oil leak, needed by pass leak and fill machine with oil. RUNC PROD Run 51/2" casing to 6822', filling every jt with Frank's fill up tool and breaking cire. every 2000'. Seen no tight spots 06:00 08:00 2.00 CASE P 08:00 09:00 1.00 RIGMNT NrEQIP 09:00 13:00 4.00 CASE P Printed: 2/3/2004 11:1S:30AM 2P-420 OPERATIONS SUMMARY FROM TO HOURS CODE mOUBL!' SUB PHASE! 13:00 14:00 1.00 CASE P RURD PROD 14:00 00:00 10.00 CEMENT CIRC PROD DESCRIPTION RID Franks fill up tool, blow down top drive, P/U landing jt. and casing hanger, P/U Dowell cementing head Circ and cond mud, lost partial returns, pump LCM sweep, 35 bbls of 15 PPB various types and sizes of LCM. Follow with mud containing 6 to 10 PPB LCM. Slowly regain circulation, cut mud weight from 10 ppg to 9.8 ppg. Regained full returns, circ. with full returns while waiting on Dowell to bring cellophane Flakes for cement job. TOTAL MUD LOST TO HOLE WHILE CI RC. WAS 403 BBLS. 24 HR SUMMARY: RIH with 3.5" X 5.5"csg, Circ. and condo hole for cement, had to fight lost returns with LCM, before cement job, lowered mud weight to 9.8 ppg. lost 403 bbls. mud to hole while circ. RESERVOIR NAME 2P-438 DS 4 G&I 3R-11 2P-420 2P-420 2P-420 Printed: 2/3/2004 11: 18:30 AM { , { ',' "",." '.',. ",.." ',"', "'",, ", " ' " , , >i, "". ."..", ,," ...'.. ",', ,,',' .L ,','" 'l'"'agel<OT .'., .i , '"" . .;... '... .,al, ,1-'- 8...."", 'I,,' "F " "",' ...... -.... ~'.,,~ ..... ,"', ,', "I "",' >''',' ,', ,,' >, "'" -' .<.-....~. '., ',." "",,' ,..', ,,' "".', 1 JOB NUMBER 1 EVENT CODE 124 HRS PROG TMD 1 TVD DFS 2P-420 I 1 ODR 1 6,860.0 1 5,863.0 22.00 ¡RIG NAME & NO. FIELD NAME I OCS NO. AUTH MD DAILY TANG Dovon 141 Meltwater 6,741.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD 0 DATE OF LAST SAFETY MEETING DAILY TOTAL 11/2/2001 529,336 LEAKOFF AFE 16.00 " .' '",'",",'>, ",.' IREPT No.1 DATE 23 111/2/2001 ¡CUM. TANGO CUM INT ANG WI MUD 0 CUM COST WI MUD 2.923,404 , ',. WELL NAME SUPERVISOR Don Presnell CURRENT STATUS Riq released at 12:00 midniqht 11/02/01, move to 2P-415 24 HR FORECAST Move ria. ria UD on 2P-415, change out top drive LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP AUTH. AK0203 LAST SURVEY: DATE TMD INC AZIM ¡LAST CASING NEXT CASING 10/27/2001 6,797.20 53.790 103.820 5.500 (in) @ 6,850.0 (ft) 5.500 (in) @ DENSITY(ppg) , 8.33 PP EC,D I ¡MUD DÄTA I)AILYCosT I 0 , FVPVNÞ GELS WUHTHPFcrr.sOLOIL./WAT %SancfIMBT I Ph/pM ,PflMf 26 / / / / / I / I / I / LAST BOP PRES TEST 6,741.0 (ft) 10/26/2001 CUIIIICOST I 0 J ' "Cf' çå I H2S i.IME I ES I I I I I ßHÄNO; I 5 I".., ," .".. "'.' ",. > "', ".' .'. .,BHA} HÖLECGNDITIONS' ,.' ,.,',' .",'" åHAW,..BE~()WJARst '.STRINGVVT.UP. I' STRINGWT.þN .STAINGWT.ROT I I If,' "" '. "'.,""'ITI:rIIIDES(;ÄlþtlO¡iJ ,.,,'., "" '., ,T NOJTS ,,' 1 1 1 1 1 1 3 1 6 1 29 ,,', ",..' > . .'",> '.'BITNo.<1 4 TORQUE/UNITS ,:¡", BHAL.E~GTH,>" I 1,302.09 CONN SIZE CONNTvPE ~E:NGTH .., ,.. . '.O.D. ". '" ,,' '.., .I.p., ' "'.,, 0.88 6.750 1.500 30.83 4.750 1.500 5.70 4.750 2.250 3.00 4.750 2.500 34.51 4.750 2.500 22.66 4.750 2.500 92.33 4.750 2.250 3.64 4.750 2.250 184.84 4.880 2.500 30.01 5.250 2.250 893.69 4.880 2.500 Bit Mud Motor Stabilizer - Non Mag Crossover LWD MWD Drill Pipe - Non-Mag 4 Comp Serv Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt .. T)" ",.', ",' .. "',..,'. ",' ,', ,,' " ","'" ,",. ,.,< ""BITS' "'" ,", " ,,' "." " "." '. ',' , ,.," ", ",' "BITIFu.ï",.SIZE. TMANUF~ I TYPE, SÊRIALNO.I.'JEtsoRTFA >"',' DEPTH IN. DATE IN ..',,"I~O.D.L~B~G~Ó~R 4/ 6.750 ¡SMITH IS75PX Ijs2424 I 13/13/13/13/13/ 4,515.0 10/23/200110-0------ '."'.'..'.""".,","',', " ",", .".""".','.' ," . .',. "'", '. "'... ,,". "'." "', '.BITOPERA1]ÖNS, ,,",'.' "" .'.,', '.,'.' .', ',,' ,'.,... ',"} , "" ,'." "".' "."."',,r "BIT/RUN' '.." "'.' '.,WOB " .,.RPM., ,, ØPM "', PREŠS . "'" PBIT '" 'HRS> I. 24ttrblST ' '.24H¡'RO~ ...ICÛI\nHRŠlcUMDÈPnilcÚM R()P' '""i,',. "',,,... ,', '".', ."", ",," "'''.''OPERA"110NSSUIVIMÄRY ..', .., ',' ", ,'.",,""."'..",... ,,"'" .", '",> ",',".,'.'''' """, . 'FROM' . TO, ,HOURS CODE ,tRoUBLE ,,''',SU8.'' PHA$E'..... ,',. ,",,'" ',.,",DESCRIPTION< ,"',. ,'". '<'..' ,,', """ 00:00 01 :30 1.50 CEMENT F PUMP PROD Hold pre-job safety meeting, test cement lines to 3500 psi, pump 30 bbls mud push at 10.5 ppg, mix and pump 255 sx artic set at 15.8 ppg, yd 1.2 cu ft per sk, with .4% celloflake, displace with water, bump plug, floats held OK, had no fluid loses during cement job. PROD R/D cement equip., UD landing jt. PROD Set casing x wellhead pack off, test to 5000 psi CMPL TN R/U to run completion equip. and 3 1/2" tubing CMPL TN Run in hole with Baker seal assembly on 3 1/2" tubing, 194 jts. 3.5" L-80 9.3# EUE mod 8rd. SOHO CMPL TN Space out seal assembly so it will be l' above locators when hung off and install tubing hanger CIRC CMPL TN Reverse circ. tubing until fluid is clean ( fresh water) SOHO CMPL TN Land hanger and run in hanger lock down screws CEMENT F W ELCTL F CMPL TN F CMPL TN F RURD NUND RURD RUNT 01 :30 02:00 0.50 02:00 03:00 1.00 03:00 04:00 1.00 04:00 09:00 5.00 09:00 10:30 1.50 CMPL TN F 10:30 11 :00 0.50 CMPL TN F 11 :00 11 :30 0.50 CMPL TN F Printed: 2/3/2004 11: 19:03 AM t('. { , .' ...:... ......,,, ..... .... ........ .'.." ... .... " .. ... ......,.,. .....', '::.. ...'.. ..,..,... ., .. .... ... I'.....' ."... ....,.:,. ...... I.... ,..;.;... '.... :.:.:: _..~..~ ..II..: ~.. ..Inc. IQ~v'- I, .- ...:. ,.:....: ... ,,~,' .., n!:iih,-- :.... - . ... ... .. " .' .-1.. "..~.. "H~_~.~_'---- - .., ... . ... ,.. ... ." ....' WELL NAME I JOB NUMBER I EVENT CODE 24 HRS PROG TMD ITVD DFS I REPT NO. DATE 2P-420 ODR 6,860.0 5,863.0 22.00 23 11/2/2001 .. OPERATIONS SUMMARY ... FROM .. TO HOURS CODE TROUBLE SUB PHASE , . DESCRIPTION 11:30 13:00 1.50 CMPL TN F DEQT CMPL TN Test tubing by casing annulus to 3000 psi for 30 mins, shear valve in gas lift mandrel with 3200 psi 13:00 13:30 0.50 WELCTL F NUND CMPL TN Set back pressure valve in tubing 13:30 16:30 3.00 WELCTL F NUND CMPL TN N/D BOP's 16:30 18:30 2.00 WELCTL P NUND CMPL TN N/U FMC 5000 psi tree, pull back pressure valve and install 2 way check, test tree to 250 psi low and 5000 psi high, test pack off to 5000 psi., pull 2 way check. 18:30 20:30 2.00 CMPL TN P FRZP CMPL TN R/U and pump 40 bbls diesel down 3112 x 51/2" annulus, let u-tube to tubing, install BPV. 20:30 00:00 3.50 CMPL TN P FRZP CMPL TN R/U on 5 1/2" x 75/8" annulus, perform LOT, pump 92 bbls flush water and 54 bbls freeze protection diesel. Blow down lines with air Release rig at 00:00 hrs (midnight) 11/02/01 24 HR SUMMARY: Cement casing as per program, set wellhead packoff, R/U and run 31/2" tubing with Baker seal ass., space out, circ clean water, hang off tbg, test casing, freeze protect .. . ,.... ". ..." ",,' ". ....,.. . '. , ".. ....... "... '" " '.." ..PERSONNELDATA .. ,. "'" . "" . ,;;..',.., ',' ." ., "" ,'. ,. , . "COMPANY , ,.", ". SERVICË . " ..... ..NÒ~ ,. HOURS' ,,' ". COMPANY" .. . .'" '. . Si:RVICE" , ""NO. HOURS Doyon 30 Service Personnel 13 ConocoPhillips Company 1 DUS 5 . ,.'" ".' ,., . ''' ',' ':" . .....,. . .MATERIALSl CONSUMÞTIÖN ... '..'.., .... . '." ...' "'."". ,.. , .' ," ,. ...' ',' ,. ',' "," ,',,". ,., ", ',',;;' , "" '. "".. ,ITEM....... ,......".. '"..".,,4NITS . .,".. USAGE .. ON HAND .," . ITEM ... .. UNITS " USAGE". . .. '..." " .. ONHAND " , ., ' Rig Fuel gals 1,390 3,560 Rig Water bbls 350 180 Camp fuel gals 1,920 Camp Potable Wate bbls 100 186 ',,'; , .;., '., . ."..'.". ".'" .."., ... ..,". ,.." .....:,.. ."...... '... ".'. ... ,SUÞPÖRTORAFT " ". ... . ",.. ......".... ....,:..... .. ... .. .. .., ". .,. ". .... ...." . ' "'" .' " ,'. ' ,"" " ... . ,. " " ....TYPE " '" ".,. ..REMARKS ..".'. ,.' ., I'." ...".. 'TYPE ";'.. "NO; '".. .,. , ' REMAR~S ". ."" ". ,,'...'" ,.,.,., I.... ." ..,NO.,.,:,' ... '.., ,',:" ".. " .., ..:"'; 2P-438 1,296 2P-420 3R-11 2P-420 DS 4 G&I 2P-420 , " ....... . ..' .'..' ",: .: .".. ..:: " . .. .." .";.. ."... .>< ..".RESERVC>IRANbINTERVALDATA ; ....'. ...\ , .'; :, :.,,' .. ,?" ., ':.. , . ';... RESEÄV(:URNAIIIIE ... :.:..' ...'. I, ."."., "'" " "., ..... ..." toP.".. I..BASË ,... ", . COMMENTS .':', ."" < , ,lONE ,.... " 2P-438 2P-420 1296 2.25 600-900 DS 4 G&I 2P-420 0 3R-11 2P-420 0 Printed: 2/3/2004 11: 19:03 AM CASING TEST and FORMATiON INTEGRITY TEST Well Name: 2p. 420 Date: 11/2/2001 Supervisor: Don Presnell Reason(s) for test: 0 Initial Casing Shoe Test I;z] Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 51/2" 15.5# L.80 )( 7 5/S" 29.7# L.SO annulus Casing Setting Depth: 2,351' TMD Hole Depth: 5,600' TMD Mud Weight: 9.8 ppg Length of Open Hole Section: 3,249' " /' . . ~ ---- --LEAI(.OFF TEST -CASING TEST LeT SHUT IN TIME i ~CASING TEST SHUT IN TIME I ¡ I .-+-. TIME LINE f ¡ I I '- ! : ¡ , I I u. j. I I I ~ '.> w - - '> - STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE FOR eSG TEST MINUTES CASING TEST DATA STROKES NOTE: TO CLEAR DATA. HIGHLIGHT AND PRESS THE DELETE KEY PRESSURE ( ( Cr~t.od by O. Hnotiulc Dote plottod : 26-.1on-201>4 Plot Rofol1linQ8 I. IroCWD <0-8880'>. Coordlnales arc In feet rcfCf'onc:o .Iol f420. Vortkal Depth8 are reference RKB (Doyon 141). .. "!!!!b nm:o ~onOCOPhilliPS Alaska, Inc. Structure: Drill Site 2P Well: 420 -.....-" Field: Mel.twater. Location: North Slope, ~~ska 1500 1400 1300 1200 700 500 <- West (feet): East (feet) -> 300 700 800 1000 1100 1200 IJOO 1400 1500 1700 Scole 1 inch = 100 ft 1800 900 400 ~ 1320 ft~~ "- ~ ^ I :z 0 'DO ::1. ;;T ,..., 100 ! V') 0 100 5- ;;T .... 200 ! I V 500 1200 9 ð/8 Casing (/) 14(]Q g ëP 1500 ~ II ~ 0 õ 0 1700 ..... ( ( ConocoPhillips Alaska, Inc. Drill Site 2P 420 slot #420 Meltwater North Slope, Alaska H 0 R I Z 0 N TAL P LAN E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: MWD <0-6860'> Our ref: svy6610 License: Date printed: 27-Jan-2004 Date created: 17-0ct-2001 Last revised: 14-Jan-2002 Field is centred on 441964.235,5869891.466,999,00000,N Structure is centred on 441964,235,5869891.466,999,00000,N Slot location is n70 3 9.754,w150 26 50.778 Slot Grid coordinates are N 5868984.299, E 444088.453 Slot local coordinates are 891.04 S 2131.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet Coordinates All data is in feet unless otherwise stated, Casing dimensions are not included. from slot #420 and TVD from RKB (Doyon 141) (254.00 Ft above mean Vertical section is from wellhead on azimuth 103.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level), (' ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M.D. T.V.D, Rect Coordinates 2351. 0 2350.9 3,lS ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M.D. T,V.D, Rect Coordinates 2351.0 2350.9 3.1S ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M.D. T.V.D. Rect Coordinates 2351..0 2350,9 3.1S ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath ( CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD w/SAG <0-10548'>, ,424,Drill Site 2P M.D. T.V.D. 5.3W 2924.7 2350.9 Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 1223,lS 608,6E 153,3 1365,8 782.0 CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD w/SAG <6940-11539'>,,424,Drill Site 2P Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 1223.1S 608,6E 153,3 1365.8 782.0 M.D. T.V,D, 5.3W 2924.7 2350,9 CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 M.D, T.V,D. Object wellpath : MWD <0-6030'>, ,434,Drill Site 2P 5.3W 2413.3 2350,9 Horiz Horiz Min'm Rect Coordinates Bearing Dist Dist 179.1N 590.9W 287,3 613,3 564.4 ~ CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD <0-8974'>1I429,Drill Site 2P Horiz Horiz Min'm M.D, T.V.D. Rect Coordinates M.D. T.V,D. Rect Coordinates Bearing Dist Dist 2351. 0 2350,9 3.1S 5. 3íÑ 2823.2 2350,9 1278. 4S 48.3E 177.6 1276.4 819.5 ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M,D, T.V.D. Rect Coordinates 2351.0 2350.9 3.1S CLEARANCE LISTING Your ref : ~¡D <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD <387 - ???'>, ,432,Drill Site 2P M.D. T.V,D. 5.3W 2424,0 2350,9 Rect Coordinates Horiz Bearing Min'm Dist Horiz Dist 494.9S 345.0W 214,6 597.7 560.5 --- w~ '> \~)() ( ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M.D. T.V.D. Rect Coordinates 2351.0 2350.9 3.1S ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath ( CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD <0-8853'>,,422,Drill Site 2P M.D. T.V.D. 5.3W 2799,4 2350.8 Horiz Bearing Horiz Dist Min'm Dist Rect Coordinates 974.6S 622.8E 147.1 1156.8 704,3 CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD <0 - 6008'>,,417,Drill Site 2P Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D, T.V,D. Rect Coordinates Bearing Dist Dist 2351. 0 2350.9 3.1S 5.3W 2352,0 2350,9 12.6N 78 .6E 79.4 85.4 84.6 Reference wellpath M.D. T.V.D. Rect Coordinates ConocoPhillips Alaska, Inc, Drill Site 2P,420 Meltwater,North Slope, Alaska 2351.0 2350.9 3.1S ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M,D. T.V,D, Rect Coordinates 2351.0 2350.9 3.1S ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M.D. T.V,D. Rect Coordinates 2351. 0 2350,9 3.1S CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD <0-10402' >, ,427, Drill Site 2P M.D. 'r.V,D. 5.3W 2967.2 2350,9 Rect Coordinates Horiz Bearing Min'm Dist Horiz Dist 1400,3S 255.6E 169.4 1421.3 811.7 CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD <0 - 9685'>,,431,Drill Site 2P M.D, T.V.D. 5.3W 2928,8 2350.9 Rect Coordinates Horiz Bea.ring Min'm Dist Horiz Dist 1420.2S 297,OW 191,6 1446.8 859.2 CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Ja.n-2002 Object wellpath : MWD <0-9224'>, ,438,Drill Site 2P M.D. T.V.D. 5.3W 2795,2 2350.9 Rect Coordinates Horiz Bearing Min'm Dist Horiz Dist 1181.4S 715,6W 211,1 1375,8 896.4 ~~ >- \S~-(J Ñ ~ ~\SdÙ \J \\ > \~3d:() ( ,( \ ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Reference wellpath Object wellpath : MWD <0 - 7327'>,,441,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2351. 0 2350,9 3.1S 5.3W 2556.1 2350.9 780.7S 579.7W 216,4 966.7 767.0 ConocoPhillips Alaska, Inc, Drill Site 2P,420 Meltwater,North Slope, Alaska CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Reference wellpath Object wellpath : MWD <0-5950'>,,451,Drill Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V,D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2351.0 2350.9 3.18 5.3W 2438,5 2350.9 288.3S 1148.9W 256.0 1178.6 1111.7 '----.... ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Reference wellpath Object wellpath : MWD <847 - 8663'>,,448,Drill Site 2P Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T,V.D. Rect Coordinates Bearing Dist Dist 2351. 0 2350.9 3.1S 5.3W 2805,1 2350.9 664.2S 1569.3W 247.1 1698.0 1116.9 ~l\ ?\ ~'ð'Q ConocoPhillips Alaska, Inc, Drill Site 2P,420 Meltwater,North Slope, Alaska CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Reference wellpath Object wellpath : MWD <4051 - 7593>,,448A,Drill Site 2P M,D. T,V,D. Rect Coordinates M.D. T.V.D, Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist ~~ 2351. 0 2350,9 3.1S 5.3W 2805.1 2350,9 664,2S 1569.3W 247,1 1698,0 1116.9 ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Reference wellpath Object wellpath : MWD <0-???'>,,447,Drill Site 2P M,D. T,V,D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist w ~ '>\ ~'à-0 2351.0 2350,9 3.1S 5.3W 2758.5 2350,9 1111. 8S 1077,5W 224.0 1542.3 1083.9 ( ConocoPhillips Alaska, Inc, Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M.D. T.V.D. Rect Coordinates 2351.0 2350.9 3.1S 5.3W 3280.5 2350,8 872.8 ConocoPhillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska Reference wellpath M.D. T.V.D. Rect Coordinates 2351.0 2350.9 3.1S 5,3W 2794,4 2350.8 - ( CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD w/SC/MC/IFR<0-???'>,,419,Drill Site 2P M,D. T.V.D. Horiz Bearing Min'm Dist Horiz Dist Rect Coordinates 1713.6S 657,1E 158,8 1834.2 CLEARANCE LISTING Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Object wellpath : MWD <2878 - 7310'>,,422A,Drill Site 2P M,D, T.V,D, Horiz Bearing Min'm Dist Horiz Dist Rect Coordinates 974,48 622.8E 147.1 1156.7 704.2 All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #420 and TVD from RKB (Doyon 141) (254.00 Ft above mean Vertical section is from wellhead on azimuth 103.68 degrees, Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ Coordinates sea level). '\:Ji\ > \~d'U Å ~ J I'Þ'-- ~ I.) l-( DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011820 Well Name/No. KUPARUK RIV U MELT 2P-420 Operator CONOCOPHILLlPS ALASKA INC ~(lAi. - / r ) Jt- -1/(}o'l API No. 50-103-20391-00-00 MD 6860 ~ Completion Status WAGIN Current Status WAGIN ~-- TVD 5863- Completion Date 12/22/2001 ~---_.-- REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type/ Med/Frmt Number ~ og t..:t6542 ------- --- Samples No Directional Survey -~ 'j)/;;t - - ~C I I I ~C JßE( C ~ ¡ Log I I Log I Log i Log i i Log I I Log I I Log i I Log I Log I Log ~ I i i I I I Well Cores/Samples Information: Name (data taken from Logs Portion of Master Well Data Maint) -., Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 5 BS 1 2278 6386 Case 6/11/2002 2250 6860 Open 2/112002 PEX, AIT, FMS Main and repeat passes 2278 6386 Case 6/11/2002 115 6860 Open 8/16/2002 115 6860 Open 8/16/2002 I 25 Blu 1 115 6860 Open 8/16/2002 t'l-t\ j(..j1,.o.y t\lt c. rz ~'[) Blu 115 Open 8/16/2002 ' L l , , I I tr it( 25 1 6860 25 Blu 1 115 6860 Open 8/16/2002 25 Blu 1 115 6860 Open 8/16/2002 25 Blu 1 115 6860 Open 8/16/2002 ~- 25 Blu 1 115 6860 Open 8/16/2002 25 Blu 1 115 6860 Open 8/16/2002 25 Blu 1 115 6860 Open 8/16/2002 25 Blu 1 115 6860 Open 8/16/2002 25 Blu 1 115 6860 Open 8/16/2002 ^ðC~ 2 Blu 1 6002 6352 Case 5/30/2003 memory PSP - Injection Profile - Pressu refT em pICa liper/FB S ---------- - ---- -- Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011820 Well Name/No. KUPARUK RIV U MELT 2P-420 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20391-00-00 MD 6860 TVD 5863 Completion Date 12/22/2001 Completion Status WAGIN Current Status WAGIN ~ ADDITIONAL INFORMA~N Well Cored? Y I(ci/ -- ~ Chips Received? Y I N Analysis ~ Received? Daily History Received? Q/N G>/N Formation Tops ~7~- ---- _u_. .-- Comments: ------- - Compliance Reviewed By: ~ Date: at J ¡Y)'\..... ~ 'f -~- (\Þ ~ .:... tt O..A ~ t «.~ F-- t~' ), "I ~~~~ ~ D,- '0<1<>- r.¡h~ 5~¡Þ-1.- f~ ()~5~ r~~ b1 ~ ~f o-~)¡&dl ~ !>-)~(J - '3~~ ~/ßC-- f~ rr-~ J~~. /tJJP/ PMMJ ?N{ ~J ~..t~o l ~ 6Jc)o -~l-{åù ~ (f)l- . c~ fiWp ~ ..(~/:u...... )..~c f ~,{c!)ö -i 7 J ú Be-. -~- RE: 2P-422A Annular Disposal Application ~Ol ~ {~d- ( Subject: RE: 2P-422A Annular Disposal Application Date: Wed, 22 Oct 2003 09:11 :28 -0800 From: "Hayden, Philip" <Philip.Hayden@conocophillips.com> To: "Tom Maunder" <tom_maunder@admin.state.ak.us> Tom, Here are the recalculated pump in pressures with some comments for the wells in question. (Did you want them in an excel spreadsheet ?) 2P-417: 14.3 ppg 2P-422: 15.2 ppg (unchanged as the difference between the correct and incorrect TVDs was so small) 2P-441: 17.2 ppg. This "new calculated" pump in pressure is greater than the orCginal FIT of 16.2 ppg. This is attributed to the fact that an intermediate casing string was run on this well due to a well control r ~ problem. This resulted in a shoe (and cement) approximately 1500 ft TVD higher than any of the other wells drilled on Meltwater. We conclude that the formations exposed on the other wells, including our candidate well 2P-422, are isolated in the case of 2P-441. Regards Philip -----Original Message----- From: Tom Maunder fmailto:tom maunder@.admin.state.ak.usl Sent: Wednesday, October 22,20038:11 AM To: Hayden, Philip Subject: Re: 2P-422A Annular Disposal Application Philip, With regard to the "new calculated" pump in pressures for 2P-417, 2P-422 and 2P-441 , would you please provide them?? Thanks, Tom Maunder "Hayden, Philip" wrote: > Tom, > > In response to your comments: > ./ > For the pump in test for well 2P-420 I must apologise for not having > made sure that the sheet had been correctly filled in. Your calculation > of 14.2 ppg EMW had been previously confirmed by us but the sheet had > not been corrected. / > ../../ V > For wells 2P-417, 2P-422 and 2P-441 the incorrect TVD was used for > calculating the EMW for injection at the shoe. This had been noted by us > and the corrected EMW for injection at the shoe had been determined and > found to be, in all cases, lower than the original injection pressure at > the initial leak off or formation integrity test. We did not amend these > files before sending them on to you as they are part of the official 1 of 3 I: t"( .) \> pm" + ~ ~ \- \..,. ,\.,. 1\ \) ~ ' Cl.V \,Hc.c..,\.\ ~f'\ ~ ~ t\ r.~\:>~. ~~ \!tcc~ <;. ô \:- -\ ,,~ (' \\". \1 ~ \I..J~, ~ ~e d?- '-\ '-\ \ , 17 P - '-\ ~ \ , d f>- \..I, ð~ df'-~d'ì ,~?-~;Q) ~?- L -.... - \ \\\ \ '""~ \Ct ~\ ~ ~«, \ ~ ~~ ~-: . L { ,_\J\()~, !kQ. '" ~ W\C) ~<! ~ ~ f\ - r~......c.~"\-,, \ ~ \" ~.\~ ~,,\- -\-0 -\.~~ ~c;.~Q.\\~", \>Jc.' \ G \"-- ') "'" ú. 'i ù. ~ 'f ~ (: c -\- \ \J c- "-.) Cè \ ç., \~~ , ~2?ytf l '0/ ~ I,J() 10/22/2003 9:59 A~ RE: 2P-422A Annular Disposal Application , > files. This would have lead to two diffet, Jt sets of data for these > wells and we felt this could be potentially more confusing. On the other > hand we recognise now that we should have brought this to your attention > in our initial correspondence. We will be sure to do so in the future. > > For well 2P-431 we have been unable to locate any record of a pump in > test after the initial leak off test was performed, We do know that this > annulus has been freeze protected and also that methanol has been pumped > down it to remove a hydrate plug but accurate pressure information is > lacking. However, due to its location, between wells 429 and 441 we are > confident that its behaviour with respect to a pump in test is similar > to these wells. > > I hope this note adequately addresses your comments and questions. If > there is anything else please let me know. > > Regards > > Philip > > -----Original Message----- > From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl > Sent: Monday, October 20, 2003 9:07 AM > To: Hayden, Philip > Subject: Re: 2P-422A Annular Disposal Application > > Phil, > Here are my further comments/questions on the 2P-422A application. I > look > forward to your reply. > Thanks, > Tom Maunder, PE > AOGCC > > On the 2P-420 pump in test, the calculation has not been done. TVDs > have > not been entered. Using the 550 psi maximum pressure and the shoe tvd, >1 > calculate 14.2 EMW. The EMW of the sustained pump in pressure would be > slightly lower. > > On the pump in test of 2P-417, the calculation does not use the tvd of > the > rathole at the surface casing shoe. Using 2430' tvd, the EMW calculates > to > 14.2 which is in agreement with the calculation for 2P-420. > > Tom Maunder wrote: > > > Hi Phil, > > Welcome back. I was looking at the application and I have a couple of > > questions. Please note that I am not finished with my review of the > > packet. This first note will allow you to capture my eddress. 2 of3 ¡Ii \ 10/22/2003 9:59 AI RE: 2P-..422A Annular Disposal Application ( ( » > > My questions/comments are: » > > On the pump in plot for 2P-422ST dated 4/22/02, the TVD used in the > > calculation is not the same as done on the initialleakoff dated > > 2/20/02. Why the difference?? » > > The TVDs on 2P-441 also are different. In particular the pump in TVD > is > > listed as the mid point between the top of cement and surface shoe. > All > > EMWs should be referenced to the surface shoe. » > > There is no pump in test for 2P-431. » > > You have made the appropriate tvd change on 2P-429. » > > Tom Maunder, PE > > AOGCC 3 of3 10/22/2003 9:59 AI Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth ~~ Well Job# Log Description Date 35-23 2N-319 2N-343 2N-348 2P-429 2P-420 3J-17 PERF & 5BHP W/JEWELRY LOG PRES5ITEMP SURVEY <. INJECTION PROFILE INJECTION PROFILE " MEM PSP INJECTION PROFILE MEM P5P INJECTION PROFILE ð MEMORY LDL 04/29/03 04/27/03 05/02/03 05/01/03 05/06103 05/06/03 05/08/03 .- ~ -. SIGNED: \'"(\ "'-~ C> ~ )~ ""- \ > ..s ; ~ ~ ¿:... ../'Y, DATE: OS/28/03 NO. 2860 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL CD Color 1 1 1 1 1 1 1 RECEIVED Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MAY 30 2003 Alaska Œi & Gas Cons~ ComnUøeioo Ancft 0I'Ige """----- ~ '"'-. Annular Disposal during the first quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-18 31501 100 0 31601 306 0 31907 January March 3S-l5,3S-l6,3S-22,3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Oec 2002 Jan 2003 3S-l0, 3S-l5, 3S-09, 3S-l4 CD2-48 20144 100 0 20244 375 11381 32000 Oec 2002 Feb 2003 CO2-45, CO2-35, CO2-08, CO2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CO2-08, CO2-48, CO2-46 CD2- 22 30773 100 0 30873 380 0 31253 Feb 2003 March CO2-08, CO2-36, CO2-51 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-2l,3S-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March lC-190, lC-174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 l' , '\ J'¡tl~l " t A l"fi h' hD" lAth" t " E " dd " th fi t t 2003 oa 0 urnes In 0 nnu l or W lC lsposa u orzza lon xplre urzng e lrs quar er , Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Inj ected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Oec 2002 CO2-B, CO2-37, CO2- 2002 35 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October CO2-38, CO2-44, CO2- 2002 2002 29, CO2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CO2-50, CO2-46, CO2- 22 b , ,.. \ ECEIVED Qj 0 ---... APR 1 6 2003 ~ Alaska Oil & Gas Cons. Conmission '93- Anchorage dOJ-I~ ;;) A L D' Ld ' h d 12002 nnu ar lsposa urzng t e secon quarter 0 0 . h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volome Volume Volome Quarter Protect Total Total Date Date Volumes CD2-I5 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-4I5A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-I7 14962 100 0 15062 372 0 15434 May 2002 June 2002 CD2-48, CD2-46 ID-II 32102 100 0 32202 235 0 32437 May 2002 June 2002 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 IC-IS 4176 100 0 4276 379 0 4655 June 2002 June 2002 1C-104 ~ L ~ L A l'fi hO hDo LA h ° E ° dd ° h d 2002 (. ora 0 urnes Into nnu I or W IC lsposa ut OTlzatlon xplre UTln~ t e secon quarter ° Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volome Volome Volome Volume Status of Annulus IJ -09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 11-10 I C-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 lC-133, lC-121, lC- 123, lC-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- 2001 15 2P-4I7 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A,2P-420 I C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001. July 2001 lC-127, IC-1l7, lC- Ill, lC-123 ( Transmittal Form { ,&¡. BAKER HUGHES aoJ~ Ji~ J I Oo~ ------------_._------------ """"'-t""""""" ---.-- .-.----..------------------. ,~,. '-"," -~ - ~ ., -, -~ - ~- " -.. INTEQ ..~. "., ".. '-'-." ~._- To: .... ,., '. Anchorage GEOScience Center ~"-----'-!-;:-,-:_~-'--- -.. - ~ ., ... AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 2P-420 - --- . 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 - Density/Neutron Measured Depth Log 1 blueline - Density/Neutron TVD Log LAC Job#: 212208 Sent By: Glen Borel '-'11 I ;:"""'1 ~.- .-. .,.",,\:- ':-' :,,1 "f .;- ',"'" '. ""'. :~I':~' "',"""~: " ~I \~~ ~,t .',' ". ~"'i;i""",,,""'t~~¡""" :r:'.F'"".,.~IP...1 /1 'I(,~ 1 6 i')ii-t'~.,/~,; h L ',j t~". . .' '1::.': '~,,;n; ':', ""::'. -' i (~i.L,' Date: Aug 15, 2002 , Received Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 -... i.----___J~1f~~~,:_-------------- I........ ..¡.;,.:~ ":;< ,., ""I" ¡~,!:~,-------~-~~~:_:_::-:.__::_.:_:.....:~ i:::;.,~.~~;.."~;:' ;".,." - --- .__m______------- 'i"~"'. "" .--..-..", ." "'" ,"." "',.'.' ", ""' '., -,~ '1 Y" 1'_' '~1~ ( . ;:.:-:.:,;¿¡.:_!+I...: ...:'.f[~:..., ""'?i"",. ".I..:......'.... .',:llò'c~ I "..".. <... : -~:i_- -"", . '.".i --.:::~..._., """1': WI'" ---------....---.-- ( ( State of Alaska Alaska Oil and Gas Conservation Commission MEMORANDUM TO: Camille O. Taylor uf. Chair U~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~ Phillips Alaska P.I. Supervisor'- , ./0 ~ 2P Pad %\5 FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL DATE: August 3, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well 2P-420 Type Inj. G TV.D. 5428 Tubing 2450 2400 2400 2450 Interval I P.T.D. 2011820 Type test P Test psi 1500 Casing 1250 1990 1950 1950 P/F P Notes: Initial MIT Well 2P-429 Type Inj. G T.V.D. 5218 Tubing 2575 2575 2575 2575 Interval I P.T.D. 2011020 Type test P Test psi 1500 Casing 1000 1910 1900 1900 P/F P Notes: Initial MIT Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F I Notes: --' Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test T es~ psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to PAl's 2P Meltwater Pad to witness Initial MIT's on MI injectors. This was the first opportunity to travel to 2P Pad since breakup. The Pad is still very soft & muddy. Nordic 3 is stacked on 2P Pad waiting for Pad conditions to allow the Drilling program to continue, Road conditions to 2P Pad are fair for light truck travel. The SVS tests for 2P Pad will be conducted this Month, M.LT's performed: ~ Attachments: Number of Failures: Q Total Time during tests: 4 hrs. cc: M IT report form 5/12/00 loG. MIT KRU 2P 08-03-02 JC.xls 8/5/2002 05/31/02 Scbbnbepgep NO. 2115 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk c~ Well Job # Log Description Date BL Sepia CD Color .~ 1D-132 fq'if- c3./ 22208 RST-SIGMA 04/18/02 1 1 1 2P-420 dDl-IK';) 22209 RST-SIGMA 04/10/02 1 1 1 S'GNEð~ ,~.p RECEIVED DATE: JUN 11 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank youAlaska Oil & Gas Cons. Commission Anchorage ( (: PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 9951 D-O360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 February 5, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2P-420 (201-182) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Meltwater we1l2P-420. If you have any questions regarding this matter, please contact Pat Reilly at 265-6048, Sincerely, c' C. Mallary Drilling Engineering Supervisor P AI Drilling CM/skad RECE\VED FEB 0 61 2002 A\aska O" & Gas Coos. eommiSS\OO Anch0f8g8 .. ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface .. -" ,- "'.-'~"'- Suspended D Abandoned D Service @. l .... LV\.J'\ I ,- Vi.~ID yoo-, 1 . }" Ii .o'! ,t .-~.. . . : --, 'Y. WAG Injector 7. Permit Number 201-182 8. API Number 50-103-20391-00 892' FNL, 2128' FWL, Sec. 17, T8N, R7E, UM ' -,.- ¡ ,'.0":.: At Top Producing Interval ;. -'--~. -Z~_:...p¡ : 1335' FNL, 1212' FEL, Sec. 17, T8N, R7E, UM : ,¡:-.'~ "'. : At Total Depth .~ ~"--~.Â~~.- ¡ 1465' FNL, 763' FEL, Sec. 17, T8N, R7E, UM ".", ~.,.~",- "..., (ASP: 446475, 5868393) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 25.5' feet ADL 373112 12. Date Spudded 13. Date T.D. Reached 14. D~e Comp., Susp. Or Aband. 15. Water Depth, if offshore E(. . ;.z..2- October 15, 2001 October 28,2001 ,2001 ,/1 NIA feet MSL 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 6860' MD 15863' TVD 6720' MD 15780' TVD YES 0 No D N/A 22. Type Electric or Other Logs Run GR/Res/Neu Dens, Platform Express, CBL 23. o' - (ASP: 444088,5868984) 9. Unit or Lease Name Kuparuk River Unit 10. Well Number (ASP: 446027, 5868527) 2P-420 11. Field and Pool Kuparuk River Field Meltwater Pool 16. No. of Completions 1 21. Thickness of Permafrost feet MD 1454' (approx) 7.625" WT. PER FT. 62.5# 29.7# 15.5# 9.3# GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 2351' Surface 6156' 6156' 6850' HOLE SIZE CASING SIZE 16" 42" CEMENTING RECORD 9 cu yds High Early 260 sx AS III Lite & 140 sx LiteCRETE 255 sx Class G AMOUNT PULLED 5.5" 3.5" 9.875" 6.75" 6.75" included above 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE cement plug @ 6720' TUBING RECORD DEPTH SET (MD) 3.5" 6156' PACKER SET (MD) N/A 6386' - 6422' MD 6361' - 6374' MD 6324' - 6352' MD 6272' - 6320' MD 5575' - 5598' TVD 5559' -5567' TVD 5535' - 5553' TVD 5502' - 5533' TVD 6 spf 6 spf 6 spf 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A NIA Date ofT est Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) WAG Injector Production for OIL-BBL GAS-MCF Test Period> Calculated 24-Hour Rate> WATER-BBL CHOKE SIZE GAS-OIL RATIO 27. Date First Production Flow Tubing press. psi 28. Casing Pressure OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A fEa 0 6 2002 -. Alaska Oil & Gas Coos. Commission Anchorage - Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 0;'" f'\ ~ _.~ I.', ~ ~ l 1" . fI Ii .. " . 1'" , :. i"',;'.v:I""111:\Hju ,\~\J~~\J,\ ... RBOMS 8Fl PEB I I 200,') ~y- t.. ., , ! ( GEOLOGIC MARKERS' 30. ( 29. FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. T3 T2 6266' 6563' 5498' 5685' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Pat Reilly 265-6048 Signed (!.1?~ 4!1A_- , Chuck Mallary /J V Title Drillina Enaineerina SuDervisor Date S ¡:¿g " )... Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in. Other-explain. RECE IVED Item 28: If no cores taken, indicate "none". Form 10-407 fEB 0 6 2002 ~ . ' '" ~ ',^"'1 r,"~"'I, ~, ""","~ \,'\ ':,: t~ ¡I 'I': \, \i: 'I (: \ I '\ II ?' Ii ~ ',' !,ì',"~ \!!I'-"":\'i,:~\I:'¡;:),,,1 , ì! \. ï ¡ ; ¡ \, \\1 f""'I,l ~..".,,::\,¡...,..,.I!þ.,~ \.. Alaska Oil & Gas Coni. Commission Anchorage .. . # Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/11/2001 10/12/2001 10/13/2001 10/14/2001 (' (' PHilliPS ALASKA INC. Operations Summary Report 2P-420 2P-420 ROT - DRILLING Doyon Doyon 141 Page 1 of 9 Spud Date: 10/15/2001 End: 11/2/2001 Group: Start: 10/15/2001 Rig Release: 11/2/2001 Rig Number: 141 Description of Operations Sub From - To Hours Code Code Phase 00:00 - 00:00 00:00 - 00:00 00:00 - 00:00 00:00 - 06:00 06:00 - 08:00 08:00 - 12:00 24.00 WAlTON OTHR MOBMIR 24.00 MOVE 24.00 MOVE 6.00 MOVE 2.00 MOVE 4.00 MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE 12:00 - 13:30 1.50 MOVE MOVE MOVE 13:30 - 15:00 1.50 MOVE MOVE MOVE 15:00 - 17:00 2.00 MOVE MOVE MOVE 17:00 - 18:00 1.00 MOVE MOVE MOVE Rig Warm Stacked with crews. **Clean all a reas on Rig after painting in preperation for move. **Did correct conductor conformatio n 2P-420 with Co Man,DSO (Greg Stuzer) & Doyon Toolpusher(Bobby Ingram ** Matt are a around 2P-420 conductor for equip to work off of to install newer 6' type cellars & co mplete CMT top job. ** Callout all support Contractors( Bariod,Baker Inteq,Epoch . All will be on location by Saturday 6:00PM. ** Start matting area between Rig & Camp in pr eperation for move. Ready rig for move to 2P-420 ** Dress hand ling tools for 4" HT 38 ** Haul unwanted Cs g to 2L pad for storage(clearing pad area) ** DTH installed 6' cellar box on 2P-420 con ductor . Welder to be here first thing this m orning to install speed head Prepare Rig for move ** GBR install speed head on conductor ** Level area around wel I & lay down herculite ** Lay matting board s for move ** Held per-spud meeting wI bot h crews & all contractors. Also in attendan ce were: Randy Thomas,Pat Reilly,Bobby Mo rrison,Wendy Mahan,Rich Nelson. APC const ruction reps Ron Cheaunalt(Safety) & Jim K aiser(General Forman) Ready Rig for move - Lay matting boards Blow dn steam & water lines -Pull all discon nects - Disconnect Hi Line Move power pack away from sub toward cam p - Move sub out & move down well row - Sp ot & level sub on 2P-420 Move and spot pits, pump, motor & boiler mod u I e s. Lay matts & spot pipe sheds Lay matt & spot rock washer - Build berm Layout & elevate elect cable to rig *****NO TE**** Can not hook back up to hi line until a certified lineman can megger the line.At t his time "NO" lineman is avaiable. Spot & Berm pipe shed Tioga Hook up all interconnects - Refit diverter ri ser Rig Accepted 00.00 hrs 10/15/01 - N/U Diver ter System - Load PS wI 4" HT38 DP LID std 5" DP standing in derrick - Change out all floor equip to 4" PIU & stand back in derrick 4" HT38 DP Fuction Test Diverter System -Test Gas alar ms - AOGCC rep John H. Crisp witnessed te st Con't to P/U & stand back in derrick( 64 std 18:00 - 19:00 1.00 MOVE MOVE MOVE 19:00 - 00:00 5.00 MOVE MOVE MOVE 10/15/2001 00:00 - 05:00 5.00 WELLS NUND MOBMIR 05:00 - 06:00 1.00 WELLS PULD MOBMIR 06:00 - 10:30 4.50 WELLS PULD MOBMIR 10:30 - 12:00 1.50 WELCT BOPE MOBMIR 12:00 - 15:00 3.00 WELLS PULD MOBMIR Printed: 1/17/2002 8:40:16AM ,.,., . l ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/15/2001 12:00 - 15:00 3.00 WELLS PULD MOBMIR 15:00 - 17:00 2.00 WELLS PULD MOBMIR 17:00 - 18:00 1.00 DRILL PULD SURFAC 18:00 - 20:00 2.00 DRILL PULD SURFAC 20:00 - 20:30 0.50 DRILL SFTY SURFAC 20:30 - 22:00 1.50 DRILL CIRC SURFAC 22:00 - 23:30 1.50 DRILL REAM SURFAC 23:30 - 00:00 0.50 DRILL DRLG SURFAC 10/16/2001 00:00 - 00:30 0.50 RIGMNT RSRV SURFAC 00:30 - 01 :00 0.50 DRILL PULD SURFAC 01 :00 - 18:30 17.50 DRILL DRLG SURFAC 18:30 - 19:00 0.50 DRILL CIRC SURFAC 19:00 - 21 :00 2.00 DRILL WIPR SURFAC 21:00 - 21:30 0.50 RIGMNT RSRV SURFAC 21 :30 - 22:30 1.00 DRILL WIPR SURFAC 22:30 - 23:00 0.50 DRILL WIPR SURFAC 23:00 - 00:00 1.00 DRILL DRLG SURFAC 10/17/2001 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 13:00 1.00 DRILL CIRC SURFAC 13:00 - 17:00 4.00 DRILL WIPR SURFAC 17:00 - 17:30 0.50 DRILL SFTY SURFAC 17:30 - 18:30 1.00 RIGMNT RSRV SURFAC 18:30 - 19:30 1.00 DRILL WIPR SURFAC 19:30 - 20:00 0.50 DRILL REAM SURFAC 20:00 - 22:00 2.00 DRILL CIRC SURFAC 22:00 - 23:30 1.50 DRILL TRIP SURFAC 23:30 - 00:00 0.50 DRILL REAM SURFAC 10/18/2001 00:00 - 01 :00 1.00 DRILL TRIP SURFAC 01 :00 - 03:00 2.00 DRILL PULD SURFAC 03:00 - 04:30 1.50 CASE SFTY SURFAC 04:30 - 05:00 0.50 DRILL SFTY SURFAC 05:00 - 08:30 3.50 CASE RUNC SURFAC 08:30 - 10:45 2.25 CASE RUNC SURFAC 10:45 - 13:30 2.75 CASE CIRC SURFAC Page 2 of 9 Spud Date: 10/15/2001 End: 11/~2001 Group: Start: 10/15/2001 Rig Release: 11 /~2001 Rig Number: 141 Description of Operations s total) 4" HT 38 DP PIU & stand by 35 its spiral WDP + 4 3/4" ja rs (Sr# 1400-1175) PIU BHA#1 P/U Motor & M/U Bit - Orient tools & upload MWD Hold Pre-Spud meeting wI rig crew and all c ontractors Fill System wI Mud - Run leak ck on complet e circu system - Repair small leak on riser TIH Tag @ 93'- cIa conductor fl 93' to 150' Drlg 150' to 180' MD - SIB drill out std SWD P cIa grabbers from 5" to 4" - Held PJSM - Re ad Procedure PIU remaining directional tools Spud Well - Dir Drill 180' to 1480' MD (1480 , TV D) CBU X2 - Monitor Well (Static) TOH - Tight hole @ 1325' & 1050' - Work un til clean Service Rig - Switch to Hi Line power. TIH - Wash & Ream 405' to 430' until clean Con't TIH - Wash & Ream 1325' to 1480' - 7' fill Dir Drl g 1480'- 1576' MD (1576' TVD) Dir Drlg 1576' to 2358' MD ( 2358' TVD) - T D Csg point CBU X 3 TOH - Tight hole 25-30K overpull & swab - Pump out & back ream 1963' thru 550' - pull clean 550' - 370' Spill Drill Rock Washer - Full responce Service Rig & Top Drive - Hazz Assessment Top Drive - Repair caskle nut on link tilt TIH - Tight hole@ 2198' Wash & Ream 2198' to 2358' CBU - Pump Wt Sweep - Circu & Condition B U X 3 TOH - Tight @ 1167' Back ream tight spot @ 1167' - Work until cl ean Con't TOH LID BHA - LID 3 flex wt DCs - Dn Load MWD & LID same. Brk Bit - LID Motor R/U to run 7 5/8"29.7# L-80 BTCM csg Hold PJSM with crew & GBR csg crew Run Csg - Hit Bridge @ 2288' ( ck float equi p) Wash from 2288' to 2358' (BTTM) Circu & Condition hole thru Franks Fill tool - Recip csg 10'-12' - Pump @ 6 bpm @ 200 p Printed: 1/17/2002 8:40: 16 AM ( .... .-.. ...... ~'PHILLiPs ~ lmi ~ í PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From -To Hours Code Sub Phase Code 10/18/2001 10:45 - 13:30 2.75 CASE CIRC SURFAC 13:30 - 14:00 0.50 CASE CIRC SURFAC 14:00 - 15:00 1.00 CEMENl CIRC SURFAC 15:00 - 16:30 1.50 CEMENl PUMP SURFAC 16:30 - 17:30 1.00 CASE NUND SURFAC 17:30 - 18:30 1.00 CASE NUND SURFAC 18:30 - 19:30 1.00 CASE NUND SURFAC 19:30 - 21 :30 2.00 CASE NUND SURFAC 21:30 - 22:00 0.50 CASE SFTY PROD 22:00 - 00:00 2.00 CASE OTHR PROD 10/19/2001 00:00 - 03:00 3.00 CEMENl OTHR SURFAC 03:00 - 03:30 0.50 CEMENl OTHR SURFAC 1.50 WELLSF NUND PROD 03:30 - 05:00 05:00 - 11 :00 6.00 WELLSF NUND PROD 1.00 WELCTL BOPE PROD 5.50 WELCTL BOPE PROD 11 :00 - 12:00 12:00 - 17:30 17:30 - 18:00 0.50 WELCTL BOPE PROD 18:00 - 22:00 4.00 DRILL PULD PROD 22:00 - 22:30 0.50 DRILL TRIP PROD 22:30 - 23:00 0.50 DRILL DEQT PROD 23:00 - 23:30 0.50 DRILL TRIP PROD 23:30 - 00:00 0.50 DRILL CIRC PROD 10/20/2001 00:00 - 02:00 2.00 WELLSF DEQT PROD 02:00 - 05:00 3.00 DRILL DRLG PROD 05:00 - 06:00 1.00 DRILL CIRC PROD Page 3 of 9 Spud Date: 10/15/2001 End: 11/2/2001 Group: Start: 10/15/2001 Rig Release: 11/2/2001 Rig Number: 141 Description of Operations si - Hole clean no excess drag - Up wt 96K , Dn wt 94K RID Franks Fill Tool - R/U Schlum CMT head (Plugs Loaded) Circu & Prime Up CMT unit CMT Csg- Shoe @ 2351' - Pump 5 bbl CW100 - Test CMT lines to 3500 psi - Can't pump 35 bbls CW100 - Drop Bttm Plug - Pump 30 bbl Mudpush XL @ 10.5 ppg (w'Red Dye) - 2 07 bbls Lead CMT @ 10.7 ppg - 56 bbls Tail CMT @ 12 ppg - Drop Top plug - Pump 5 bbl s water - Switch over to Rig for displacemen t - Rig pumping mud displace w I 981 stks ( 99.08 bbls) Bumped plug wI 500 psi. Pumpe d to 1000psi - Shut in for 5 min - Bleed off - Floats Held *u* NoteU NO CMT TO SURFA CE u* CIP 16:30 hrs RID Schlum - LID Landing jt - LID Csg Tools N/D Riser & Flow Lines Flush & Clean Diverter System N/D Diverter System and remove from cellar PJSM for CMT Top Job M/U 1" Hydril tbg and run in to 16" X 7 5/8" Ann to 200' "Hard Bttm" - R/U to circu Can't CMT Top Job(Have 1" Hyd Tbg run to 2 00') - Flush Ann pumping 88 bbls H2O - CMT pumping 151 bbls 10.7 ppg Lead - Rate 2 b pm @ 600psi - Flush and LID Tbg RID and blowout all CMT equip - Clean all Top Job tools from floor Install & Orient FMC Gen V Csg head - Test 1000psi - Hold 10 min N/U BOPs - C/O Bttm pipe rams to 4" - Modi fy flow riser Install test plug - R/U Test lines Test BOPs & Choke Manif - Test 250psi 150 00 psi high - Test Ann 250/3500 psi- Test G as detectors - AOGCC rep Lou Grimaldi witn essed test Install Wear bushing - RILDS P/U BHA #2 - Orient & Program MWD - Load RA sources TIH wI SWDP Shallow Test Smart Tools TIH - Tag @ 2262' Circu out Contaminated Mud for Csg Test Test 7 5/8" Csg to 2500 psi on chart - Hold 30 m in Drlg FC ,CMT & FS - New hole 2358' to 2588 , MD Circu & Condition - Circu out CMT contamin ated mud Printed: 1/17/2002 8:40: 16 AM ","" ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/20/2001 06:00 - 06:30 0.50 DRILL FIT PROD 06:30 - 15:30 9.00 DRILL DRLG PROD 15:30 - 16:00 0.50 DRILL CIRC PROD 16:00 - 18:00 2.00 DRILL TRIP PROD 18:00 - 19:30 1.50 DRILL TRIP PROD 19:30 - 20:00 0.50 DRILL OTHR PROD 20:00 - 20:30 0.50 DRILL PULD PROD 20:30 - 21 :30 1.00 DRILL PULD PROD 21 :30 - 23:30 2.00 WAlTON EQIP PROD 23:30 - 00:00 0.50 FISH MILL PROD 10/21/2001 00:00 - 01 :30 1.50 FISH PULD PROD 01 :30 - 03:00 1.50 FISH TRIP PROD 03:00 - 04:00 1.00 FISH FISH PROD 04:00 - 06:00 2.00 FISH TRIP PROD 10/22/2001 06:00 - 09:00 3.00 DRILL PULD PROD 09:00 - 09:30 0.50 DRILL TRIP PROD 09:30 - 10:30 1.00 DRILL TRIP PROD 10:30 -11:00 0.50 DRILL SURV PROD 11 :00 - 00:00 13.00 DRILL DRLG PROD 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 13:00 1.00 DRILL DRLG PROD 13:00 - 14:00 1.00 DRILL CIRC PROD 14:00 - 15:30 1.50 DRILL WIPR PROD 15:30 - 17:00 1.50 DRILL WIPR PROD 17:00 - 21 :00 4.00 DRILL DRLG PROD 21 :00 - 22:00 1.00 DRILL CIRC PROD 22:00 - 00:00 2.00 DRILL TRIP PROD 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 02:30 1.50 DRILL PULD PROD 02:30 - 05:30 3.00 DRILL PULD PROD 05:30 - 06:30 1.00 DRILL TRIP PROD 06:30 - 08:00 1.50 RIGMNT RURD PROD 08:00 - 08:30 0.50 DRILL SFTY PROD 10/23/2001 Page 4 of 9 Spud Date: 10/15/2001 End: 11/2/2001 Group: Start: 10/15/2001 Rig Release: 11/2/2001 Rig Number: 141 Description of Operations Preform FIT to 16.0 EMW - WI 10.0 ppg mud @ 2388' MD -Pump to 745 psi surface press ure Dir Drlg 2388' to 2728' MD (2726' TVD) - M WD Failed Circu hole clean TOH Remove RA Sources - Dn Load MWD - Inspec t Bit "Bit has extensive damage" Evaluate Bit damage - Discuss options with Team Leader Lay dn failed MWD ( failure found to be cou piing plud between SDN & MPR) LID motor, stab & remaining MWD Waiting on Globe Reverse Basket & BTC ope rator P/U Globe Reverse Junk Basket P/U Globe Reverse Basket TIH wI Reverse Basket to 2726' Brk Circu - Jet & Rotate to Bttm 2726' to 27 28' + TOH LID Fishing tools - Recovery: 2 large pi eces wipper plug ,spring from float equip,2 small pieeces metal (from float equip) and a large amount of shale(golf ball size and lar ger)1 did not see any metal that appeared to be from damaged bit. PIU BHA # 4 - Orient & program MWD TIH to 2360' Pulse test MWD - Con't TIH to 2648' Mad Pass logs for Baker MWD - 2648' to 27 28' Dir Drlg 2728' to 3580' MD (3278') ART 6.9 hrs , AST 2.1 hrs Dir Drlg 3580' to 4325' MD (4206' TVD) Dir Drlg 4325' to 4373' MD (4242' TV D) Wt Sweep pumped @ 4330' Circu hole clean Wiper Trip to Shoe @ 2351' TIH - Wash 90' to Bttm - No Fill Dir Drlg 4373' to 4515' MD ( 4356' TVD) -**1< 1< TOOL FAILURE**1< SND tools not working Clrcu Hole Clean - Monitor well - Pump dry j ob TOH - Monitor per tripping procedure Con't TOH for MWD Tool failure BHA - pull sources -Bk Bit - Dn Load MWD - LID MWD & Motor PIU Motor,Bit & MWD - program MWD -instal I sources TIH to 2260' Cut Drill Line - Service Rig & TD PJSM - New Crew-First Day of Hitch Printed: 1/17/2002 8:40:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/23/2001 10/24/2001 10/25/2001 10/26/2001 (' PHilliPS ALASKA INC. Operations Summary Report 2P-420 2P-420 ROT - DRILLING Doyon Doyon 141 Page 5 of 9 Spud Date: 10/15/2001 End: 11/2/2001 Group: Start: 10/15/2001 Rig Release: 11/2/2001 Rig Number: 141 Description of Operations Sub From - To Hours Code Code Phase 08:30 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 16:30 16:30 - 18:00 18:00 - 22:00 22:00 - 00:00 00:00 - 01 :30 01 :30 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 12:00 12:00 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 03:00 03:00 - 04:30 04:30 - 07:30 07:30 - 09:30 09:30 - 12:00 12:00 - 14:00 14:00 - 15:30 15:30 - 17:00 17:00 - 19:00 19:00 - 19:30 19:30 - 00:00 00:00 - 04:00 04:00 - 05:00 05:00 - 05:30 1.50 DRILL 1.00 DRILL 1.00 DRILL 4.50 DRILL 1.50 DRILL 4.00 DRILL 2.00 DRILL 1.50 DRILL 3.00 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 4.50 DRILL 12.00 DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 1.50 DRILL 3.00 DRILL 2.00 DRILL 2.50 DRILL 2.00 DRILL 1.50 DRILL 1.50 DRILL 2.00 DRILL 0.50 DRILL 4.50 DRILL 4.00 DRILL 1.00 DRILL 0.50 DRILL TRIP PROD REAM PROD SURV PROD DRLG PROD CI RC PROD TRIP PROD PULD PROD PULD PROD PULD PROD PULD PROD TRIP PROD CIRC PROD TRIP PROD SURV PROD DRLG PROD DRLG PROD SURV PROD DRLG PROD CIRC PROD TRIP PROD PULD PROD PULD PROD PULD PROD TRIP PROD SURV PROD TRIP PROD SURV PROD DRLG PROD DRLG PROD CIRC PROD CIRC PROD Con't TIH to 4180' - Tight hole Brk Circu - Ream and work tight spot at 418 0' - Wash to 4460' MADD pass log 4460' to 4515' MD Dir Drlg 4515' to 4791' MD (4554') - MWD To 01 Failed Circu hole clean TOH for failed MWD tool - Flow ck per polic y PJSM BHA - Remove sources - Dn load MWD - LID MWD/LWD P/U repaired tool PIU repaired MWD from pipe shed - Attempt to initialize tool- Tool not responding Baker Lead technician rebuild tools that had been pulled from hole. P/U rebuilt tools TIH to 2450' - Shallow Test MWD CBU - Condition Mud TIH to 4545' MD MADD pass 4545' to 4791' MD Dir Drlg 4791' to 5428' MD (5003' TV D) ART 7.9 hrs AST 1.4 hrs Dir Drlg 5428' to 5577' MD (5055' TVD) - M WD Tool Failure Trouble shoot MWD Failure Drlg 5577 to 5591' MD (5063' TVD) - Attemp t to initilize signal from tool -" No signal" Circu Hole Clean -(At the same time) Confer with Engineers(Steve Moothart & Pat Rielly ) Eng. Notified Team Leader - Decision mad e to pull tools and rebuild for another run. Baker was instructed to put together it's "B EST" group of tools with the "HIGHEST" cha nce of completing the well. TOH - Monitor well per trip procedure BHA - Remove sources - Drain motor - Attem pt Dn load MWD (Tool will not communicate - LID MWD & SDN PIU rebuilt SND -Attempt to initilize tool - N 0 communication - Rebuild SND and trouble shoot Source test SND - Program MWD - Orient to 01 - Load sources TIH to 2360' - CBU Trouble shoot and Shallow test MWD Con't TIH to 5527' MADD pass 5527' to 5591' MD Dir Drlg 5591' to 5783' MD ( 5188' TVD) Dir Drlg 5783' to 5898' MD (5257' TVD) - M WD Tools failed Circu hole clean - Confir wI DTL & Engineer s Stop pumps -Monitor well per policy(Static) Printed: 1/17/2002 8:40: 16 AM f ( Page 6 of 9 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/26/2001 05:00 - 05:30 0.50 DRILL CIRC PROD 05:30 - 09:00 3.50 DRILL TRIP PROD 09:00 - 10:30 1.50 DRILL PULD PROD 10:30 - 12:00 1.50 WELCT BOPE PROD 12:00 - 17:00 5.00 WELCT BOPE PROD 17:00 - 17:30 0.50 WELCT BOPE PROD 17:30 - 18:30 1.00 RIGMNT RSRV PROD 18:30 - 21 :00 2.50 DRILL PULD PROD 21 :00 - 23:00 2.00 DRILL TRIP PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 10/27/2001 00:00 - 00:30 0.50 RIGMNT RSRV PROD 00:30 - 01 :30 1.00 DRILL TRIP PROD 01 :30 - 03:00 1.50 DRILL REAM PROD 03:00 - 00:00 21.00 DRILL DRLG PROD 10/28/2001 00:00 - 05:00 5.00 DRILL DRLG PROD 05:00 - 07:00 2.00 DRILL CIRC PROD 07:00 - 07:30 0.50 WELCT OBSV PROD 07:30 - 09:00 1.50 DRILL WIPR PROD 09:00 - 10:30 1.50 DRILL CIRC PROD 10:30 - 11:00 0.50 WELCT OBSV PROD 11 :00 - 16:30 5.50 DRILL PROD TRIP Spud Date: 10/15/2001 End: 11/2/2001 Group: Start: 10/15/2001 Rig Release: 11/2/2001 Rig Number: 141 Description of Operations - Pump dry job - Blow dn mud lines and Top Drive TOH - Monitor fill & flow per Phillips proced ure BHA - Remove sources - LID NDT , MWD & L WD (Baker will attempt repair) R/U & pull wear bushing - Set Test plug. Test Choke Manif & BOPs 250psi/3500psi all equip - No#1 on choke manifold failed - Re place valve - Re-test "OK" AOGCC rep Chuc k Scheve waived witness test. RID test equip - Pull test plug - install wear bushing - RILDS C/O Bell Guide on Top Drive PIU BHA # 8 - M/U Bit,Motor,MWD- orient to 01 - Program MWD TIH to Shoe - CBU - Shallow test MWD Con't TIH - (@ 4165' Midnight) Rig service TIH to 5850' Run MWD log F/5850' to 5898', MAD pass Drill from 5898' to 6659' MD, 5744' TVD AR T = 14.5 hrs. AST = 2.0 hrs. Lost 65 bbls of mud to formation at 6650' and start loss ing at 10 bbls per hr. their after. Pumped a LCM sweep with no effect. When we shut the pump down we get the mud coming back, sl owing down to nothing with time.( Formation ballooning) Drill from 6659' to 6860' MD, 5863 TVD. Los t mud to formation at 10 bbls per hr. while d rill i n g. Circ. and condo hole, pump weighted sweep, lost 150 bbls of mud to formation while tryi ng to pump weighted sweep out of hole, redu ced circ. rate during losses. Shut off pumps, check for flow, well flowing , monitor in trip tank, flow declined to a tric kle after 30 mins. Determined well was brea thing, from ballooning formation. Short trip new hole, to 5800', well didn't tak e proper fill until 9th stand out of hole Circ. and condo hole, lost 59 bbls mud to for mati on while circulating at 252 gpm. Bottom s up had 250 units of gas, normal drilling g as was 30 to 50 units, Shakers were clean Shut down pumps, well flowing, observe well to trip tank, flow slowed to a trickle in 30 mins. POOH for logs, hole didn't take proper fill t he first 5 stands, check for flow, no flow, C ontinue to POOH, hole taking proper fill, no tight spots. Printed: 1/17/2002 8:40: 16 AM ,( (' PHilliPS ALASKA INC. Operations Summary Report 21 :30 - 22:30 1.00 LOG PULD PROD 22:30 - 00:00 1.50 LOG TRIP PROD 10/29/2001 00:00 - 02:30 2.50 LOG TRIP PROD 02:30 - 10:00 7.50 LOG TRIP PROD 10:00 - 12:00 2.00 LOG CIRC PROD 12:00 - 13:30 1.50 LOG TRIP PROD 13:30 - 14:00 0.50 LOG CIRC PROD 14:00 - 16:00 2.00 LOG TRIP PROD 16:00 - 17:00 1.00 LOG TRIP PROD 17:00 - 18:00 1.00 LOG PULD PROD 18:00 - 22:00 4.00 LOG ELOG PROD Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/28/2001 16:30 - 17:30 1.00 DRILL PULD PROD 17:30 - 18:30 1.00 LOG PULD PROD 18:30 - 21:30 3.00 LOG ELOG PROD 10/30/2001 22:00 - 00:00 2.00 LOG ELOG PROD 00:00 - 12:30 12.50 LOG ELOG PROD Page 7 of 9 Spud Date: 10/15/2001 End: 11/~2001 Group: Start: 1 0/15/2001 Rig Release: 11/2/2001 Rig Number: 141 Description of Operations LID MWD tool and motor RIU and PIU Schlumberger logging equipmen t Run in hole with log run #1, PLATFORM EXP RESS with hole finder on bottom of tool, tag and set down at 5088', took 1 hr. of workin g tool to fall thru this spot, continue in hole to 5300', started to hang up again, worked tool to 5370', tool stuck, worked tool free w ith 4600 Ibs pull, POOH to make wiper trip w ith hole opener. LID Schlumberger tools PIU hole opener, bit sub, float sub, 6 5/8" s tab, DC, 6 5/8" stab, and rest of BHA, RIH TIH to 5000" Wash and Ream hole from 5000' to 6860', ti ght hole f/5353' to 5449' and 6570' to 6860' Circ and cond hole, spot drill and slide pill from bottom to 5000' Flow check, POOH 15 stds. monitoring hole fill Pump dry job POOH LID hole opener and stabilizers, stand back DC's R/U and P/U Schlumberger tools, hold pre-jo b safety meeting Re-Run log #1 Platform express, tool set do wn at 6292', P/U and stuck tool at 6188', wo rk tool free with 6700 Ibs. overpull, Work to 01 back down to 6292', took several try's to work thru tight spot from 6292' to 6300', co ntinue to bottom, 6868' loggers depth. Log f rom bottom to 7 5/8" casing shoe (2358'), di dn't have any problems coming thru tight sp ot at 6292'. POOH, LID tool PIU and Run log #2 FMS, set down at 6310', working thru tight spot at 6310' Run log #2 FMS - work thru tight spot at 631 0 to 6315', Run in to bottom, Log up from 68 60' to 5300', had 4000 Ibs overpull coming u p thru spot at 6310', POOH, LID tool P/U a nd Run log #3, RFT, correlate with 1st log r un(platform express), Take pressures as pic ked by geologist on the way in the hole star ting at 6283, after 5th set, hit tight spot at 6310', worked tool thru to 6325' and fell thr u, RIH to 6500', correlate tool with 1st log r un(platform express), Start taking pressures as picked by geologist coming up from 642 6' back to 6283', didn't see tight spot at 63 10'. Had no problems setting or releasing to 01, POOH Printed: 1/17/2002 8:40:16 AM (' l 11 PHilliPS ALASKA INC. Operations Summary Report 19:30 - 23:00 3.50 DRILL TRIP PROD 23:00 - 00:00 1.00 DRILL RIRD PROD 11/1/2001 00:00 - 02:30 2.50 CASE RUNC PROD 02:30 - 04:30 2.00 CASE RURD PROD Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/30/2001 12:30 - 13:00 0.50 LOG PULD PROD 13:00 - 13:30 0.50 RIGMNT RSRV PROD 13:30 - 14:30 1.00 DRILL PULD PROD 14:30 - 16:30 2.00 DRILL DEOT PROD 16:30 - 18:30 2.00 DRILL DEOT PROD 18:30 - 20:30 2.00 DRILL TRIP PROD 20:30 - 00:00 3.50 DRILL OTHR PROD 10/31/2001 00:00 - 09:30 9.50 DRILL OTHR PROD 09:30 - 11 :30 2.00 DRILL CIRC PROD 11:30-12:00 0.50 WELCT OBSV PROD 12:00 - 19:30 7.50 DRILL TRIP PROD 11/212001 04:30 - 06:00 1.50 CASE RURD PROD 06:00 - 08:00 08:00 - 09:00 2.00 CASE RUNC PROD 1.00 RIGMNT RGRP PROD 09:00 - 13:00 4.00 CASE RUNC PROD 13:00 - 14:00 1.00 CASE RURD PROD 14:00 - 00:00 10.00 CEMEN CIRC PROD 00:00 - 01 :30 1.50 CEMEN PUMP PROD Page 8 of 9 Spud Date: 10/15/2001 End: 11/2/2001 Group: Start: 10/15/2001 Rig Release: 11/2/2001 Rig Number: 141 Description of Operations LID tools and RID Schlumberger Rig service, Service top drive P/U hole opener, XO's and MWD tool, surfac e test Baker MWD, failed LID MWD to pipe shed, trouble shoot tool, f ound fuse blowen inside tool, repair same. PIU MWD, load source, test MWD, TIH with BHA TIH to 5800' Mad Pass with MWD from 5800' to 6024' Finish Mad Pass with MWD from 6024' to 68 60' M D Circ. and Condo Hole for running casing Check for flow, fill trip tank, blow down sta nd pipe and top drive with air. POOH LID drill pipe, pump dry job after pull ing 15 stands, check for flow at the shoe an d at the BHA POOH LID HWDP, jars, DC's, download MWD and LID Pull wear bushing and R/U to run casing Run 21 jts. 3 1/2" casing and float equip. RID 3 1/2" casing equip., RIU to run 5 1/2" casing, had a broblem with the casing pup jt on top of the seal bore extension. The PuP jt. was a 6" OD, threaded with 5 1/2" BTC a nd the elevators or casing slips wouldn't wo rk. Things had to be modifid for one connec t ion Change out guide bowl and grabber dies on t op drive, the OD of the Franks Fill Up tool HT-38 box was to big to go into the top driv e guide and grabber dies, had to change out to larger guide and dies. Run 5 1/2" casing to 2475' Repair pipe handling skate, Had oil leak, ne eded by pass leak and fill machine with oil. Run 5 1/2" casing to 6822', filling every jt w ith Frank's fill up tool and breaking circ. ev ery 2000'. Seen no tight spots RID Franks fill up tool, blow down top drive, P/U landing jt. and casing hanger, P/U Dow ell cementing head Circ and cond mud, lost partial returns, pum p LCM sweep, 35 bbls of 15 PPB various typ es and sizes of LCM. Follow with mud contai ning 6 to 10 PPB LCM. Slowly regain circula tion, cut mud weight from 10 ppg to 9.8 ppg. Regained full returns, circ. with full return s while waiting on Dowell to bring cellophan e Flakes for cement job. TOTAL MUD LOST TO HOLE WHILE CIRC. WAS 403 BBLS. Hold pre-job safety meeting, test cement lin Printed: 1/17/2002 8:40: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/2/2001 ( PHilliPS ALASKA INC. Operations Summary Report 2P-420 2P-420 ROT - DRILLING Doyon Doyon 141 Sub From - To Hours Code Code Phase 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 09:00 09:00 - 10:30 1.50 CEMEN PUMP PROD 0.50 CEMEN RURD PROD 1.00 WELCT NUND PROD 1.00 CMPL TN RURD CMPL TN 5.00 CMPL TN RUNT CMPL TN 1.50 CMPL TN SOHO CMPL TN 10:30 - 11 :00 0.50 CMPLTN CIRC CMPL TN 11 :00 - 11 :30 0.50 CMPL TN SOHO CMPL TN 11:30 -13:00 1.50 CMPL TN DEOT CMPL TN 13:00 - 13:30 13:30 - 16:30 16:30 -18:30 18:30 - 20:30 20:30 - 00:00 0.50 WELCT NUND CMPL TN 3.00 WELCT NUND CMPL TN 2.00 WELCT NUND CMPL TN 2.00 CMPL TN FRZP CMPL TN 3.50 CMPL TN FRZP CMPL TN Page 9 of 9 Spud Date: 10/15/2001 End: 11/2/2001 Group: Start: 10/15/2001 Rig Release: 11/2/2001 Rig Number: 141 Description of Operations es to 3500 psi, pump 30 bbls mud push at 1 0.5 ppg, mix and pump 255 sx artic set at 1 5.8 ppg, yd 1.2 cu ft per sk, with .4% cellofl ake, displace with water, bump plug, floats held OK, had no fluid loses during cement j 0 b. RID cement equip., LID landing jt. Set casing x wellhead pack off, test to 5000 ps i R/U to run completion equip. and 3 1/2" tubi ng Run in hole with Baker seal assembly on 3 1 12" tubing, 194 jts. 3.5" L-80 9.3# EUE mod 8rd. Space out seal assembly so it will be l' abo ve locators when hung off and install tubing hanger Reverse circ. tubing until fluid is clean ( fr esh water) Land hanger and run in hanger lock down sc rews Test tubing by casing annulus to 3000 psi fo r 30 mins, shear valve in gas lift mandrel wi th 3200 psi Set back pressure valve in tubing NID BOP's N/U FMC 5000 psi tree, pull back pressure v alve and install 2 way check, test tree to 25 0 psi low and 5000 psi high, test pack off to 5000 psi., pull 2 way check. R/U and pump 40 bbls diesel down 3 1/2 x 5 1/2" annulus, let u-tube to tubing, install B PV. R/U on 5 1/2" x 7 5/8" annulus, perform LOT , pump 92 bbls flush water and 54 bbls freez e protection diesel. Blow down lines with air Release rig at 00:00 hrs (midnight) 11/0 2/01 Printed: 1/17/2002 8:40:16 AM Date 12/13/01 12/14/01 12/22/01 12/23/01 ( (" 2P-420 Event History Comment TAGGED FILL @ 67001 WLM. INSTALLED DV @ 60451RKB. PT TBG & CSG TO 2500#. GOOD [PT TBG- CSG, TAG, GLV] CLEANED OUT FILL TO TD AT 67031 CTM WI A 2.25" JET-SWIRL NOZZLE USING SEAWATER J313 AND SLICK DIESEL. WELL FREEZE PROTECTED TO 25001+ WI DIESEL. [FCO] RUN 1 11/16 CBL (SCMT) FOR CEMENT BOND. PERFORATE 63861-64221 WI 2.5" HSC 6 SPF, 60 DEG PHASED, POWERJET CHARGES. MAP-- CCL-GAMMA RAY-MAP TOOL SHOOT 2.5 POWERJETS @ 6SPF PERFORATE 6361'-741,6324'-521,62721-320' WITH 6 GUNS LOADED WITH 2.5" HSC 6 SPF, 60 DEG PHASED, POWERJET CHARGES. OBTAIN SBHP AT 6347' (2439 PSI), AND 6203' (2384 PSI), [PERF] Page 1 of 1 1/17/2002 ~ ( ( ~, Phillips Alaska, Inc. Drill Site 2P 420 slot n420 Meltwater North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref: MWD <0-6860'> Our ref: svy6610 License: Date printed: 14-Jan-2002 Date created: 17-0ct-2001 Last revised: 14-Jan-2002 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.754,w150 26 50.778 Slot Grid coordinates are N 5868984.299, E 444088.453 Slot local coordinates are 891.04 S 2131.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North (" ( Phillips Alaska, Inc. SURVEY LISTING Page 1 Drill Site 2P,420 Your ref : MWD <0-6860'> Meltwater,North Slope, Alaska Last revised: 14-Jan-2002 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O,OOE 0.00 0.00 444088.45 5868984.30 150.00 0.00 0.00 150.00 O.OON O.OOE 0.00 0.00 444088,45 5868984.30 180.00 0.44 344.64 180.00 O.l1N 0.031'1 1. 47 -0.06 444088.42 5868984.41 203.00 0,44 20.85 203.00 0.28N 0.021'1 1.19 -0.09 444088.43 5868984.58 298.50 0.35 28.60 298.50 0.88N 0.25E 0.11 0.03 444088.71 5868985.18 392.90 0.53 17.30 392.89 1. 55N 0.52E 0.21 0.13 444088.98 5868985.84 487.40 0.70 358.00 487.39 2.54N 0.63E 0.28 0.01 444089.10 5868986.84 579.00 0.70 5.39 578.98 3.66N 0.66E 0.10 -0.23 444089.14 5868987.95 671. 40 0.62 10.31 671. 38 4.71N 0.80E 0.11 -0.34 444089.29 5868989.00 764.60 0.70 1. 87 764.57 5.78N 0.91E 0.13 -0.48 444089.41 5868990.07 857.10 0.35 30.35 857.07 6.59N 1. 07E 0.46 -0.52 444089.57 5868990.88 948.80 0.26 7.85 948.76 7.03N 1. 24E 0.16 -0.46 444089.75 5868991.32 1041. 90 1.05 199.10 1041.86 6.44N 0.99E 1. 40 -0.56 444089.49 5868990.73 1134.60 1. 23 208.59 1134.54 4.76N 0.24E 0.28 -0.90 444088.73 5868989.06 1226.70 1.14 205.07 1226.62 3.06N 0.621'1 0.13 -1. 33 444087.85 5868987.37 1319.90 1. 05 202.26 1319.81 1. 43N 1. 341'1 0.11 -1. 64 444087.12 5868985.74 1415.70 0.97 198.39 1415.59 0.155 1. 931'1 0.11 -1. 84 444086.52 5868984.16 1511.00 1. 05 199.10 1510.88 1.745 2.471'1 0.08 -1. 99 444085.97 5868982.58 1607.40 0.62 210.35 1607.26 3.025 3.02\'1 0.48 -2.22 444085.41 5868981. 30 1705.70 0,35 224.76 1705.56 3.705 3.501'1 0.30 -2.53 444084.92 5868980.63 1801.29 0.35 215.27 1801.15 4.145 3.88\'1 0.06 -2.79 444084.54 5868980.19 1897.70 0.26 277.49 1897.56 4.355 4.26\'1 0.34 -3.11 444084.16 5868979.98 1993.50 0.18 314.06 1993.36 4.225 4.591'1 0.16 -3.46 444083.83 5868980.11 2090.00 0.18 324.25 2089.86 3.995 4.78\'1 0.03 -3.70 444083.64 5868980.34 2184.10 0.18 326.36 2183.96 3.755 4.95\'1 0.01 -3.92 444083.47 5868980.59 2281.40 0.26 341.83 2281.26 3.415 5.11\'1 0.10 -4.15 444083.32 5868980.93 2295.70 0.26 308.43 2295.56 3.365 5.14\'1 1. 04 -4.20 444083.29 5868980.98 2371.30 0.44 340.20 2371.15 2.98S 5.37\'1 0.34 -4.52 444083.06 5868981.36 2467.70 0.44 0.81 2467.55 2.265 5.49\'1 0.16 -4.80 444082.94 5868982.08 2563.20 3.08 103.12 2563.01 2.485 2.99\'1 3.35 -2.32 444085.44 5868981. 84 2644.60 4.83 95.74 2644.21 3.325 2.55E 2.23 3.26 444090.98 5868980.96 2754.76 6.24 86.60 2753.86 3.435 13.14E 1.51 13.58 444101.57 5868980.77 2848.90 8.96 98.55 2847.17 4.215 25.50E 3.33 25.77 444113.92 5868979.89 2946.40 10.72 101.71 2943.23 7.185 41. 89E 1. 89 42.40 444130.28 5868976.80 3043.10 11.34 118.94 3038.17 13.615 59.02E 3.46 60.57 444147.36 5868970.24 3137.80 11. 60 128.43 3130.98 24.045 74.63E 2.01 78.20 444162.89 5868959.70 3232.90 12.48 119.64 3224.00 35.065 91. 05E 2.14 96.76 444179.23 5868948.55 3329.50 14.59 118.59 3317.91 46.055 110.81E 2.20 118.56 444198.90 5868937.41 3426.30 16.96 119.64 3411.06 58.875 133.79E 2.47 143.92 444221. 78 5868924.42 3531. 20 18.98 116.83 3510.84 74.135 162.31E 2.09 175.24 444250.18 5868908.94 3618.40 21. 01 111.56 3592.78 86.285 189.51E 3.11 204.54 444277.28 5868896.59 3713.70 23.38 109.10 3681.02 98.755 223.27E 2.67 240.29 444310.94 5868883.86 3810.00 25.66 105.58 3768.63 110.605 261.42E 2.81 280.16 444349.00 5868871.72 3906.10 27.86 102.77 3854.44 121.165 303.37E 2.64 323.42 444390.86 5868860.85 4002.20 30.23 102.06 3938.45 131.175 348.93E 2.49 370.06 444436.34 5868850.48 4099.10 32.61 103.47 4021.13 142.355 398.19E 2.57 420.56 444485.50 5868838.93 4194.90 34.54 100.66 4100.95 153.395 449.99E 2.59 473.50 444537.21 5868827.50 4289.20 36.39 102.06 4177.76 164.185 503.62E 2.14 528.17 444590.76 5868816.30 4386.10 38.50 99.25 4254.69 175.045 561.51E 2.80 586.98 444648.56 5868805.00 4480.80 40.69 98.90 4327.66 184.565 621. llE 2.32 647.14 444708.08 5868795.03 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #420 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level). Bottom hole distance is 2458.63 on azimuth 103.49 degrees from wellhead. Vertical section is from wellhead on azimuth 103.68 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ .: (' (' Phillips Alaska, Inc. 5URVEY LI5TING Page 2 Drill 5ite 2P.420 Your ref : MWD <0-6860'> Meltwater,North 5lope, Alaska Last revised: 14 -Jan-2002 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO R DIN ATE 5 Deg/l00ft 5ect Easting Northing 4577.10 42.28 101.36 4399.80 195.795 683.89E 2.36 710.80 444770.76 5868783.32 4672.40 43.77 103.12 4469.47 209.595 747. DE 2.01 775.79 444834.19 5868769.04 4771.30 46.05 101. 71 4539.51 224,585 815.61E 2.52 845.59 444902.25 5868753.53 4866.80 47.64 103.12 4604.83 239.575 883.64E 1. 98 915.24 444970.16 5868738.02 4964.30 49.39 104.17 4669.42 256.815 954.61E 1. 97 988.27 445040.99 5868720.25 5059.20 50.27 104.88 4730.63 275.005 1024.81E 1. 09 1060.78 445111.04 5868701. 52 5155.00 51.15 104.53 4791. 30 293.825 1096.53E 0.96 1134.91 445182.60 5868682.16 5250.40 52.29 104.17 4850.40 312.385 1169.08E 1.23 1209.79 445255.00 5868663.05 5348.00 51. 59 103.47 4910.56 330.745 1243.70E 0.91 1286.64 445329.47 5868644 .13 5453.60 51. 33 101. 36 4976.36 348.505 1324.35E 1. 58 1369.21 445409.99 5868625.76 5539.20 50.19 102.42 5030.51 362.155 1389.23E 1. 64 1435.47 445474.75 5868611.61 5635.40 49.83 101. 71 5092.34 377.565 1461.30E 0.68 1509.14 445546.70 5868595.66 5731. 80 50.89 101. 36 5153.83 392.405 1534.04E 1.13 1583.32 445619.31 5868580.26 5834.60 49.39 98.55 5219.73 406.065 1611. 74E 2.56 1662.05 445696.90 5868566.01 5923.00 48.87 98.90 5277.57 416.205 1677.81E 0.66 1728.65 445762.89 5868555.37 6019.10 49.66 98.55 5340.28 427.245 1749.79E 0.87 1801.19 445834.77 5868543.78 6116.10 50.54 97.85 5402.50 437.855 1823.44E 1.06 1875.27 445908.33 5868532.61 6211.40 50.36 100.31 5463.19 449.455 1895.99E 2.00 1948.50 445980.78 5868520.46 6307.60 50.01 102.77 5524.79 464.225 1968.38E 2.00 2022.33 446053.05 5868505.14 6404.00 50.80 104.53 5586.24 481. 765 2040.56E 1. 63 2096.61 446125.09 5868487.05 6499.60 51.59 104.53 5646.15 500.455 2112. 68E 0.83 2171.10 446197.05 5868467.82 6595.20 52.38 105.58 5705.02 520.015 2185. HE 1. 20 2246.39 446269.62 5868447.70 6691.80 53.09 104.88 5763.52 540.215 2259.59E 0.93 2323.24 446343.64 5868426.94 6787.80 53.70 104.17 5820.76 559.535 2334.19E 0.87 2400.30 446418.08 5868407.05 6797.20 53.79 103.82 5826.32 561.375 2341.54E 3.15 2407.88 446425.42 5868405.16 6860.00 54.00 103.80 5863.32 573.485 2390.81E 0.34 2458.62 446474.60 5868392.68 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #420 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level). Bottom hole distance is 2458.63 on azimuth 103.49 degrees from wellhead. Vertical section is from wellhead on azimuth 103.68 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ .; ,. Phillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 6860.00 5863.32 Top MD Top TVD ----------------------------------------------------------------------------------------------------------- 7 5/8" Casing 0.00 Target name Rectangular Coords. 573.485 Rectangular Coords. 0.00 O,OON ( SURVEY LISTING Page 3 Your ref: MWD <0-6860'> Last revised: 14-Jan-2002 Comment Comments in wellpath -------------------- 2390.81E Projected Data - NO SURVEY Bot MD Casing positions in string 'A' Rectangular Coords. O,OOE 2351.00 ------------------------------ 3.12S Bot TVD 2350,86 Targets associated with this wellpath Geographic Location ------------------------.------------ 2016.54E T.V.D. Rectangular Coordinates (' Casing 5.32\>1 Revised ----------------------------------------------------------------------------------------------------------- 22-Feb-2001 MW(J) Rvsd 12 Jun 01 446101.000,5868478.000,999.00 5582.00 491.005 Sc~lIn~epgep NO. 1750 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Company: Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Log Description Date BL Sepia CD Color Job # 2P-420 21484 PEX,AIT & FMS 10/29/01 1 2P-420 21484 PEX-AIT 10/29/01 1 1 2P-420 21484 PEX-AIT SSTVD 10/29/01 1 1 2P-420 21484 PEX-NEUTRONIDENSITY 10/29/01 1 1 ~ 2P-420 21484 PEX-NEUTRONIDENSITY SSTVD 10/29/01 1 1 2P-420 21484 PEX-TRIPLE COMBO 10/29/01 1 1 - 2P-420 21484 PEX-TRIPLE COMBO SSTVD 10/29/01 1 1 2P-420 21484 PEX-CALIPER LOG 10/29/01 1 1 2P-420 21484 FMS 10/29/01 1 1 ) 2P-420 21484 RFT 10/29/01 1 1 a ~ RECEIVED DATE: FEB 0 1 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank yo~OiI&GasCons, Cornmi8IIor AndIorage 01 /28/02 ..-,. ~~~ --- óbl - ddb ~O l-olð9 a 0 ,- , ~ ~ aOI-dÒO õ?OI-aa1 d,oJ- ,t...-I d ,60)- ~J -7=--- Sc~__ergep NO. 1725 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Company: Field: Well Job# Log Description Date BL Sepia 01 /15/02 Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD Color 2P-415A PRESSrrEMP STATION LOGS 12/24/01 1 1 2P-417 STATIC BOTTOM HOLE PRESS SURVEY 12/13/01 1 1 2P-420 PRESSrrEMP STATION LOGS 12/23/01 1 1 1 C-135 22010 USIT 12/18/01 - 1 1 R-36 22009 USIT 12/27/01 1 2N-348 22011 SCMT 12/09/01 1 2P-420 22008 SCMT 12/22/01 1 REC~ï:i\¡;- 'I SIGNE&- ~-(J2e~ DATE: JAtI 2 5 2ODL Alaska Oil & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, Thank you. Anchorage , (' ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,AJaska 9951QH)360 C. Mallary Phone(907)265~434 Fax: (907) 265~224 January 3, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approvals for 2P-420 Dear Commissioner: Phillips Alaska, IDc, submits the attached Application for Sundry Approvals for 2P-420. Weare requesting approval for annular injection down this well. If you have any questions regarding this matter, please contact Pat Reilly at 265-6048. Sincerely, CR C. Mallary Drilling Engineering Supervisor P AI Drilling CM/skad RECEIVED dAN 04 2002 Alaska 011 & Gas Cons. Commission Anchorage ('" f.,"""'1?'... 1.1. ;."'-.' .... F..'. '..'..... I..'.' ...' r ' ¡, ¡ r ... I I , ,.' ~~-(;t--:(I,.\i;.::j.l: .J~\ ,,~jl \Jl\.l 1. Type of request: !' " LJ, rJ IIJ G .4 We I 0 L STATE OF ALASKA ( ~ ~~. 'I'ð ID~ ALASKA OIL AND GAS CONSERVATION COMMISSIO . \\ DIT:) 1/10 /0 '¿ APPLICATION FOR SUNDRY APPRO ALS d1t1JJ 1/15/02- ( Abandon- Suspend- Alter casing - Repair well - Change approved program Operational shutdown - Plugging - Pull tubing 5. Type of Well: 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface Development - Exploratory - Stratigraphic - Service X 892' FNL, 3150' FEL, Sec. 17, T8N , R7E, UM At top of productive interval 1335' FNL, 1212' FEL, Sec. 17, T8N, R7E, UM At effective depth (asp's 444089, 5868984) (asp's 446026.5. 5868527) At total depth 1450'FNL, 757'FEL,Sec.17,T8N, R7E,UM 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing CONDUCTOR SURFACE PRODUCTION PRODUCTION Perforation depth: (asp's 446480. 5868411) measured true vertical 6860 feet 5863 feet 6720 feet 5780 feet Junk (measured) Re-enter suspended well- Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 26 feet 7. Unit or Property name Other _X Annular Disposal Kuparuk River Unit 8, Well number 2P-420 9. Permit number / approval number 201-182 10. API number 50-103-20391-00 11. Field / Pool Ku aruk River Field / Meltwater Pool Plugs (measured) cement plugs @ 6720' Length 108' 2351' 6156' 694' Size Cemented Measured Depth True vertical Depth 16" 9 cu yds High Early 108' 108' 7-5/8" 207 bbls AS III Lite, 64 bbls 2351' 2351' LiteCrete 5-1/2" 255 sx Class G 6156' 5422' 3-1/2" (included above) 6850' 5853' measured None true vertical None Tubing (size, grade, and measured depth 3-1/2",9.3#, L-80 Tbg @ 6156' MD. j No packer Packers & SSSV (type & measured depth) CAMCO 'OS' NIPPLE W/2.875" PROFILE @ 488' MD. Description summary of proposal - Detailed operations program - BOP sketch - Refer toattachëd morning drilling report for LOT tests, surface cement details and casing detail sheets, schematic_X 14. Estimated date for commencing operation 15. Status of well classification as: January 17, 2002 16. If proposal was verbally approved 13. Attachments Oil- RECEIVED JAN 04 2002 Alaska Oil & Gas Cons. Commission Anchorage Gas- Suspended - Name of approver Date approved Service -_X 17. I hereby ccrti~' Ihe foregoin~ i hue ~nd co"",,' 10 Ihe best of my knovAedgc. Signed C ~ n /. .. TIDe: Drilling Engineering Supervisor C.Mal/a FOR COMMISSION USE ONLY Conditions of approval: Notify Commiss so representative may witness Plug integrity - BOP Test - Location clearance - f} ~ ,9 t t- Mechanical Integrity Test - Subsequent form required 10- I<€ r f) i. f) Original Signed By ( /, ~1 ! ("""" fi ; '; ;; -). ~,:J,.(,." ~I" ,~..~ II Ii (I ~ \ I,) 'I 1 ,;' .,..."" u u \;; Approved by order of the Commission Form 1 0-403 Rev 06/15/88 . Approval no. Commissioner ,I it SUBMIT IN TRIPLICATE ( (' Annulus Disposal Transmittal Form - Well 2P-420 A. Designation of the well or wells to receive drilling 2P-420 wastes: B. The depth to the base of freshwater aquifers and No Aqujérs / Base Permafrost = +/- 1454' TVD RKB permafrost, if present. / C. A stratigraphic description of the interval exposed to the From the 9-5/8" shoe./to the Cement top all that is open open annulus and other information sufficient to support is interbedded claystone, siltstone and shale with a commission finding that the waste will be confined and occasional minor non-hydrocarbon bearing sands. will not come to the surface or contaminate freshwater. D. A list of all publicly recorded wells within one-quarter See attached horizontal plane clearance report and plot ./ mile and all publicly recorded water wells within one mile indicating one well (2P-417) within 1/4 mile of the of the well to receive drilling waste. surface casing shoe of 2P-420. There are no potable water wells within one mile of 2P-420. Well 2P-417 pas been permitted for annular disposal with 6825 bbls having been disposed of down this well as of 1/3/02. E. Identify the types and maximum volume of waste to be Types of waste can be drilling mud, drilling cuttings, disposed of and the estimated density of the waste cement-contaminated drilling mud, completion fluids, slurry, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,~.~~..-~ bbls. ,--- F. An estimate of maximum anticipated pressure at the Maximum anticipated pressure at casing shoe during outer casing shoe during annular disposal operations disposal operations is 1,952 psi. See attached and calculations showing how this value was calculation page. determined. G. Details that show the shoe of the outer casing is set See attached: cementing reports, LOT / FIT reports and below the base of any freshwater aquifer and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation: H. Details that show the inner and outer casing strings See attached casing summary sheet and calculation have sufficient strength in collapse and burst to pages. withstand anticipated pressure of disposal operations: I. Any additional data required by the Commission to confirm containment of drilling wastes: '" (1 ø '" (1 ø Well 2P-420 Date 1/3/2002 '" (1 ø '" (1 ø Surface Tbg Intermediate (' ( TVD 2351 ft. Surface CasinQ Size Wt. Grade Pburst @ 100% Pburst @ 85% Fluid Weigth on Backside Max Disposal Pressure 7.625 In. 29.70 Ibs. L 80 6890 psi 5857 psi 8.3 ppg 1500 psi Maximum Mud Weight = (to burst casing) Surface Casing Burst MMW = Pb@85%+(Fluid Weight on Backside)(.O52)(TVD)-Max Disposal Press (.O52)(TVD) 43.9 ppg Maximum Pressure at Surface Shoe Max Disposal MW 12.0 ppg Max Pressure at Surface Shoe = 1952 psi Max Pressure at Surface Shoe Max Press=Max Disposal Press+(Max Disposal MW)(.O52)(TVD)-(Fluid Wt. On Backside)(.O52)(TVD) Intermediate CasinQ Size Wt. Grade Pcollapse @ 100% Pcollapse @ 85% Gas Depth (TVD) Gas Gradient Max Disposal Pressure 5.500 In. 15.50 Ibs. L 80 4990 psi 4242 psi 2351 ft. 0.11 ppg 1500 psi Maximum Mud Weight = (to collapse casing) 24.5 ppg Intermediate Casing Collapse MMW = Pc@85%+(Gas Gradient)(Gas TVD)-Max Disposal Press (TVD)(.O52) ( ( Phillips Alaska, """,....,..........,.................. ..,.. ...., ............" Inc. c-.. by """.'" Do.. ...... , 3O-0c<-2001 ...... ...~~. ;0 ...., cO-""">, , c-""'n..';.'"""~_"""",,, ;,.... ."'1<0' Oop'" ~ """"C' OK. (..,.. "'~' '"fA:' ..,I,:':~,~"", Structure: Drill Site 2P Field: Meltwater Location ., TRÜËNORT¡::¡' "" ..c:r = 0 Well: 420 : North Slope. Alaska; 350 10 340 1440 20 1-'2Al..,..,... -"'-"""'....,..,.~20 310 """ """" 330 30 40 50 300 60 70 280 80 270 '-""'...:.~ .-..~ 260 100 250 240 120 230 130 220 140 Horizontal Clearance - Feet i 2101 ! !1J 150 200 160 190 180 170 All depths shown are Vertical depths on Reference Well c;..".... ;;;';¡;;~~;;" Do'o pIO"" , 30-0<'-2001 Plol "'~",' :. WI) <0-6860'>. Co.'d"""" 010 'n ,... ,o'"one. 0101 "20- ,TM Yo"'<ol Cop'.' 0.. Iii.' RK. (o.,.on 1<1).' 0&11.. ~ II<T~Q Scale 1 ;nch = 100 It 1400 1300 1200 1100 f ( :-~- ~~!_!,~_P.~._._~_!.~.?_~-~~-, ,,' _1 n c Well: 420 Structure: Drill Site 2P Field: Meltwater 1000 I>OQ 000 700 = '00 300 000 1320 ft I / I / / / / / / / I / / / / / ! / I ./JI. . 6/8 C,,'n. I I I & vJ¿/{s bJl - c / >Vr Qt/L~ Lc;>/~j 5/.fD¿ Location: North Slope, Alaska East (feet) -> 200 "'" 1200 1300 000 '00 800 1100 100 100 200 '00 600 000 1000 1...".1 '" ""'" ""'" """" ...,.,. ,., .,.,., ...,., ~ P '/8 Co.I" r4i71 ~"""""""""'~C."" .. ' '/8 .,'. (1- )3;0 ¡-TV])) Jí (JIJ)e. oJ- 2P"1J,,!:> ¿J I ílil N 1000 1= 1'00 "00 1300 1200 1100 1000 000 800 '°0 600 600 .00 300 ^ I Z 0 :J. ::T 200 '°0 ~ (þ .=. 100 V1 0 S. ::T ~ - CD CD ..:::. 200 300 I V .00 600 800 700 800 900 1000 lIDO 1200 VI 0 0 ¡;- 1300 S' 0 =r 1.00 0 0 '600 ::: ( ( ~, Phillips Alaska, Inc. Drill Site 2p 420 slot l420 Meltwater North Slope, Alaska H 0 R I Z 0 N TAL PLANE C LEA RAN C E R E P 0 R T by Baker Hughes INTEQ Your ref: MWD <0-6860'> Our ref: svy6610 License: Date printed: 30-0ct-200l Date created: l7-0ct-200l Last revised: 30-0ct-200l Field is centred on 44l964.235,586989l.466,999.00000,N Structure is centred on 44l964.235,586989l.466,999.00000,N Slot location is n70 3 9.754,w150 26 50.778 Slot Grid coordinates are N 5868984.299, E 444088.453 Slot local coordinates are 891.04 S 2131.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with Horizontal Last revised Distance M.D. 25-May-200l 59.6 979.8 4-Jun-2001 360.2 100.0 26-Feb-2001 448.9 6860.0 26-Feb-200l 603.7 5482.1 26-Feb-2001 6566.5 5348.0 6-Mar-2001 46416.6 6860.0 Plane method Diverging from M.D. 3589.3 100.0 6860.0 5482.1 5348.0 6860.0 MWD <0' - 6008'>, ,417,Dril1 Site 2P MWD <0-9224'>,,438,Drill Site 2P PMSS <0-6300'>"MWN#2,Meltwater North #2 PMSS <2212-7349'>, ,MWN#2A,Me1twater North #2 PMSS <0-6122'>"MWN#1,Meltwater North #1 PMSS <0-8935'>"MWSouth1,Meltwater South #1 ( ( Phillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska CLEARANCE LISTING Page 1 Your ref : ~~ <0-6860'> Last revised: 30-0ct-2001 Reference wellpath Object wellpath : MWD <0 - 6008'>,,417,Drill Site 2P Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2351.1 2351.0 3.1S 5.3W 2352.1 2351. 0 12.6N 78.6E 79.4 ?é. . <, 84.6 Phillips Alaska, Inc. Drill Site 2P,420 Me1twater,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref: MWD <0-6860'> Last revised: 30-0ct-2001 Reference we11path Object we11path : MWD <0-9224'>,,438,Dril1 Site 2P M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 2351.1 2351.0 3.15 5.3W 2795.5 2351.0 1181.65 715.7W 211.1 l.'rï6.0 896.5 Coordinates All data is in feet unless otherwise stated. Casing dimensions are not included. from slot #420 and TVD from RKB (Doyon 141) (254.00 Ft above mean Vertical section is from wellhead on azimuth 103.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ sea level). m (' ~I~PS PHilliPS Alaska, Inc. m A Subsidiary of PHILLIPS PETROLEUM COMPANY TUBING . 2P-420 (0-6156, 00:3.500, 10:2.992) SURFACE (0-2351, 00:7.625, Wt29.70) PRODUCTION (0-6156, 00:5.500, Wt15.50) SLEEVE (6095-6096, 00:4.500) NIP (6111-6112, 00:3.750) SEAL (6156-6157, 00:4.000) LINER (6156-6850, 00:3.500, Wt:9,30) P!..'J'J --, .:;72'}-%3; .-::-: t, C'::'i Bottom 6156 Man V Mfr T e KBG-2-9 . JEWELRY { \, KRU To 0 0 0 6156 Bottom 108 2351 6156 6850 Descri tion CAMCO 'OS' NIPPLE W/2.875" PROFILE BAKER 'CMU' SLIDING SLEEVE CAMCO '0' NIPPLE W/2.75 PROFILE XO LOCATOR BAKER GBH-22 SEAL ASSEMPBL Y CEMENT PLUGS TVD 6156 2P-420 TVD 108 2351 6156 6850 Wt 62.50 29.70 15.50 9.30 Grade H-40 L-BO L-BO L-80 Thread WELD BTCM BTCM EUE8RO Thread EUE8RO V Type V OD Latch Port TRO Date Vlv Run Cmnt SHEAR 1.0 OCK-3 0.000 0 11/212001 ID 2.875 2.813 2.750 2.980 3.000 0.000 -. . Well Name: CASING TEST and FORMATION INTEGRITY TEST Supervisor. Dearl W. Gladden 2P-420 Date: 10120101 ~ Initial Casing Shoe Test D. Formation Adequacy for Annular Injection . 0 Deep Test Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 75/8" 29.7# L-80 BTC-M Reason(s) for test Casing Setting Depth: 2,351" TMD 2,351" TVD Hole Depth: 2,388" TMD 2,388" TVD Mud Weight: 10.0 ppg Length of Open Hole Section: 37" EMW= Leak-off Press. + Mud Weight = 750 psi + 10.0 ppg 0.052 x TVD 0.052 x ~ . ./ ~'\S, \Ip,\ EMW for open hole section = 16.0 ppg ~ Fluid Pumped = 0.6 bbl 'I ~ ... Pump output = 0.1010 bps 3.200 psi 3.100 psi 3,000 psi 2.900 psi 2.800 psi 2.700 psi 2.600 psi 2.500 psi 2.400 psi 2.300 psi 2.200 psi 2,100 psi 2,000 psi W 1.900 psi D:: 1.800 psi ~ 1.7oopsl VI 1.600 psi W 1.500 psi D:: 1.400 psi D.. 1 .300 psi 1.200 psi 1.100 psi 1.000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi V ./ T'MElINE:->. .' ONE MiNUte TICKS . . . IJ , A . I I Ir -+-LEAK-QFF TEST - - -CASING TEST - - ,. -- LOT SHUT IN TIME - I - >1:.',<,",¡.~,("..:oe"" --+-CASING TEST SHUT IN TIME - , . - - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ t ~ ~ ! ~ I ~ ~ ~ ~. i æ ~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT INTIME":see time line above . CASING TEST DATA LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ,- - - - -- --- - --- -..,.- - - - - - -- -----r- - ---- - - ------" l--------------~--~-~!.~~---~----~-~~~~---~ t-----------_..JL_--~-~~~-_--L___1_!~_~!_~-_J l---- ---- -.1 - -~_! !~!.---L~- ~ ~- P.!!..ji ~---------------~---~-~~!_---t--_!!'_~~_P.!J_-- ~- - - --- - --- - - ---t - ---- -- --- ----r-- - -- - - -- - ----- L - - --- - -- - -- ---1. - ---- - ---- __--_L - -- -- - - ------- I I I t - - --- - - ------ -- t ----- - - --- --j-- -- - - - - -- ----- I ~-- - --- - ----- - -- t -- ---- - - ------ ---- - -- - - - - - ---- i t---------------+-------------~-------------i ..--- -- --- ------...-------- ------ r----------f--------------t--------------- i ..--- - --- ------ --...--------------...---------------- ï-------------t------~--------t----------------i [----- ---- -- - -- -¡-- ------------...---- -- ---------- r---------------""---------------r-------- ---------1 --- ------------- -------------... ---- ------------ ~--------------~--"-----------J.----------------~..---------------...--------------...---------------- L_--____-----_.l_-------------_t_-------------_J ..-------- -------...------- ------- I I I ~ . I I ~--------------...---------------..---------------- ..-------- -------...------ ------- I I I.' I t --- - -- - ---- ---t ---- --------t-- --- - - - -- --- --, .. - -- --- - - - ---- --... - --- - - - - - ----- ~---------------t-----------~-- -- ----------i 10-------------- -...-- ------------ l---------------+-------------~---------------~ ..------- -- ------...-------------- t------------f---------------L---------------j ..-------- -------...------- ------- I I I I I I I r - ----- -------- -..,. - --- --- - - --- -- r ----- -- - - - -----, t--------------+--------------~----------------j _!~-~!_~ ~ _!~~!¡~---- ---------SfH-~! _I_~!.~_~! !~~ E L_____------l.--------__--___L_____m_____- ___9.:Q_!:11..l!!- - -- ------------ -_?! ~ ?9_£S.L t--------------+......---.........-+...-,-......................... ---~~g-~m-- __m______-- -~;~-:~-~i+- I I --------------- -------------r---------------- ~_!!i_~~~ !I_~!¡--------------~rl!~!!~-~~~~_!~-~ E -- -~.:Q - !:11..l!!- -t-__m_____- - ~!~_~~_P!5L l_- _9.:g _!T: l£1...JL - - -- --- --_--_L- _?. ?9- E5- .!..--i -- -~.: Q _!:11.. l!!- - f m_- - - - -- ---- - ~! ~- ~ ~ - P. ~_L ~-_J.:g_!T:l£1.__L-_-_----------~--_!!'_~~- P.!L_.: 1--_~.:Q_!:11..l!!_- --------- ----- -~ !~-~~ _p.~L ~--_?:g- m i £1.--+------- --------~--_!!'_~ ~- P'!_I__-J --- ~.:Q_!:11..l !!--I-------------- -~!~-~ ~ _P.!L ~ - --~.:g _!T:l £1._-+ -------- - -- - -~ -- }-~ ~ -P. !L_~ - _.?: Q _!:11.. 1 !! - - - --- - - - - -- - - ~ - - ~! ~- ~ -~ _P.!L Lj.:Q_~!!__L____--_--___-t_l_~~_P.!!..J ---~.:..~_!:11..1!!_- -------------- -~!~_~~_P.!L L~.:Q_~l!!_.l-__----------~- -_!_~~ _P.!!--~ m~': Q _~l !!--t-- ______m- - - J.! ~-~~-P.. !L. ~-_~.:Q_~l!!_-!-_----------.J--_!!'_~~_P.!!.--I __1_Q .:~u."]! ~--rm----------"7" -~! ~-~-~ _P.!L. ~-_'?:Q_~l!!__~__._m---_____-~ --_!_~!. _P.!L_~ - - ~-~.: Q -rJ] !~--t- m__- ------f' - ~ !~-~ .Q_p' ~LI. i_--~.:_~--~l!!__~--------------L_-_!_~~_P.~~_J t-_?_Q.:Q-~!~-_JL_------------- -~!~-~~-~!_~- l---~.:Q_~l!1--_jL__------------l---!!'-~~_P.!J_--j t--~~.:Q-rJ]!.~-~------------I-~!~-~~-~~ L_-~_Çl.:Q_!:11..1~__Jl__--------_____l___!!'_~!._f!a~__J L--~_Q.:Q-rJ]!~-_JL_------------ -~!~-~~~ MINUTES FOR CSG TEST STROKES ---------------...- ---- - -------- 1 0 stks ~~ ~ :~=::: :~~~ ~ f ~I! ~ !::: . 4 atka -------- -------oio------------ 6 atka ------- -------..¡..------- ------- 8 atka - --- --------- --...-------------- 10 atka -_m- ----------- f f äik-ã-- ------------ ---"'-14Š-tk-ã-- -------------- -...----------- --- 16 atka PRESSURE ---4Õf;šr-~- --------------- 5 ~ =~1~~~::- ~~ --------..P---- . ---~!.!»."p_~~--- _!!~-~~_P.!}-- ¡ --"' _!~~_~~_P.!L -~~~_?~_P.!L -~!~-~~-p.~-'-- :~~~~~~~:~~~~~~~¡ ::::::::::::::=~ ----------------1 ---------------- --.. NOTE: TO CLEAR DATA. HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P-420 Date: 11/212001 Supervisor: Don Presnell Reason(s) for test: D Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 51/211 15.5# L-80 x 7 5/811 29.7# L-80 annulus Casing Setting Depth: 2,3511 TMD Hole Depth: 5,6001 TMD Mud Weight: Length of Open Hole Section: 9.8 ppg 3,2491 EMW= Leak-off Press. + Mud Weight 0.052 x TVD = 550 psi + 9.8 ppg 0.052 x 0' ~ 'lS \ EMW for open hole section = #DIV/O! \,-\,~ Pump output = 0.0280 bps Fluid Pumped = 3.2 bbl 3,2oopsi" ,n, I "II li'I' 31oopsil!;i "';' ,,)111 II", 3'000 psi ,Iii I I I '" il/I,III'I ,II , . I I I I I ':: ! Y I! I ! I I I I I 2.900PS! I!' í ; "¡";'/I iliilllill 2.8oopSI" , I"TIMELINE I" I 1"I'i 2.7oopSi;: 'I !I ,¡,lil!,I;,: 2.6oopsi;' ,I !lONE MINUTE TICKS [I[,¡,:,!!I,: 2500psi ,II I ,II.I!I,III'" 2'4oosi I,' I i L~-~__...IIIIIIIIII!:II Úoo~Si ::1 '--LEAK-OFF TEST .!-.~--;-;-¡,.::!!I!!I!I' Iii: 2.200 psi 1,1 I J-.....----:; ;_,!IIII,I¡ ,[; 21oopsi ,,! I~CASINGTEST J-.:-.,.,,:: ': ,1111,11 I,ll 2'OOOsi ii' I. J-i".::.:.._.:.- 1111,,1, I !i ,p. 1I11I "...<.,.LOT SHUT INTIME ¡', l'III,llli!'1 W1,900ps~ II!I! ,', t¡-¡:¡. ':c- I il!I!! I!I § 1,800ps~ I I ! 1 i .-;-CASING TEST SHUT IN TIME 1 I" ;..: : : :: I ! I I I ¡I, I i I CJ)1,7ooPs~ 11,1 I¡"I,:' I ¡I'I!I '¡II 1,600 pSI ' , -+- TIME LINE IT- "--"-"'----,--. - --'; -.;.. I ' " " CJ)15OOPS'1 I , 1:'::1 ,1111111 iil W . I I "',' i' '1'1 I ,,' a: 14OOsi i ,: Ii':' :i!i i, :1;1 . p I I ,', "I I I I I ' I' " D.1300psi '" " , ',I ;, , . i I I I ",,' I i I I I I I Ii, I 1,2oopS! II' ¡ !' '::';' iillll!'!¡;!! 1.1oopS! III; I'; ii, :11111",,11;" 1.000 pSI " "!""~""",:",','.,I 9OOPSi~'I! I ¡!:,!! Ii,' "~' 800 si ,I I ii',,::,: Ii, ¡I; 'i I P , , " I I 'I'" 700 psi: i : I :" i , I , , : ,: ", 6oopsi,""";' ""~":II 500 psi II" '_'..)1;: I'll' '1',- 400 psi II"-¡ 1,,1.:,'1 ";I!! III, 300 psi II I , ,', ','¡!ii,III!,,!! '.I"I I I , 'I I I i , I ! , , I , 2oops,'-' "",1',,1,,",'" - I I ' I ! I' . , ' I i I I ,I ¡' I 1oopsi"" i : , ',I, ""I,r, Opsi iil i I",_;¡-~.,-~~!!;j!!:!:!¡!:! - ~ W ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ m m m ~ ~ 00 00 00 W W - - - - - - - - ~ ~ ~ ~ ~ - ~ ~ ~ ~ - - - ~ ~ ~ ~ ~ W ~ ~ ~ ~ W ~ ~ - ~ W ~ ~ ~ ~ W ~ ~ D 0 a . - ~ N N ~ ~ ~ ~ ~ ~ ~ m m m ~ ~ 00 00 - ~ ~ W ~ - ~ W W ~ - ~ W ~ ~ ~ ~ W ~ ~ ~ ~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ----------------¡----------------T-----------------T i I 0 stks I 0 psi I ,______----------"""--------------_'&_----------------" i ¡ 5 stks i 200 psi! 1---_------------"""---------------'&-- ---------------.. ! i 10 stks ¡ 350 psi i 1----------------+----------------+-----------------. ¡ i 15 stks ! 500 psi i 1----------------""'---------------"-----------------" i ! 20 stks ! 550 psi ...r ,----------------.,..---------------..-----------------.. I I 25 stks I 500 psi I :----------------+---------------~-----------------~ : I 30 stks 1 475 psi I I----------------+---------------f-----------------f I I 35 stks 1 475 psi I I----------------+---------------t-----------------t I I 40 stks I 475 psi 1 ,______----------"""---------- ----_'&_----------------1 ¡ i 45 stks ! 475 psi I 1----------------"""---------------'&-----------------" ! i 50 stks ! 475 psi ¡ 1----------------+----------------+-----------------. ¡ ¡ 55 stks ! 475 psi i ,----------------+----------------..-- -- ---------- ---.. r I I 60 stks I 475 psi I , :- ---------------+---------------~------------- ----~ I I 65 stks 1 475 psi I I----------------+---------------~-----------------f I I 70 stks 1 475 psi I I----------------+---------------f-----------------f I I 75 stks : 475 psi I I----------------+---------------t-----------------i I I 80 stks 1 475 psi 1 1----------------"""--------------_'&_----------------1 i i 85 stks ! 500 psi 1 1----------------..&0---------------.&-----------------" i ¡ 90 stks ! 500 psi! 1----------------+----------------+-----------------. I 1 95 stks I 500 Psi 1 , 1 1 1 1- ---------------.....- ------- -------.. --- ---- -------- --.. ! i 100 stks! 500 psi! ,----------------""---------------,,-----------------, 1 I 105 stks 1 500 psi 1 :----------------+---------------~-----------------~ 1 I 110 stks: 500 psi I 1----------------\ 115 stks I 500 Psi I I I . , 1 SHUT IN TIME I SHUT IN PRESSURE ,______---------- ..&._-------------------- ------------- 1 0 0 . I I 500 . I : . mln I I pSI 1 1----------------..&0---- -----------.&------------ -----.. 1 1 0 . 1 I 300 . 1 1 . mln I I pSI 1 1----------------+--- -- --- ------ --..-----------------. I 2 0 . I I 300 . 1 I ,mln: : pSI: 1----------------+-------- -- ------"-----------------of I 3 0 . I 1 300 . I I.mlnl I pSI 1 ,----------------.,..---------------..-----------------, 140' I '300'1 I. minI I pSI I ¡-----------,;,----t-- -------------t------ --------;---1 1 5.0 mln I I 300 pSI 1 I-----------,;,----+---------------f--------------;---f I 6.0 mln I I 300 pSI 1 1-----------,;,----+------ ---------t----_:"_-- -----;---i : 7.0 mln I I 300 pSI 1 ,-- --------------..&._-------------_.&_--------- ------- 1 ¡ 8.0 min ! ! 300 psi I I----------------..&. -------- -- -----.&-- - --------------.. I 9 0 . I I 300 . , 1 . mln : : pSI I 1----------------+---------- -- --- -+------------ -----. ! 10.0 min ! ! 300 psi i 1- -----_u_--- u_+- u_------- -----._u_--------_u --of CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .- -- -- -----------r---------------, - u ----- ---------¡ ~-- -- ----------- -~---~-~-~~~---~ - ----~ J>.~L___~ I I r I I I I I ..---- ---------- -- .._u u_------- -- ..----------- ---- --oJ I 1 1 1 I 1 I 1 1 , 1 1 o.--------- ------- ..---------------..-- - ----- ------ ---oJ 1 I 1 1 I I I , 1 I I I o.------- ---------..------ u -------1-------- ------ ---.. I I I , 1 I I I I I I , .. -- ------ --------..- -- ---------- --,---- ------- - -----.. I I 1 ..&-<~ r--------- ---- ---r------- - -- -----1-- - -- ----------- " I I I t-- --------- -- ---t------ -- u-----1- ---- --- ---------1 I I 1 1 ~----------------t ---------------i------ --- -------- i I I 1 I I I , I ~------------ -- -- t--- ---------- --1---- -------_u ---1 , 1 1 I I 1 , 1 ..----- -------- ---.. ---------------.. ----------- - -- ---oJ I I I I I I , r I I , I o.-- --------------..- ---- -------- - -..----- ---- - --- - ---.. I 1 1 I I I 1 I I 1 I I ..---------- -- -- --..- u_- ---- -- - - - -1----- ---- - ---- ---.. I 1 1 , I 1 1 I I I 1 1 ..---------- --- u-r--------- -- --- -,- - - ----- ---------., I 1 I r I 1 I I ~- ---- -----------~ ------ ---------~--- --------------.{ 1 I I r 1 I I I ~-- -- ------------~--------------- i------ ----- - --- --~ 1 I I I 1 I I 1 ~------ ----------t--_u -------- --i------- ----------i I 1 I I I I . I ~- ---- -- -- -- -- -- -t---------- -----1- ----------------1 1 I . I 1 I 1 I ..- -- -- -----------..---- -- ---------..- ----- ----- ------oJ 1 I I , 1 I I I 1 I I I o.---------------- ..--------- ---- u"u --- -- -------- --.. I I I I I I I I I I , I ! SHUT IN TIME! SHUT IN PRESSURE r------- -- u,---- -r---------- -----1------------;- ----, 1 O.Omln 1 1 0 pSI I ~--- -- - --- --,-- -- -~---- ------ -- ---~-------- --- ------.{ 1 1.0 mln : 1 I ~-----------.-----~---- u -- ------- i-------- --- -----~ 1 2.0mln I : " ~ ---- -------.-----t-- -- -- - -------- i- -- --- -- ----- --. 1 3.0 mln I I ~-------_u -.----- t- -- ---- ------ - -1-_u --- --_u_-- --1 I 4.0mln 1 I : ..--- -------- -- -- - ..---------- -- -- -..---- - -------- - ---.. ¡ 5.0min ! ! ! o.----- -------- -- - ..----------- --- -..--- ----- -- ---- ---.. ! 6.0 min ! ! ! ..-- -- - - -- --------..-- ---- ---------..--- ----- ---------.. ! 7,0 min ! ! ! r---------------- r- --- - -- u_--- - - ,---- -------- -----., 1 8.0 min I 1 : ~--- -- ---- -- -----~-------- -- -- ---~--- -- --- - ---- ----.{ 1 9.0 min I : 1 ~-----------':----~---- - -- --------i---- -- - ----- -----~ : 10.0 mln : I : ~-----------': ---- t- -- ---- ---- ---- of ---- - - - -------- --i : 15.0 mln I I : 1.------------- ---t --- --------- -- -, ---- - ------------..1 ! 20.0 min I ! ! ..-------- --------.._u - - -- u------..- --- -- ------ --- --oJ ! 25.0 min i ¡ ! o.----- ---- ---- - u" u_--------- -- -..-------- ---------.. ¡ 30.0 min i i i ..- ---------------..------------ ---..------- ---..--..-.. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ,'I" { Casing Detail 75/8" surface casing ;'1" ¡If",' i I r : :: ::: ::::,' ,:: ::: :::, ::, ¡Ii J8;,,>-t :.,;:::::::::::::" .'." WELL: 2P-420 DATE: 9/17/01 1 OF 1 PAGES PHilLIPS Alaska, Inc. # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LOS = 27.90' TOPS Above Rotary 6.70' 7 5/8" Landing Joint (35.20 total) RKB t< 27.90 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.85 27.90 30.75 30.75 jts 3-55 7 5/8", 29.7# L-80 STCM 2232.01 30.75 Gemeco Float Collar 1.33 2262.76 jts 1-2 75/8",29.7# L-80 STCM 85.82 2264.09 Gemeco Float Shoe 1.51 2349.91 81M OF SHOE @-----»»> 2351.42 TD 9 7/8" Hole 2358' Csg Hanger goes in the top of Joint # 55 " 12 TOTAL, Gemeco Bow Spring Centralizers - 3 Stop Rings 3- Centralizers in center of jts.1, 2,& 3 over stop rings 9 - Centralizers over collars of jts,4- 12 .' ** Fill using "Franks" fill tool - Remove tool on Joint before Hangel ** Baker Lok all connections from the Top of FC down ** Monitor returns closely ** Remove air from slips for first 10 its ## Torque first 10 and average-Torque to AVG - Watch Diamond Remarks: String Weights with Blocks: ???k Up, ???k On, ??kJD & Blocks. Ran 55 joints of casing, Drifted casing with 6,750" plastic rabbit. Use Jet Lube Lead free thread compound on all connections. ) Doyon 7 4 7 Drilling Supervisor: Dearl W. Gladden f (" PHilliPS ALASKA INC. Cementing Report Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Page 1 of 3 Report #: Start: Spud Date: 10/15/2001 1 Report Date: 10/18/2001 10/15/2001 End: 11/2/2001 Cement Job Type: Primary Prima Hole Size: 9.625 (in) Hole Size: TMD Set: 2,351 (ft) sa TMD: (ft) Date Set: 10/18/2001 sa Date: Csg Type: Surface Casing sa Type: Csg Size: 7.625 (in.) Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cement Co: Dowell Schlumberger S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: StevenDoughten Pipe Movement: Reciprocating Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Rot Time Start: : Rec Time Start:14:26 Time End: : Time End: 16:25 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 12.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 106 (Ibs) Max Torque: (ft-Ibf) Drag Down: 65 (lbs) Stage No: 1 of 1. Type: Cement Casing Start Mix Cmt: 14:48 Disp Avg Rate: 6.00 (bbl/min) Returns: Full Volume Excess %: 2.50 Start Slurry Displ: Disp Max Rate: 6.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: 16:02 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 16:25 Press Prior: 550 (psi) To Cementing: 3.00 End Pump Date: 10/19/2001 Press Bumped: 1,050 (psi) Ann Flow After: N Mud Circ Rate: 252 (gpm) Top Plug: Y Press Held: 5 (min) Mixing Method: Mud Circ Press: 400 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Scale Type: KCL Density: 9.8 (ppg) Visc: 51 (s/qt) Bottom Hole Circulating Temperature:70 (OF) Displacement Fluid Type:Mud PVIYP: 14 (cp)/30 (lb/100ft2) Gels 10 sec: 10 (lb/100ft2) Gels 10 min: 17 (lb/100ft2) Bottom Hole Static Temperature: 68 (OF) Density: 9.8 (ppg) Volume: 104.20 (bbl) . Stage No: 1 Slurry No: 1 of2.. Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Description: AS Lite To: 1,474.00 (ft) Gmt Vol: 206.0 (bbl) Slurry Vol:260 (sk) Class: G Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Vol: 128.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/3/2002 3:14:06 PM (' (" PHilliPS ALASKA INC. Page 2 of 3 Cementing Report Legal Well Name: 2P-420 Spud Date: 10/15/2001 Common Well Name: 2P-420 Report #: 1 Report Date: 10/18/2001 Event Name: ROT - DRILLING Start: 10/15/2001 End: 11/2/2001 Stage No: 1 Slurry No: 1 of 2 - Additives Trade Name T e Concentration 50.0 % 30.0 % 1.5 % 1.5 % 1.5 % 0.5 % Units Li uid Cone. Units D124 DO53 D079 SO01 D046 D065 Slurry Data Fluid Type: TAIL Slurry Interval: (ft) Water Source: Rig To: (ft) Description: LiteCRETE Class: Cmt Vol: 64.4 (bbl) Density: 12.00 (ppg) Yield: 2.40 (ft3/sk) Slurry Vol:140 (sk) Water Vol: (bbl) Other Vol: 0 Purpose: TAl L Mix Water: (gal) Foam Job: N Test Data Thickening Time: 3.42 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Stage No: 1 Slurry No: 2 of 2-Additives . Concentration Units Units Trade Name. D962 D046 D065 D079 CemPlus Blend Casing Test . Liner Top Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 16.00 (ppge) Tool: N Open Hole: 37 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N ~ . Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: No CMT to surface TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Y 1 Printed: 1/3/2002 3:14:06 PM (' ( PHilliPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Report #: Start: Spud Date: 10/15/2001 1 Report Date: 10/18/2001 10/15/2001 End: 11/2/2001 Remarks Pumped 5 bbl CW100 @ 8.4 ppg , Test Lines, 35 bbls CW100 @ 8.4 ppg , Drop Bttm Plug, 30 Bbls Mudpush XL @ 10.5 (wi Dye) , 207 bbls Lead CMT 10.7ppg wi 0124 50.00% , D053 30.00% I 0079 1.5%, SO01 1.5% I D046 .600%, 0065 .500%, 6 1 bbls Tail CMT@ 12.00ppg wI D962 CemPLUS Blend, 0046 0.200 % ,D065 1.00% ,0079 1.00% (Note)Bow Spring Centrilizers used on first 12 joints. There are 3 on stop rings in the middle of joints 1,2,&3 . They are run across collars on jts 3 thru 12 **Note** Preformed Top Job - Ran 200' 1" Hyd Tbg down along side 7 5/8 " csg. Flushed by pumping 88 bbl h20 (8.4+ h20 to surJace) - CMT by pumping 151 b bls 10.7 ppg lead CMT . Had 10.7+ CMT to surface ý' Printed: 1/3/2002 3:14:06 PM (' f Page 1 of 2 Phillips Alaska, Inc. Daily Drilling Report WELL NAME 2P-420 SUPERVISOR RIG NAME & NO. Dearl W. Gladden Do on 141 CURRENT STATUS N/U BOPs REPT NO. DATE 8 10/18/2001 CUM. TANG 0.00 CUM INT ANG WI MUD 0.00 CUM COST WI MUD 639,341 24 HR FORECAST N/U BOPs - Test BOPs - PIU BHA #2 - Drill Out LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP AFE AUTH. LAST SURVEY: DATE TMD 10/16/2001 2,295.70 INC 0.260 AK0203 LAST BOP PRES TEST ft 0.00 CUM COST 0.00 PflMf CI Ca H2S LIME ES 1870 DENSITY(ppg) FV PVNP 46 14/19 9.80 PP GELS WUHTHP 8/12 6.21 ECD MUD DATA DAILYCOST FCIT.SOL OIL/WAT %SandIMBT Ph/pM I I /7.0 9.41 03:00 04:30 1.50 CASE P SFTY 04:30 05:00 0.50 DRILL P SFTY 05:00 08:30 3.50 CASE P RUNC 08:30 10:45 2.25 CASE P RUNC 10:45 13:30 2.75 CASE P CIRC 13:30 14:00 CASE P CIRC 0.50 14:00 15:00 15:00 16:30 CEMENT CEMENT CIRC PUMP 1.00 1.50 16:30 17:30 1.00 CASE P NUND 17:30 18:30 1.00 CASE P NUND 18:30 19:30 1.00 CASE P NUND 19:30 21 :30 2.00 CASE P NUND 21 :30 22:00 0.50 CASE P SFTY 22:00 00:00 2.00 CASE T OTHR 24 HR SUMMARY: Run Csg - Gmt Csg - Preform Top Job OPERATIONSSU M MARY : PHASE I SURFAC Con' t TO H SURFAC LID B H A - LID 3 fie x w t D C s - D n Loa d M W D & L D same. Brk Bit - LID Motor SURFAC R I U tor u n 7 5/8" 2 9 . 7 # L - 8 0 B T C M c s g SURFAC H 0 I d P J S M wit h c r e w & G B R C s g c r e w SURFAC Run C s g - Hit B rid g e @ 22 8 8' ( C k f loa t e qui p) SURFAC Was h fro m 2288 I to 235 8' (B T T M ) SURFACCircu & Condition hole thru Franks Fill tool - Re cip csg 10'-12' - Pump @ 6 bpm @ 200 psi - Hol e clean no excess drag - Up wt 96K , Dn wt 94K SURFACR/D Franks Fill Tool - R/U Schlum CMT head (PI ugs Loaded) SURFAC C i r c u & P rim e U p C M Tun i t SURFAC C M T C s g - S hoe @ 2 3 5 1 I - P u m p 5 b b I C W 1 0 0 - T est CMT lines to 3500 psi - Con 't pump 35 bbls CW100 - Drop Bttm Plug - Pump 30 bbl Mudpush XL @ 10.5 ppg (w'Red Dye) - 207 bbls Lead CMT @ 10.7 ppg - 56 bbls Tail CMT @ 12 ppg - Drop Top plug - Pump 5 bbls water - Switch over to Rig for displacement - Rig pumping mud displac e w 1981 stks (99.08 bbls) Bumped plug wi 500 psi. Pumped to 1000psi - Shut in for 5 min - BI eed off - Floats Held **** Note** NO CMT TO SU RFACE *** CIP 16:30 hrs SURFAC RID S chi u m - LID Lan din g j t - LID C s g Too I s SURFAC N I D R i s e r & F low L i n e s SURFAC Flu s h & C I e anD i V e r t e r S y s t e m SURFAC N I D D i ve r t e r S y s t e man d rem 0 V e fro m cell a r PROD P J S M for C M T Top Job PROD M/U 1" Hydril tbg and run in to 16" X 7 5/8" Ann to 200' "Hard Bttm" - R/U to circu Printed: 1/3/2002 3:15:57 PM ( WELL NAME 2P-420 SUPERVISOR RIG NAME & NO. Dearl W. Gladden Do on 141 CURRENT STATUS Preform LOT 24 HR FORECAST JOB NUMBER LITHOLOGY Preform LOT - Drl JAR HRS OF SERVICE LAST SURVEY: DATE TMD 10/16/2001 2,295.70 INC 0.260 DENSITY(ppg) FV PVNP 60 16/27 10.00 PP GELS WUHTHP 9/12 5.01 FCIT.SOL I BHA NO. 2 BHAWT. BELOW JARS STRING WT. UP ITEM DESCRIPTION Bit Mud Motor Stabilizer - NonMag Crossover Sub ~ Bottom Hole Orienting LWD MWD Drill Pipe - Non-Mag 4 Comp Serv Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt SIZE MÄNUF. TYPE 6.750 HUGHES-CHR dp0283 1 woe CODE. CEMENT 03:00 03:30 0.50 03:30 05:00 1.50 05:00 11:00 6.00 11:00 12:00 1.00 WELCTL 12:00 17:30 5.50 WELCTL OTHR NUND NUND BOPE BOPE ( Page 1 of 2 Phillips Alaska, Inc. Daily Drilling Report REPT NO. DATE 9 10/19/2001 CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 799,845 AFE AUTH. AK0203 6,741.0 ft LAST BOP PRES TEST 1 0/19/2001 I 16.0 0.00 PflMf 1870 CUM COST 0.00 CI Ca H2S LIME ES BHA! HOLE CONDITIONS STRING WT. DN STRING WT. ROT TORQUE I UNITS NO JTS 1 1 1 1 1 1 1 3 1 6 1 29 1 LENGTH 0.90 30.98 5.70 3.00 2.16 34.51 22.66 92.33 3.64 184.84 30.01 893.69 I.D. 1.500 1.500 2.250 2.500 2.500 2.500 2.500 2.250 2.250 2.500 2.250 2.500 O.D. 6.750 4.750 4.750 4.750 4.750 4.750 4.750 4.750 4.750 4.880 5.250 4.880 ---.-- BITS SERIAL NO, .... JETS OR .TFA 1904074 13/13/13/1311 [)EPTH IN . DATE IN I-O-D-L-B-G.O-R 2,358.0 10/19/2001 32,484-32,484-CT -A-O-I- D-Dl 24HrDIST OPERATIONSSUNIMARY PHASE . ... ... DESCRIPTION SURFAC Con 't C M T Top Job ( H a v e 1" H Y d T b g run to 200 I ) - Flush Ann pumping 88 bbls H2O - CMT pumpin g 151 bbls 10.7 ppg Lead - Rate 2 bpm @ 600ps i-Flush and LID Tbg SURFACR/D and blowout all CMT equip - Clean all Top Job tools from floor PROD Install & Orient FMC Gen V Csg head - Test 100 Opsi - Hold 10 min PROD N/U BOPs - C/O Bttm pipe rams to 4" - Modify fl ow riser PROD PROD Install test plug - R/U Test lines Test BOPs & Choke Manif - Test 250psi I 5000 P Printed: 1/3/2002 3:17:59 PM Page 1 of 2 Casing Report Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Report #: 2 Start: 10/15/2001 Spud Date: 10/15/2001 Report Date: 10/31/2001 End: 11/2/2001 String Type: Production Casing Hole TVD: 5,863.0 (ft) Ground Level: 224.00 (ft) Circ Hours: 10.00 (hr) Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Rig Floor 251.70 (ft) (ft) 10.0 (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: (ft) (ft) 25.55 (ft) Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 6,860.0 (ft) 90,000 (Ibs) 53.00 (O) 20.00 (days) ~, CäsingFlange ¡Wellhead Manufacturer: FMC Hanger Model: Actual TMD Set: 6,850.83 (ft) Integréll Casing. Detail Size Weight Grade Drift.. . ... ... JTS Length .. MU Torq. THD Manufacturer Model Condo Max OD Min ID I Compo Name I Threads Top (in.) . (Ib/ft) (in) ..... (ft) (ft) (fHbf) (in) (in) CASING HANGER & PU 5.500 15.50 L-80 4.825 BTC 1 2.84 25.55 Y VETCO EW FMC Gen V 5 1/2"CASING - PRODU 5.500 15.50 L-80 4.825 BTC 144 6,118.32 28.39 ATLAS BRAD FOR EW 4.950 5.5" L-80 15.5# SBE WITH PUP 5.500 L-80 4.825 BTC 1 10.09 6,146.71 BAKER EW 4.950 5.5" L-80 15.5# SEAL LOCATOR SUB 6.000 4.825 1 1.16 6,156.80 BAKER EW I I~, CSR ASSEMBLY 5.500 4.000 1 19.43 6,157.96 BAKER EW 4.000 CROSS OVER 5.500 15.50 L-80 2.867 EUE 1 0.57 6,177.39 PPCo EW 2.992 5.5" x 3.5" CASING - PUP JT 3.500 9.30 L-80 2.867 EUE 1 9.97 6,177.96 ARMCO EW 2.992 3.5" L-80 9.3# E 31/2"CASING - PRODU 3.500 9.30 L-80 2.867 EUE 1 30.41 6,187.93 ARMCO EW 2.992 3.5" L-80 9.3# E CASING - PUP JT 3.500 9.30 L-80 2.867 EUE 1 6.02 6,218.34 ARMCO EW 2.992 3.5" L-80 9.3# E 3 1/2"CASING - PRODU 3.500 9.30 L-80 2.867 EUE 16 499.50 6,224.36 ARMCO EW 2.992 3.5" L-80 9.3# E LANDING PLATE 3.500 1 6,723.86 Y PES! EW 3 1/2"CASING - PRODU 3.500 9.30 L-80 2.867 EUE 1 31.43 6,723.86 Y ARMCO EW I I 2.99213.5" L-80 9.3# E FLOAT COLLAR 3.500 EUE 1 1.14 6,755.29 Y WEATHERFORD EW 3 1/2"CASING - PRODU 3.500 9.30 L-80 2.867 EUE 3 93.18 6,756.43 Y ARMCO EW I I 2.99213.5" L-80 9.3# E FLOAT SHOE 3.500 EUE 1 1.22 6,849.61 Y WEATHERFORD EW Model: Gen 4/5 Packoff Model: Top Hub/Flange: 11.000 (in) 15,000 (psi) BTM Hub/Flange:11.000 (in) / 5,000 (psi) Printed: 1/3/2002 1:14:58 PM Page 2 of 2 Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Report #: 2 Start: 10/15/2001 Spud Date: 10/15/2001 Report Date: 10/31/2001 End: 11/2/2001 Accessory ManufaCturer Number Interval How Fixed .. Non-Integral Casing Accessories Bowspring Centralizer Centering Guides Bowspring Centralizer Centering Guides WEATHERFORD PESI WEATHERFORD PESI 16 5 19 18 Top (ft) 6,350.0 6,187.0 5,391.0 142.0 Bottom (ft) 6,850.0 Clamped 6,320.0 Clamped 6,155.0 OverCollar 2,413.0 OverCollar -... Casing went in hole with no excess drag or tight spots. Filled pipe every jt with mud and broke circ. every 2000'. Af ter getting to bottom and starting to circulate, we lost partial returns. We had to use LCM sweeps and put 6 to 10 P pb LCM in system to regain good circulation. We then lowered mud weight from 10 to 9.8 ppg and regained full circ. . Cement was then pumped and had complete returns through out the job. Ran 21 its. 3 1/2. L-80 9.3# EUE Tubi ng Ran 144 jts. 5 1/2. L-80 15.5# BTC Mod Casing 16 - 3 1/2" Bow Spring Centralizers 5 - 3 1/2. Straight Blade Centralizers 19 - 5 1/2. Bow Spring Centralizers 18 - 5 1/2. Centering Guides 26 - 3 1/2. Lock collars ,-~, Printed: 1/3/2002 1:14:58 PM (" (" PHilliPS ALASKA INC. Cementing Report Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Prima 6.750 (in) 6,850 (ft) 11/2/2001 Production Casing (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Page 1 of 2 Report #: Start: Spud Date: 10/15/2001 2 Report Date: 11/2/2001 10/15/2001 End: 11/2/2001 Cement Job Type: Primary (ft) S ueeze Casin Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Cmtd. Csg: Cementer: Kevin Anderson Plu Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start:14:00 Time End: : Time End: 23:59 RPM: SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 30.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 10,000 (Ibs) Max Torque: (ft-Ibf) Drag Down: 15,000 (Ibs) Type: Cement Casing Volume Excess %: 50.00 Meas. From: caliper Time Circ Prior To Cementing: 10.00 Mud Circ Rate: 130 (gpm) Mud Circ Press: 500 (psi) Start Mix Gmt: 00:01 Start Slurry Displ: 00:27 Start Displ: 00:08 End Pumping: 01 :22 End Pump Date: 11/2/2001 Top Plug: Y Bottom Plug: Y Stage No: 1 of 1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 3.00 (bbl/min) 3.00 (bbl/min) Y 1 ,158 (psi) 1,800 (psi) 1,800 (min) Y Returns: Full Total Mud Lost: Gmt Vol to Surf: (bbl) (bbl) . M udData Ann Flow After: N Mixing Method: batch Density Meas By: Scale Type: KCL Polymer Density: 9.8 (ppg) Visc: 43 (s/qt) Bottom Hole Circulating Temperature:62 (OF) Displacement Fluid Type: Fresh Water PV/yP: 10 (cp)/14 (lb/100ft2) Gels 10 sec: 3 (lb/100ft2) Gels 10 min: 9 (lb/100ft2) Bottom Hole Static Temperature: 130 (OF) Density: 8.4 (ppg) Volume: 152.00 (bbl) Stage No: 1 Slurry No: 1 of 1 Slurry Data Fluid Type: TAIL Description: ARCTIC SET Class: G Slurry Interval: 5,600.00 (ft)To: 6,850.00 (ft) Gmt Vol: 54.5 (bbl) Density: 15.80 (ppg) Yield: 1.20 (ft3/sk) Water Source: Trucked Slurry Vol:255 (sk) Water Vol: 18.6 (bbl) Other Vol: 0 Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: 132 (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: ZONAL ISOL Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 1/3/2002 1:15:06 PM (' (" PHilliPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: 2P-420 Common Well Name: 2P-420 Event Name: ROT - DRILLING Report #: Start: Spud Date: 10/15/2001 2 Report Date: 11/2/2001 10/15/2001 End: 11/2/2001 Stage No: 1 Slurry No: 1 of 1 - Additives Trade Name T e DISPERSANT DEFOAMER GYPSUM RETARDER RETARTER GASBLOK L.C.M. Concentration 0.6 % 0.2 GAL 3.0 % 0.0 GAL Units Li uid Conc. Units D-065 0-047 D-053 D-110 0-800 D-600G 0-29 CELLOPHANE Test Press: 3,000 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure:. (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: How Determined: TOC Sufficient: N Job Rating: . If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: (ft) Remarks After casing was on bottom, we lost returns, after circ. 10 hrs. and adding LCM to t he system we regained full returns. We mixed and pumped 30 bbls Dowell Mud Push at 10.5 ppg, followed with 255 sx (54.5 bbls) cement mixed at 15.8 ppg, dropped plu g and displaced with fresh water, bumped plug right on calc. displacement. Floats h eld ok. Had full returns through out cement job and well stayed static after job was complete. Printed: 1/3/2002 1:15:06 PM Well Name: CASING TEST and FORMATION INTEGRITY TEST Supervisor: Dearl W. Gladden 2P-417 Date: 5/212001 Reason(s) for test: 0 Initial Casing Shoe Test D Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/811 40# L-80 BTC M Casing Setting Depth: Length of Open Hole Section: h £;01 psi o.oSi x 2,430' ...-/ EMW for open hole section = 16.0 ppg 2,382' TMD 2,381' TVD Mud Weight: 9.7 ppg Hole Depth: 2,432' TMD 2,430' TVD 50' = + 9,7 ppg EMW= Leak-off Press. + Mud Weight 0.052 x TVD Pump output = 0.1010 bps 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi W 1,700PS~ c: 1,600 pSI ::::) 1,500 psi en 1,400 psi fa 1,300 psi c: 1,200 psi C. 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi Opsi Fluid Pumped = 0.9 bbl r--i - , J ! i I I i ! i , , 'I ! I: ; [ I : : i i ¡ I I i I If¡ h I' ~I I : I I I ME LINE - ONE MINUTE TICKS ~ , I I : I' ! ...1_- l--.! I I I ~LEAK-OFFTEST ~CASING TEST ,,<>,. LOT SHUT IN TIME -:k-CASING TEST SHUT IN TIME i t I ì 1 , I ¡ i fl I ¡ ¡ ! Ii! I ¡I: I r--+-H t I ¡ ¡ I ' I Ii' , I ' I ¡,I ' I: i rt-H r-r----r-t ! ¡ : i I i ! I i ! I I ~ ~ ~ ~ ~ ~ ~ ~ w w ~ ~ ~ ~ ~ m m m ~ ~ m m m ~ ~ ~ ~ ~ ~ ~ ~ ~ w ~ ~ ~ ~ w ~ ~ ~ ~ w ~ ~ ~ ~ w ~ ~ ~ ~ w ~ 0 0 0 ~ ~ ~ ~ ~ ~ ~ '" ~ ~ ~ ~II i i , I FIi STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA ; MINUTES FOR LOT STROKES PRESSURE ,----------------¡----------------,-----------------, 1 I 0 stks 1 0 psi 1 1_---------------""--------------_.£_----------------1 ! ! 2 stks ¡ 60 psi: '---------------""---------------"--------------_u" ! ! 4 stks ! 260 psi! 1----------- -----....- --------------+_u_-------------+ ! ! 6 stks ! 540 psi! ,----------------+----------_u_--+-----------------. 1 1 8 stks : 790 Psi 1 1 1 1 1 I----------------+----------_U_--"----------------~ 1 : 9 stks I 801 psi 1 I----------------+---------------~-----------------~ 1 . 1 . 1 1 1 . ----------------+--------- ------f------ ---- -------f 1 . . 1 1 1 I 1 1----------------+-------- -- -----t -----------_u -- - t 1 1 , , . 1 , 1 ,______----------""--------------_.£- ----------------.. 1 1 1 1 1 1 , I 1 I 1 I 1----------------""-- -------------..------ -----_u ---.. 1 I 1 I 1 I 1 1 1 , 1 1 I----------------+-------_u -----+ -------------- ---. 1 . 1 1 1 I 1 1 . I 1 1 I--------_u -----+------ ----------.--- --------------. . 1 , 1 , 1 , 1 I 1 , 1 1-------------- --.....--------------- ..-----------------.. 1 1 , 1 1 1 , 1 1---- -----_u_- u+------------- --~----_u ---- -- ----~ 1 1 , 1 1 1 , 1 I-----------_u u+----------- ----f---------- -------f 1 1 , 1 1 1 1 1 --- ---------- ---+---------- -----t ---- -------------t 1 1 1 , I 1 , , :--- --------_u_-+---------- -----t---- -------------1 . I 1 , . 1 1 , I---_u----------""------- ------- -..--- --------------.. . 1 , , I I 1 , I 1 1 , 1------------ ----+-----------_u_+- u -------- -- ----. 1 1 , 1 1 1 , 1 1 1 , , 1---- ----_u_----+----------------.------- -- u u_- --. 1 1 1 , 1 1 , 1 1 , 1 , ,----------------""'----------- ----..-------- u -- u_--.. 1 1 1 1 1 1 I I 1----------------+--- u_- --- -----~------ ------ -----~ 1 I I I 1 1 1 I :---------------- I I I 1 1 , , , 1 , , I I . . : SHUT IN TIME 1 SHUT IN PRESSURE ,___- ---------_u....----------------------- -- -- -- ----, ! 0.0 min ! ! 801 psi: I-------------_u""---------------"- ------------ ----. '10' 1 '798" 1 . mln : : pSI: 1----------------+---------------.-----------------. I 20 . 1 I 797 . I I ,mln I I pSI I 1----------------+------------- ---.-------- ---------. , 30 . 1 1 797 . I : .mlnl I pSI: ,---------_u_---..... - ------ --- -- ---..-- --_u_---------.. '40' 1 '796" , . mln 1 1 pSI' !-----------';' ----t------------ ---I -------------,;,---1 , 5.0 mln 1 1 795 PSI, :-----------';'----+-------- ---- ---f -- --- --------,;,---f : 6.0 mln 1 1 794 pSI I :-----------';'--- -+--------------- t- ---------- --,;,---t 1 7.0 mln 1 1 794 pSI: 1______---------_.1.._-------------_.£_----------- -----1 ! 8.0 min ! ! 794 psi 1 ,----------------.... u_---- ----- ---.. ---- u -----------.. 1 90 . 1 . 794 . 1 : .mlnl : PSI! 1----------------+---- ----------- +----------- ------. ¡ 10.0 min ¡ ¡ 794 psi i 1--------------------------------.-----------------. CASING TEST DATA MINUTES FOR CSGTEST STROKES PRESSURE -----------------r-- -------------,----------- - -----¡ L______--- ------ ~ --- !!_~-~~~-- - L ----~_p.~L- -_J L_____u -------- L__~_~_~~~---~----~~_P.~~---.J ! ! 4 stks : 275 psi! ..-------- --------..- ------ ------ --.-- --- ----_u_- ---. ! ! 6 stks I 457 psi ¡ ~- ----- _u ---- ---~------- - -------., ------ --------- --., : 1 8 stks I 721 Psi: 1 1 , I ..-------------- --..------------- --.,------ ------ -----., 1 1 10 stks : 929 psi ...-.... 1--------- --------~ ---------------,----------- ----- 1 1 12 stks , 1 ,182 psi I------_u --------~ -- -- ----------- ~----_u_--- - ---.--. I 1 1 14 stks : 1,443 pSI f ~ -----_u ---- u_- ~ - -------- -_u--1---- - --_u__u -,;--~ : 1 16 stks , 1,686 pSI: L______- u u u_--t---------------1------u ---------..1 ! 1 18 stks I 1,957 psi! ..----------------~----- ----------..---- -------------.. ! ¡ 20 stks ! 2,233 psi! .. ------------ ---- ..----- --------- -.----- ------------. ! ! 22 stks ! 2,503 psi! ~-------_u - -- --- ~- ------- -------.,- - - -- --- --- ------., I I 1 1 , I , 1 , 1 1 1 r- u ---- ---------r -- u ---- -- -----,- u_--- ---- - -----l , , 1 I 1-- -_u u_- ---- ---~ ------ u u ---- -~- ------- ------ ---~ , 1 , I , I I I 1--- -- - ------ -----~ u -- -- ------- -- f------ --_u - --- --~ , 1 1 I 1 1 I 1 ~ -- -- -- ---------- t--_u -------- - -i---- - ------------~ , I 1 1 , 1 I 1 ~------------ -- -- t- -- u u_----- --1---- _u ----------1 , 1 1 I 1 , 1 1 ..------ ---- ------..- ------------ - - ..-- -- - -- ----------. , , 1 I , I I I , , 1 1 ..---------- -- -- --..- -- ------ -- -- - -..---- - -- -----u - --. , 1 1 1 , I 1 I I , I 1 ! SHUT IN TIME! SHUT IN PRESSURE ..-- - ------ u_----..-- -- ---- -------.,- ------- ____n_--., ! 0.0 min 1 i 2,503 psi! ,. -- ---------.-----~-- -- -- --------- .,------ ------ --- --., : 1.0 mln 1 : 2,496 psi: t ---¿~Õ-ñ'-iñ- -- t-_m ---- ---- --1-- 2: 4' 9~fpsf~, '----------- ------ t--------- --- - - -i---- - ----------- i 3.0 min : 1 2,493 psi L____- ------ --- ut------------- - -..-- -- - ------------..1 ! 4,0 min , ¡ 2,490 psi! ~---------- -.- - u - ~----- ---- - - ----1---- - -------- --,;--1 I 5.0 mln : , 2,488 pSI 1 ..----- ------ -----..-----_u u_----.- - ------ --- ------. ! 6.0 min ! ! 2,486 psi! ~---------- ------ ~-- u- -- --------.,- ----- ----- u_---., ! 7.0 min ! ! 2,486 psi! ,. -- ---- u_-------,.-- -- u - - u_----.,- u_------- - -----., : 8.0 min 1 1 2,485 psi: I- ---- -------.-____~n u u --------- ~------ -------_u_-I : 9.0 mln 1 : 2,483 psi: I- ---------- --:----~-- -- - - - ------ -- ~- --_u - ---- - ---,;---1 : 10.0 mln : I 2,482 pSI: ~-------_u --: -- -- t---------- - -- - -i---- - ----------,;--~ : 15.0 mln : : 2,482 pSI: L______--- - - - - u- t- ---------- - u -1--- - ------ -------..1 L-?- g; 2_~J!!__L u -- -- ------_L~!~~_~_p.~Lj ! 25.0 min i ! 2,480 psi ¡ ..---------- -- -- - - ..----------- - - - -..--- ------- --- ----. L 9.~.: ~_~J~__L_- - -- ---- - -- -L~! ~~_~_p.~Lj NOTE: TO CLEAR DATA. HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2P- 417 Reason(s) for test: Date: 5/15/2001 Supervisor: Don Presnell D Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/811 EMW= Casing Setting Depth: Mud Weight: #40 L-80 BTC M Hole Depth: 4,810' TMD 4,803' TVD 2,382' TMD 2,381' TVD 10.1 ppg Length of Open Hole Section: 2,428' ?1 ~. . Þ4Ø pSI O.OŠ2 x ~' EMW for open hole section = 12; ppg ðS'=6 \ Leak-off Press. + Mud Weight 0.052 x TVD Pump output = 0.1010 bps ; í ' í ! I ! ! ! I ! í : I -----j , 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi W 1,800 psi !š 1,700 ps! en 1,600 ps~ en 1,500 pSI W 1,400 psi a: 1,300 psi D. 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi Opsi <> T T I I í T T I .. = + 10,1 ppg Fluid Pumped = 4.0 bbl I t T í I T Y'..---- -. ". r-Á-r,k-,."'--¡'-'", 7 ! J ! ì I I rTIME LINE JONE MINUTE TICKS -~-r- !~LEAK-OFF TEST ¡~CASING TEST . ¡ .. LOT SHUT IN TIME -.--CASING TEST SHUT IN TIME ì I I I ! . .. - .... -t ¡ : T T .,~_..,----_. .n (þ '" <> '" .. '" CD Co> '" Co> a> ¡;; ¡;; STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA i MINUTES FOR LOT STROKES PRESSURE ----------------¡----------------T---U------------T ! 1 0 stks 1 0 psi: 1______----------""--------------_'&_---------------_'& ! ! 2 stks ! 175 psi! 1----------------""---------------6-----------------. ! ! 4 stks ! 450 psi! ,----------------+----------------.-----------------.. ! ! 6 stks ! 450 psi! ,----------------....---------------..-----------------.. I 1 8 stks I 450 Psi: , 1 , 1 I-----------------r---------------Y-----------------Y : I 10 stks : 475 psi: :----------------+ -------------- -~ ----------------- 4 1 I 12 stks : 500 psi I :----------------+---------------+-----------------+ I 1 14 stks I 500 psi I I----------------+---------------t-----------------t 1 I 16 stks : 500 psi: ,---------- -----_...._-------------_.&_---- ------------.& ! ! 18 stks ! 520 psi! 1---------- ------""---------------6-------- -- -------. ! ! 20 stks ! 500 psi! 1----------------+----------------.-----------------" ! ! 22 stks ! ! 1---------- ------....-- -------------..----- ----- -------.. ! ! 24 stks ! ¡ I-----------------r---------------Y-----------------Y 1 I 26 stks I 1 :----------------+---------------~ ---------- ------ - 4 1 I 28 stks : I 1----------------+---------------+-----------------+ I I 30 stks : I 1--------------- -+------------- --t----- -- -- --------t I I 32 stks : 1 1_____-- --------_...._-------------_.&_----- ---- -------of ! ¡ 34 stks ! 1 1----------------""---------------6-----------------. ! ! 36 stks ! ! 1----------------+----------------.-----------------" : I 38 stks I : 1 , 1 , 1----------------""---------- -----..-----------------.. ! ! 40 stks ! ! I-----------------r------ ---------Y- -------------- -- Y I , 1 , 1 , 1 I 1----------------+-------- -------~ -----------_u -- - 4 , , 1 I , , 1 1 1---------------- I : I , 1 1 , ! ! ! ! ----1 j ¡ SHUT IN TIME ¡ SHUT IN PRESSURE ,______----------""--------- ------------- ------------ 1 0 0 ,I 1 0 ' , : ,mln 1 1 pSI: 1----- -----------....--------- ------6---------- -------. 1 1 0 . 1 1 500 " , 1 . mln 1 : pSI: 1----------------"-- --------- -----6-- ---------------.. , 2 0 ., 1 275 . I I. minI : pSI I ,--------- ----- --....-------------- -..- -- ----------- ---.. '30" '250"' I .mlnl : pSI I r----------,;,-- UT--------------- y- -- -----_u --: ---, , 4.0 mln 1 1 250 pSI' !--- --------,;,----t-- -------------t-------------:---1 1 5,0 mln 1 1 250 pSI I 1-----------,;,----+---------------+-------------:---+ : 6.0 mln I I 250 pSI: 1- ----------';'----+- ------ U- ---- -t -- -----------:---t I 7,0 mln I : 250 pSI: ,----------------....- ------------- -.&-- ---------------of ! 8.0 min ! ! 250 psi I 1------------ ---- ....---------- -----6-----------------. , 9 0 ., 1 250 . , I. mini I pSI I 1- ---------------+----------------.----------- -- ----.. ¡ 10.0 min ¡ ¡ 240 psi ¡ 0------- - ------------------ ------.------------ -----.. / .. <> CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE . -- - -- -------_u -r -- -- --------u -, - ----- -----------"\ ! : 0 stks : 0 psi: L_- ------------- -t - - ------------ -.I - ------- ----- ---_.& ! I 2 stks ¡ 530 psi! 10------ ---------- 10--------------- .&--------------- --.& ! ¡ 4 stks ! 720 psi! Jo--- -- ---- ------ -Jo---- -----------1------------ -----.. ! ¡ 6 stks I 900 psi ¡ .. ---- ------------..---------------,---------- -------.. I : 8 stks 1 1 '11 0 Psi: , I 1 I ..-------- -- ---- -- ..---------------,--- ------- --- u--, I I 10 stks : 1,300 psi ~... t---------- ---- -- t--1~fŠ-tkŠ--t1:52Õps i ~ -- U ---------- --~ - - ----------- --1------ ---u - --- :-. . I I 14 stks I 1,770 pSI: I-----------------t-- -- -- ---------1- --------------.---1 : I 16 stks : 2,000 pSI: L______---- ------t------- --- - ----1-- - - ------ ------_.& ! I 18 stks 1 2,240 psi! 10- -- ---- ---------10 ------ -- -------.& -------------- ---.& ! ! 20 stks ! 2,490 psi! Jo----------------"------ - --- -----..- ------- ----- - ---.. ! ! 22 stks ! 2,700 psi! ..- -- - ------------.. ------ u_------1- ----------------.. ! ¡ 24 stks ! 2,850 psi! ..-- -- ------------..- - ----------- -- ,-----------------' : I 26 stks 1 3,000 psi: ~ -----_u ------ -- ~_u_--- --------1--------- -- - --- ---I I I 1 : ~-------- -- -- - - -- ~------- --- - - - --~-- --- n_- - --- ---- ~ I : 1 : 1---- -- -- -- ---- ---t------ - - -------1-- - -- --- ------ ----1 , , I I , , I I t -- -- ------------t - - -------------1------------ -----1 " 1 Io---_u------- ---10 ---- -- -- -------.& -------- ---------.& I , 1 1 1 I 1 1 , , 1 1 Jo- -- -- -- ------ ---..------- - - - -----..-- --- -------- - ---.. I I 1 I , , I I I I I I ! SHUT IN TIME! SHUT IN PRESSURE ..-------- ---- -- -- ..--------- -- - - --'u -- - ---- - -------"' I 0.0 min : I 3,000 psi: ~ -----------.-----~-- -- ---- -------~ - ---------- - --- ---I I 1,0 mln I I 3,000 psi: ~---------------- ~------------- -- +---- ------- -----~ : 2.0 min ' I 3,000 psi """" '----------- - ----- ~---------- -----1-- --- U_- ------. ! 3.0 min I : 3,000 psi ~ - -- - - ---- --,-- ---t---------- -- ---1-- --- ----- -----:-1 I 4.0 mln I : 3,000 pSI: 10- -- -- ------ -- ---.. -- -------- -----.& -- ------ ---------.& ! 5.0 min ! ¡ 2,990 psi! 10-- -- ------------.. ---- -- -- -- -----..- ----- -- --- ------.. l---?:Q-~J_~- --l. -- - --------- -- L~!~~-~. p.~LJ ~-_'?:Q-~ In- -- ~- -- -- ------ -- - - j--~ !~~.Q_p.~LJ ! 8.0 min : : 2,980 psi ¡ ..- -- ------ ---- ---~----- ---- - - - -- -~-- - -- ------------, : 9.0 min I : 2,980 psi: ~- ---- - -----~----~-------- -- -----~--- -- ----- --- - -:- ~ : 10.0 mln : : 2,970 pSI: ~ -- -- -- -----~----t -- -- -- -- -------1- ----- -- --- ----.---1 : 15.0 mln : : 2,970 pSI: L -- -- - - ----------t ---- -- ---------.1- ----- -- ----- ---_.& ! 20.0 min I ! 2,960 psi ¡ 10 -- - - -- -------u-~ ------ U ---- ---.&- -- -- --- -- -------" ! 25.0 min ! ! 2,950 psi! Jo------------ -- --.. U_------ -- _u - ..-- -- - ---- - - ------.. l-_~ g.:Q-~J~j- ---- ---- ---- - -1. ~! ~~-~ _P.!'.~- J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY .of' (, (' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O.Taylor, Chair DATE: October 19, 2001 THRU: Tom Maunder, P. I. Supervisor Lou Grimaldi, Petroleum Inspector SUBJECT: Surface Casing Top Job P.P.Co.2P-420 Kuparuk River Field PTO 201-182 NON-CONFIDENTIAL FROM: Monday. Aygyst 20,2001: I witnessed the Surface Casing cement "Top Job" on Phillips Alaska well 2P-420 in the Kuparuk River Field (Meltwater) Dearl Gladden had called earlier to inform us that the cement had not reached Surface although returns had remained consistent throughout the pump job. The preflush had been dyed and it was reported that dye was observed at surface when the plug was bumped. This indicates a large washout increasing the hole volume beyond the expected. I traveled to location to witness the performance of a Top cement Job on the Surface casing. I observed strong indications of dye in the conductor and cellar. The mud had a high Ph (10-11) indicating that cement was evident in the mud. 1" CS Hydril wash pipe was run in to 195" (Conductor shoe at 120') where it fetched up and could not be pushed any lower. The pipe tended to stick and had all indications of setting in green cement. By calculating returns and pumped volumes it appeared the cement was 25 bbl's short. 88 bbl's of preflush (clear drill water) was pumped before the mud cleared and the Ph dropped significantly. 151 bbl's of 10.8 arctic set cement was pumped and returns came up to 10.7 ppg and a strong 12 Ph. I felt confident a adequate Top Job had been performed. SUMMARY: I witnessed the Top cement Job performed on Phillip's 2P-420 in the Kuparuk River Field NON-CONFIDENTIAL Attachment: None 0110 19-5urface casing Top-Job KRU 2P-420.doc ,~: ~ (. Note to File Well 2P-420 PTD 201-182 Sundry 302-002 Phillips Alaska, Inc. (PAl) requests approval for annular disposal in the subject well. This note analyzes information submitted by PAl and recommends approving PAl's request for annular disposal. Well 2P-420 is part of the Meltwater development, which is located south of the Tarn prospect and is the southernmost Kuparuk satellite. 2P-420 was completed in November 2001, after drilling was suspended during the previous summer. There is one surface casing shoe (Well 2P-417) within a quarter-mile of 2P-420's 7 -5/8" casing shoe. 7 -5/8" surface casing in 2P-420 was cemented with 207 bbls lead cement followed by 56 bbls tail cement, totaling about 1600/0 excess cement relative to gauge wellbore. Cement did not, however, circulate to surface during initial placement. A subsequent top cement procedure placed an additional 151 bbls cement in the well's 16" x 7-5/8" annulus. Successful placement of such volumes of cement indicates that 2P-420's surface casing is adequately cemented. After drill-out to 37 feet below the 7-5/8" shoe, the formation did not leak off to 16.1 ppg EMW. Applied pressure dropped only 3 psi (from 750 psi) during a 10 minute observation. 2P-420 was then drilled to about 5600 feet MD (about 3249 feet below the 7-5/8" casing shoe), at which point an injectivity test showed a pressure gradient of 14.3 ppg EMW. During this test, pressure response departed from linear at about 500 psi, reaching a maximum of 550 psi, then stabilizing between 475 psi and 500 psi. 300 psi shut-in pressure was observed. After drilling to TD of 6156 feet, 5-1/2" x 3-1/2" production casing was run and cemented, followed by 3-1/2" tubing completion. Based upon information submitted, AOGCC recommends approval of Phillips' request for annular disposal in Well 2P-420 (PTD 201-182). WC1Å- J t lOr o~ Winton Aubert Petroleum Engineer ir~fTV] \,\Ó~ { I~' ~i&\iŒ illJ~ fA\~fA\~[K{&\ ALAS IiA 0 IL AlWD GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 w. JTH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc, PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit 2P-420 Phillips Alaska, Inc, Permit No: 201-182 Sur Loc: 892' FNL, 2128' FWL, Sec, 17, T8N, R7E, UM Btmhole Loc, 1448' FNL, 866' FEL, Sec. 17, T8N, R7E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of.. 20 AAC 25.080 are met, Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations, Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 2P must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste ill a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year, Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole, Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607, aniel T. Seamount, Jr, Commissioner BY ORDER OF THE COMMISSION DATED this 13th day of September, 2001 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( f ftJ-~~û\ G\ \\ A hÁ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Drill 0 Redrill .0 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil 0 Re-entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 0 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 30 feet 3. Address 6. propeMI~~~io~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 AD~~ AL Meltwater Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 892' FNL, 2128' FWL, Sec. 17, T8N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8, Well number Number 1357' FNL, 1254' FEL, Sec. 17, T8N, R7E, UM 2P-420 #59-52-180 At total depth 9. Approximate spud date Amount 1448' FNL, 866' FEL, Sec. 17, T8N, R7E, UM October 1, 2001 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVO) 866' @ TD feet 2P-417 ,57' @ 2020' 2560 6741 'MD /5816' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 2500 MD Maximum hole angle 500 Maximum surface 2275 psig At total depth (TVD) 2729 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantitvof Cement Hole Casino Weiaht Grade Coupllna Lenath MD TVD MD TVD (include staQe data). 42" 16" 62.5# H-40 welded 80' Surf. Surf. 110' 110' 9 cy High Early 9.875" 7.625" 29.7# L-80 BTC, ABmoc 2351' Surf. Surf. 2351' 2351' 230 sx AS III Ute & 130 sx Utecrete 6.75u 5.5" 15.5# L-80 BTC, ABmoc 6741' Surf. Surf. 6120' 5416' 230 sx Class G 6.75u 3.5u 9.3# L-80 EUE 8rd Mo( 621' 6120' 5416' 6741' 5816' included above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECE,~VED Liner SEP 11 2001 Perforation depth: measured Alaska Oìl & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby ce'Œ, the 'oregolng Is trup p; to the best ut my knowledge Questions? Pat Reilly 265-604l 10 S-Llr ~/ Signed If.; -- - -" ~ Y TItle: Orin". Eo""".ri.. $,peM'" Date Chuck Mallarv hlJ "I. jjJ/clln_f)r~kf. U Commission Use Onl\ Permit Number . 'if' 2- API number Approval date Cf. ,.~ Ù See cover letter ;¿1::> / - / 50- /03 - 2D39 I '-é:{) for other requirements Conditions of approval Samples required 0 Yes iii No Mud log required 0 Yes ~ No Hydrogen sulfide measures 0 Yes ŒJ No Directional survey required ŒI Yes 0 No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 ~~\ \"¥\.'\ ~ \ ""'~'"'" ~? .~~~ Other: ~\\~ u~~~~-:: :~~~'-, '-.°') by order of q .1?J~n ( Approved bv ORI6IN}:(t..t~¡r'" . r, Commissioner the commission Date UJa "or ~. Form 10-401 Rev. 12/1/85. v .. f 0 RIG I IV A!mi' ill triplicaæ ( (,t-'Jlcation for Permit to Drill, Well 2P-420 Saved: 7-Sep-O1 Permit It - Meltwater 2P-420 Application for Permit to Drill Document MoximizE Well Value Table of Contents 1. Well Name................................................................................................................. 3 Requirements of 20 AAC 25,005 (f)..................................,.....................,....,....................................,..... 3 2. Location Sum mary ................................................................................................... 3 Requirements of 20 AAC 25.005(e)(2) ..........,...................,...............................................................,....3 Requirements of 20 AAC 25. 050(b).......,...................,..................................,.............,........,................., 3 3. Blowout Prevention Equipment Information ......................................................... 4 Requirements of 20 AAC 25. 005( e)(3) """""""""""""""'" ~,......,..............,...................................,...... 4 4. Dri II i ng Hazards Information................................................................................... 4 Requirements of 20 AAC 25,005 (e)(4) ."""""""""""""""""""""""""""""""""""""""""""""""'" 4 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25,005 (e)(5) ........,............................................,..........,........,........,............... 4 6. Casi ng and Cementing Program ...... ......... ...... ....................... ................. .... ... .........4 Requirements of 20 AAC 25,O05(e)(6) ".".".,......."",...."..,....."",...,...,..",..".".....,.",..",..,...,.".."",.....,4 7. Diverter System Information ................................................................................... 5 Requirements of 20 AAC 25, 005( e)(7) ............................,....,.........,..................,........,....,................,...., 5 8. Dri II i ng FI u id Program............................................................................................. 5 Requirements of 20 AAC 25. 005( e)(8) ..............,.....,.....,............,....,.......................,..........,................... 5 9. Abnormally Pressured Formation Information ...................................................... 6 Requirements of 20 AAC 25,005 (e)(9) """"""""""""""""""""""""""""""""""""""""""""""""" 6 1 O. Seism ic Analysis...................................................................................................... 6 Requirements of 20 AAC 25.005 (e)(10) ......,.............................,............................................,.............. 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25,005 (e)(11) .................................,..........,..,................................................ 6 12. Evidence of Bond i ng............................................................................. ................... 6 Requirements of 20 AAC 25.005 (e)(12) ...........................................,.....,........,.,..,........,....,..............,... 6 2P-420 Permitlt.doc 0 RIÙtiVÁ L \... .. ( d.'( ".~ AI-'I-'Ilcation for Permit to Drill, Well 2P-420 Saved: 7-Sep-O1 13. Proposed Dri II i ng Program................................................ ........ ....... ............ ........... 6 Requirements of 20 AAC 25,005 (c)(13) """"'" ....,.... ........,..,.............,..................... ..", .....,..,.......,.......6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25,005 (c)(14) ....,..,....,....,..,.,....,..............,............................,.,..,...,...........,... 7 15. Attachments ....................................................................... ...................................... 7 Attachment 1 ADGCC Form 10-401 (Front of permit package) ................,...........,.,............,."............. 7 Attachment 2 Directional Plan.,...,..,."".""....,.".,..",....,.,.,.."..",..."""""""""""""""""""""""""""'" 7 Attachment 3 Dn11ing Hazards Summary....... """ ...... """"""""""""" ........., ...,... ........ ....,.. .....,... ........' 7 Attachment 4 Well Schematic ,......".",."............,..,....,.".........".....,.,.."..,."".",.,........".."....."........."..,7 Attachment 5 Cement Details,......,.......................,...................,..,..,..,.........,...........,............................, 7 2P-420 Permitltdoc 0 111~fÑA L t c' ( ,i AI-'t.lllcation for Permit to Drill, Well 2P-420 Saved: 7-Sep-O1 1. Well Name Requirements of 20 AAC 25,005 (f) Each well must be identifié:d by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25,040(b). For a well with multiple well branches! é:ach branch must similarly be Identified by a unique name and API number by adding a suffix to thé: name designaté:d for the well by the operator and to the number assigned to tile /I'vell by the commission. The well for which this Application is submitted will be designated as 2P-420. 2. Location Summary Requirements of 20 AAC 25,O05(c)(2) An application for a Permit to Drill must be accompanied by each of the following item.~ except for an item already 017 file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of'the well at the !/urface¡ at the top of each objective formation and at total depth! referenæd to govemmental section lines. (B) the coordinates of the proposed location of tile well at tIle sllrt"ace! referenced to the state plane coordinate !>'ystem fòr t1lis state as mallltained by tile National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each oLJjective formation and at total depth; Location at Surface I 892' FNL, 2128' FWL, Sec 17, T8N, R7E, UM NGS Coordinates RKB Elevation: 254 ft AMSL Northings: 5868984.3 Eastings: 444088.45 Pad Elevation: 224 ft AMSL Location at Top of 1357' FNL, 1254' FEL, Sec 17, T8N, R7E, UM Productive Interval (Bermuda Formation) NGS Coordinates Measured Depth (RKB feet): 6221' Northings: 5868505.55 Eastings: 445983.84 True Vertical Depth (55 feet): 5227' True Vertical Depth (RKB feet): 5481' Location at Total De th NGS Coordinates Northings: 5868414.29 Eastings: 446371.93 1448' FNL 866' FEL Sec 17 T8N R7E Measured Depth (RKB feet): True Vertical Depth (55 feet): True Vertical De th RKB feet: UM 6741' 5562' 5816' and (0) other information required by 20 AAC 25: OSO(b); Requirements of 20 AAC 25. 050 (b) if a well is to be intentionally deviate(~ the application for a Permit to Drill (Form .1 V-1m) must (1) include a plat; drawn to a 8uitable 5"(;ale" showing the path of the proposed wel/bore" including all adjacent" we/lbore!>' within 200 feet of any pOft/Of} of the propœ,-ed well; Please see Attachment 2: Directional Plan and (2) fòr all wells wIthin 200 féet ot the proposed wel/bore (A) list the names of the operators of those well~ to the extent that those names are known or di:..1::overable lil public records" and show that each named operator has been furm:t;!7ed a copy of tile applicc-')tion by certified mai¿' or (8) state that the applicant ~'i the only affected owner. The Applicant is the only affected owner. 2P-420 Permit/t.doc 01f/~f~ A L , .- ( {' A Jt-'lícation for Permit to Drill, Well 2P-420 Saved: 7-Sep-O1 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to On/I must be accompanied by each of the following items¡ except for an Item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035., 20 AAC 25.036, or 20 MC 25.03~ as applicable; Please refer to Doyon 141 BOP Schematic currently on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25,005 (c)(4) An application for a PermIt to Dlill must be accompanied by each of the following Items¡ except for an Item already on file with the comm£'ision and identitied 117 the application: (4) information on dri/lli7g hazard~~ includJi7g (A) the maxllnum downhole pressure that may be encounterect cfltefl~7 used to determine it;, and maximum potentJ~J/.<;urfaæ pressure based 017 a methane gradient/ The expected reservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.51 psi/ft, or 8.5 to 9.7 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing operations on the nearby exploration wells, Meltwater North #1 and Meltwater North #2/2A, and on development wells. The maximum potential surface pressure (MPSP) based on the the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Bermuda formation is: MPSP as a function of reservoir pressure =(5687 ft TVD)(0.51 - 0.11 psi/ft) = 2275 psi Assuming a LOT / FIT of 16 ppg based on open hole results from the closest offset well, MELTWATER NORTH # 2, MPSP as a function of LOT / FIT at the surface shoe (2351' TVD) =( 16* .052*2351') =1697 psi. Therefore, the MPSP may be based on the reservoir pressure calculation of 2275 psi. (8) data 017 potential gas zones; No potential gas zones have been identified along the planned well path. and (C) data concerning potential c:;¡uses of hole prDb/ems such as abnormally geo'pre.":;:":,ìJred strata/ lost circulation zones/ and zone:; that have a propensity for dlfferenÜ/)/ slickiny; Please see Attachment 3: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25,005 (c)(5) An application for a Permit to Drill must be accompanied by eaäl of" the following items/ exC(;:pt for an item already 017 file with the i.:vmmission and Identified in the application: {.5) a description of'the procedure for conducting fÓ¡mðtion integrity test'i, as required under 20 AAC 25.030(1); A formation integrity test will be performed after drilling out below surface in accordance with the Phillips Alaska LOT / FIT procedure, currently on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25,O05(c)(6) An application for a Permit to Drill must be accompanied by each of the following ¡[em5~ except tÒr an item already on file with the commission and identified in the application: 2P-420 Permitlt.doc ØRTrfl1J A L (' ('r-'o,cation for Permit to Drill, Well 2P-420 Saved: 7-Sep-O1 (6) a complete proposed casing and cementing program as required by 20 MC 25030/ and a description of any slotted line~ pre- perforated line~ or screen to be ¡f7stalled; Casing and Cementing Program Hole Top Btm CsgíTbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) Oblft) Grade Connection (fi) (ft) (ft) Cement ProGram 30 X 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 9 cy High Insulated Earlv 75/8 97/8 29.7 L-80 BTC AB 2321 30 / 30 2351 / 2351 230 sx 10.7 MOD ppg AS3 Lead, 130 sx 12 ppg LiteCrete Tail Planned Top of Cement: SURFACE 51/2 63/4 15.5 L-80 BTC AB 6091 30 / 30 6121 / 5417 230 sx 15.8 MOD ppg Class 'G' 31/2 63/4 9.3 L-80 8RND 620 6121 / 5417 6741 / 5816 Planned Top of MOD Cement: 5621' MD 7. Diverter System Information Requirements of 20 AAC 25,O05(c)(7) An application tor a Permit to Drill must be accompanied by each of the fvllowing item.'i¡ except fvr an item already on fìk: with the comm£'ision and identified in the application: (7) a diagram and descliption of the diverter .sy¿:;tem as required by 20 AAC 25: OJ.5~ lInles..'; this requirement is waived by the commission under 20 AAC 25:0J5(tJX?l' Please refer Doyon 141 Diverter Schematic currently on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Perlnlt to Drill must be accompanied by each of the following ¡tems~ except fÒr an item already 017 flle with the comm£'ision and identified in the appik":ation: (8) a dnlling fluid progrõ/n fi7e1uding a diagram and description of the drillfi7g flUId systern as requin,:d by 20 AAC 25:033; Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be built and maintained to the following specifications: Spud to 9 7/8" Drill Out to Top Bermuda Surface Casing Top Bermuda To Well TD Initial Value Final Value Initial Value Final Value Initial Value Final Value Density (ppg) 9.6 9.8 9.4 9.8 9.8 9.8 Funnel Viscosity 80 100 50 65 50 65 (seconds) Yield Point 35 45 10 25 20 30 (cP) Plastic Viscostiy 13 21 6 14 6 14 Obl100 sf) 10 second Gel 10 15 2 6 4 7 StrenGth Obl100 sf) 10 minute Gel 15 40 4 8 4 8 2P-420 Permitlt.doc ORfrilN A L f t"'r-'oIcation for Permit to Drill, Well 2P-420 Saved: 7-Sep-O1 Strenath (lb/100 sf) pH 9.5-10 9.5-10 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5 API Filtrate(cc) <15 <15 <6 <6 8-10 8-10 Please refer to Doyon Rig 141 Fluid System Components currently on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25,005 (c)(9) An application for a PermIt to Drill mUi:>7: be accompanied by eaä7 of the following items- except for an item already on file with the commission and identified in the application: (9) for an exploratOlY or stratigraphic test we/~ a tabulation setting out the deptl¡s of predicted abnormally geo-pressured strata as required by 20 MC 25. 033(f)/' Not applicable: Application is not for an exploratory of stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25,005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commis:c,ion and identitìed in the application: (10) fvr an exploratory or stratigraphic test wel¿ a seignic refraäion or rer7ect.ion analysis as required by ,ZO AAC 25: 06.1 (;:1); Not applicable: Application is not for an exploratory of stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be acc'Ompanied by each of the {allowing item~ except f'or an item already on tHe with the commission and identified in the application: (1.1) for a well elf/lIed from an off...;;,1ìore platfvm~ mobile bottom-founded strvä:ure/ jack..up 11g/ or floating dnlling vesse¿ an analysis of seabed conditÙ)ns as required by 20 AAC .25". 06.1 (b)/ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application tor a Permit to Drill mast be accompanied by each of the following items.- except f'or an item already on (¡'Ie wtZ17 the commL<;..'j/on and identified In the application: (12) evIdence showing that the requirements of 20 MC 25. 025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Olill mufit be accompanied by each of the fvllowing items~ except fvr an item already on ¡lIe with the commission and identified in the applicalion: The proposed drilling program is listed below. Please refer as well to Attachment 4: Well Schematic: 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Doyon 141. Install diverter & function test same. 3. Spud and directionally drill 9 7/8" hole to 7 5/8" surface casing point (+/- 2351 MD') according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. 2P-420 Permitlt.doc 0 Rt UfNf A L t {1-'~'JI cation for Permit to Drill, Well 2P-420 Saved: 7-Sep-O1 4. Run and cement 7 5/8" 29.7# L-80 BTC AB MOD casing to surface using ArcticSet 3 lead slurry and LiteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to ensure cement reaches the surface. Displace cement with mud, 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results. 7. Drill out cement and 20' minimum to SO' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. 8. Directionally drill 6 3/4" hole to well total depth (+/- 6741' MD) according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. Circulate and condition hole. POOH. 9. Run open hole e-line or drill pipe conveyed logs as needed. 10. Run and cement 5 1/2" 15.5# L-80 BTC AB MOD x 3 1/2 9.3# L-80 8RND MOD tapered production casing string with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' above the planned top perforation. 11. Run and land 3 1/2" 9.3#, L-80, 8RND MOD tubing. Displace well to completion brine. 12. Pull landing joint. Install BPV, Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 13. Freeze protect well. Set BPV. Release rig and turn well over to production. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. * Cement bond log will be run prior to perforating. 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 music be accompanied by eaä7 of the lollowing ilems~ except IÓr an Hem already Ofl file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of'drilling mud and cuttings and a statement ot' whether the operator intends to request ðutl7orìzation under 20 MC 25. 080 fÒr an annular cH:"f)osì:ìl o¡x?r¡:¡tion in the well,/ Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P pad or hauled to a Class II disposal well. All cuttings to be disposed of will be either disposed of down the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for disposal down an approved disposal well. At the end of drilling operations, a request will be submitted for this well to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 AOGCC Form 10-401 (Front of permit package) Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Cement Details 2P-420 Permitlt.doc ðfFTf11N A L C :::J:J ----. ~ ---- 2: ~ r-- ,-- ------ -- - -- - -- - ----:---- ----- -- - - ---- - ---- -. - --- --- -------- ---- --I ! Crealed by bmlChael For: P Reilly i i Dole plaited: 15-Aug-2001 I , i i Pial Reference is 2P-420 Versianl/3- ! i Coordinates are in feel reference sial 1420. ! ¡True Vertical Deplhs are reference RKB (Doyon 141).1 ! iii. I i ~ ! roo-, .--. -. - - --- J - - ----. --..-- - ---- - ~~~~~.. ----..- 'm'" - - -_._--_J..- --------- --- ------ -- - ----- ---.-- ._----- --- -- - ----- - -.-'--'-"-' --. --..--. -.- - --- -- ----.. - -- __--"'m - - , - - - --- , PROF~LE COMMENT DATA ==== '----- Point ----- MD 1454.00 1854.00 I Base Permafrost ,Base Westsak .7 5/8 Csg iC80 !KOP [Begin Bld/Trn 2351 .00 2451 .00 2500.00 3000.00 ¡C50 3032.05 3271 .25 .C40 1C37 IT7 3436.51 4669.24 5006.03 IEOC ,T 4.1 (Top Cairn) IT3.1 ,Casing x/a T3(Top Bermuda) 5850.59 5979.71 6120.85 6220.85 ¡Target-Bermuda MidptY 6377.96 ¡T2(Base Bermuda) 6541 .33 \C35(TOp Albain) 6707.79 LID...._____=--_C ~- p1___..________m- 674 1 .33 ¡- - ------- - --- ----- - --- -- .---.-.-- -- ----- -- ---- --- - - ----1 ¡Phillips Alaska, Inc. - ¡ Structure: Drill Site 2P Well: 420 ¡ i I Location: North Slope, Alaska¡ ---...I Field: Meltwater Inc Dir TVD North East 0.00 111 .00 1454.00 0.00 0.00 0.00 1 11 .00 1854.00 0.00 0.00 0.00 111 .00 2351.00 0.00 0.00 0.00 111 .00 2451.00 0.00 0.00 0.00 111 .00 2500.00 0.00 0.00 10.00 111 .00 2997.46 -15.60 40.63 10.63 110.41 3029.00 -1 7.63 46.00 15.37 107.53 3262.00 -34.88 96.95 18.66 106.39 3420.00 -48.95 143.22 43.27 103.17 4469.00 -203.26 753.23 50.00 102.80 4700.12 -258.20 991 .68 50.00 102.80 5243.00 -401.51 1622.58 50.00 102.80 5326.00 -423.42 1719.04 50.00 102.80 5416.72 -447.37 1824.47 50.00 102.80 5481.00 -464.33 1899.1 7 50.00 102.80 5581.99 -490.99 2016.53 50.00 102.80 5687,00 -518.71 2138.56 50.00 102.80 5794.00 -546.96 2262.91 50.00 102.80 5815.56 -552.65 2287.97 , ""-"'-"-"'! ¡ I I ¡ Deg/1O01 I 0.00, 0.001 0.001 I 0.00,' 0.00 I 2.00 2.001 2.001 i 2.001 i 2.001 I I 2.001 0_001 0.001 I 0.001 I 0.001 0.001 I 0.001 0.001 "..Q:.QQl ==== V. Sect 0.00 0.00 0.00 0.00 0.00 43.17 48.87 102.45 150.73 779.94 1024.62 1671.51 1770.41 1878.51 1955.10 2075.44 2200.57 2328.07 ---------.----------.----------- 2353.77 .--------.---------_-------m------_.__._m..""- - -- -------...------ -----..-- -- ,~ ---,--,---------------'-"--"--'- - .---.---, - - , Created by bmÖC;l\Qe' For: P Reilly: Date plotted: 15-Auc¡-2001 , Plcl Rel.rence ;. 2P-420 vers;onl3. uæ- - IN1'¡;Q - Coord;nDt.. Dr. ;n I.e\ reloronce SlD\ 1420. - - - - - ;True VOftôcDI DeplhS Dro roloronco RKB (Dayan 141).: ----- a 400 800 1200 1600 ,,--.., -+- Q) 2000 Q) '+- '--'" ...c 2400 -+- 0.. Q) 0 2800 0 U -+- 3200 L Q) > Q) 3600 ::J L I- I 4000 V 4400 4800 5200 5600 6000 { -~. !-~-~~!!~'p_~_~l~_~~~_,- I .l!- -~: -'- Structure: Drill Site 2P Well: 420 Field: Meltwater Location: North Slope, Alaska! RKB Elevation: 254' 103.68 AZIMUTH 2075' (TO TARGET) .nPlane of Proposaln. Bose Permafrost Base Westsak j l 7 5/8. Csg C80 . KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 ft 8.00 Begin Bld/Trn I 1.98 C50 13.96 C40 15.95 17.94 C37 DLS: 2.00 deg per 100 ft 19.93 21.92 23.91 25.91 27.91 29.90 31.90 33.90 37.89 41.89 T7 45.88 49.88EOC TANGENT ANGLE 50 DEG T4.1 (Top Cairn) 13.1 - Casing x/a T3(Top Bermuda) Target-Bermuda Midpt T2(Base Bermuda) C35(Top Albain) r TO - Csg pt. a 400 800 1200 1600 2000 2400 2800 Vertical Section (feet) -> Azimuth 103.68 with reference 0.00 N, 0.00 E from slot #420 ORIGINAL C ::t::J - - ~ - - ~ r--- ,--_. .-. .-. --- - - ---. - --.- - -. -------. 1 Crealed by bmichael For: P Reilly i ¡ Date plaited: 15-Aug-2001 : i Plot Reference is 2P-42D Versianl3. i ¡ Coordinales are in feel reference sial 1420. ¡ ¡True Vertical Depths are relerence RKB (Dayan 141)'1 i .£ I [ INT~Q i 450 300 150 111 <4Z c,'"~O; l'ò 1'=> 0 150 SURFACE LOCATION: 892' FNL 2128' FWL SEC. 17, T8N, R7E \'\ (" ~\Ò çf ." ~().e,ctè> C), "VC;-{,o.:')1 C, 300 450 600 ~----- ¡Phillips Alaska, ¡----------.----------- i Structure: Drill Site 2P l Field: Meltwater Location -------.-----.-- Inc. -------------'-j Well: 420 ¡ : --~~~ Slop~~as~~J 750 900 103.68 AZIMUTH 2075' (TO TARGET) ***Plone of Proposal*** TRUE East (feet) -> 1050 1200 1350 0 102.80 AZ 1500 1650 1950 1800 '(~ c,o' ~oç ,\1>.:'- '\'):'- 0 .0° ((;° O' Ëj , -~ ~ ..},òQ .;þO ((;é~ 1\:" ,\o(O;e 2100 2400 2550 2700 2250 TARGET LOCATION: 13B3' FNL. 1137' FEL SEC. 17, TBN, R7E .;þÒ\ ~e((\' Ö'~ o?e t¡i.'9 q\.' '\1-~ b~oQ c,?0; c,"3 ~ /" --4 ,\v TO LOCATION: 144B' FNL, B66' FEL SEC. 17, TBN, R7E 2850 3000 300 ~- 150 0 (J) 150 0 C -+- :Y 300 ,--..., - CD CD -+- 450 "--'" I V 600 750 900 --ro- ( .~: ---.-----.--------"----' , Crootld by ÞmöchQ" For: P Reilly Dolo piotto. : 14-Auq-2DOI 'Phillips Alaska, Inc. Coorcfonol.. are õn 1..1 roforonco ,ICI IUD. Field: Meltwater Well: 420 Location: North Slope, Alaska. Plot Roloronce Õ, 2P-42D VorsõonlJ. Structure: Drill Site 2P ,True Vorl;,;OI Doplha or. ral.ronco RKB (Doyon 141)., .- ...... - JNTtQ ill TRUE NORTH ~ c::::J 350 0 10 340 20 240 330 ,*1500 30 320 40 50 300 .~ 290 70 280 80 270 90 260 100 250 110 .. 900 120 '~ 'II: 1300 " 130 230 220 2',0.. 140 ~ 1100 210 ~ 13 '", 1300 150 6>.. ~ ,¡,1500 . 200 . 1300 'I' Œ\ ~ 1 90 .. 1 80 ~ ',~ ~5ØcO ~~ 160 ' ill œ ~ ~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ORIGINAL c::> ::0 - ~ ~ ~,,;;.> c:::: ~ r--- i Crealed by bmichael For: P Reilly I i Dale plaUed : 15-Aug-2001 ¡ I Pial Reference is 2P-420 Versian63. ¡ i Caardinales are in leel reference sial 1420. ¡ I ! ¡True Verlical Deplhs are reference RKB (Dayan 141).: i ~. ¡ i ~ i i INT~Q : I j 80 60 ~300 8 300 ~300 '7, --- ',.500 ", - -' -. 700 2 --- 900 -'.... .-- 700 - --1100' '. --- '..900 - . -,- " - " - -....~300 - ~ --- "..JI00 .. 1100 - - ... }500 "' " ----- ,,"'.,,1300 >,"00 - - -~,!,OO 3900 - 40 20 0 20 -$-.300 -$-.300 -$: 300 " It 500 ' '.500 -$- ~ '.. 700 , 'if 900 :. 700 ' ~ \\) . 700 .. 700 ".900 .. 900 .. 1100 'if 900 ", 1100 .. 1300 .. 11 00 ' ~ \\) ,--- Inc.! '-'--------------'--"--1 Structure: Drill Site 2P Well: 420 I Field: Meltwater Location: North Slope, Alaska! ~-,------, ,,---------,--,-----,,---_..,.._-,---' ,Phillips Alaska, 40 80 East (feet) -> 100 120 140 160 180 200 I I I ....' l ~ 900 ø -E? 300 -e:, fðgó~ODt7 900 I"" ." " 900 , .. 1100 220 240 260 60 ,¡ 700 -e: -$- 700~300, m .. : Ò300 ~300 .."" ,- ,. .. ,..." + -$-300 '7"" ;1 3 ~ e 300 " " , . 700 ~i1~~ '73~0 2500' .500 2700 2900, .. ~__.,.330~ 35ð\>-:.ìIiJ -,~.,---------.~---_...._.,_,m '" ~ .-...~, a 2300'.. ' " 900 .. .,700 " .. 700 ' , '".1,100 "._~OO - '- - ._~OO - -, ..--1..100 , .. 900 " , , . 1 300 .. 1100 " " 1 300 '~300 '.. -. 1500 ~ ~ \(!) ~ ~ 280 300 320 340 360 I I I -e: 700 .. .. 1100 .. 1300 80 ~. 60 40 20 0 20 If) 0 C 40 - :r ---.. -+. 60 CD CD - '-./ 80 I .-.' V 100 120 140 160 180 C) ::tJ - - ~ - - <: ~ r-- 320 €Ð.. ~. I Creoled by bmichoel For: P Reilly i ! Dole plolled : 14-Aug-2001 ! i Pial Reference is 2P-420 Versianl3. i ¡ Caardinales are in feel reference sial 1420. ¡ !True Vertical Deplhs are reference RKB (Doyon 141).: ~ Hi.. , t. -------.. -.-- ---~ ~~~---_..- -. ___1 340 360 380 400 420 440 ¡-- ___on_un] IPhillips Alaska, Inc.! ¡ I Structure: Drill Site 2P Well: 420 I Field: Meltwater Location: North Slope. Alaska I L--- ---_J 460 480 500 East (feet) - > 520 540 560 580 '. ___'700 600 620 660 700 720 740 -. , 300 B?Ð- - ~.. ". ...1500 ~-~._-.c.._-.._........._- -"'-... 4100 - .,. ": :- - - - - - - - -. - 17òG- - - - - - - - - '...1500 ------- ---<5~~____-------------------------- - '420 ~ . 1 700 -A>... ~ EB ...15~0 640 680 -- '. . , 900 '. . Ii};) "'liB 760 20 --~. 40 60 80 100 (f) 120 0 C -+- :r 140 ,--.. -+. CD CD -t- 160 -....- I V 180 200 220 --'~ 240 260 280 <:::> ::c - - ~ ~ :æ: ~ r- i Created by bmichael--- - For: P Reilly I ¡ Dote plotted: 15-Aug-2DOI 1 ! Plot Reference is 2P-420 Versionl3. ! i Coordinates are in feet reference slot 142D, ¡ ¡True Vertical Depths are reference RKB (Doyon 141).1 ... ¡ Bfm.s ! L_____.-. - - --~ ~~ ~ -- - - --- ,-- - --- - J ¡Phillips Alaska, Tnc. Structure: Drill Site 2P Well: 420 ¡ ,___~ield : _~eltwo!~_~ocotion : North Slope~_~los~~J 500 1400 East (feet) -> 2000 ~ , " " . '.2}'o~~9~0- - . - ---' ,-",.: ,~' :- ... ....... , ... " , , ... "',4700 ... , , ....... -'... , , ... ....... , ~,4500 "'... , , '... ... ... , "'... ... '... "".. 4300 "'... ... "', ... , ... ", .2,9bQ """'~~,OO , """" 420 300 '::i.~'70Ò-: -....,: - - - - - 4500 ~-š\", " " 1900 . - - - - c - - - 4700 ' . - . - - - 4900 """ ............... 5100 ".,1l00" '.2100 ---~----------__5-'00 --------- '-" "" 2300 "', "" , " ~ " 1900 "" . c, 600 700 800 900 1000 1100 1200 1300 -,~O l'l.3-0OJO " 1 . ",.,15DO" " .- ,.,300 .aú'" " .- ~'.1:1~8(). :17.~500i~7~0...." ' 1Jö8° ... ,,' "0- ,..1 fiiiiJ 1900 ,".. ' ,21d6--0,~ - ... .-,}12foo '*-"-"-'" ,,---,.-'" ..'"~ 192~0 :/,300 ,e'" ",' EÐ ",.,1700 " ,. 1900 " """':2.1 00 , .:?~OO ~....1900 ~ ~ .... , "., ?500 , .. 2100 " ~ "\D " -'. 2100 , ... , '~ 2100 '. 2300 ~ '., 2100 , . 2500 '. 2300 ~ '* 2300 ~ ~ ~ ~ ~ \!) 1500 1600 1700 1800 1900 }~~~~ '" ," ,\ ,:: :c ::, ' ".,,2500 'e2700 "..,2900 - -. . 3100 , --._2300 2100 2200 2300 2400 2500 2700 - 3lO0 '. 2900 . 3500 , .' .. 3300500 ',." ."', . ;?700 -.. ~7_0~ - -~ , 'e,3300 '. e. 3500 , '. 2500 -'~ 2600 '~I- 1000 2700 200 100 0 100 200 tf) 300 0 C -+- :r 400 ~ -+-. CD CD -+- 500 '--'" I V 600 r~ -~ 700 800 900 1100 ( Phillips Alaska. Inc. Drill Site 2P 420 slot U20 Meltwater North Slope, Alaska PRO P 0 S A L LIS TIN G by Baker Hughes INTEQ Your ref: 2P-420 Version*3 Our ref: prop4512 License: Date printed: 15-Aug-2001 Date created: 25-Feb-2001 Last revised: 15-Aug-2001 Field is centred on 441964.235.5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.754,w150 26 50.778 Slot Grid coordinates are N 5868984.299, E 444088.453 Slot local coordinates are 891.04 S 2131.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ~ ORIGINAL II ~, Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,420 Your ref : 2P-420 version*3 Meltwater,North Slope, Alaska Last revised : 15-Aug-2001 Measured Inc1in. Azimuth True Vert R E C TANGULAR Dogleg Vert Depth Degrees Degrees Depth COO RDINATES Deg/100ft Sect 0.00 0.00 111.00 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 111. 00 500.00 0.00 S 0.00 E 0.00 0.00 1000.00 0.00 111.00 1000.00 0.00 S 0.00 E 0.00 0.00 1454.00 0.00 111.00 1454.00 0.00 S 0.00 E 0.00 0.00 Base Permafrost 1500.00 0.00 111. 00 1500.00 0.00 S 0.00 E 0.00 0.00 1854.00 0.00 111. 00 1854.00 0.00 S 0.00 E 0.00 0.00 Base Westsak 2000.00 0.00 111 . 00 2000.00 0.00 S 0.00 E 0.00 0.00 2351.00 0.00 111.00 2351. 00 0.00 S 0.00 E 0.00 0.00 7 5/8 Csg 2451.00 0.00 111.00 2451. 00 0.00 S 0.00 E 0.00 0.00 C80 2500.00 0.00 111.00 2500.00 0.00 S 0.00 E 0.00 0.00 KOP 2600.00 2.00 111.00 2599.98 0.63 S 1.63 E 2.00 1. 73 2700.00 4.00 111.00 2699.83 2.50 S 6.52 E 2.00 6.92 2800.00 6.00 111.00 2799.45 5.62 S 14.65 E 2.00 15.57 2900.00 8.00 111.00 2898.70 9.99 S 26.03 E 2.00 27.66 3000.00 10.00 111.00 2997.46 15.60 S 40.63 E 2.00 43.17 Begin B1d/Trn 3032.05 10.63 110.41 3029.00 17.63 S 46.00 E 2.00 48.87 C50 3100.00 11. 98 109.37 3095.63 22.15 S 58.53 E 2.00 62.11 3200.00 13 .96 108.19 3193.07 29.36 S 79.78 E 2.00 84.46 3271.25 15.37 107.53 3262.00 34.88 S 96.95 E 2.00 102.45 C40 3300.00 15.95 107.30 3289.68 37.21 S 104.35 E 2.00 110.19 3400.00 17.94 106.60 3385.34 45.69 S 132.23 E 2.00 139.28 3436.51 18.66 106.39 3420.00 48.95 S 143.22 E 2.00 150.73 C37 3500.00 19.93 106.04 3479.92 54.80 S 163.36 E 2.00 171.69 3600.00 21. 92 105.58 3573.33 64.53 S 197.72 E 2.00 207.37 3700.00 23.91 105.19 3665.43 74.85 S 235.27 E 2.00 246.30 3800.00 25.91 104.86 3756.12 85.76 S 275.95 E 2.00 288.40 3900.00 27.91 104.57 3845.29 97.25 S 319.72 E 2.00 333.65 4000.00 29.90 104.32 3932.83 109.31 S 366.52 E 2.00 381. 97 4100.00 31.90 104.09 4018.63 121. 91 S 416.30 E 2.00 433.32 4200.00 33.90 103 . 89 4102.59 135.04 S 469.00 E 2.00 487.63 4300.00 35.89 103 .71 4184.61 148.68 S 524.55 E 2.00 544.84 4400.00 37.89 103.55 4264.58 162.83 S 582.89 E 2.00 604.86 4500.00 39.89 103.40 4342.42 177.46 S 643.94 E 2.00 667.64 4600.00 41. 89 103.26 4418.01 192.55 S 707.63 E 2.00 733.09 4669.24 43.27 103.17 4469.00 203.26 S 753.23 E 2.00 779.94 T7 4700.00 43.88 103.14 4491.28 208.09 S 773.88 E 2.00 801.14 4800.00 45.88 103.02 4562.13 224.05 S 842.61 E 2.00 871.70 4900.00 47.88 102.91 4630.48 240.42 S 913.74 E 2.00 944.68 5000.00 49.88 102.80 4696.24 257.18 S 987.18 E 2.00 1020.00 5006.03 50.00 102.80 4700.12 258.20 S 991. 68 E 2.00 1024.62 EOC 5500.00 50.00 102.80 5017.64 342.02 S 1360.68 E 0.00 1402.97 5850.59 50.00 102.80 5243.00 401. 51 S 1622.58 E 0.00 1671.51 T4.1(Top Cairn) 5979.71 50.00 102.80 5326.00 423.42 S 1719.04 E 0.00 1770.41 T3.1 6000.00 50.00 102.80 5339.04 426.86 S 1734.19 E 0.00 1785.95 6120.85 50.00 102.80 5416.72 447.37 S 1824.47 E 0.00 1878.51 Casing X/O 6220.85 50.00 102.80 5481.00 464.33 S 1899.17 E 0.00 1955.10 T3(Top Bermuda) 6377 . 96 50.00 102.80 5581.99 490.99 S 2016.53 E 0.00 2075.44 Target-Bermuda Midpt 6377.98 50.00 102.80 5582.00 491.00 S 2016.54 E 0.00 2075.46 MW(J) Rvsd 12 Jun 01 6500.00 50.00 102.80 5660.44 511.70 S 2107.69 E 0.00 2168.92 6541. 33 50.00 102.80 5687.00 518.71 S 2138.56 E 0.00 2200.57 T2(Base Bermuda) All data is in feet unless otherwise stated. Coordinates from slot *420 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea Bottom hole distance is 2353.77 on azimuth 103.58 degrees from wellhead. Total Dogleg for we1lpath is 50.12 degrees. Vertical section is from wellhead on azimuth 103.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ORIGINAL ~. Phillips Alaska. Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska 6707.79 6741.33 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 2262.91 E 2287.97 E RECTANGULAR COO R DIN ATE S 50.00 50.00 102.80 102.80 5794.00 5815.56 546.96 S 552.65 S . PROPOSAL LISTING Page 2 Your ref: 2P-420 Version'3 Last revised: 15-Aug-2001 Dogleg Deg/IOOft Vert Sect 0.00 0.00 2328.07 C35(Top AlbainJ 2353.77 TD - Csg Pt. All data is in feet unless otherwise stated. Coordinates from slot #420 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea Bottom hole distance is 2353.77 on azimuth 103.58 degrees from wellhead. Total Dogleg for wellpath is 50.12 degrees. Vertical section is from wellhead on azimuth 103.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ORIGINAL { ( Phillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 2P-420 Version'3 Last revised: 15-Aug-2001 Comments in wellpath -------------------- -------------------- lID TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 1454.00 1454.00 0.00 S 0.00 E Base Permafrost 1854.00 1854.00 0.00 S 0.00 E Base Westsak 2351.00 2351. 00 0.00 S 0.00 E 7 5/8 Csg 2451.00 2451.00 0.00 S 0.00 E C80 2500.00 2500.00 0.00 S 0.00 E KOP 3000.00 2997.46 15.60 S 40.63 E Begin Bld/Trn 3032.05 3029.00 17.63 S 46.00 E C50 3271.25 3262.00 34.88 S 96.95 E C40 3436.51 3420.00 48.95 S 143.22 E C37 4669.24 4469.00 203.26 S 753.23 E T7 5006.03 4700.12 258.20 S 991. 68 E EOC 5850.59 5243.00 401. 51 S 1622.58 E T4.l(Top Cairn) 5979.71 5326.00 423.42 S 1719.04 E T3.l 6120.85 5416.72 447.37 S 1824.47 E Casing X/O 6220.85 5481. 00 464.33 S 1899.17 E T3(Top Bermuda) 6377.96 5581.99 490.99 S 2016.53 E Target-Bermuda Midpt 6377.98 5582.00 491. 00 S 2016.54 E HW(J) Rvsd 12 Jun 01 6541.33 5687.00 518.71 S 2138.56 E T2(Base Bermuda) 6707.79 5794.00 546.96 S 2262.91 E C35(Top Albain) 6741. 33 5815.56 552.65 S 2287.97 E TD - Csg Pt. Casing positions in string 'A' ============================== Top lID Top TVD Rectangular Coords. Bot lID Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE O.OOE 2351. 00 6741.33 2351.00 5815.56 O.OOS 552.65S O.OOE 2287.97E 7 5/8" Casing 5 1/2 x 3 1/2" Csg Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- HW(J) Rvsd 12 Jun 01 446101.000,5868478.000,999.00 5582.00 491. OOS 2016.54E 22-Feb-2001 ORIGINAL ( ( Phillips Alaska, Inc. Drill Site 2p 420 slot 11420 Meltwater North Slope, Alaska SUMMARY C LEA RAN C ERE PO R T by Baker Hughes INTEQ Your ref: 2P-420 Versionll3 Our ref: prop4512 License: Date printed: l5-Aug-200l Date created: 25-Feb-2001 Last revised: 15-Aug-2001 Field is centred on 441964.235.5869891.466.999.00000.N Structure is centred on 441964.235,5869891.466.999.00000,N Slot location is n70 3 9.754,w150 26 50.778 Slot Grid coordinates are N 5868984.299, E 444088.453 Slot local coordinates are 891.04 S 2131.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 25-May-2001 57.3 2020.0 3637.5 4-Jun-2001 360.2 0.0 0.0 26-Feb-2001 6580.8 5240.0 5240.0 26-Feb-2001 578.5 5580.0 5580.0 6-Mar-2001 46420.7 6741.3 6741.3 MWD <0 - 6008'>,,417.Drill Site 2P MWD <0-9224'>,,438,Dril1 Site 2P PMSS <0-6122'>"MWNll1,Meltwater North III PMSS <2212-7349'>"MWNII2A,Me1twater North 112 PMSS <0-8935'>"MWSouthl,Meltwater South III ORIGINAL ¡ I~, Phillips Alaska, Inc. Drill Site 2P 420 slot U20 Meltwater North Slope. Alaska PRO PO S ALL I S TIN G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: 2P-420 Versioni3 Our ref: prop45l2 License: Date printed: l5-Aug-200l Date created: 25-Feb-200l Last revised: l5-Aug-200l Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235.5869891.466,999.00000,N Slot location is n70 3 9.754,w150 26 50.778 Slot Grid coordinates are N 5868984.299, E 444088.453 Slot local coordinates are 891.04 S 2131.27 E Projection type: alaska -' Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( ORIGINAL ( 't Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,420 Your ref : 2P-420 Versioni3 Meltwater,North Slope. Alaska Last revised : 15-Aug-2001 Measured Inc1in. Azimuth True Vert R E C TAN GULAR Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth COO RDINATES Sect Major Minor Vert. Azi. 0.00 0.00 111.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 500.00 0.00 111.00 500.00 0.00 S 0.00 E 0.00 1.31 1.31 0.75 N/A 1000.00 0.00 111. 00 1000.00 0.00 S 0.00 E 0.00 2.61 2.61 1.50 N/A 1454.00 0.00 111.00 1454.00 0.00 S 0.00 E 0.00 3.80 3.80 2.18 N/A 1500.00 0.00 111. 00 1500.00 0.00 S 0.00 E 0.00 3.92 3.92 2.25 N/A 1854.00 0.00 111. 00 1854.00 0.00 S 0.00 E 0.00 4.84 4.84 2.78 N/A 2000.00 0.00 111. 00 2000.00 0.00 S 0.00 E 0.00 5.22 5.22 3.00 N/A 2351. 00 0.00 111.00 2351.00 0.00 S 0.00 E 0.00 6.14 6.14 3.53 N/A 2451.00 0.00 111.00 2451.00 0.00 S 0.00 E 0.00 6.40 6.40 3.68 N/A 2500.00 0.00 111.00 2500.00 0.00 S 0.00 E 0.00 6.53 6.53 3.75 N/A 2600.00 2.00 111.00 2599.98 0.63 S 1. 63 E 1. 73 6.79 6.79 3.90 N/A 2700.00 4.00 111. 00 2699.83 2.50 S 6.52 E 6.92 7.06 7.05 4.05 N/A 2800.00 6.00 111.00 2799.45 5.62 S 14.65 E 15.57 7.35 7.31 4.20 291.00 2900.00 8.00 111. 00 2898.70 9.99 S 26.03 E 27.66 7.67 7.58 4.35 291. 00 3000.00 10.00 111.00 2997.46 15.60 S 40.63 E 43.17 8.06 7.85 4.51 291. 00 3032.05 10.63 110.41 3029.00 17.63 S 46.00 E 48.87 8.21 7.94 4.56 290.84 3100.00 11. 98 109.37 3095.63 22.15 S 58.53 E 62.11 8.53 8.13 4.66 290.51 3200.00 13.96 108.19 3193.07 29.36 S 79.78 E 84.46 9.12 8.41 4.82 289.90 3271.25 15.37 107.53 3262.00 34.88 S 96.95 E 102.45 9.64 8.62 4.94 289.45 3300.00 15.95 107.30 3289.68 37.21 S 104.35 E 110.19 9.86 8.71 4.99 289.27 3400.00 17.94 106.60 3385.34 45.69 S 132.23 E 139.28 10.77 9.01 5.15 288.69 3436.51 18.66 106.39 3420.00 48.95 S 143.22 E 150.73 11.18 9.13 5.22 288.49 3500.00 19.93 106.04 3479.92 54.80 S 163.36 E 171.69 11. 89 9.33 5.33 288.15 3600.00 21. 92 105.58 3573.33 64.53 S 197.72 E 207.37 13.24 9.66 5.51 287.66 3700.00 23.91 105.19 3665.43 74.85 S 235.27 E 246.30 14.84 10.01 5.70 287.22 3800.00 25.91 104.86 3756.12 85.76 S 275.95 E 288.40 16.70 10.37 5.91 286.82 3900.00 27.91 104.57 3845.29 97.25 S 319 .72 E 333.65 18.84 10.75 6.13 286.46 4000.00 29.90 104.32 3932.83 109.31 S 366.52 E 381. 97 21.27 11.14 6.37 286.14 4100.00 31.90 104.09 4018.63 121.91 S 416.30 E 433.32 23.99 11. 55 6.62 285.85 4200.00 33.90 103.89 4102.59 135.04 S 469.00 E 487.63 27.01 11. 98 6.90 285.58 4300.00 35.89 103.71 4184.61 148.68 S 524.55 E 544.84 30.33 12.41 7.21 285.34 4400.00 37.89 103.55 4264.58 162.83 S 582.89 E 604.86 33.96 12.86 7.54 285.12 4500.00 39.89 103.40 4342.42 177.46 S 643.94 E 667.64 37.90 13.32 7.91 284.91 4600.00 41. 89 103.26 4418.01 192.55 S 707.63 E 733.09 42.15 13.80 8.30 284.73 4669.24 43.27 103.17 4469.00 203.26 S 753.23 E 779.94 45.31 14.13 8.60 284.61 4700.00 43.88 103.14 4491.28 208.09 S 773.88 E 801.14 46.71 14.27 8.74 284.56 4800.00 45.88 103.02 4562.13 224.05 S 842.61 E 871.70 51.58 14.76 9.20 284.40 4900.00 47.88 102.91 4630.48 240.42 S 913.74 E 944.68 56.77 15.25 9.71 284.25 5000.00 49.88 102.80 4696.24 257.18 S 987.18 E 1020.00 62.25 15.74 10.25 284.11 5006.03 50.00 102.80 4700.12 258.20 S 991. 68 E 1024.62 62.59 15.77 10.29 284.10 5500.00 50.00 102.80 5017.64 342.02 S 1360.68 E 1402.97 90.09 18.23 13.15 283.68 5850.59 50.00 102.80 5243.00 401. 51 S 1622.58 E 1671. 51 109.78 20.03 15.28 283.53 5979.71 50.00 102.80 5326.00 423.42 S 1719.04 E 1770.41 117.03 20.70 16.06 283.47 6000.00 50.00 102.80 5339.04 426.86 S 1734.19 E 1785.95 118.17 20.80 16.18 283.46 6120.85 50.00 102.80 5416.72 447.37 S 1824.47 E 1878.51 124.98 21. 43 16.93 283.43 6220.85 50.00 102.80 5481. 00 464.33 S 1899.17 E 1955.10 130.62 21. 95 17.55 283.40 6377.96 50.00 102.80 5581.99 490.99 S 2016.53 E 2075.44 139.47 22.77 18.53 283.36 6377.98 50.00 102.80 5582.00 491.00 S 2016.54 E 2075.46 139.47 22.77 18.53 283.36 6500.00 50.00 102.80 5660.44 511. 70 S 2107.69 E 2168.92 146.36 23.41 19.29 283.33 6541. 33 50.00 102.80 5687.00 518.71 S 2138.56 E 2200.57 148.69 23.63 19.55 283.32 All data is in feet unless otherwise stated. Coordinates from slot i420 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea Bottom hole distance is 2353.77 on azimuth 103.58 degrees from wellhead. Vertical section is from wellhead on azimuth 103.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ORIGINAL ( Phillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope. Alaska PROPOSAL LISTING Page 2 Your ref: 2P-420 Version'3 Last revised: 15-Aug-200l 6707.79 6741.33 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 24.51 24.69 RECTANGULAR COO R DIN ATE S Vert Sect Ellipse Semi Axes Major Minor Vert. 50.00 50.00 102.80 102.80 5794.00 5815.56 546.96 S 552.65 S 2262.91 E 2287.97 E 2328.07 2353.77 158.09 159.98 POSITION UNCERTAINTY SUMMARY ------------------------------ ------------------------------ Depth From To ~, Minor Azi. 20.60 20.81 283.29 283.28 0 6741 159.98 position Uncertainty Major Minor Vert. 20.81 Survey Tool Error Model ---------------------------------------------------------------------------------------------------- ARCO (H.A) Mag) User specified 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. other. All data is in feet unless otherwise stated. Coordinates from slot *420 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea Bottom hole distance is 2353.77 on azimuth 103.58 degrees from wellhead. Vertical section is from wellhead on azimuth 103.68 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 24.69 level) . OR¡~JNAL i. I ~ Phillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 2P-420 Version.3 Last revised: l5-Aug-200l Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 1454.00 1454.00 0.00 S 0.00 E Base Permafrost 1854.00 1854.00 0.00 S 0.00 E Base Westsak 2351.00 2351.00 0.00 S 0.00 E 7 5/8 Csg 2451. 00 2451.00 0.00 S 0.00 E C80 2500.00 2500.00 0.00 S 0.00 E KOP 3000.00 2997.46 15.60 S 40.63 E Begin Bld/Trn 3032.05 3029.00 17.63 S 46.00 E C50 3271. 25 3262.00 34.88 S 96.95 E C40 3436.51 3420.00 48.95 S 143.22 E C37 4669.24 4469.00 203.26 S 753.23 E T7 5006.03 4700.12 258.20 S 991. 68 E EOC 5850.59 5243.00 401. 51 S 1622.58 E T4.11Top Cairn) 5979.71 5326.00 423.42 S 1719.04 E T3.1 6120.85 5416.72 447.37 S 1824.47 E Casing XIO 6220.85 5481. 00 464.33 S 1899.17 E T3(Top Bermuda) 6377.96 5581. 99 490.99 S 2016.53 E Target-Bermuda Midpt 6377.98 5582.00 491. 00 S 2016.54 E MW(J) Rvsd 12 Jun 01 6541.33 5687.00 518.71 S 2138.56 E T2(Base Bermuda) 6707.79 5794.00 546.96 S 2262.91 E C35(Top Albain) 6741.33 5815.56 552.65 S 2287.97 E TD - Csg Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OOE 2287.97E 7 5/8" Casing 5 1/2 x 3 1/2" Csg O.OON O.OON O.OOE O.OOE 2351.00 6741.33 2351.00 5815.56 O.OOS 552.65S Targets associated with this wel1path ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(J) Rvsd 12 Jun 01 446101.000,5868478.000,999.00 5582.00 491.00S 2016.54E 22-Feb-2001 ORIGINAL :( Phillips Alaska, Inc. Drill Site 2P 420 slot U20 Meltwater North Slope, Alaska PROPOSAL LIS TIN G by Baker Hughes INTEQ Your ref: 2P-420 Version*3 Our ref: prop4512 License: Date printed: 15-Aug-2001 Date created: 25-Feb-2001 Last revised: 15-Aug-2001 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 9.754,w150 26 50.778 Slot Grid coordinates are N 5868984.299, E 444088.453 Slot local coordinates are 891.04 S 2131.27 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( ORIGINAL .( ( ( Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,420 Your ref : 2P-420 Version'3 Meltwater,North Slope, Alaska Last revised: 15-Aug-2001 Measured Inclin Azimuth True Vert R E C TAN GULAR G RID COORD5 G E 0 G RAP HIe Depth Degrees Degrees Depth COO RDINATES Easting Northing COO R DIN ATE 5 0.00 0.00 111.00 0.00 O.OON O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 500.00 0.00 111.00 500.00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 1000.00 0.00 111.00 1000.00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 1454.00 0.00 111.00 1454.00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 1500.00 0.00 111.00 1500.00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 1854.00 0.00 111. 00 1854.00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 2000.00 0.00 111.00 2000.00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 2351.00 0.00 111.00 2351.00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 2451. 00 0.00 111.00 2451. 00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 2500.00 0.00 111.00 2500.00 0.005 O.OOE 444088.45 5868984.30 n70 3 09.75 w150 26 50.78 2600.00 2.00 111.00 2599.98 0.635 1.63E 444090.08 5868983.66 n70 3 09.75 w150 26 50.73 2700.00 4.00 111.00 2699.83 2.505 6.52E 444094.95 5868981.75 n70 3 09.73 w150 26 50.59 2800.00 6.00 111. 00 2799.45 5.625 14.65E 444103.06 5868978.56 n70 3 09.70 w150 26 50.36 2900.00 8.00 111.00 2898.70 9.995 26.03E 444114.40 5868974.11 n70 3 09.66 w150 26 50.03 3000.00 10.00 111.00 2997.46 15.605 40.63E 444128.96 5868968.39 n70 3 09.60 w150 26 49.61 3032.05 10.63 110.41 3029.00 17.635 46.00E 444134.32 5868966.32 n70 3 09.58 w150 26 49.45 3100.00 11. 98 109.37 3095.63 22.155 58.53E 444146.81 5868961. 71 n70 3 09.54 w150 26 49.09 3200.00 13.96 108.19 3193.07 29.365 79.78E 444168.00 5868954.34 n70 3 09.47 w150 26 48.48 3271.25 15.37 107.53 3262.00 34.885 96.95E 444185.12 5868948.68 n70 3 09.41 w150 26 47.99 3300.00 15.95 107.30 3289.68 37.215 104.35E 444192.51 5868946.30 n70 3 09.39 w150 26 47.77 3400.00 17.94 106.60 3385.34 45.695 132.23E 444220.31 5868937.61 n70 3 09.30 w150 26 46.97 3436.51 18.66 106.39 3420.00 48.955 143.22E 444231.28 5868934.27 n70 3 09.27 w150 26 46.65 3500.00 19.93 106.04 3479.92 54.805 163.36E 444251.38 5868928.26 n70 3 09.21 w150 26 46.07 3600.00 21. 92 105.58 3573.33 64.535 197. 72E 444285.66 5868918.28 n70 3 09.12 w150 26 45.08 3700.00 23.91 105.19 3665.43 74.855 235.27E 444323.12 5868907.67 n70 3 09.02 w150 26 44.00 3800.00 25.91 104.86 3756.12 85.765 275.95E 444363 .71 5868896.44 n70 3 08.91 w150 26 42.83 3900.00 27.91 104.57 3845.29 97.255 319. 72E 444407.39 5868884.62 n70 3 08.80 w150 26 41.57 4000.00 29.90 104.32 3932.83 109.315 366.52E 444454.09 5868872.21 n70 3 08.68 w150 26 40.22 4100.00 31. 90 104.09 4018.63 121. 915 416.30E 444503.77 5868859.24 n70 3 08.55 w150 26 38.79 4200.00 33.90 103.89 4102.59 135.045 469.00E 444556.36 5868845.71 n70 3 08.42 w150 26 37.27 4300.00 35.89 103.71 4184.61 148.685 524.55E 444611.80 5868831.64 n70 3 08.29 w150 26 35.67 4400.00 37.89 103.55 4264.58 162.835 582.89E 444670.03 5868817.05 n70 3 08.15 w150 26 33.99 4500.00 39.89 103.40 4342.42 177.465 643.94E 444730.96 5868801.96 n70 3 08.01 w150 26 32.23 4600.00 41.89 103.26 4418.01 192.555 707.63E 444794.52 5868786.38 n70 3 07.86 w150 26 30.40 4669.24 43.27 103.17 4469.00 203.265 753.23E 444840.04 5868775.32 n70 3 07.75 w150 26 29.08 4700.00 43.88 103.14 4491.28 208.095 773.88E 444860.65 5868770.34 n70 3 07.70 w150 26 28.49 4800.00 45.88 103.02 4562.13 224.055 842.61E 444929.25 5868753.86 n70 3 07.55 w150 26 26.51 4900.00 47.88 102.91 4630.48 240.425 913.74E 445000.25 5868736.95 n70 3 07.39 w150 26 24.46 5000.00 49.88 102.80 4696.24 257.185 987.18E 445073.55 5868719.63 n70 3 07.22 w150 26 22.34 5006.03 50.00 102.80 4700.12 258.205 991. 68E 445078.05 5868718.57 n70 3 07.21 w150 26 22.21 5500.00 50.00 102.80 5017.64 342.025 1360. 68E 445446.36 5868631.95 n70 3 06.39 w150 26 11. 59 5850.59 50.00 102.80 5243.00 401.515 1622.58E 445707.77 5868570.48 n70 3 05.80 w150 26 04.04 5979.71 50.00 102.80 5326.00 423.425 1719.04E 445804.05 5868547.84 n70 3 05.58 w150 26 01. 27 6000.00 50.00 102.80 5339.04 426.865 1734.19E 445819.17 5868544.28 n70 3 05.55 w150 26 00.83 6120.85 50.00 102.80 5416.72 447.375 1824.47E 445909.28 5868523.09 n70 3 05.35 w150 25 58.23 6220.85 50.00 102.80 5481.00 464.335 1899.17E 445983.84 5868505.55 n70 3 05.18 w150 25 56.08 6377.96 50.00 102.80 5581. 99 490.995 2016.53E 446100.99 5868478.00 n70 3 04.92 w150 25 52.70 6377.98 50.00 102.80 5582.00 491. 005 2016.54E 446101.00 5868478.00 n70 3 04.92 w150 25 52.70 6500.00 50.00 102.80 5660.44 511.705 2107.69E 446191.98 5868456.60 n70 3 04.71 w150 25 50.07 6541. 33 50.00 102.80 5687.00 518.715 2138.56E 446222.80 5868449.36 n70 3 04.64 w150 25 49.18 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot 1420 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level). Bottom hole distance is 2353.77 on azimuth 103.58 degrees from wellhead. Total Dogleg for wellpath is 50.12 degrees. Vertical section is from wellhead on azimuth 103.68 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL Phillips Alaska, Inc. Drill 5ite 2P,420 Meltwater,North 51ope, Alaska Azimuth Degrees 6707.79 6741. 33 Measured Inclin Depth Degrees 50.00 50.00 102.80 102.80 5794.00 5815.56 True Vert Depth { ( 546.965 552.655 n70 n70 3 04.37 3 04.31 G EO G RAP HI C COO R DIN ATE 5 w150 25 45.60 w150 25 44.88 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot i420 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level). Bottom hole distance is 2353.77 on azimuth 103.58 degrees from wellhead. Total Dogleg for wellpath is 50.12 degrees. Vertical section is from wellhead on azimuth 103.68 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PROPO5AL LISTING Page 2 Your ref: 2P-420 Versiont3 Last revised: 15-Aug-2001 RECTANGULAR COO R DIN ATE 5 G RID Easting COORD5 Northing 2262.91E 2287.97E 446346.91 446371. 93 5868420.17 5868414.29 O.r.-, , ."."ry.IL' .H ¡ Lt'i /VA { ( Phillips Alaska, Inc. Drill Site 2P,420 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 2P-420 Versiont3 Last revised: 15-Aug-2001 Comments in we11path -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 1454.00 1454.00 0.005 O.OOE Base Permafrost 1854.00 1854.00 0.005 O.OOE Base Westsak 2351.00 2351.00 O.OOS O.OOE 7 5/8 Csg 2451. 00 2451. 00 0.005 O.OOE C80 2500.00 2500.00 0.005 O.OOE KOP 3000.00 2997.46 15.605 40.63E Begin B1d/Trn 3032.05 3029.00 17.635 46.00E C50 3271.25 3262.00 34.885 96.95E C40 3436.51 3420.00 48.95S 143.22E C37 4669.24 4469.00 203.265 753.23E T7 5006.03 4700.12 258.20S 991.68E EOC 5850.59 5243.00 401.51S 1622.58E T4.1(Top Cairn) 5979.71 5326.00 423.425 1719.04E T3.1 6120.85 5416.72 447.375 1824.47E Casing X/O 6220.85 5481.00 464.335 1899.17E T3(Top Bermuda) 6377.96 5581.99 490.995 2016.53E Target-Bermuda Midpt 6377.98 5582.00 491.00S 2016.54E MW(J) Rvsd 12 Jun 01 6541.33 5687.00 518.71S 2138.56E T2(Base Bermuda) 6707.79 5794.00 546.96S 2262.91E C35(Top A1bain) 6741.33 5815.56 552.65S 2287.97E TD - Csg Pt. Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 7 5/8" Casing 5 1/2 x 3 1/2" Csg O.OON O.OON O.OOE O.OOE 2351.00 6741.33 2351. 00 5815.56 0.005 552.655 O.OOE 2287.97E Targets associated with this we11path ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(J) Rvsd 12 Jun 01 446101.000,5868478.000,999.00 5582.00 2016.54E 22-Feb-2001 491.005 ORIGINAL ( { Tie-ln,:?,::,,'<::';O.QO: 0.00, .'f>'111~OO 0.00 ~:',,:,,-254:00 444088.45, 5868984~30 0.00 ~'d:\;,:,",O.OO' 0.00 :",~,:::\-:::J'¡:?~)O.OO 1 ';.:t.:i"'S'OO"",O'O' 000:':,,'/';~~,'1:11i:OO"': 50000<,t~:<',"2'46"";OO' '44408845,'58'6'8'9"'8"4':3"0' 000>4~./¡i",'O';'OO'~" OOO~,,~"~,,;;i'>'~~~,';:O"'OO' ". . ."".... .,."". . . """"",',,', . ".'.. ..~,. 2 --",:;1000~oO; 0.00:t>~'Ù1~00 1000.00.'/:\>i4å~oo 444088.45~58689Š4:30 O.OO<,'~:;,,<,~Ò~OÓ O.OO~\:~':::;;:;;i,',;:,'O;OO , ,.. ," '" "d," .. , , "...' , '" "", , " ""..' ",,' " ' , " . , ,'", 3 ,,'l:: ,,1454;Q9 0.00 >:\tt1 1';00' 1454.00 t\1~bQ.OQ 444088.45: 5~68~~~30' 0.00 ,:L'<i:'>~O:()Ö. 0.00 ::,:>x'\,~..';;;n).oô ,",.'., ,':"" """"'0"'" "'.",'^"'" ,""""',.""',, "",,"',,:"" ,,"',",,""" 4 ":"150000 000:""'):'11'1'00 150000":",,'1246'00' 44408845 '5868984:'30 000:';':)';,:,0:00 000'("";:..:,,';',1-'000 :"::"""'~"'" . ::";'::';:'~"',,',', . '",:""", "".,,', . ;'""..'",',', . ,;'f\':';;,'"',,.., . :":':':';"",'::.":<", 5 .'!<1854;OO 0.00,'.yY't1U;o 1854.00 :-::::1600.00 444088.45:,5868984.30 O.OO<::~,"r;::.':o;OO O.OO:,:}:"':/','~."\"O;OO 6 ,{':2000:00' 0.00: ~i:",:-'.'tÙ~ÖO 2000.00 L:';',174S'.ÒÒ 444088.45 :'5868984.30 0.00 :;';:,:;,:';:.':0:00' 0.00 ~~:',;;:>,:-" A'"o~oo ," ',","" " "",' , .. ' ,,'" ',,' , ""','" " " '.. ".., " ", ' "" "", """ .. 7 ::":'~'23s1~;P:ø 0.00 ;<,\'111 ~OO 2351.00 ":,,"2091'.ÞÒ 444088.45, ,586å~84~30 O.OO:>,~~::,'i:,J: ,O:QO: 0.00 :,~,!<+,:: ',:~/:O.OO 8 ;~\'::2451~ÒO' 0.00::"',;:.111:00 2451.00',,:::-:'2'197.00 444088.45. 5868'984.30 O.OO~:":'>':"":;"~O;O'O, O.OO;!:,~::':i,:,'::,',>~~Ô~ÓO " "', ", ,'" ,,'v.. " , ' ,.. ..,," , ' " ," ", '", '", . '" ,;',:- '" ','¡, .. 9 ,:":.:'2S0();OO" 0.00;::;.:,~,:,::,t11;00' 2500.00r',,:~46.00 444088.45 586~~,8~.30 o.OO(,:\i:+;:,::~[OO O.OO:,::,,:'F..<:,<,O~OO 10 '>:'~~ø.(lP~f 2.00,:-: ,::'1,1-~~00: 2599.98':>;;2345:~8 444090.08.586~Ø8~;66, -0.63;;:::;(~:;;1;6~, 2.00:\"<::,;'::1:':,1:73 11 ::"2iöO;öo: 4.00>:~.^:,1Ú'.OO' 2699.83~:";"2445.83 444094.95',5868981'.75 -2.50::<';:'<,6:52, 2.00;;!:~~:,: ':':;6.92 12 :: 2800.00; 6.00 ':';<"11 1'.00 2799.45 ;¡,;2~$~45 444103.06: 5868978.'56 -5.62:: ", .14;65, 2.00 ;":::: ~" :' :15~57 13": ~9ò<iòo 8.00 :>":'111 :00 2898. 70 /:":264~k7Ö 444114.40 586~974~11 -9.99 (»":2()~å3, 2.00 :,::", :',,:,:<':27.66 14 .', 3åOO.oO' 10.00',:,0:.111:00' 2997.46':'",2743.46 444128.96"5868968.39, -15.60':':'~"<",,40.63 2.00:':':"':';':::' 43:17 15 ,':'3032.05 10.63:' "',:,11Ö~41 3029.00, ,.,,2775.00 444134.32"5868966~'32 -17.63', ':;;:46.00' 2.00:?~:'::,,",;i':48:87 16:':3100~00 11.98><:1Ó~~,37 3095.63<-",2841-:63 444146.81 5868961:-:71 -22.15:,;:,,<58~53' 2.00;/':i;:',:.'6?;11 17 :,";:3~OO.OO 13.96:':,',108;19 3193.07': ~39.07 444168.00'5868954:34 -29.36::' '79:78: 2.00::':,:" "'84.46 18 :' :3~'?t:25 15.37:',",,',;1C17~53 3262.00;,: 3008.00 444185.12: 58~94:8.68' -34.88 ,', :""96~95: 2.00':";:--;:", ,102.45 19:<3300;00' 15.95:,':.::~07.30 3289.68,:' ;3035,68 444192.51 58~~946:30 -37.21 ",'-::-,:::104;35: 2.00"/,119;1~ 20 .' ~,3,4qø.OO 17.94. ,: 106;60 3385.34;;')31.31'.34 444220.31 5868,9,37.61 -45.69 :"" 132.23 2.00':."::' 1'39:28 21 .,':3436.51 18.66: :<:'106;39 3420.00::,;:3166.00444231.285868934.27 -48.95 ::',143.22 2.00":,;;,':150.73 22 "',3500.00 19.93 :;';\'106.04 3479.92 :'> 3225.~2 444251.38,5868928..26 -54.80 ';;,' ~63.36: 2.00 :',;:';,.:,;',:, ;171:69 23 3600.00 21.92 ',' 105.58 3573.33,' .-'3319.33 444285.66' 5868918.28 -64.53' ,197.72 2.00 ,:"," "207.37 24 ".3700.9.0 23.91, 10~.19 3665.43:". <W11.43 444323.12 5868907.67, -74.85 ,..,235~27: 2.00:,',:".: '246;30 25 3~()O~00 25.91' 104~86 3756.12>:,.3502.12,444363.715868896.44 -85.76',275.95 2.00 <"::':"288AO 26 ,,:3~()ô.OO 27.91;:,:,:104~~7 3845.29,',:'3591.29 444407.39:58688134.62, -97.25',:, ',31,9~72 2.00;",>,':'333.65 27' ,40~Q:00 29.90.,,: ,: 1,04.32 3932.83', ,:.3678.83 444454.09586~872.?1 -109.31, '" ,.366,~52; 2.00 ,::,~ ,: ,381.97 28: 41'00;00, 31.90 ','-:-:,',104.09 4018.63:'" "3764.63 444503.77: 5868859.24 -121.91" 416:30 2.00 ~/' ,'433.32 29 ,"..'4200:'00: 33.90 "'....'103.'89 4102.59 ", '3848.59 444556.36: 5868845.71. -135.04". 469:00, 2.00 ,:'->;:', :487.63 30 :::.43OO~QP; 35.89:, '::::103.71, 4184.61,','3930.61, 444611.80 .5868831.64 -148.68:,/:,524:55 2.00 ;'.<:':", ':54,4.84 31 ,,>:WOÖ~OO, 37.89,,::,,103.55' 4264.58,' 4010.58 444670.03586881.7.0S -162.83':':',,:582.89 2.00;"..'<:',,604;86 32 ',4500.0Ô: 39.89: ';:,::1'03.'40 4342.42,' ',,:4088.42 444730.96 5868801.96 -177.46~:.':' ,643~94 2.00:,::<:~: '667.64 33 '~.460Ò.ÓO 41.89:,'.. 103:26 4418.01' "4164.0.1. 444794.52 5868786.38 -192.55 :"".707~63" 2.00::'+~:':' '733.09 34 ::,,'4669:24' 43.2i""':'103:17 4469.00 A21Š~ÖÒ, 444840.04,5868775.'32: -203.26';;' :.753':23: 2.00,':';:" "779.94' 35 -"'4700;00 43.88:"".103.14-' 4491.28 "423i28444860.65'58äs770.34 -208.09'::""7-73.88; 2.00',;':'-':,:'::801.14 36 ":":'.4800.00' 45.88:...fjO3~Ô2 4562.13.',:4.308.13 444929.25:'5868753.86: -224.05"'/';: ,å42.6r 2.00::.::::;"'" '871-.7.0' , ,," ,," ,'", ' , "', : ' ,,' " " '.-.. ,,': ;:"" ' 37 ,4:900.0Q, 47.88, ':::'10~,:9r 4630.48 ,~376.48 445000.25: 5ß687~6.9S -240.42 ;;"..', ::91,3:7.4; 2.00,::,::>" :Ø44.68 38 ",' ',,~ciOO;oo, 49.88; ,', ,..1.g2~80 4696.24 :': :4442.24 445073.55 58ß87t t}. 63" -257.18;::: ,987...18" 2.00::';,-";::10g0.00 39 ..,SÔop~:p3, 50.00": :~O2.8Ö 4700.12:,:',:,':#i6.1?,445078.05..58~~718.57 -258.20::,;','..9~1.68: 2.00~'?,::';>Ü)24.62 40 :',,:5500,:00: 50.00 ,102.80 5017.64:' '4763.64' 445446.36 : 58()8631.95 -342.02 ',i",1360.68: 0.00> ,»','1402.97, 41 ' '5850:S9 50.00 ,;',102:80, 5243.00 ',~'4989.00 445707.77 5868570.48 -401.51 ;:" ,1622~58 0.00':;:,:: 1'671.5:1 42 ,.', 5979:71, 50.00 ;::-. ':102.80' 5326.00 '5072.00 445804.05' 5868547.84 -423.42.:: 1719.04: 0.00 :::::)',"~, fnO.41, 43 ,,6000.00, 50.00:',': 102.80 5339.04::'5085~04 445819.17 q86'8544.28 -426.86 ,'::1734:1~: 0.00:;..:::'",'1,785.95 44 '612,O:8~ 50.00::,102.80 5416.72: ~16¿.72 445909.28'5868523.09 -447.37',1824.:4r 0.00::'-:',1,878.51, 45 ,':6220.85 50.00', '102.80 5481.00:"5227~OO 445983.84:5a68505.55 -464.33~':,','189,9.17, 0.00"",t~~5;10 46 '. 'S377.,9Et 50.00' '102:~0 5581.99,~::5327,99 446100.99 .586847~"OO -490.99::',:'20~6.5~: 0.00;>,:207'5.44 47 : 6377.98 50.00','102.80 5582.00.:' 5328.00 446101.00 5868478.00 -491.00,:'2016:S4 0.00:,,:',::'.'2Ó75A6 48 6500'.00 50.00,,',,102.80 5660.44','~..5406.44 446191.98 5868456.60, -511.70:,' ,2107:6~ 0.00<:",',2.168.92 49 :,"654.1..33' 50.00: -: 102.1;i0 5687.00 ':"':5433.00 446222.80 '5868449.3£) -518.71:< 21,38:5Ø, 0.00:;:::">' 220();57 50 ',' 67(JJ;79: 50.00 " " ' '102:130' 5794.00 ,;' 5540.00 446346.91 5868420.17 -546.96': ': 2262:91 0.00 ,,;,:: ~32ß~07 51 . '6741.33 50.00 :,: ': :102.80 5815.56:',,: ,'556.1'.56 446371.93,5a68414.29 -552.65"" 2287;97 O.OO¡ -' , 2353.77 ",...."" ..",..", ",' ,," ..,""""',..." ..""'.'" ORIGINAL ( ~: 2P-420 Drillinq Hazards Summar'l (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan for further discussion of these risks) Surface CasinQ Interval Event Risk Level Conductor Broach Low Well Collision Low G ravel and sand Low slou hin Shakerffrough Cuttings Low S stem Overflow Permafrost Hydrates Low Shoe Fracture/Lost Returns during cement .ob Low Production Casinq Interval Event Lost Circulation in Bermuda interval High ECD and swabbing if higher MW is re uired Hole stability during e- line runs Risk Level Low Low Moderate M iti ation Strate Monitor cellar continuousl durin interval. Careful well planning and surveying, adherence to anti-collision olic Elevated mud viscosity from spud; Hi dens swee s. Controlled Rap Controlled drilling, reduced pump rates, higher mud weights, lower viscosities, and lecithin additions as needed Reduced pump rates, and lightweight tail cement M iti ation Strate Good drilling practices. LCM as needed. Possible PBL sub on corin assembl Pumping and rotating out on all trips to reduce swab and barite sag potential. Emphasis on maintaining mud properties. Clean out runs as needed. Good drilling ractices 2P-420 Drilling Hazards Summary. doc ôR; ã#fA L ( Meltwater 2P-420 Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String 30" x 16" 62.6# (Insulated) @ +1- 120' MD Depths are based on Doyon 141 AKB Surface csg. 7-5/8" 29.7# L-80 BTCM +1- 2351' MD 12351' TVD 12' Pup (Critical) Intermediate csg. 5-1/2" 15.5# L-80 BTCM run CSR to surface +1- 6121' MD I 5417' TVO Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD TO to CSR +1- 6741' MD I 5816' TVD ( PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple wi 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +1- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Camco 'KBG-2-9' mandrel wi STS-2 shear valve and bottom latch (Max. OD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Camco No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 3-1/2" Cameo 'D' nipple wi 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly wi 15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" 00 x 4" ID 17' Seal Bore Extension CSR set at +1- 100' MD above top perforation ORIGINAL PJR, 8/24/01 l ( ";,, 2P-420 , '. ' , "'., '.' , S chlum berger , CemCAD.EPrøl1minary ,Job Design , 7 5/8"Surfàce Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 8/16/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 250% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 20' below base of permafrost.) Lead Slurry (minimum pump time 153 min.) ASLite @ 10.7 pp~, Class G + 50%0124,9%044,0.4%046,30%053, 1.5%S1, 1.5%079 - 4.44 ft Isk < TOCat Surface A"evious Csg. < 16",62.6#, H-40 grade Welded O:>nnection at 120 ft. M) < Base of Perrrafrost at 1,454 ft. M) < Top of Tail at 1,474 ft. M) < 7518",29.7#, L-80 grade BTC, AB fvtx:inied in 97/8" OH lD at 2,351 ft. M) (2,351 ft. lVO) "Mark of Schlumberger 0.9513 felft x (120') x 1.00 (no excess) = 0.2148 felft x (1454' -120') x 3.50 (250% excess) = 0.2148 felft x (1474' -1454') x 1.45 (45% excess) = 114.2 fe + 1002.9 fe+ 6.2 fe = 1009.1 fe 14.44 fe/sk = Round up to 230 sks 114.2 fe 1002.9 fe 6.2 fe 1 009.1 fe 227.3 sks Have 170 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 123 min.) LiteCRETE @ 12.0 ppg - 2.40 fe/sk 0.2148 felft x (2351' -1474') x 1.45 (45% excess) = 0.2578 fe/ft x 80' (Shoe Joint) = 273.2 fe + 20.6 fe = 293.8 ft31 2.40 fe/sk = Round up to 130 sks 273.2 fe 20.6 fe 293.8 fe 122.4 sks BHST = 55°F, Estimated BHCT = 73°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW 1 00 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 30 5.0 14.7 Lead Slurry 6 182 30.3 45.0 Tail Slurry 6 56 9.3 54.3 Drop Top Plug 3.0 57.3 Displacement 6 84 14.0 71.3 Bump Plug 3 20 6.7 78.0 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv:=:: 17-20, T y :=:: 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Schl urn b e rger I . CemOADE prelimlnaryJob.Design . 51/2" x3.1 /2!'Production Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 8/16/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing X-over. Tail Slurry (minimum thickening time 130 min.) GasBLOK wI Class G + 053, 0600, 0135, 0800, 0047, 0065, per lab testing @ 15.8 ppg, 1.2 fe/sk Previous Csg. < 75/8",29.7#, L-80 grade BTC, AB fvbdified at 2,351 ft. till) < 51/2",15.5#, L-80 grade BTC, AB f\fodified in 6 3/4" OH < Top of Tail at 5,621 ft. till) < X-over at 6,121 ft. till) < Top of Berrruda An at 6,221 ft. till) < 31/2",9.3#, L-80 grade BJE, 8rd f\fodified in 6 3/4" OH ID at 6,741 ft. till) (5,816ft.lVD) Mark of Schlumberger 0.0835 felft x 500' x 1.75 (75% excess) = 0.1817 ft3/ft x (6741' - 6121') x 1.75 (75% excess) = 0.0488 felft x 80' (Shoe Joint) = 73.1 fe + 197.1 fe + 3.9 fe = 274.1 fel 1.2 fe/sk = Round up to 230 sks 73.1 fe 197.1 fe 3.9fe 274.1 fe 228.4 sks BHST = 145°F, Estimated BHCT = 132°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW 100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 30 5.0 14.7 Tail Slurry 6 49 8.2 22.9 Drop Top Plug 3.0 25.9 Displacement 6 130 21.7 47.6 Bump Plug 3 20 6.7 54.3 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv:::= 19-22, T y :::= 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL (' PHILLltøS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 September 7,2001 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 2P-420 Surface Location: Target Location: Bottom Hole Location: 892'FNL,2128'FWL,Sec.17,T8N,R7E 1383'FNL,1137'FEL,Sec.17,T8N,R7E 1448' FNL, 866'FEL, Sec. 17,T8N, R7E Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2P-420. The well will be drilled and completed using Doyon 141. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2P, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Steve Moothart, Geologist 265-6965 If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048. Chuck Mallary Drilling Engineering Supervisor RECEIVED SEP 11 2001 Alaska Oil & Gas C Anch ons. Commission , Drage ~ ( American Express~ DATE (D >rfe- þ,"/ 2a:¿~ill2L PAno THE 51-. r f 1!::trx f2 C $ )êJÒ 00 ~ :R:;;:12:!:~t:. ~ - - {¡ ~þ ~to~ I_L.~:.~~D:OLLA:~I Cash Advance Draft 162 Issued by Integr:l.ted Payment System. Ine. Englewood. Color;¡.do NOT VALID FOR AMOUN OVER $1000 Payable at Norwest Bank of Gr;¡.nd junction - Downtown. NA . SHARON SU..p. );i)ìw.... .<i GrMld junction. Color;Ldo ~ ~~ ä~ &... PERIOD ENDING "--~yY{J;O /--- ------ ---- I: ~ 0 2 ~ 0 0 ~ 0 0 I: :1 5 III 0 ~ ? 5000 5 :1 bill 0 ~ b 2 ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 STANDARD LETTER DEVELOPMENT '" A/¿,J ¡ (~V<,Ú?-;> \ /iud! ) DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL WELL NAME KÍG¿{ 7- -P-- L/ 20 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTILATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL L-> NO ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new well bore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOS~ zo 0. THER Please note that an disposal of fluids generated. . . ANNULUS YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. ïi.. WELL NAME Zp- '-/Zð PROGRAM: exp - dev - redrtl / tÙfl éS / GEOL AREA R9r) @N y @ ß&~ð-cI ~/ ( ¿~ l~c_'7 ..led 1:<)' / /i:..-<-i.. rt-hL- :3 7.3 I (Z:. .46 ..;N oN WELL PERMIT CHECKLIST FIELD & POOL . 0 ') ADMINISTRA TION CaMP ANY "\ INIT CLASS 1. Permittee attached. . . . . . . . .. . . . . . i- .'- ~ . . . . (¡ 2. Lease number appropriate. ~ .$.e.e.. çÞ.r.K?c;.~.) /9 ~ '(0 I 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . ..' N 7. Suffident aaeage available' in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellbore plat induded.. . . . . . . . . . . .'. . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . ... N 10. Operator has appropriate bond in force. . . . . . . . . . . . . ~ N 11. Permit can be issued without conservation order. . . . . . . . ; N 12. Permit can. be issued without administrative approval.. . . . . ì N 13. Can permit be approved before 15-day wait.. . . . . . . . . . y . N 14. Conductor string provided . . . . . . . . .. . . . . . . . . . ~ N 15. Surface casing protects all known USDWs. . .. . . . . . . . 16. CMT vol adequate to ciraJla\e on conductor & suñ csg. . . . . : ~ . 17. CMT vol adequate to ,tie-in long string to surf csg. . . . . . . . ~Y (N) , , 18. CMT will cover all known productive horizons. . . . . '; . . . . Itr' 19. Casing'designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ç~~~~.... \I'...~"~l ~ ~~~~ ~~\- 21. If a re-<lrill. has a 10-403 for abandonment been approved. . . ~ III -~ "'- '- - - ~ . -', -', 22. Adequate weilbore separation proposed.. . . . . . ; . . . .. . N -_L~~ ~ ~ ~C'~\œ.~-- ~ 23. If diverter required, does it meet regulations. . . . . . . . . . . N . 24. Drilling .fluid program schematic & equip list adequate. . . . . N . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . ~ . . N 26. BOPE press rating appropriate; test to -3$Ot-:) psig. oN ~~ ~~~.Q ;};;L"),Ç p£\ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N . 28. Work will occur without operation shutdbwn. . . . . . . . . . . . 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . .. N R\~ ~~<;a:II""\.~\:"- Q. ~"=>~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . " &.. N .---/ . , ' ' -k. .....¡::z.. 31. Da~a ~resente~ on potential overpressure zones. . . . . . . N~ ðffs<-J toUì~ t...-k..dt¿ð, ~~v~ rr~ tJ...ç Þ 7,,7 ~ E/?J4.,.) 32. Seismic analysIs of shallow gas zones. . . . . . . . . 2,'" 1t;;Y N APPR BATE 33. Seabed condition survey (if off-shore). . . . . . . . . .. .' Y N . ,.)Sf) ¡. / Z 'D ( 34. Contad name/phone for weekly progress reports [exp atory only) Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. ~,"",'V\o.;.'ðt-c;;.~~~\ \:) \.\-\~~'" \>\~f'\~~c \h.~~\.r:~.~"",\.~ ~<t..\\. (A) will contain waste in a suitable receiving zone; . . . . . . . Y N' C>..'(,.-,~~,\>'Ç>~~~ ~,,~~,~'> CJ.~ (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; . . .' (C) will not impair mechanical hltegrity of the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING:..' UIC/Annular ~: WM 8~s - JM A~§t .DATE. r Q,I2.-0 ENGINEERING ~ ~ll\ GEOLOGY APPR DATE serv wellbore seg _ann. disposal para req - III t::,Õ ON/OFF SHORE 0/1- UNIT# v ~ \ \ \ "y ~~ 'c~ "" ~ ~ :~ <::.. \:- ~ ~'D ~ÞB ~ Comments/Instructions: 4ii '")r/O c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -t :E ::u (" - -to m - Z -t .J: - en :Þ :u m > ( ~. ( Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. . To improve the readability of the Well History file and to simpltfy finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special 'e'ffort has been made to chronologically" . organize this category of information. ,\.' ( **** REEL HEADER **** LDWG 02/08/15 AWS 01 **** TAPE HEADER **** LDWG 02/08/15 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! TAPE HEADER MELTWATER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD ( LDWG File Version 1.000 Extract File: LISTAPE.HED 2P-420 501032039100 Phillips Alaska, Inc. BAKER HUGHES INTEQ 15-AUG-02 MWD RUN 1 MWD RUN 2 MWD RUN 3 1 2 3 C. WONG K. THRASHER N. HENRY D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 4 MWD RUN 5 MWD RUN 6 4 5 A. HAMMOND D. BARBA C. WONG D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 7 MWD RUN 8 MWD RUN 9 K. THRASHER D. BARBA D. GLADDEN D. PRESNELL 17 8N 7E MSL 0) 254.00 aO!~ J't~ I I 00 ~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION # REMARKS: {' ¡. ~, OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.875 2358.0 STRING 6.750 6860.0 (SOURCE UNKNOWN), THE THE DEPTH REFERENCE SHIFTS HAVE BEEN PER PHILLIPS ALASKA INSTRUCTIONS GAMMA RAY CURVE FROM THIS LOG IS FOR THIS WELL. AS SUCH, NO DEPTH APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 3' 9.754" LONG: W150 DEG 26' 50.778" LOG MEASURED FROM D.F. AT 254.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) BAKER HUGHES INTEQ RUN 1 UTILIZED A MULTIPLE PROPAGATION RESISTIVITY TOOL IN A STEERABLE ASSEMBLY FROM 108 - 2358 FEET MD (108 - 2358' TVD). (2) BAKER HUGHES INTEQ RUNS 2 THROUGH 6 UTILIZED A TRIPLE COMBO TOOL COUPLED WITH THE MULTIPLE PROP. RESISTIVITY TOOL (MPR) IN A STEERABLE ASSEMBLY FROM 2358 TO 5898 FEET MD (2358 - 5261' TVD). 3) BAKER HUGHES INTEQ RUN 7 UTILIZED A MULTIPLE PROPAGATION RESISTIVITY TOOL IN A STEERABLE ASSEMBLY FROM 5898 TO 6860 FEET MD (5261 - 5863' TVD). 4) BAKER HUGHES INTEQ RUN 8 UTILIZED A SLIM HOLE DENSITY NEUTRON (SDN) TOOL COUPLED WITH A GAMMA RAY IN A ROTARY CLEANOUT ASSEMBLY FROM 5898 TO 6860 FEET MD (5261 - 5863' TVD). REMARKS: ( 1 ) 16 INCH 16 INCH RESISTIVITY (108 - 850' PERMAFROST. (2) DUE TO AN INTERMITTENT MEMORY PROBLEM, ONLY REAL TIME LOGGING DATA IS AVAILABLE OVER THE INTERVAL FROM 1250 TO 1437' MD (1250 - 1437' TVD). REAL TIME GAMMA RAY, RPS (RPCHM) , AND FET (RPTHM) DATA WAS SPLICED INTO THE MEMORY DATA. ALL OTHER CURVES CONTAIN NULL VALUES OVER THIS INTERVAL. (3) 7.625 INCH CASING DEP - LOGGER: 2353' MD (2353'TVD) 7.625 INCH CASING DEP - DRILLER: 2358' MD (2358' TVD) THE INTERVAL FROM 2312 TO 2358' MD (2312 - 2358' TVD) WAS NOT LOGGED DUE TO SENSOR OFFSETS AT THE 7.625" CASING POINT. (4) THE INTERVAL FROM 2663 TO 2727 MD (2663-2727' TVD) WAS LOGGED UP TO 21.8 HOURS AFTER BEING DRILLED DUE TO TRIP OUT OF THE HOLE TO REPLACE THE MWD TOOL. (5) DUE TO AN INTERMITTENT TOOL PROBLEM, THERE IS NO NEUTRON/DENSITY DATA PRESENTED OVER THE FOLLOWING INTERVALS: 2706 - 2783' MD (2705 - 2782' TVD) 2999 - 3050' MD (2995 - 3045' TVD) 3945 - 3978' MD (3889 - 3758' TVD) 4223 - 4254' MD (4124 - 4149' TVD) 5174 - 5190' MD (4803 - 4813' TVD) 5714 - 5738' MD (5143 - 5158' TVD) THE INTERVALS WERE NOT RELOGGED PER CUSROMER REQUEST. (6) THE INTERVAL FROM 4464 TO 4491 MD (4316-4335' TVD) WAS LOGGED UP TO 18.3 HOURS AFTER BEING DRILLED DUE TO TRIP OUT OF THE HOLE TO REPLACE THE MWD TOOL. (7) THE INTERVAL FROM 4491 TO 4518 MD (4335-4356' TVD) CASING DEPTH - LOGGER: 108' MD (108' TVD). CASING DEPTH - DRILLER: 108' MD (108' TVD). DATA OVER THE INTERVAL FROM 108 - 850' MD TVD) IS ERRATIC DUE TO DRILLING THROUGH \ ( WAS LOGGED UP TO 37.3 HOURS AFTER BEING DRILLED DUE TO TRIP OUT OF THE HOLE TO REPLACE THE MWD TOOL. (8) THE INTERVAL FROM 4518 TO 4791 MD (4356-4553' TVD) WAS LOGGED UP TO 22.4 HOURS AFTER BEING DRILLED DUE TO TRIP OUT OF THE HOLE TO REPLACE THE MWD TOOL. (9) THE INTERVAL FROM 5516 TO 5591 MD (5016-5064' TVD) WAS LOGGED UP TO 18.1 HOURS AFTER BEING DRILLED DUE TO TRIP OUT OF THE HOLE TO REPLACE THE MWD TOOL. (10) THE INTERVAL FROM 5847 TO 5898 MD (5228-5261'TVD) WAS LOGGED UP TO 25.0 HOURS AFTER BEING DRILLED DUE TO TRIP OUT OF THE HOLE TO REPLACE THE MWD TOOL. (11) DENSITY/NEUTRON DATA OVER THE INTERVAL FROM 5835 6848' MD (5220 - 5856' TVD) WAS ACQUIRED ON MEASUREMENT AFTER DRILLING (MAD) PASS. THE DATA WAS LOGGED ROUGHLY 116.6 HOURS AFTER THE FORMATION WAS DRILLED. (12) THE INTERVAL FROM 6848 TO 6860' MD (5856-5863'TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT TD. $ Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! !! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD $ 127 records... 8 bytes 132 bytes LDWG File Version 1.000 Extract File: FILEOOl.HED 1 clipped curves; all bit runs merged. .5000 START DEPTH 108.0 2358.0 2657.0 4464.0 4728.0 5540.0 5818.0 STOP DEPTH 2311.0 2657.0 4464.0 4728.0 5540.0 5818.0 6810.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 MERGE TOP 108.0 2358.0 2728.0 MERGE BASE 2358.0 2728.0 4517.0 (: { MWD MWD MWD MWD $ 4 5 6 7 4517.0 4791.0 5591. 0 5898.0 4791.0 5591.0 5898.0 6860.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS REFERENCE FOR THIS WELL. FOR COMPLETENESS, THIS DATA INCLUDES MAD PASS (5835 - 6848' MD). LOG IS THE DEPTH THE NEUTRON/DENSITY $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420_5.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPCLM 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPCHM 0.0 RPX RPX RPCSHM 0.0 NPHI NPHI NPCKSFM 0.0 RHOB RHOB BDCFM 0.0 DRHO DRHO DRHFM 0.0 PEF PEF DPEFM 0.0 CALN CALN CALM 0.0 MTEM MTEM TCDM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length ," ( ( 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 NPHI MWD 68 1 PU-S 4 4 7 RHOB MWD 68 1 G/C3 4 4 8 DRHO MWD 68 1 G/C3 4 4 9 PEF MWD 68 1 BN/E 4 4 10 CALN MWD 68 1 IN 4 4 11 MTEM MWD 68 1 DEGF 4 4 12 ROP MWD 68 1 FPHR 4 4 13 FET MWD 68 1 HR 4 4 ------- 52 Total Data Records: 751 Tape File Start Depth = 108.000000 Tape File End Depth = 6860.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 813 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! !, ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILEO02.HED FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ .5000 START DEPTH 5835.0 STOP DEPTH 6848.0 # MERGED PBU MWD $ DATA SOURCE TOOL CODE MAD RUN NO. MAD PASS NO. 1 1 MERGE TOP 5898.0 MERGE BASE 6860.0 # REMARKS: MERGED MAD PASS. $ # ~i I, ( *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420_5.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- NPHI NPHI NPCKSFM 0.0 RHOB RHOB BDCFM 0.0 DRHO DRHO DRHFM 0.0 PEF PEF DPEFM 0.0 CALN CALN CALM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 42 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 NPHI MAD 68 1 PU-S 2 RHOB MAD 68 1 G/C3 3 DRHO MAD 68 1 G/C3 4 PEF MAD 68 1 BN/E 5 CALN MAD 68 1 IN Size Length 4 4 4 4 4 4 4 4 4 4 ------- 20 Total Data Records: 49 Tape File Start Depth = 5835.000000 Tape File End Depth = 6860.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 80 records... (: Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE011.HED 3 î( log header data for each bit run in separate files. 1 .2500 START DEPTH 51.0 STOP DEPTH 2311.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 17-0CT-01 MSB 18704 6.75 MPR MEMORY 2358.0 51.0 2311. 0 0 .0 .3 TOOL NUMBER MPR 16783 SRIG 5332 9.875 108.0 Clay Seal 9.65 .0 .0 27000 .0 .000 .000 .000 .000 92.0 .0 .0 .0 t # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # ,( .00 .000 .0 0 BIT RUN 1. GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-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) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 1 { 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 330 Tape File Start Depth = 51.000000 Tape File End Depth = 2358.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 416 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .oo~ 1024 *** LIS COMMENT RECORD *** ! ! ! !! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILEOI2.HED 4 ( log header data for each bit run in separate files. 2 .2500 START DEPTH 2358.0 STOP DEPTH 2657 . 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): 20-0CT-Ol MSB 18704 4.75 TC MEMORY 2728.0 2358.0 2657.0 { BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL CN NEUTRON DEN DENSITY MPR MULT. PROP. RESIST. GRAM GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE ( IN): DRILLER'S CASING DEPTH ( FT) : # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # ( 0 0.4 4.8 TOOL NUMBER SDN 2960 SDN 2960 MPR 1060 SRIG 27520 6.750 2358.0 Clay Seal 9.90 .0 .0 30000 .0 .000 .000 .000 .000 78.0 .0 .0 .0 SANDSTONE .00 .000 .0 0 BIT RUN 2. GR/MPR/cN/DEN. THIS DAT FILE IS PRESENTED UP TO 2150' TO CAPTURE THE NEUTRON-DENSITY DATA RECORDED IN CASING AT THE START OF THIS BIT RUN. 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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ ( { { WDFN LCC CN WN FN COUN STAT 2p-420.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM: 0.0 RPSH RPSH RPCSHM: 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet .Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 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 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 113 ( (. Tape File Start Depth = 2150.000000 Tape File End Depth = 2657.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 216 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILEO13.HED 5 log header data for each bit run in separate files. 3 .2500 START DEPTH 2657.0 STOP DEPTH 4464.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRI LLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 22-0CT-01 MSB 18704 4.75 TC MEMORY 4517.0 2657.0 4464.0 0 4.8 39.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL CN NEUTRON DEN DENSITY MPR MULT. PROP. RESIST. GRAM GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # TOOL NUMBER SDN 29259 SDN 29259 MPR 1060 SRIG 27520 6.750 2358.0 ( BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # ( Clay Seal 10.00 .0 .0 29000 .0 .000 .000 .000 .000 100.0 .0 .0 .0 SANDSTONE .00 .000 .0 0 BIT RUN 3. GR/MPR/cN/DEN. 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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH NPCK BDCF DPEF GRAM RPCL RPSL RPCH RPSH NPCK BDCF DPEF GRAM RPCLM RPCSLM RPCHM RPCSHM NPCKSFM BDCFM DPEFM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 t ,/ t DRHF DRHF DRHFM 0.0 CALM CALM CALM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 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 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 402 Tape File Start Depth = 2657.000000 Tape File End Depth = 4464.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 6 502 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .006 1024 ( *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILEOI4.HED 6 ( log header data for each bit run in separate files. 4 .2500 START DEPTH 4464.0 STOP DEPTH 4728.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL CN NEUTRON DEN DENSITY MPR MULT. PROP. RESIST. GRAM GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH ( FT) : # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 23-0CT-Ol MSB 18704 4.75 TC MEMORY 4791. 0 4464.0 4728.0 0 39.8 44.8 TOOL NUMBER SDN 29260 SDN 2926.0 MPR 1060 SRIG 27520 6.750 2358.0 Clay Seal 10.10 .0 .0 29500 . a .000 .000 .000 .000 92.0 . a . a . a SANDSTONE .00 .000 . a a REMARKS: # ( ( BIT RUN 4. GR/MPR/cN/DEN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420.xtf 150 . Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = ONE DEPTH PER FRAME 18 1 0.250 * F ( (' Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD. 68 1 DEGF 4 4 ------- 52 Total Data Records: 59 Tape File Start Depth 4464.000000 Tape File End Depth = 4728.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 7 159 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .007 1024 *** LIS COMMENT RECORD *** ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! !! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILEOI5.HED 7 log header data for each bit run in separate files. 5 .2500 START DEPTH 4728.0 STOP DEPTH 5540.0 # LOG HEADER DATA DATE LOGGED: 25-0CT-Ol ( SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL CN NEUTRON DEN DENSITY MPR MULT. PROP. RESIST. GRAM GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # ( MSB 18704 4.75 TC MEMORY 5591.0 4728.0 5540.0 0 44.8 51.3 TOOL NUMBER SDN 29260 SDN 29260 MPR 1113 SRIG 27524 6.750 2358.0 Clay Seal 10.00 .0 .0 28000 .0 .000 .000 .000 .000 102.0 .0 .0 .0 SANDSTONE .00 .000 .0 0 BIT RUN 5. GR/MPR/cN/DEN. 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) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ (I ( *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 0.0 RapS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 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 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- ( ( 52 Total Data Records: 181 Tape File Start Depth = 4728.000000 Tape File End Depth = 5540.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 8 281 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .008 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE016.HED 8 log header data for each bit run in separate files. 6 .2500 START DEPTH 5540.0 STOP DEPTH 5818.0 # 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: 26-0CT-01 MSB 18704 4.75 TC MEMORY 5898.0 5540.0 5818.0 0 50.9 51.3 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CN DEN MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL NEUTRON DENSITY MULT. PROP. GAMMA RAY TOOL NUMBER RESIST. SDN 29259 SDN 29259 MPR 1113 SRIG 27524 # ( BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # I ' \ 6.750 2358.0 Clay Seal 10.00 .0 .0 28000 .0 .000 .000 .000 .000 102.0 .0 .0 .0 SANDSTONE .00 .000 .0 0 BIT RUN 6. GR/MPR/cN/DEN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - ME~IUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) CALM - BOREHOLE CALIPER (IN) DRHF - DENSITY CORRECTION, FILTERED (G/CC) BDCF - BULK DENSITY COMPENSATED, FILTERED (G/CC) NPCK - NEUTRON POROSITY CALIPER & SALINITY CORRECTED, FILTERED (SANDSTONE PU) DPEF - PHOTOELECTRIC FACTOR (B/E) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH GRAM RPCL RPSL RPCH 0.0 0.0 0.0 0.0 GRAM RPCLM RPCSLM RPCHM ( ( RPSH RPSH RPCSHM 0.0 NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DPEF DPEF DPEFM 0.0 DRHF DRHF DRHFM 0.0 CALM CALM CALM 0.0 RaPS ROPS RaPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 18 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 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 NPCK MWD 68 1 PU-S 4 4 7 BDCF MWD 68 1 G/C3 4 4 8 DPEF MWD 68 1 BN/E 4 4 9 DRHF MWD 68 1 G/C3 4 4 10 CALM MWD 68 1 IN 4 4 11 ROPS MWD 68 1 FPHR 4 4 12 RPTH MWD 68 1 MINS 4 4 13 TCDM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 62 Tape File Start Depth - 5540.000000 Tape File End Depth = 5818.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 9 162 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .009 ( 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! !! !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 Extract File: FILEO17.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 9 ('" log header data for each bit run in separate files. 7 .2500 START DEPTH 5818.0 STOP DEPTH 6810.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD, TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) I 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): 28-0CT-01 MSB 18704 4.75 MPR MEMORY 6860.0 5818.0 6810.0 0 48.9 53.8 TOOL NUMBER MPR 1113 SRIG 27524 6.750 2358.0 Clay Seal 10.00 .0 .0 28500 .0 .000 .000 .000 .000 114.0 .0 . a . a .00 .000 . a ~. ( EWR FREQUENCY (HZ): 0 # REMARKS: BIT RUN 7. 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) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 2 GRAM RPCL MWD MWD 68 68 1 1 GAP I OHMM 4 4 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 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 149 Tape File Start Depth = 5818.000000 Tape File End Depth = 6860.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 10 235 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .010 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILEO18.HED (' FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: MAD PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 1 1 .2500 START DEPTH 5818.0 STOP DEPTH 6848.0 # 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: # 31-0CT-01 MSB 18704 4.75 TC MEMORY 6860.0 5818.0 6848.0 0 .0 .0 ( TOOL STRING (TOP TO VENDOR TOOL CODE GRAM DIR CN DEN $ BOTTOM) TOOL TYPE GAMMA RAY DIRECTIONAL NEUTRON DENSITY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: CN/DEN MAD PASS. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 2p-420.xtf 150 Phillips Alaska, Inc. 2P-420 Meltwater North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- NPCK NPCK NPCKSFM 0.0 BDCF BDCF BDCFM 0.0 DRHF DRHF DRHFM 0.0 DPEF DPEF DPEFM 0.0 CALM CALM CALM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet ( TOOL NUMBER SRIG 27524 SDN 29260 SDN 29260 6.750 2358.0 clay Seal 10.00 .0 .0 28500 .0 .000 .000 .000 .000 106.0 .0 .0 .0 SANDSTONE .00 .000 .0 0 ( Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 42 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 NPCK MAD 68 1 PU-S 2 BDCF MAD 68 1 G/C3 3 DRHF MAD 68 1 G/C3 4 DPEF MAD 68 1 BNIE 5 CALM MAD 68 1 IN Total Data Records: 100 Tape File Start Depth = 5818.000000 Tape File End Depth = 6860.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 11 175 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 02/08/15 01 **** REEL TRAILER **** LDWG 02/08/15 AWS 01 Tape Subfile: 12 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes , Î.' \ 1 Size Length 4 4 4 4 4 4 4 4 4 4 ------- 20
