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2025-0715_Location_Clear_KRU_2P-448A_ksj Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 07/18/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Site Clearance Petroleum Inspector KRU 2P-448A ConocoPhillips Alaska LLC. PTD 2020050; Sundry 324-525 07/15/2025: Went out to KRU 2P Pad for site clearance inspections and met with Roger Mouser (CPAI). We went over the surface area of KRU 2P-448A which has been P&A and buried. The area was clean of debris and had a settling mound for soil over the well location. We verified the well-site with the pad location map and well conductor “as built”. Marker plate and top of well are at 6 feet 11 inches below original tundra. Overall, the site clearance was in good condition. The well site still had barriers around due to other work going on in the area. Only follow up would be a full pad site clearance once CPAI has completed all pad P&A work. Attachments: Photo 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.16 14:15:01 -08'00' 2025-0715_Location_Clear_KRU_2P-448A_ksj Page 2 of 2 Surface Abandonment Inspection – KRU 2P-448A (PTD 2020050) Photo by AOGCC Inspector K. StJohn 7/15/2025 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 110' 7-5/8" L-80 2440' 5-1/2" L-80 5192' 3-1/2" L-80 5746' 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 42" 9-7/8" 64.9 bbls AS I 29' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 20 bbls 15.8 ppg balanced plug 5076' (SW TOC)' -6770' MD 31 bbls 15.8 ppg Class G Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 2541-3035' 36-2540' SUSPENDED 7195-7210' MD and 5436-5448' TVD (below cement plug) Gas-Oil Ratio:Choke Size: 145 bbls 15.8 ppg Cement Per 20 AAC 25.283 (i)(2) attach electronic information 391 sx AS Lite, 202 sx LiteCrete 9.3# 29' 6894' 2976'29' 29' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# 6880' MD/ 5181' TVD (seal assembly) 6894' SIZE DEPTH SET (MD) 7586' 26' 5192' 62.5# 29.7# 110' 26' PACKER SET (MD/TVD) GRADE 1/13/2002 CEMENTING RECORD 5866144 1488' MD/ 1458' TVD SETTING DEPTH TVD 5865859 TOP HOLE SIZE AMOUNT PULLED 441000 441007 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 9. Ref Elevations: KB: 30' 50-103-20396-01-00 KRU 2P-448A ADL0373112 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM 1240' FSL, 931' FEL, Sec. 18, T8N, R7E, UM ALK 4998 1/9/2002 5076' MD/ 3730' TVD Surface/Surface P.O. Box 100360, Anchorage, AK 99510-0360 443543 5868859 1525' FSL, 949' FEL, Sec. 18, T8N, R7E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 12/15/2024 202-005/324-525 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above6.75" TUBING RECORD 56 bbls Class G6.75" 6884' MD3-1/2" CASING WT. PER FT. Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Received by J. Brooks on 1/6/2025 at 11:54AM Abandoned 12/15/2024 JSB RBDMS JSB 011325 xG Aband. SFD 3/25/2025 253' SFD *Total Depth: 7593' M /5752' TVD SFD DSR-4/7/25 * Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1488' 1458' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations, Photos, Cement Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Shane Germann Digital Signature with Date:Contact Email: shane.germann@conocophillips.com Contact Phone:(907) 263-4597 Senior CTD/RWO Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov N/A- Abandoned N/A - Abandoned Digitally signed by Shane GermannDN: O=ConocoPhillips, CN=Shane Germann, E= shane.germann@conocophillips.com Reason: I am the author of this document Location: Date: 2025.01.06 08:55:50-09'00'Foxit PDF Editor Version: 13.0.0 g Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,219.0 2P-448A 12/28/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Plug and abandoned 7' below OG (Tundra)AOGCC INSPECTOR ADAM EARL. 2P-448A 12/15/2024 mouser Notes: General & Safety Annotation End Date Last Mod By NOTE: Plug and Abandoned 7' below original ground (Tundra) AOGCC INSPECTOR ADAM EARL 12/15/2024 mouser NOTE: Mandrel Orientation: #1)9:30, #2)2:00, #3)11:00, #4)10:00 10/21/2013 hipshkf NOTE: LEAK FOUND AT 6770' MANDREL 10/28/2012 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 110.0 110.0 63.00 WELDED SURFACE 7 5/8 6.87 36.0 2,976.3 2,440.2 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 6894' 5 1/2 4.95 3,030.0 7,585.7 5,745.9 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.0 Set Depth … 2,520.0 Set Depth … 2,198.8 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-M ID (in) 2.99 Top (ftKB) 3,140.0 Set Depth … 6,883.7 Set Depth … 5,183.8 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) 4,921.2 3,612.5 41.11 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,096.3 4,543.5 36.38 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,770.4 5,091.7 35.55 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,820.0 5,132.1 35.61 SLEEVE-C 4.530 SLIDING SLEEVE w/2.81" DS PROFILE (CLOSED 9/26/12) BAKER CMU 2.810 6,835.9 5,145.0 35.63 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,880.5 5,181.2 35.81 SEAL 4.000 SEAL ASSY w/G-22 LOCATOR BAKER 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) 35.8 35.7 0.06 MARKER PLATE 1/4" Marker plate for Plug and Abandonment 30" 1/4" marker plate 12/14/2024 0.000 3,035.0 2,471.7 57.41 CUT MSC on rig 11/15/2024 4.950 3,040.0 2,474.4 57.40 CIBP CIBP MID ELEMENT @ 3,040.5'. TOP @ 3,040'. BTM @ 3,041.25'. OAL = 1.25' Yellow Jacket - America n Completi on Tools Model A Premium Bridge Plug 11/15/2024 0.000 3,140.0 2,528.3 57.67 CUT JET CUT @ 3140' RKB 10/6/2024 2.992 6,765.5 5,087.8 35.55 TUBING PUNCH TBG PUNCH FROM 6765.5' TO 6770' RKB W/ 4 SPF 9/10/2024 2.992 7,155.3 5,403.8 36.21 CIBP CIBP MID-ELEMENT AT 7156' RKB, OAL 1.37' 7/25/2024 0.000 7,203.3 5,442.5 36.36 CIBP CIBP MID-ELEMENT AT 7204' RKB, OAL 1.37' (PLUG MOVED DOWNHOLE ~34' FROM ORIGINAL SET DEPTH OF 7170' RKB) 7/23/2024 0.000 7,463.6 5,649.8 37.97 Plug Catcher PLUG CATCHER SET IN 3.5" CASING 1/9/2002 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,195.0 7,210.0 5,435.8 5,447.9 T-3, 2P-448A 1/27/2002 6.0 IPERF 2.5" HSC PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,195.0 7,210.0 1 FRAC 2/3/2002 0.0 0.00 0.00 7,195.0 7,210.0 1 RE-FRAC 12/4/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,118.0 7,155.3 5,373.7 5,403.8 Cement Plug Slickline dump bailed cement on top of CIBP 7/28/2024 5,076.0 6,770.0 3,730.3 5,091.4 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 46 BBLS OF 9.8 PPG NaCl KWF. 9/26/2024 2,541.0 3,035.0 2,210.3 2,471.7 Cement Plug Pumped 24 Bbls of 10 PPG spacer. Drop foam ball. Pumped 20 Bbls of 15.8 PPG cement. Drop foam ball. Pump 6 Bbls of 10 PPG spacer. Displace w/ 14.2 Bbls 9.8 PPG NaCl. POOH w/ 3 1/2" EUE work string F/ 3030' T/ 2248' @ 30 ft/min. Cement in place @ 05:30 Hrs. Constant returns throughout job. No losses. 11/16/2024 2P-448A, 12/27/2024 11:48:06 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6894'; 3,030.0-7,585.7 Plug Catcher; 7,463.6 CIBP; 7,203.3 IPERF; 7,195.0-7,210.0 FRAC; 7,195.0 RE-FRAC; 7,195.0 CIBP; 7,155.3 Cement Plug; 7,118.0 ftKB TUBING; 6,782.5 GAS LIFT; 6,770.4 TUBING PUNCH; 6,765.5 GAS LIFT; 6,096.3 Cement Plug; 5,076.0 ftKB GAS LIFT; 4,921.2 CUT; 3,140.0 CIBP; 3,040.0 CUT; 3,035.0 SURFACE; 36.0-2,976.3 Cement Plug; 2,541.0 ftKB CONDUCTOR; 36.0-110.0 Plug – Plug Back / Abandonment Plug; 36.0 ftKB MARKER PLATE; 35.7 KUP PROD KB-Grd (ft) 33.01 RR Date 1/8/2002 Other Elev… 2P-448A ... TD Act Btm (ftKB) 7,593.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039601 Wellbore Status PROD Max Angle & MD Incl (°) 59.90 MD (ftKB) 3,380.68 WELLNAME WELLBORE2P-448A Annotation Last WO: End DateH2S (ppm) 50 Date 12/6/2016 Comment SSSV: NIPPLE Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 36.0 2,540.0 36.0 2,209.7 Plug – Plug Back / Abandonment Plug Pumped 145 bbls of 15.8# cement to surface. Filled 3 1/2" Tubing and 7 5/8" Production Casing to surface. 11/19/2024 2P-448A, 12/27/2024 11:48:06 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6894'; 3,030.0-7,585.7 Plug Catcher; 7,463.6 CIBP; 7,203.3 IPERF; 7,195.0-7,210.0 FRAC; 7,195.0 RE-FRAC; 7,195.0 CIBP; 7,155.3 Cement Plug; 7,118.0 ftKB TUBING; 6,782.5 GAS LIFT; 6,770.4 TUBING PUNCH; 6,765.5 GAS LIFT; 6,096.3 Cement Plug; 5,076.0 ftKB GAS LIFT; 4,921.2 CUT; 3,140.0 CIBP; 3,040.0 CUT; 3,035.0 SURFACE; 36.0-2,976.3 Cement Plug; 2,541.0 ftKB CONDUCTOR; 36.0-110.0 Plug – Plug Back / Abandonment Plug; 36.0 ftKB MARKER PLATE; 35.7 KUP PROD 2P-448A ... WELLNAME WELLBORE2P-448A Page 1/7 2P-448 Report Printed: 12/27/2024 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) 11/13/2024 08:00 11/13/2024 12:00 4.00 MIRU, MOVE MOB P R/D hardline. Clean out cuttings tank. Suck out returns tanks. Pull support equipment away from rig. Warm up rig move system. Back off 2P-449 @ 12:00. 0.0 0.0 11/13/2024 12:00 11/13/2024 20:30 8.50 MIRU, MOVE MOB P Shoot pad grade. Pickup mats from 2P- 449. Clean up area. Lay cellar pit liner and T-mats. Lay rig mat dance floor. Stage contingency dry hole tree behind cellar. Spot sub over well 2P-448 @ 17:30. Level rig. Berm in cellar. Move support equipment back in place. Record initial RKB's. Complete rig acceptance check list. Pump open SSV. Rig accept @ 20:30 Hrs. 0.0 0.0 11/13/2024 20:30 11/13/2024 21:45 1.25 MIRU, WELCTL RURD P Take on 9.8# KW brine. Build 35 Bbls vis deep clean pill. R/U circ equipment. Take initial pressures T/IA/OA = 0/0/200. Obtain initial RKB's 0.0 0.0 11/13/2024 21:45 11/13/2024 22:00 0.25 MIRU, WELCTL SFTY P PJSM on well kill w/ rig crew. 0.0 0.0 11/13/2024 22:00 11/13/2024 22:15 0.25 MIRU, WELCTL PRTS P PT circ manifold & hard line T/ 2500 PSI. 0.0 0.0 11/13/2024 22:15 11/13/2024 23:15 1.00 MIRU, WELCTL KLWL P Kill well w/ 30 Bbls vis deep clean pill followed by 120 Bbls 9.8 PPG NaCl. ICP=235, FCP=534. Bleed OA F/ 700 PSI T/ 200 PSI. 0.0 0.0 11/13/2024 23:15 11/13/2024 23:30 0.25 MIRU, WELCTL OWFF P OWFF no flow at tank. -30 Min no flow. Bleed OA F/ 200 PSI T/ xxx PSI 0.0 0.0 11/13/2024 23:30 11/13/2024 23:45 0.25 MIRU, WELCTL RURD P B/D circ equipment & hard lines. 0.0 0.0 11/13/2024 23:45 11/14/2024 00:00 0.25 MIRU, WELCTL OWFF P OWFF begin 30 Mn no flow. Bleeding OA F/ 200 PSI T/ 50 PSI - Gas. 0.0 0.0 11/14/2024 00:00 11/14/2024 00:15 0.25 MIRU, WELCTL OWFF P OWFF, complete 30 Min no flow. 0.0 0.0 11/14/2024 00:15 11/14/2024 02:00 1.75 MIRU, WHDBOP NUND P N/D tree. Inspect hanger neck threads. Function LDS. Install H BPV & test dart. 0.0 0.0 11/14/2024 02:00 11/14/2024 04:30 2.50 MIRU, WHDBOP NUND P N/U DSA & BOP. Install flow nipple. R/U trip hose. Grease manuals & HCR's. 0.0 0.0 11/14/2024 04:30 11/14/2024 14:30 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/2500 PSI for 5 Min each, Tested annular, UVBR's, w/ 2 7/8" & 5 ½” test joints. Test blinds rams. Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½” & 4 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1700 PSI, 200 PSI attained =15 sec, full recovery attained =97 sec. UVBR's= 5 sec, LVBR’s= 5 sec. Annular= 17 sec. Simulated blinds= 1 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2000 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Guy Cook. Valve failure on mud manifold (MM valve #13). 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/19/2024 Page 2/7 2P-448 Report Printed: 12/27/2024 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) 11/14/2024 14:30 11/14/2024 15:30 1.00 MIRU, WHDBOP SVRG P Service rig. Begin Mud Manifold Valve #13 repair, 2" Demco kill valve. Cut out old valve. 0.0 0.0 11/14/2024 15:30 11/15/2024 00:00 8.50 MIRU, WHDBOP BOPE T Continue to replace MM Valve #13. Weld in new valve. X-ray welds to confirm good. First X'-ray showed good bottom weld. Bad top weld. Grind out bad weld, Re weld. 0.0 0.0 11/15/2024 00:00 11/15/2024 02:00 2.00 MIRU, WHDBOP BOPE T Re X-ray verifying top weld. Passed. Weld stiffing bracket back in place. 0.0 0.0 11/15/2024 02:00 11/15/2024 03:00 1.00 MIRU, WHDBOP BOPE T PT MM #13 kill line Demco T/ 250/2500 PSI. PT weld integrity test T/ 5000 PSI. 0.0 0.0 11/15/2024 03:00 11/15/2024 03:30 0.50 MIRU, WHDBOP RUNL P B/D, R/D testing equipment. Suck out stack. 0.0 0.0 11/15/2024 03:30 11/15/2024 04:00 0.50 MIRU, WHDBOP MPSP P Pull dart & BPV. 0.0 0.0 11/15/2024 04:00 11/15/2024 05:00 1.00 COMPZN, RPCOMP PULL P P/U landing joint. Set 10K down on hanger. BOLDS. Pull hanger to rig floor @ 55K. 0.0 3,180.0 11/15/2024 05:00 11/15/2024 05:30 0.50 COMPZN, RPCOMP CIRC P Circ. STS. 3 BPM @ 328 psi. Pumping 120 bbls 9.8# Brine. Clean returns. SD pumps 3,180.0 3,107.0 11/15/2024 05:30 11/15/2024 06:15 0.75 COMPZN, RPCOMP RURD P Crew C/O. L/D hanger and landing joint. 3,107.0 3,087.0 11/15/2024 06:15 11/15/2024 07:30 1.25 COMPZN, RPCOMP PULL P Pull 3 1/2" Tubing F/ cut @ 3,140' to 2,287'. PUW = 50K. Broke fitting on Eckel's. 3,087.0 2,287.0 11/15/2024 07:30 11/15/2024 08:00 0.50 COMPZN, RPCOMP SVRG P Replace fitting on Eckels. 2,287.0 2,287.0 11/15/2024 08:00 11/15/2024 10:00 2.00 COMPZN, RPCOMP PULL P Cont. pulling 3 1/2" Tubing F/ 2,287' to surface. Cut Joint Length = 5.4'. Clean Tubing. 2,287.0 0.0 11/15/2024 10:00 11/15/2024 10:30 0.50 COMPZN, RPCOMP RURD P Clean and clear rig floor. C/O pipe handling equipment for 2 7/8" DP. Load Yellow Jacket tools. 0.0 0.0 11/15/2024 10:30 11/15/2024 11:00 0.50 COMPZN, RPCOMP BHAH P MU BHA #1 (5 1/2" CIBP). 0.0 9.0 11/15/2024 11:00 11/15/2024 13:15 2.25 COMPZN, RPCOMP TRIP P TIH on 2 7/8" HT PAC w/ CIBP to 3,023'. MU last stand. Drop 5/8" ball. P/U single 2 7/8" DP. MU XO #773. MU single. 9.0 3,023.0 11/15/2024 13:15 11/15/2024 13:45 0.50 COMPZN, RPCOMP MPSP P Screw in TD. TIH to CIBP set depth of 3,040'. PUW = 60K. SOW = 55K. Pressure up to set CIBP. See initial shear @ 1,380 psi. Pressure up to 2,400. Did not see 2nd shear. Bleed off. Pressure back up to 2,400 psi. See 2nd shear out. P/U 2'. Slack off and set 5K down on CIBP. Confirmed good set. 3,023.0 3,040.0 11/15/2024 13:45 11/15/2024 15:15 1.50 COMPZN, RPCOMP TRIP P L/D single 2 7/8" w/ XO. TOOH w/ BHA #1 (CIBP setting tool) racking back 2 7/8" DP. 3,040.0 9.0 11/15/2024 15:15 11/15/2024 15:45 0.50 COMPZN, RPCOMP BHAH P L/D BHA #1 (CIBP setting tools) 0.0 0.0 11/15/2024 15:45 11/15/2024 16:30 0.75 COMPZN, RPCOMP PRTS P Drain Stack. Set Wear Ring. Close Blinds. Line up to pump through kill. Sensator on test spool. PT CIBP and 5 1/2" casing to 1,000 psi for 10-min. 7 strokes. Chart. Bleed off. Open blinds. 0.0 0.0 11/15/2024 16:30 11/15/2024 17:00 0.50 COMPZN, RPCOMP BHAH P MU BHA #2 (5 1/2" MSC) 0.0 10.0 11/15/2024 17:00 11/15/2024 18:30 1.50 COMPZN, RPCOMP TRIP P TIH w/ MSC to CIBP. T 3029'. PUW=60K, SOW=55K. 10.0 3,029.0 Rig: NORDIC 3 RIG RELEASE DATE 11/19/2024 Page 3/7 2P-448 Report Printed: 12/27/2024 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) 11/15/2024 18:30 11/15/2024 19:00 0.50 COMPZN, RPCOMP CPBO P Establish parameters. Pump @ 1.5 BPM, 780 PSI, Rot @ 80 RPM, 1.3K Free TQ, ROT=58K,. Kill Rot back pumps T/ .5 BPM, 140 PSI. RIH T/ 3037' Verify no collars. P/U T/ cut depth @ 3035'. Cut 5 1/2', stage pumps up T/ 2 BPM, 1400 PSI. 2.2K Tq. CSG cut. No PSI wrap around T/ OA. 3,029.0 3,035.0 11/15/2024 19:00 11/15/2024 19:45 0.75 COMPZN, RPCOMP CIRC P P/U T/ 3026. Pulled 15K over had to rotate cutter blades out of cut. Set 2 7/8" DP in slips. L/D single. MU TIW. B/D TD. Close UPR. Line up to pump through kill line. Attempt T/ pump out OA. Pressured up .5 Bbls away 555 PSI. @ 1 Bbls away 552 PSI. No flow or PSI building on OA. Shut down pumps. Open up well. Appears LOT 550 PSI w/ 9.8 PPG. 3,035.0 3,026.0 11/15/2024 19:45 11/15/2024 20:15 0.50 COMPZN, RPCOMP OWFF P OWFF - static w/ slight gas migration in 5 1/2" CSG. R/D TIW. 3,026.0 3,026.0 11/15/2024 20:15 11/15/2024 20:30 0.25 COMPZN, RPCOMP TRIP P POOH F/ 3026' T/ 2932, PUW=60K. 3,026.0 2,932.0 11/15/2024 20:30 11/15/2024 21:00 0.50 COMPZN, RPCOMP CPBO P Establish parameters. Pump @ 1.5 BPM, 780 PSI, Rot @ 80 RPM, 1.3K Free TQ, ROT=58K,. Kill Rot back pumps T/ .5 BPM, 140 PSI. RIH locate collar @ 2958'. P/U T/ cut depth @ 2953'. Cut 5 1/2', stage pumps up T/ 2 BPM, 1300 PSI. 1.8K Tq. CSG cut. OA went T/ 400 PSI. 2,932.0 2,953.0 11/15/2024 21:00 11/15/2024 22:45 1.75 COMPZN, RPCOMP CIRC P P/U T/ 2926'. Set 2 7/8" DP in slips. L/D single. MU TIW. B/D TD. Close UPR. Line up to pump through kill line. Pump 65 bbls heated deep clean pill. Pump 145 Bbls 9.83 Brine @ 3 BPM, 240 PSI. No loses. Clean 9.8# returns from OA. Shut down pumps. 2,953.0 2,926.0 11/15/2024 22:45 11/15/2024 23:30 0.75 COMPZN, RPCOMP OWFF P OWFF, verify no flow from 5 1/2" open UPR. Suck out BOP stack OWFF for 30 Min. 2,926.0 2,926.0 11/15/2024 23:30 11/16/2024 00:00 0.50 COMPZN, RPCOMP RURD P B/D, R/D circ equipment. Shuffle 3 1/2" DP in derrick to make it accessible for next RIH. 2,926.0 2,926.0 11/16/2024 00:00 11/16/2024 00:15 0.25 COMPZN, RPCOMP RURD P Continue shuffle 3 1/2" DP in derrick to make it accessible for next RIH. 2,926.0 2,926.0 11/16/2024 00:15 11/16/2024 01:45 1.50 COMPZN, RPCOMP TRIP P POOH racking back 2 7/8" DP F/ 2926' T/ 10', PUW=57K. 2,926.0 10.0 11/16/2024 01:45 11/16/2024 02:00 0.25 COMPZN, RPCOMP BHAH P L./D BHA #2 MSC. 10.0 0.0 11/16/2024 02:00 11/16/2024 02:30 0.50 COMPZN, RPCOMP CLEN P Clean & clear RF. Mobilizing tools for BHA #3. 0.0 0.0 11/16/2024 02:30 11/16/2024 03:00 0.50 COMPZN, RPCOMP RURD P Pull wear bushing. 0.0 0.0 11/16/2024 03:00 11/16/2024 03:30 0.50 COMPZN, RPCOMP WWSP P Pull 7 5/8" x 5 1/2" pack off. 0.0 0.0 11/16/2024 03:30 11/16/2024 04:30 1.00 COMPZN, RPCOMP PULD P M/U 6 1/2" LH Acme landing joint. K/U. Pull hanger T/ RF, pulling cut T/ 2919'. PUW=70K. L/D hanger & landing joint. 0.0 2,919.0 11/16/2024 04:30 11/16/2024 05:00 0.50 COMPZN, RPCOMP CIRC P Circ CSG volume @ 2 BPM, 90 PSI. Overboarding contaminated fluid. 2,919.0 2,919.0 11/16/2024 05:00 11/16/2024 08:15 3.25 COMPZN, RPCOMP PULL P Crew C/O. L/D 5 1/2" CSG F/ 2919' T/ surface. Inspect cut joint. Cut Joint Length = 38.34'. 2,919.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/19/2024 Page 4/7 2P-448 Report Printed: 12/27/2024 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) 11/16/2024 08:15 11/16/2024 09:15 1.00 COMPZN, RPCOMP RURD P Clean and clear rig floor. RU pipe handling equipment for 3 1/2" DP. 0.0 0.0 11/16/2024 09:15 11/16/2024 10:15 1.00 COMPZN, RPCOMP BHAH P MU BHA #3 (5 1/2" Spear w/ Jars and DC's) 0.0 230.0 11/16/2024 10:15 11/16/2024 11:45 1.50 COMPZN, RPCOMP TRIP P TIH w/ BHA #3 (5 1/2" Spear) to 2,941' (5 1/2" casing stub is @ 2,953'). PUW = 68K, SOW = 65K. 230.0 2,960.0 11/16/2024 11:45 11/16/2024 13:00 1.25 COMPZN, RPCOMP FISH P Screw in TD. Obtain parameters. RIH and engage fish w/ 5 1/2" Spear @ 2,960'. Set 15K down. PU 10K over to confirm latched. Set down 20K. PU to 100K (32K over). Slack off. PU to 125K (57K over). Wait for jars to hit. No movement. No jar hits. Cycle jars up and down to warm up. Hit 14 Jar licks picking up to 300K (232K over). Fish came free @ 300K over. Pulled fish up until surface casing shoe @ 2,853'. L/D single. 2,960.0 2,854.0 11/16/2024 13:00 11/16/2024 15:00 2.00 COMPZN, RPCOMP CIRC P Screw in TD. Circ STS (115 bbls) @ 2 BPM and 154 psi. OA pressure = 10 psi. Monitor for losses at 2 BPM. No losses. Last 10 bbls pump 3 BPM @ 340 psi. OA = 10 psi. Slight losses at 3 BPM on gain/loss at pits. (lost 0.8 BBLS in 10 bbl test). Blowdown lines. 2,854.0 2,854.0 11/16/2024 15:00 11/16/2024 15:30 0.50 COMPZN, RPCOMP OWFF P OWFF. 2,854.0 2,854.0 11/16/2024 15:30 11/16/2024 16:00 0.50 COMPZN, RPCOMP SFTY P Perform post jarring derrick inspection. Finish processing 3 1/2" Tubing. 2,854.0 2,854.0 11/16/2024 16:00 11/16/2024 17:00 1.00 COMPZN, RPCOMP TRIP P TOOH w/ BHA #3 (5 1/2" Spear). F/ 2854', 230', PUW=73. 2,854.0 230.0 11/16/2024 17:00 11/16/2024 17:30 0.50 COMPZN, RPCOMP BHAH P L/D BHA #3. 230.0 0.0 11/16/2024 17:30 11/16/2024 19:30 2.00 COMPZN, RPCOMP PULD P L/D 5 1/2" CSG. Recovered 82.74' cut T/ cut of 5 1/2" CSG. Both cuts clean. Had to cut CSG on RF, could not release spear from CSG. 0.0 0.0 11/16/2024 19:30 11/16/2024 20:45 1.25 COMPZN, RPCOMP RURD P Clean and clear floor & pipe shed. Prep to run 3 1/2" EUE Tubing. 0.0 0.0 11/16/2024 20:45 11/17/2024 00:00 3.25 COMPZN, RPCOMP PUTB P RIH w/ old 3 1/2". 9.3#, L-50, EUE TBG T/ 2904', PUW=52K, SOW=51K. 0.0 2,904.0 11/17/2024 00:00 11/17/2024 00:45 0.75 COMPZN, RPCOMP PUTB P RIH w/ old 3 1/2". 9.3#, L-50, EUE TBG F/ 2904', T/ 2966', PUW=52K, SOW=51K. Wash in hole @ 2 BPM, 63 PSI F/ 2699' T/ 3030'. No losses, EUE-M torque T/ 2250 Ft/lbs 2,904.0 3,030.0 11/17/2024 00:45 11/17/2024 01:00 0.25 COMPZN, RPCOMP CIRC P Stage pumps up T/ 4.5 BPM, 180 PSI. No losses. 3,030.0 3,030.0 11/17/2024 01:00 11/17/2024 01:30 0.50 COMPZN, RPCOMP SFTY P PJSM w/ HES & rig crew on pumping balance cement plug. 3,030.0 3,030.0 11/17/2024 01:30 11/17/2024 03:00 1.50 COMPZN, RPCOMP RURD P R/U cement hose. Blow air T/ cement truck. Batch up 10 PPG spacer & 15.8 PPG cement. Cement wet @ 02:30 3,030.0 3,030.0 11/17/2024 03:00 11/17/2024 03:48 0.80 COMPZN, RPCOMP PRTS P HES come on line w/ 9.8 PPG NaCl. Observed returns. SI. PT cement hose T/ 2000 PSI. 3,030.0 3,030.0 Rig: NORDIC 3 RIG RELEASE DATE 11/19/2024 Page 5/7 2P-448 Report Printed: 12/27/2024 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) 11/17/2024 03:48 11/17/2024 04:36 0.80 COMPZN, RPCOMP CMNT P Turn job over T/ HES. Pump 23.9 Bbls 10.0 PPG spacer @ 2,5 BPM, 120 PSI. Drop 4" foam ball. Pump 20 Bbls 15.8 PPG cement @ 3 BPM, 100 PSI.. Drop 4" foam ball. Pump 6.1 Bbls 10.0 PPG spacer @3 BPM, 100 PSI. Pump 14.2 Bbls 9.8 PPG NaCl @ 2 BPM, 75 PSI. Good returns throughout job. 3,030.0 3,030.0 11/17/2024 04:36 11/17/2024 04:45 0.15 COMPZN, RPCOMP RURD P B/D, R/D cement hose. 3,030.0 3,030.0 11/17/2024 04:45 11/17/2024 05:30 0.75 COMPZN, RPCOMP TRIP P POOH, racking back 3 1/2" TBG F/ 3030' T/ 2248'. PUW=53K. Pulling @ 30 ft/min. Cement in place 05:30 Hrs 3,030.0 2,248.0 11/17/2024 05:30 11/17/2024 06:00 0.50 COMPZN, RPCOMP CIRC P Screw in TD. Circ out @ 4 BPM and 150 psi. Pumped 107 bbls total. Clean returns. SD pump. Saw top of spacer in returns as planned. HES cementers finishing RD ops. Cement samples in cups (1 in refrigerator / 1 on desk at room temp). 2,248.0 2,248.0 11/17/2024 06:00 11/17/2024 06:30 0.50 COMPZN, RPCOMP RURD P Blow down TD. Prep to L/D 3 1/2" Tbg stands and 4 3/4" DC stands. Break 4' pup off joint of Tubing. 2,248.0 2,248.0 11/17/2024 06:30 11/18/2024 00:00 17.50 COMPZN, RPCOMP WOC P WOC for 26.5 hrs (23 hr 35 min to 500 psi + 3 hr safety) until 08:00 on 11/18. At 10:00 AM reciprocate pipe 1 stand and break circulation briefly to confirm flow path/returns. Reciprocate 1 stand up/down every 6 hours to confirm pipe is free above TOC. At 4 PM, reciprocate 1 stand pipe up/down. At 10 PM, reciprocate 1 joint up/down. Break circ w/ charge pump. Cont. to WOC until 08:00 on 11/18. 2,248.0 2,248.0 11/18/2024 00:00 11/18/2024 09:30 9.50 COMPZN, RPCOMP WOC P At 04:00 Hrs reciprocate 1 joint up/down. WOC for 26.5 hrs (23 hr 35 min to 500 psi + 3 hr safety) until 08:00 on 11/18. AOGCC Rep is flying in this morning. Build 6 more stands 3 1/2" IF DP while WOC. Load test joints for next well. 2,248.0 2,248.0 11/18/2024 09:30 11/18/2024 12:30 3.00 COMPZN, RPCOMP WASH P PU Joint #73. Screw in TD. PUW = 49K. SOW = 48K. Wash down circulating out green cement to 2,530' (Joint #81 buried). Washing through cement stringers seeing 3-4K set downs. Circ BU @ 2,530'. 3 BPM @ 160 psi. MU Joint #82. Cont. wash down to 2,537'. Set down 8K. Pressure increase to 300 psi. PU. SD pumps. TIH and Tag TOC @ 2,541' (TVD = 2210'). Set 10K down. Repeat tag @ 2,541' (set 10K down). SC Shoe = 2,976' MD (2440' TVD). TOC = 435' MD above SC shoe (230' TVD). Circ BU @ 3 BPM @ 150 psi to clear out last of contaminated cement. PUH. Set in slips. L/D single. 2,248.0 2,541.0 11/18/2024 12:30 11/18/2024 13:15 0.75 COMPZN, RPCOMP RURD P P/U T/ 2543'. Blowdown TD. RU testing equipment (green valves w/ double block, tee, sensator). Close UPR. 2,541.0 2,532.0 Rig: NORDIC 3 RIG RELEASE DATE 11/19/2024 Page 6/7 2P-448 Report Printed: 12/27/2024 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) 11/18/2024 13:15 11/18/2024 14:45 1.50 COMPZN, RPCOMP PRTS P Pressure up to 700 psi and hold for 10- min. Bled of from 720 psi to 600 psi. Replace sensator and IA valve in cellar. Pressure back up to 720 psi. OA gauge = 740 psi. IA gauge = 710 psi. Good test. Confirm no leak off to formation. Cont. to pressure up to 1,500 psi. PT cement plug to 1,500 psi for 30-min. Charted. Initial = 1,800 psi. 15-min = 1,680 psi (120 psi loss), 30-min = 1680 psi. No loss in 2nd 15-min. Pass. Double checked against cellar gauges. 2,532.0 2,532.0 11/18/2024 14:45 11/18/2024 15:00 0.25 COMPZN, RPCOMP RURD P RD testing equipment. 2,535.0 2,532.0 11/18/2024 15:00 11/18/2024 16:30 1.50 COMPZN, RPCOMP CIRC P Screw in TD. TIH to tag at 2,541'. Mark pipe. L/D 7.5' of Joint #82. Set Joint #81 in slips. Pump 5 BPM @ 252 psi to circ out contaminated cement until returns are clean. SD Pumps. Cuttings box getting full. Swap to take returns to open top. Pump 6 BPM @ 880 psi. Pumped 162 BBLS total. Clean 9.8# returns. 2,532.0 2,532.0 11/18/2024 16:30 11/18/2024 18:00 1.50 COMPZN, WHDBOP HOSO P L/D full joints #81 and #80. Total pulled = 70.26'. Total needed for RKB + Hangeer + Pup + 20' Space out = 49.6'. Delta = Space out Pups = 20.66' of pups (10.18', 10.13'). MU space out pups. MU Tubing Hanger and Landing Joint. Land 3 1/2" Tubing Hanger w/ bottom of sting @ 2520' ORKB. RILDS. PUW=52K, SOW=51K. 2,532.0 2,520.0 11/18/2024 18:00 11/18/2024 18:30 0.50 COMPZN, WHDBOP RURD P L/D landing joint. Drain Stack. 2,520.0 2,520.0 11/18/2024 18:30 11/18/2024 19:30 1.00 COMPZN, WHDBOP WWWH P P/U BOP wash tool. Flush stack with rinate and water. Drain Stack L/D wash tool. 2,520.0 2,520.0 11/18/2024 19:30 11/19/2024 00:00 4.50 COMPZN, WHDBOP OTHR P Open ram doors and Clean green cement from ram cavities, Perform BWM. 2,520.0 2,520.0 11/19/2024 00:00 11/19/2024 01:45 1.75 COMPZN, WHDBOP OTHR P Cont open ram doors and Clean green cement from ram cavities, Perform BWM. Changed out top seals on UVBR's. 2,520.0 2,520.0 11/19/2024 01:45 11/19/2024 03:00 1.25 COMPZN, WHDBOP NUND P N/D BOP & DSA. 2,520.0 2,520.0 11/19/2024 03:00 11/19/2024 03:45 0.75 COMPZN, WHDBOP NUND P N/U old adaptor spool & tree. 2,520.0 2,520.0 11/19/2024 03:45 11/19/2024 04:00 0.25 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 15 Min. Good test. 2,520.0 2,520.0 11/19/2024 04:00 11/19/2024 07:00 3.00 DEMOB, MOVE RURD P R/U HES cement. RU circ equipment to tubing and IA w/ blowdown tee's to flush cement from surface lines post- cementing. Spot rinsate pills in cuttings tank and open top tank. Spot in water trucks. Crew C/O. Blowdown lines to cementers and returns tanks to ensure clear flow path. 2,520.0 2,520.0 Rig: NORDIC 3 RIG RELEASE DATE 11/19/2024 Page 7/7 2P-448 Report Printed: 12/27/2024 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) 11/19/2024 07:00 11/19/2024 10:00 3.00 DEMOB, MOVE CMNT P PJSM. Flood lines w/ 20 bbls FW to warm up lines. 2 BPM @214 psi. Low PT to 1,000 psi. High PT Lines to 3000 psi. Pump 20 bbls of FW spacer w/ surfactant wash. 2 BPM @ 267 psi. Mix first tub of cement. Cement wet @ 07:33AM. Pump 145 bbls of 15.8# cement. 2 BPM @ 21 psi. At 90 bbls cement pumped, swap from open top to cuttings tank returns. Start seeing some lift pressure. 2 BPM @ 60 psi. Blowdown line Monitor for cement returns. See returns @ 105 bbls pumped. Est. 45 BBLS cement returns to cuttings tank. Finish pumping @ 2 BPM / 960 psi. SD Pump. 2,520.0 0.0 11/19/2024 10:00 11/19/2024 11:00 1.00 DEMOB, MOVE RURD P Flush lines to tanks and to cement van. Blowdown surface lines. Open Swab on Tree. Vac out tree with stinger. Wash tree w/ rig pump water hose. Clean out tree down to Wellhead. Clean and clear cellar. Rig Release @ 12:00PM. 0.0 0.0 11/19/2024 11:00 11/19/2024 12:00 1.00 DEMOB, MOVE DMOB P Prep to back rig off 2P-448. Lay rig mats behind rig to make turn. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 11/19/2024 DTTMSTART JOBTYP SUMMARYOPS 11/13/2024 RECOMPLETION R/D hardline. Clean out cuttings tank. Suck out returns tanks. Pull support equipment away from rig. Warm up rig move system. Back off 2P-449. Pickup mats and cleanup. Lay cellar pit liner and T-mats. Lay rig mat dance floor. Stage contingency dry hole tree behind cellar. Pull rig over 2P-448. Berm in cellar. Move in auxiliary equipment. Pump open SSV. R/U hardline & tiger tanks. Complete acceptance checklist. Take on 8.9 PPG NaCl. Build deep clean pill. R/U circ equipment. PT circ manifold & hard line T/ 2500 PSI. Kill well w/ 30 Bbls deep clean pill followed by 120 Bbls 9.8 PPG NaCl. B/D, R/D circ equipment. OWFF begin 30 Min no flow. 11/14/2024 RECOMPLETION Complete 30 Min no flow. N/D tree. Inspect hanger neck threads, function LDS. Install H BPV & test dart. N/U BOP. Install flow nipple. Grease manual and HCR valves. Perform initial BOP test to 250/2500 psi (witness waived by Guy Cook). MM #13 kill line Demco failed. Cut valve out of manifold and weld new valve in. X-ray to verify welds. Bottom weld passed. Top weld failed. Grind out & re weld. 11/15/2024 RECOMPLETION Re X-ray & verify upper weld. PT MM #13 T/ 250/2500. PT weld integrity test T/ 5,000 psi. Pull dart & BPV. M/U landing joint, set 10K down. BOLDS. Pull hanger to rig floor @ 55K. Circ STS. OWFF. L/D hanger and landing joint. Pull 3 1/2" tubing F/ cut @ 3,140' to surface. Cut Joint length = 5.40'. Clean pipe. Decide to skip drift run. R/U 2 7/8" handling equipment. MU BHA #1 (5 1/2" CIBP). TIH and set CIBP @ 3,040'. See initial shear @ 1,380 psi. 2nd shear @ 2,400 psi. P/U 2' to confirm off plug. Slack off and set 5K down on CIBP to confirm a good set. TOOH s standing back 2 7/8" DP. L/D BHA #1. Set Wear Ring. Close blinds. PT CIBP to 1,000 psi for 10-min. Open Blinds. MU BHA #2 (5 1/2" MSC), TIH w/ BHA #2 T/ 3029. K/U obtain parameters pump in hole, verify no collars T/ 3037', P/U cut 5 1/2" casing @ 3035', No PSI wrap around to OA. P/U T/ 3026', attempt to circ OA. Pumping into formation @ 455 PSI, no returns out OA. POOH T/ 2929'. Obtain parameters, pump in hole locate collar @ 2958'. P/U cut CSG @ 2953'. 400 PSI transfer T/ OA. P/U T/ 2926'. Close UPR, circ OA out w/ 65 Bbls Deep Clean pill followed by 145 Bbls 9.8 NaCl. OWFF - 30 Min no flow. Shuffle DP in derrick. 11/16/2024 RECOMPLETION POOH, L/D BHA #2. Pull wear bushing. Pull 11" x 5 1/2" pack off, M/U 6 1/2" LH Acme landing joint. Pull hanger T/ RF. Circ CSG volume. L/D hanger & landing joint. L/D 5 1/2" CSG F/ cut @ 2953'. Cut Joint Length = 38.34'. RU pipe handling equipment for 3 1/2" DP. MU BHA #3 (5 1/2" Spear w/ Jars and DC's). TIH to 2,941'. Screw in TD. PUW = 68K. SOW = 65K. TIH and find top of stub @ 2,960'. Set 15K down. Repeat. Confirm latched. Cycle pipe to warm up jars. Work fish. 14 Jar hit. P/U to 300K. Fish came free. PUH w/ fish inside surface casing T/ 2,854'. Circ STS. 2 BPM @ 158 psi. OA = 20 psi. 3 BPM @ 340 psi. OA = 10 psi. OWFF. Perform derrick inspection. TOOH. L/D BHA #3 & 5 1/2" CSG. Recovered 82.74' of. Clean cut on both ends. RIH w/ old 3 1/2" EUE TBG T/ 2904'. 11/17/2024 RECOMPLETION Cont RIH F/ 2904' T/ 2966'. K/U Wash in hole @ 2 BPM T/ 3030'. PJSM w/ HES. Circ establish pump rate at 250 PSI. R/U cement hose T/ head pin. Turn job over T/ HES. Flood lines PT T/ 2500 PSI. Pump 23.9 Bbls of 10 PPG spacer. Drop foam ball. Pump 20 BBls 15.8 PPG balance cement plug. Drop foam ball. Pump 6.1 Bbls 10 PPG spacer. Chase w/ 14.2 Bbls 9,8 PPG NaCl. B/D, R/D cementers. POOH F/ 3030 racking back 3 1/2" Tubing T/ safety @ 2,248'. Cement in Place @ 05:30AM. Screw in TD. Circ 107 bbls 9.8# brine @ 4 BPM / 150 psi. See spacer in returns. Cleaned up. SD Pumps. WOC until ~11/18 @ 08:00AM (26.5 hrs). 11/18/2024 RECOMPLETION WOC until ~11/18 @ 09:30AM (28 hrs). Wash down to TOC tag @ 2,541' MD (approx. 230' TVD above SC shoe). Set 10K. Circ BU. L/D single. B/D TD. RU testing equipment. Test Plug to 700 psi. No Leak off. PT cement plug to 1,500 psi for 30-min. Chart. Passed. Witness by Sean Sullivan. R/D testing equipment. MU Joint #82. TIH and Tag @ 2,540'. Mark pipe. P/U and set in slips. L/D Joint #82. Screw in TD. Circ out residual green cement. SD Pumps. Space out. L/D 3 joints, M/U space out pups (10.18', 10.13'). MU Hanger w/ pup, MU landing joint. Land hanger w/ BTM of string @ 2520' ORKB. RILDS. Jet BOP stack. Perform BWM while cleaning out green cement from ram cavities. 2P-448A Plug and Abandon Summary of Operations 11/19/2024 RECOMPLETION Cont BWM while cleaning out green cement from ram cavities. N/D BOP. N/U adaptor spool & tree. PT hanger void T/ 5000 PSI. RU Halliburton cementers. PT lines to tanks. Blow air through hardline and cementers to ensure clear flow path. PJSM. Pump 20 bbls FW to warm lines. SD Pumps. PT cement hardline to 3,000 psi. Pump 20 BBLS FW w/ Surf. Wash. Mix 1st tub of cement. Cement wet @ 07:33. Pump 145 bbls of 15.8# Cement. At 90 bbls cement away, swap to cuttings tank. See good 15.8# returns @ 105 bbls cement away. Pump total of 145 bbls 15.8# cement (est. 45 bbls cmt returns to cuttings tank). SD pumps. Flush and blowdown surface lines. RD cementers. Clean cement from tree. RD cellar hoses and hardline. Clean and clear cellar. Rig Released @ 12:00. Warm rig move hydraulic system. Prep for rig move over to 2P-447. 11/25/2024 SUPPORT OTHER OPERATIONS (P&A) IA AND OA DDT (IN PROGRESS) 11/26/2024 SUPPORT OTHER OPERATIONS (P&A) IA AND OA DDT (IN PROGRESS). 11/27/2024 SUPPORT OTHER OPERATIONS (P&A) IA AND OA DDT (IN PROGRESS) 11/28/2024 SUPPORT OTHER OPERATIONS (P&A) IA AND OA DDT (IN PROGRESS) SURVEYORS MARKED IC FLANGE 7' TO TUNDRA 11/29/2024 SUPPORT OTHER OPERATIONS (P&A) IA AND OA DDT (IN PROGRESS). 11/30/2024 SUPPORT OTHER OPERATIONS (P&A) IA AND OA DDT (IN PROGRESS). 12/1/2024 SUPPORT OTHER OPERATIONS (P&A) IA AND OA DDT (PASS) CLEAR CELLAR OF DEBRIS (COMPLETE). 12/4/2024 SUPPORT OTHER OPERATIONS (P&A) REMOVE IA AND OA CASING VALVES (COMPLETE) REMOVE TREE (IN PROGRESS) IDENTIFIED ICE PLUG IN TUBING (~25" BELOW THE THA) 12/7/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS. VERIFIED 0 PSI INSIDE OF WELLHEAD. REMOVED TREE, TOP OF FLUID 25" BELOW THA. BAD CEMENT TO 48" BELOW THA. ATMOSPHERIC TESTING NORMAL INSIDE OF WELLHEAD . ***NEXT STEPS- CUT AND REMOVE WELLHEAD, CELLAR, AND BEGIN EXCAVATION.*** 12/8/2024 SUPPORT OTHER OPERATIONS (P&A) PREP IN PROGRESS. CUT/ REMOVED 6' 9" OF WELLHEAD/CONDUCTOR. ***NEXT STEP- BEGIN EXCAVATING TO 14' FOR SHORE CAN INSTALL.*** 12/9/2024 SUPPORT OTHER OPERATIONS (P&A) PREP- IN PROGRESS. BEGAN EXCAVATION, TARGET DEPTH OF 14' FOR SHORE CAN INSTALL. ACHIEVED 6.5' OF DEPTH. 12/10/2024 SUPPORT OTHER OPERATIONS (P&A)PREP IN PROGRESS- EXCAVATED TO 14', SET SHORE CAN AND BACKFILLED AROUND (8' D X16' H) SHORE CAN. NEXT STEP: CUT AND REMOVE ADDITIONAL LENGTH OF WELL STUB TO BE GREATER THAN 4' BELOW ORIGINAL GROUND (TUNDRA). 12/11/2024 SUPPORT OTHER OPERATIONS (P&A) CUT 86" (7 ,2"') OF ADDITIONAL WELL STUB, OAL 169" (14' 1") FROM OG REFERENCE FINAL CUT 83" (6' 11") BELOW OG. PREPARED REMAINING WELL STUB FOR WELL MARKER PLATE. ***NEXT STEP: AOGCC WITNESS OF MARKER PLATE INFORMATION, TOC AND WELD. BACKFILL AND EXTRACT SHORE CAN.*** 12/12/2024 SUPPORT OTHER OPERATIONS PHASE 3 WAIT ON WEATHER 12/13/2024 SUPPORT OTHER OPERATIONS PHASE 3 WAIT ON WEATHER 12/14/2024 SUPPORT OTHER OPERATIONS (P&A) PREP POST STORM CLEAN UP DIG OUT. ***NEXT STEP: AOGCC TOC AND MARKER PLATE VERIFICATION.. EXTRACT SHORE CAN, BACKFILL.*** 12/15/2024 SUPPORT OTHER OPERATIONS (P&A) AOGCC INSPECTOR ADAM EARL VERIFIED TOC AND MARKER PLATE INFORMATION. WELL STUB 7' BELOW OG. NES WELDED MARKER PLATE TO WELL STUB. PULLED SHORE CAN, BACKFILLED EXCAVATION. NEXT STEP : OBTAIN FINAL SITE CLEARANCE FROM AOGCC. Page 1/1 2P-448 Report Printed: 12/27/2024 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 11/17/2024 02:30 Cementing End Date 11/17/2024 05:30 Wellbore Name 2P-448A Comment Pumped 20 Bbls 15.8 PPG balance plug cover open hole & surface casing shoe into 7 5/8" CSG. Tag cement @ 2541'. PT plug T/ 1500 PSI for 30 Minutes, test witnessed by AOGCC Sully Sulivan. Cement Stages Stage # 1 Description Cement Plug Objective Top Depth (ftKB) 2,541.0 Bottom Depth (ftKB) 3,035.0 Full Return? No Vol Cement …Top Plug? No Btm Plug? No Q Pump Init (bbl/m… 3 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 3 P Pump Final (psi) 75.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 2,541.0 Tag Method Tubing Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 24 Bbls of 10 PPG spacer. Drop foam ball. Pumped 20 Bbls of 15.8 PPG cement. Drop foam ball. Pump 6 Bbls of 10 PPG spacer. Displace w/ 14.2 Bbls 9.8 PPG NaCl. POOH w/ 3 1/2" EUE work string F/ 3030' T/ 2248' @ 30 ft/min. Cement in place @ 05:30 Hrs. Constant returns throughout job. No losses. Cement Fluids & Additives Fluid Fluid Type Plug Back Cement Fluid Description Estimated Top (ftKB) 2,563.0 Est Btm (ftKB) 3,030.0 Amount (sacks) 94 Class *NOT IN LIBRARY Volume Pumped (bbl) 20.0 Yield (ft³/sack) 1.20 Mix H20 Ratio (gal/sa… 5.03 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) 3.55 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: RECOMPLETION-<jobsubtyp> 11/13/2024 … Page 1/1 2P-448 Report Printed: 12/27/2024 Cement Detail Report Cement Details Description Cement Plug Cementing Start Date 11/19/2024 07:30 Cementing End Date 11/19/2024 10:00 Wellbore Name 2P-448A Comment Pumped 145 bbls of 15.8# cement to surface. Filled 3 1/2" Tubing and 7 5/8" Production Casing to surface. Cleaned cement out of 3 1/8" Tree down wellhead. Flushed and sucked out tree. Cement Stages Stage # 1 Description Plug – Plug Back / Abandonment Plug Objective Top Depth (ftKB) 36.0 Bottom Depth (ftKB) 2,540.0 Full Return? No Vol Cement … 45.0 Top Plug? No Btm Plug? No Q Pump Init (bbl/m… 2 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 2 P Pump Final (psi) 960.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 145 bbls of 15.8# cement to surface. Filled 3 1/2" Tubing and 7 5/8" Production Casing to surface. Cement Fluids & Additives Fluid Fluid Type Plug Back Cement Fluid Description Estimated Top (ftKB) 23.9 Est Btm (ftKB) 2,540.0 Amount (sacks) 725 Class *NOT IN LIBRARY Volume Pumped (bbl) 145.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 4.98 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) Thickening Time (hr) 2.85 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Cement Plug Job: RECOMPLETION-<jobsubtyp> 11/13/2024 … 3 2P-448A Actual Final P&A Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 56 bbls of 15.8# Cement Calculated TOC @ 4,635' KB Production Casing: 5.5" x 3.5" @ 6,894' KB, 15.5# x 9.3#, L-80 BTCM Set @ 7,585.7’ KB T-3 Peforations: @ 7,195'– 7,210' KB (15') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,976.3' KB (2440' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,883.7' KB 1 2 4 7 5 6 /ƚĞŵ ĞƉƚŚͲƚŽƉƐ;<Ϳ ϭ &D,ĂŶŐĞƌ Ϯϯ͘ϴΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϰϬΖ ϯ dƵďŝŶŐ>ĞĂŬŝŶ'>D ϲ͕ϳϳϬΖ ϰ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬϮ͘ϴϭΗ ^WƌŽĨŝůĞ;ĐůŽƐĞĚϵͬϮϲͬϭϮͿ ϲ͕ϴϮϬΖ ϱ ĂŵĐŽEŝƉƉůĞ ϲ͕ϴϯϱ͘ϵΖ ϲ ĂŬĞƌ^ĞĂůƐƐĞŵďůLJǁͬ'ͲϮϮ >ŽĐĂƚŽƌ ϲ͕ϴϴϬ͘ϰΖ ϳ WůƵŐĂƚĐŚĞƌƐĞƚŝŶϯ͘ϱΗĐĂƐŝŶŐ ϳ͕ϰϲϯ͘ϲΖ C80 @ 2980' KB C80 @ 2980' KB Plug #1 – Reservoir TOC ±7118' RKB Plug #2 – Intermediate TOC ±5076' RKB BOC @ ±6800' RKB Plug #3 – Surface Shoe TOC 2541' RKB (2210' TVD) BOC @ ±3040' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2541' RKB 2024-1215_Surface_Abandon_KRU_2P-448A_ae Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:12-18-2024 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector KRU 2P-448A ConocoPhillips Alaska Inc. PTD 2020050; Sundry 324-525 12-15-2024:I traveled out to KRU 2P-448A to inspect the surface abandonment. Roger Mouser was the CPAI representative on the job. The well was cut-off 6 feet 11 inches below tundra grade and the cement was set up nice in all strings. The marker plate had the correct information. I witnessed welding the plate to the outermost casing. Approval was given to bury the abandoned well. Attachments:Photos (3) 2024-1215_Surface_Abandon_KRU_2P-448A_ae Page 2 of 3 Surface Abandonment – KRU 2P-448A (PTD 2020050) Photos by AOGCC Inspector A. Earl 12/15/2024 2024-1215_Surface_Abandon_KRU_2P-448A_ae Page 3 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 17 Township: 8N Range: 7E Meridian: Umiat Drilling Rig: Nordic 3 Rig Elevation: 29.71 ft Total Depth: 7,593 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: P&A: X Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 7 5/8" O.D. Shoe@ 2,976 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5-1/2"x 3-1/2" O.D. Shoe@ 7,560 Feet Csg Cut@ 3,035 Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 6,884 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 3,040 ft 2,541 ft 9.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing 1800 1680 1680 IA 1820 1680 1660 OA 1800 1700 1660 Remarks: Attachments: Tyson Wiese Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Travel out to KRU 2P pad for plug tag and MIT of the first casing abondonment plug on 2P-448A. Nordic Rig 3 was over the well to set CIBP @ 3040 ft MD then performing cut of production casing @3,03 5ft RKB. Cement plug was laid on top of CIBP. Rig washed down to 2534 ft MD @ 5k lbs and final tag was performed with 10k lbs down @ 2,541 ft MDRKB (435 ft above the csg shoe). MIT showed good integrity. November 18, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-448A ConocoPhillips Alaska Inc. PTD 2020050; Sundry 324-484 none Test Data: P Casing Removal: rev. 3-24-2022 2024-1118_Plug_Verification_KRU_2P-448A_ss 9 9 9 9 9 9 999 9 9 9 9 9 9 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.22 15:05:08 -09'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 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: 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 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 110' 7-5/8" L-80 2440' 5-1/2" L-80 5192' 3-1/2" L-80 5746' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above6.75" TUBING RECORD 56 bbls Class G6.75" 6884' MD3-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/6/2024 202-005/324-484 50-103-20396-01-00 KRU 2P-448A ADL0373112 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM 1240' FSL, 931' FEL, Sec. 18, T8N, R7E, UM ALK 4998 1/9/2002P.O. Box 100360, Anchorage, AK 99510-0360 443543 5868859 1525' FSL, 949' FEL, Sec. 18, T8N, R7E, UM WT. PER FT.GRADE 1/13/2002 CEMENTING RECORD 5866144 1488' MD/ 1458' TVD SETTING DEPTH TVD 5865859 TOP HOLE SIZE AMOUNT PULLED 441000 441007 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended 9. Ref Elevations: KB: 30' 391 sx AS Lite, 202 sx LiteCrete 9.3# 29' 6894' 2976'29' 29' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# 5076' (SW TOC)' -6770' MD 31 bbls 15.8 ppg Class G Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 7195-7210' MD and 5436-5448' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 6880' MD/ 5181' TVD (seal assembly) 6894' SIZE DEPTH SET (MD) 7586' 26' 5192' 62.5# 29.7# 110' 26' PACKER SET (MD/TVD) 42" 9-7/8" 64.9 bbls AS I 29' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 10. Plug Back Depth MD/TVD: 18. Property Designation: 5076' MD/ 3730' TVD 7593' MD/ 5752' TVD 12. SSSV Depth MD/TVD: N/A By James Brooks at 10:35 am, Oct 22, 2024 Suspended 10/6/2024 JSB RBDMS JSB 103024 xG DSR-11/22/24 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1488' 1458' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Katherine O'Connor Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com Contact Phone:(907) 263-3718 Senior Well Interventions Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A- Suspended Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: N/A - Suspended Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.10.22 07:47:47-08'00'Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,219.0 2P-448A 12/28/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added jet cut at 3140' RKB 2P-448A 10/6/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: Mandrel Orientation: #1)9:30, #2)2:00, #3)11:00, #4)10:00 10/21/2013 hipshkf NOTE: LEAK FOUND AT 6770' MANDREL 10/28/2012 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 110.0 110.0 63.00 WELDED SURFACE 7 5/8 6.87 28.8 2,976.3 2,440.2 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 6894' 5 1/2 4.95 25.9 7,585.7 5,745.8 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 6,883.7 Set Depth … 5,183.8 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) 23.8 23.8 0.04 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 522.8 522.7 3.18 NIPPLE 4.520 CAMCO LANDING DS NIPPLE CAMCO DS 2.875 2,527.8 2,203.1 56.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,921.1 3,612.5 41.11 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,096.3 4,543.5 36.38 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,770.3 5,091.7 35.55 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,820.0 5,132.0 35.61 SLEEVE-C 4.530 BAKER CMU SLIDING SLEEVE w/2.81" DS PROFILE (CLOSED 9/26/12) BAKER CMU 2.810 6,835.9 5,145.0 35.63 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,880.4 5,181.2 35.81 SEAL 4.000 BAKER SEAL ASSY w/G-22 LOCATOR BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,140.0 2,528.3 57.67 CUT JET CUT @ 3140' RKB 10/6/2024 2.992 6,765.5 5,087.8 35.55 TUBING PUNCH TBG PUNCH FROM 6765.5' TO 6770' RKB W/ 4 SPF 9/10/2024 2.992 7,155.3 5,403.8 36.21 CIBP CIBP MID-ELEMENT AT 7156' RKB, OAL 1.37' 7/25/2024 0.000 7,203.3 5,442.5 36.36 CIBP CIBP MID-ELEMENT AT 7204' RKB, OAL 1.37' (PLUG MOVED DOWNHOLE ~34' FROM ORIGINAL SET DEPTH OF 7170' RKB) 7/23/2024 0.000 7,463.6 5,649.8 37.97 Plug Catcher PLUG CATCHER SET IN 3.5" CASING 1/9/2002 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,527.8 2,203.1 56.91 1 GAS LIFT SOV DK1 1 0.0 9/17/2024 Shear at 2000 PSI (Casin g) 0.000 4,921.1 3,612.5 41.11 2 GAS LIFT DMY DK1 1 0.0 1/22/2002 0.000 6,096.3 4,543.5 36.38 3 GAS LIFT OV DK1 1 5/21/2018 0.313 6,770.3 5,091.7 35.55 4 GAS LIFT PATCH 1 0.0 2/16/2013 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,195.0 7,210.0 5,435.8 5,447.9 T-3, 2P-448A 1/27/2002 6.0 IPERF 2.5" HSC PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,195.0 7,210.0 1 FRAC 2/3/2002 0.0 0.00 0.00 7,195.0 7,210.0 1 RE-FRAC 12/4/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,118.0 7,155.3 5,373.7 5,403.8 Cement Plug Slickline dump bailed cement on top of CIBP 7/28/2024 5,076.0 6,770.0 3,730.3 5,091.4 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 46 BBLS OF 9.8 PPG NaCl KWF. 9/26/2024 2P-448A, 10/10/2024 5:23:11 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6894'; 25.9-7,585.7 Plug Catcher; 7,463.6 CIBP; 7,203.3 IPERF; 7,195.0-7,210.0 FRAC; 7,195.0 RE-FRAC; 7,195.0 CIBP; 7,155.3 Cement Plug; 7,118.0 ftKB TUBING; 6,782.5 GAS LIFT; 6,770.3 TUBING PUNCH; 6,765.5 GAS LIFT; 6,096.3 Cement Plug; 5,076.0 ftKB GAS LIFT; 4,921.1 CUT; 3,140.0 SURFACE; 28.8-2,976.3 GAS LIFT; 2,527.8 NIPPLE; 522.8 CONDUCTOR; 29.0-110.0 KUP PROD KB-Grd (ft) 33.01 RR Date 1/8/2002 Other Elev… 2P-448A ... TD Act Btm (ftKB) 7,593.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039601 Wellbore Status PROD Max Angle & MD Incl (°) 59.90 MD (ftKB) 3,380.68 WELLNAME WELLBORE2P-448A Annotation Last WO: End DateH2S (ppm) 50 Date 12/6/2016 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 8/22/2024 ACQUIRE DATA (P&A) T DDT (PASSED) IA DDT (PASSED) 9/3/2024 ACQUIRE DATA (P&A) FUNCTION TEST ALL T LDS/GNS (COMPLETE), T POT (PASSED) T PPPOT (PASSED), FUNCTION TEST ALL IC LDS/GNS (COMPLETE), IC POT (PASSED) IC PPPOT (PASSED), 9/10/2024 SUPPORT OTHER OPERATIONS TUBING PUNCH INTERVAL: 6765.5' - 6770' WITH 4.5', 4 SPF PUNCHES. UNABLE TO PRESSURE UP TUBING TO CONFIRM GOOD COMMUNICATION DUE TO KNOWN TBG LEAK. JOB COMPLETE, READY FOR SL 9/16/2024 SUPPORT OTHER OPERATIONS SET 3-1/2" SLIPSTOP CATCHER @ 6274' RKB (LIH-48"), PULLED 1" BTM LATCH OV FROM STA #3 @ 6096' RKB, SET 1" DMY VLV BTM -LATCH @ 6096' RKB. LDFN, JOB IN PROGRESS. 9/17/2024 SUPPORT OTHER OPERATIONS PULLED 1" BTM LATCH DMY FROM STA# 1 @ 2527' RKB, SET 1" BTM LATCH SOV ***2000 PSI CASING SHEAR***, IN STA #1 @ 2527' RKB, PULLED 3-1/2" SLIP STOP CATCHER FROM 6274' RKB. RDMO, JOB COMPLETE. 9/24/2024 SUPPORT OTHER OPERATIONS STEP RATE TEST PUMP 30BBLS OF DSL 3BPM AT 1000 PSI ON TBG U TUBE WELL FOR FREEZE PROTECT JOB COMPLETE 9/26/2024 SUPPORT OTHER OPERATIONS INTERMEDIATE CEMENT BALANCE PLUG. LOAD TBG & IA WITH 9.8 PPG NaCl KWF. PUMPED 31 BBLS OF 15.8 PPG CEMENT & DISPLACED CEMENT w/ 46 BBLS OF 9.8 PPG NaCl KWF. PLACING TOC IN TBG & IA @ ~5270' MD. WAIT ~48 HRS TO FREEZE PROTECT. IN PROGRESS 9/28/2024 SUPPORT OTHER OPERATIONS PRESSURE UP IA 2700psi TO SHEAR, SHEAR OUT VALVE, PUMPED 60 BBLS DSL DWN IA, RETURNS FROM TBG TO TANK, U-TUBE FOR FREEZE PROTECT. READY FOR SW TAG & TEST. 10/5/2024 SUPPORT OTHER OPERATIONS STATE WITNESS ( SULLEY ) TAG TOC 5076' SLM, GOOD SAMPLE. PERFORM 1500 PSI CMIT Tx IA W/ PASSING RESULTS. READY FOR E-LINE. 10/6/2024 SUPPORT OTHER OPERATIONS CUT TUBING AT 3140' W/ 2.5" JET CUTTER LOG CORRELATED TO TUBING TALLY DATED 12/22/2002 WELL LEFT S/I 2P-448A Intermediate Suspend Summary of Operations ORIGINATED TRANSMITTAL DATE: 10/9/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5104 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5104 2P-448A 50103203960100 Tubing Cut Record 6-Oct-2024 RECIPIENTS ConocoPhillips Alaska, Inc. DIGITAL FILES PRINTS CD'S 1 0 0 0 USPS 0 0 0 0 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS 1 Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 202-005 T39647 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.09 12:54:04 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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: 7,593 ft MD Lease No.: ADL0373112 Operator Rep: Suspend: X P&A: Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 7 5/8" O.D. Shoe@ 2976 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 5-1/2"x 3-1/2" O.D. Shoe@ 7586 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 6,884 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 6,800 ft 5,076 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1820 1730 1700 IA 1775 1705 1705 OA 410 367 352 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Sid Ferguson Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Traveled to KRU 2P pad for plug tag and MIT-TxIA combo test of the intermediate balanced plug on 2P-448. Wire line tool was 28 ft long with 150lbs of weight bar and a flap bailer on the end .Initial tag at 5,076 ft MD and after beating down a few times the final tag was still 5,076 ft MD. The bailer returned a good cement sample. 0.8 bbl in and 0.8 bbl out during the MIT. October 5, 2024 Sully Sullivan Well Bore Plug & Abandonment KRU 2P-448A ConocoPhillips Alaska Inc. PTD 2020050; Sundry 324-484 none Test Data: P Casing Removal: rev. 3-24-2022 2024-1005_Plug_Verification_KRU_2P-448A_ss 9 9 9 9 9 9 99 9 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.18 16:10:55 -09'00' Originated: Delivered to:12-Sep-24 Alaska Oil & Gas Conservation Commiss 12Sep24-NR ATTN: MeredithGuhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD2-58 50-103-20457-00-00 203-085 Colville River WL SBHPS-RBP FINAL FIELD 16-Aug-24 CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 18-Aug-24 CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24 1B-07 50-029-20616-00-00 181-089 Kuparuk River WL MechCutter FINAL FIELD 24-Aug-24 2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24 3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24 2A-20 50-103-20196-00-00 193-151 Kuparuk River WL IPROF FINAL FIELD 30-Aug-24 3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24 3J-18 50-029-22701-00-00 196-147 Kuparuk River WL Lee-PPROF FINAL FIELD 3-Sep-24 2U-12 50-029-21304-00-00 185-041 Kuparuk River WL PPROF FINAL FIELD 4-Sep-24 1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24 2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24 2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39555 T39556 T39557 T39558 T39559 T39560 T39561 T39562 T39564 T39565 T39566 T39567 T39668 T39563 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.13 08:31:59 -08'00' 2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Suspend-Intermediate Plug 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7593'None Casing Collapse Structural Conductor Surface Intermediate Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10/30/2024 3-1/2" Packer: Baker Seal Assy SSSV: None Perforation Depth MD (ft): L-80 2947' 7195-7210' (below cement plug) 7560' 5436-5448' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2976' 5746'7586' 16" 7-5/8" 81' 6884' MD 110' 2440' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Abandoned TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 202-005 P.O. Box 100360, Anchorage, AK 99510 50-103-20396-01-00 Kuparuk River Field Meltwater Oil Pool - Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6880' MD and 5181' TVD N/A Shane Germann Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: shane.germann@conocophillips.com (907) 263-4597 Senior CTD/RWO Engineer KRU 2P-448A 5752' 7118' 5374' 7118', 7155', 7203' 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 940 By Grace Christianson at 4:03 pm, Sep 12, 2024 Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E=shane.germann@ conocophillips.comReason: I am the author of this document Location: Date: 2024.09.12 15:12:49-08'00' Foxit PDF Editor Version: 13.0.0 324-525 A variance from 20 AAC 25.112(a)(1)(A)which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata is granted to instead allow the recovery of 50' of production casing below the surface casing shoe and a cement plug placed across this open hole section and 150' into the surface casing. June 30, 2025 X X 10-407 A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. BOP test to 2500 psig Annular preventer test to 2500 psig AOGCC witness required after wellhead cutoff and prior to top job if needed. DSR-9/13/24 XX VTL 10/20/24 Abandoned See attached "Conditions of Approval" SFD 10/4/2024 Abandoned Abandon *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.21 20:05:21 -08'00'10/21/24 RBDMS JSB 102224 KRU 2P-448A Abandonment Conditions of Approval: 1. A variance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata. 2. A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as the recovery of 50' of production casing below the surface casing shoe and a cement plug placed across this open hole section and 150' into the surface casing. The plug must pass a State Witnessed pressure test and tag according to 20 AAC 25.112(g). 3. A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata. 4. A failed pressure test of the surface casing shoe plug requires the submission of a new sundry (10-403) to cover the rigless abandonment scope if planned. Completion of workover operations under the original sundry will be complete and a 10-407 Well Completion or Recompletion Report and Log must be filed with the Commission within 30 days following the completion of workover operations. 5. If surface abandonment operations are not initiated within 30 days after the successful placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407 Well Completion or Recompletion Report and Log must be filed with the Commission within 30 days after the completion of workover operations to date. 6. Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20 AAC 25.120. 7. AOGCC witness is required after the wellhead cutoff and prior to a top job. Variances granted provide for at least equally effective plugging of the well and prevention of fluid movement into sources of hydrocarbons or freshwater. 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It has no known tubing or IA integrity issues. This well will be P&A’d as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for the Willow development project in 2026. This well was suspended via reservoir cement plug and intermediate cement plug. The objective of this procedure is to pump the surface casing shoe cement plug and final abandonment cement plug with Nordic 3 and ultimately execute final abandonment. Well Data Meltwater Formation: x Reservoir pressure 7/4/2018 = 1259 psi @ 5400’ TVD x MASP = 719 psi C-80 Formation: x OAP = 358 psi (11/5/22) (fluid packed with diesel) x MASP = 940 psi Anticipated intermediate plug TOC = 5300’ MD Anticipated tubing cut depth = 3140’ MD 3 2P-448A Well Suspension Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 56 bbls of 15.8# Cement Calculated TOC @ 4,635' KB Production Casing: 5.5" x 3.5" @ 6,894' KB, 15.5# x 9.3#, L-80 BTCM Set @ 7,585.7’ KB T-3 Peforations: @ 7,195'– 7,210' KB (15') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,976.3' KB (2440' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,883.7' KB 1 2 4 7 5 6 ĞƉƚŚͲƚŽƉƐ;<Ϳ/ƚĞŵ ϭ &D' EsdƵďŝŶŐ,ĂŶŐĞƌ Ϯϯ͘ϴΖ Ϯ ĂŵĐŽ>ĂŶĚŝŶŐ^EŝƉƉůĞ ϱϮϮ͘ϴΖ ϯ dƵďŝŶŐ>ĞĂŬŝŶ'>D ϲ͕ϳϳϬΖ ϰ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ Ϯ͘ϴϭΗ^WƌŽĨŝůĞ;ĐůŽƐĞĚϵͬϮϲͬϭϮͿ ϲ͕ϴϮϬΖ ϱ ĂŵĐŽEŝƉƉůĞ ϲ͕ϴϯϱ͘ϵΖ ϲ ĂŬĞƌ^ĞĂůƐƐĞŵďůLJǁͬ'ͲϮϮ >ŽĐĂƚŽƌ ϲ͕ϴϴϬ͘ϰΖ ϳ WůƵŐĂƚĐŚĞƌƐĞƚŝŶϯ͘ϱΗĐĂƐŝŶŐ ϳ͕ϰϲϯ͘ϲΖ C80 @ 2980' KB C80 @ 2980' KB Plug #2 – Intermediate TOC ±5300' RKB BOC @ ±6800' RKB Plug #1 – Reservoir TOC ±7118' RKB Surface Casing Plugs – Rig Date: 9-11-2024 Prepared by: Shane Germann Estimated Start Date: 10-30-2024 MIRU 1. MIRU on 2P-448A. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed oƯ IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead before proceeding. 3. ND Tree and NU BOPE. Test rams and annular to 250/2,500 PSI. a. Will not set BPV due to two tested cement plugs below providing two barriers to formation. b. BOPE ConƱguration: Annular / Variable Bore Rams / Blind Rams / Pipe Rams 4. Circulate tubing and IA to brine. Retrieve Tubing 5. MU landing joint and BOLDS. 6. Pull tubing from pre-rig cut to surface and LD. Execute First Surface Casing Abandonment Plug 1. Set bridge plug in production casing 100’ below surface casing shoe 2. Cut production casing 50’ below surface casing shoe 3. Circulate OA to brine and complete 30-minute NFT. a. Punch holes in production casing at the surface casing shoe if unable to achieve circulation from production casing cut. 4. MU landing joint for production casing hanger and conƱrm casing is free from cut. a. Contingency: If unable to pull production casing from original cut depth i. Perform second cut inside surface casing shoe ii. Pull casing down to upper cut and laydown iii. PU DP and Ʊshing assembly iv. TIH and engage cut stub of prod casing. Fish stub free. v. Retrieve to surface. LD DP 5. Pump cement plug through the production casing cut. Utilize ~17 BBL of cement, plus excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll the space vacated by the casing displacement. Ensure base of 5-1/2” casing is between 150’ – 200’ TVD inside the surface casing shoe based on space out of a casing collar at the Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for cement volume calculations. a. Contingency: if unable to pull prod casing from original cut depth i. TIH with tubing to above the casing shoe ii. Pump cement plug across the shoe through the tubing. PU and circulate the base of the tubing clear b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon bearing zones. It is our intention to recover 50’ of production casing from the open hole section. c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor recommendation for the integrity of the abandonment, to drill out the cement plug once pumped. 6. WOC 7. Tag cement and PT to 1,500 PSI with state witness a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to increasing pressure to full 1,500 PSI for 30-min state witness b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư- rig remediation. 3 2P-448A Well Surface Shoe Cement Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 56 bbls of 15.8# Cement Calculated TOC @ 4,635' KB Production Casing: 5.5" x 3.5" @ 6,894' KB, 15.5# x 9.3#, L-80 BTCM Set @ 7,585.7’ KB T-3 Peforations: @ 7,195'– 7,210' KB (15') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,976.3' KB (2440' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,883.7' KB 1 2 4 7 5 6 ĞƉƚŚͲƚŽƉƐ;<Ϳ/ƚĞŵ ϭ &D,ĂŶŐĞƌ Ϯϯ͘ϴΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϴϬΖ ϯ dƵďŝŶŐ>ĞĂŬŝŶ'>D ϲ͕ϳϳϬΖ ϰ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ Ϯ͘ϴϭΗ^WƌŽĨŝůĞ;ĐůŽƐĞĚϵͬϮϲͬϭϮͿ ϲ͕ϴϮϬΖ ϱ ĂŵĐŽEŝƉƉůĞ ϲ͕ϴϯϱ͘ϵΖ ϲ ĂŬĞƌ^ĞĂůƐƐĞŵďůLJǁͬ'ͲϮϮ >ŽĐĂƚŽƌ ϲ͕ϴϴϬ͘ϰΖ ϳ WůƵŐĂƚĐŚĞƌƐĞƚŝŶϯ͘ϱΗĐĂƐŝŶŐ ϳ͕ϰϲϯ͘ϲΖ C80 @ 2980' KB C80 @ 2980' KB Plug #2 – Intermediate TOC ±5300' RKB BOC @ ±6800' RKB Plug #3 – Surface Shoe TOC 2692' RKB (2290' TVD) BOC @ ±3080' RKB Base of 5-½” Casing 350'-400' MD Inside Surface Shoe Plug #1 – Reservoir TOC ±7118' RKB ϮWͲϰϰϴϯĂůĐƵůĂƚĞĚWdKΛϰϲϯϱ͛Z<^^ŚŽĞΛϮϵϳϲ͛Z</WΛϯϬϴϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϲϵϮ͛Z<WƵƚΛϯϬϯϬ͛Z<ϴϬΛϮϵϴϬ͛Z<4594' RKB Execute Final Abandonment Plug 8. Land workstring in casing hanger proƱle. 9. Circulate cement surface to surface until full cement returns observed on surface. See table below for cement volumes. RDMO 10. ND BOPE. NU dry hole tree. a. Note: this step may be performed prior to pumping Ʊnal surface to surface abandonment plug. 11. RDMO. Cement Plug TOC BOC Section ID BBL/FT Volume Notes Surface Shoe 3030 3080 Open Hole 6.75 0.03867 1.9 Displacement of Prod Casing Stub Included in BBL/FT calc 2976 3030 Open Hole 6.75 0.04426 2.4 2692 2976 Surface Casing 6.87 0.04585 13.0 17.3 Total Volume of Plug Surface Casing 23 2692 Surface Casing 6.87 0.04026 107.5 Displacement of Prod Casing Included in BBL/FT calculation Execute Final Abandonment Surface Excavation 12. DHD to perform drawdown test on tubing, IA, and OA 13. Remove well house. 14. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system. 15. Remove tree in preparation for excavation and casing cut. 16. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 17. Cut oƯ wellhead and all casing strings at 4 feet below original ground level. 18. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 19. Send the casing head with stub to materials shop. Photo document. 20. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. a. ConocoPhillips b. KRU 2P-448A c. PTD #: 202-005 d. API #: 50-103-20396-00-01 21. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground level. 22. Obtain site clearance approval from AOGCC. RDMO. 23. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location condition after work is completed 3 2P-448A Well Final P&A Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 56 bbls of 15.8# Cement Calculated TOC @ 4,635' KB Production Casing: 5.5" x 3.5" @ 6,894' KB, 15.5# x 9.3#, L-80 BTCM Set @ 7,585.7’ KB T-3 Peforations: @ 7,195'– 7,210' KB (15') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,976.3' KB (2440' TVD) Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,883.7' KB 1 2 4 7 5 6 ĞƉƚŚͲƚŽƉƐ;<Ϳ/ƚĞŵ ϭ &D,ĂŶŐĞƌ Ϯϯ͘ϴΖ Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϬϴϬΖ ϯ dƵďŝŶŐ>ĞĂŬŝŶ'>D ϲ͕ϳϳϬΖ ϰ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞǁͬ Ϯ͘ϴϭΗ^WƌŽĨŝůĞ;ĐůŽƐĞĚϵͬϮϲͬϭϮͿ ϲ͕ϴϮϬΖ ϱ ĂŵĐŽEŝƉƉůĞ ϲ͕ϴϯϱ͘ϵΖ ϲ ĂŬĞƌ^ĞĂůƐƐĞŵďůLJǁͬ'ͲϮϮ >ŽĐĂƚŽƌ ϲ͕ϴϴϬ͘ϰΖ ϳ WůƵŐĂƚĐŚĞƌƐĞƚŝŶϯ͘ϱΗĐĂƐŝŶŐ ϳ͕ϰϲϯ͘ϲΖ C80 @ 2980' KB C80 @ 2980' KB Plug #2 – Intermediate TOC ±5300' RKB BOC @ ±6800' RKB Plug #3 – Surface Shoe TOC 2692' RKB (2290' TVD) BOC @ ±3080' RKB Plug #4 – Surface TOC 23' RKB BOC @ ±2692' RKB Plug #1 – Reservoir TOC ±7118' RKB Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,219.0 2P-448A 12/28/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement on CIBP 2P-448A 7/28/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Mandrel Orientation: #1)9:30, #2)2:00, #3)11:00, #4)10:00 10/21/2013 hipshkf NOTE: LEAK FOUND AT 6770' MANDREL 10/28/2012 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 110.0 110.0 63.00 WELDED SURFACE 7 5/8 6.87 28.8 2,976.3 2,440.2 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 6894' 5 1/2 4.95 25.9 7,585.7 5,745.8 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 6,883.7 Set Depth … 5,183.8 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) 23.8 23.8 0.04 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 522.8 522.7 3.18 NIPPLE 4.520 CAMCO LANDING DS NIPPLE CAMCO DS 2.875 2,527.8 2,203.1 56.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,921.1 3,612.5 41.11 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,096.3 4,543.5 36.38 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,770.3 5,091.7 35.55 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,820.0 5,132.0 35.61 SLEEVE-C 4.530 BAKER CMU SLIDING SLEEVE w/2.81" DS PROFILE (CLOSED 9/26/12) BAKER CMU 2.810 6,835.9 5,145.0 35.63 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,880.4 5,181.2 35.81 SEAL 4.000 BAKER SEAL ASSY w/G-22 LOCATOR BAKER 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) 7,155.3 5,403.8 36.21 CIBP CIBP MID-ELEMENT AT 7156' RKB, OAL 1.37' 7/25/2024 0.000 7,203.3 5,442.5 36.36 CIBP CIBP MID-ELEMENT AT 7204' RKB, OAL 1.37' (PLUG MOVED DOWNHOLE ~34' FROM ORIGINAL SET DEPTH OF 7170' RKB) 7/23/2024 0.000 7,463.6 5,649.8 37.97 Plug Catcher PLUG CATCHER SET IN 3.5" CASING 1/9/2002 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,527.8 2,203.1 56.91 1 GAS LIFT DMY DK1 1 0.0 1/22/2002 0.000 4,921.1 3,612.5 41.11 2 GAS LIFT DMY DK1 1 0.0 1/22/2002 0.000 6,096.3 4,543.5 36.38 3 GAS LIFT OV DK1 1 5/21/2018 0.313 6,770.3 5,091.7 35.55 4 GAS LIFT PATCH 1 0.0 2/16/2013 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,195.0 7,210.0 5,435.8 5,447.9 T-3, 2P-448A 1/27/2002 6.0 IPERF 2.5" HSC PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,195.0 7,210.0 1 FRAC 2/3/2002 0.0 0.00 0.00 7,195.0 7,210.0 1 RE-FRAC 12/4/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,118.0 7,155.3 5,373.7 5,403.8 Cement Plug Slickline dump bailed cement on top of CIBP 7/28/2024 2P-448A, 8/15/2024 5:06:45 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6894'; 25.9-7,585.7 Plug Catcher; 7,463.6 CIBP; 7,203.3 IPERF; 7,195.0-7,210.0 FRAC; 7,195.0 RE-FRAC; 7,195.0 CIBP; 7,155.3 Cement Plug; 7,118.0 ftKB TUBING; 6,782.5 GAS LIFT; 6,770.3 GAS LIFT; 6,096.3 GAS LIFT; 4,921.1 SURFACE; 28.8-2,976.3 GAS LIFT; 2,527.8 NIPPLE; 522.8 CONDUCTOR; 29.0-110.0 KUP PROD KB-Grd (ft) 33.01 RR Date 1/8/2002 Other Elev… 2P-448A ... TD Act Btm (ftKB) 7,593.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039601 Wellbore Status PROD Max Angle & MD Incl (°) 59.90 MD (ftKB) 3,380.68 WELLNAME WELLBORE2P-448A Annotation Last WO: End DateH2S (ppm) 50 Date 12/6/2016 Comment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Germann, Shane To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); O"Connor, Katherine Subject:RE: [EXTERNAL]DS-2P Surface casing shoe abandonment operations questions Date:Monday, September 30, 2024 3:20:07 PM Victoria, Greg Hobbs, Katherine O’Connor, and I compiled the answers in red to your questions below. They should fill in points that were made in prior meeting discussions but not fully captured. Let me know if anything further is needed. Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, September 30, 2024 11:28 AM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Germann, Shane <Shane.Germann@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov> Subject: [EXTERNAL]DS-2P Surface casing shoe abandonment operations questions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Greg, Shane, Outlined below are several requests/questions concerning the DS-2P future abandonments: 1. I know we have reviewed this question in meetings but would like a written response to this question: What are the advantages/disadvantages to using the production casing as the cementing string? Efficiency and reduction of pipe handling on-rig are the biggest advantages. Pulling the PC on each well would add a substantial amount of rig time and pipe handling for the crews throughout the entirety of the campaign. The only disadvantage of using the PC as the cementing string is the tighter annulus clearance which can increase the likelihood of cement contamination versus using a smaller string. Our goal is to utilize the PC successfully considering the changes we’re making to cement designs, but we’ll keep the option open to use a smaller string (most likely 3.5” tubing) if we’re seeing issues. 2. We had discussion concerning cutting the production casing 50’ below the surface casing shoe versus a deeper cut. There was some discussion on the value of logging prior to making the cut. Also, there was past experience information presented. Please provide information justifying the 50’ cut below the surface casing shoe. Experience with casing recovery operations have found that logs may not show the extent of formation collapse around casing that prevents it from being movable. The most recent example of this was 3S-626 where logs showed free pipe, but cement debris led to the pipe being pulled in 40-foot sections or less due to the cement debris around it that was not noted from the logging pass. Greg Hobbs brought extensive experience with slot recovery operations from BP. That experience found that recovery of casing deeper than 50 feet below the surface casing shoe became significantly harder with multiple cuts and jarring operations to retrieve the short sections of casing. This experience was replicated in the few slot recovery operations at Kuparuk in the past 10 years. The reflection of this experience during our meetings led to the intermediate casing cut point 50 feet below the surface shoe. 3. What modifications have been made in the cementing procedure for the surface casing shoe plug given the difficulties in setting the plug for 2P-415A? Here are the cement design and procedure changes we’re targeting for this campaign: a. Targeting a 150’ TVD cement height instead of MD b. Cement design- additives being utilized to help combat microannuli and improve bond to casing c. Improvements to wellbore cleanup techniques prior to pumping cement (surfactant wash targeting a minimum contact time) d. Batch mixing cement instead of mixing on the fly 4. If the well is suspended and the rig moved off, what are the plans, including timing for the non-rig abandonment? The general plan is to cleanout cement to the surface casing shoe using a coil underreamer. Then do a hesitation squeeze program with a fairly aggressive cement ramp, and lay in the same size plug as the rig laid in. Specific timing for this would be based on SIMOPS with the rig & excavation crew, but intention would be to follow the rig timing fairly closely. The hope is still to get these wells fully abandoned ASAP. 5. What are the timing plans for the surface abandonments included in these sundries? After the rig is successful abandoning the wells to surface, the excavation crew will be following ~4 wells behind to do the excavation and cuts. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From:Germann, Shane To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451 Date:Wednesday, September 25, 2024 2:52:29 PM Hi Victoria, That's correct, the depths provided are the top of the C-80. For the C-80 bottom depths, our geologist informed me to use the top of the C37 which should be picked on each of the logs I sent you. He said the C-37 marker is the next best correlative marker below the C-80 marker. I have provided those depths below: 2P-451 - 3556' RKB 2P-449 - 5119' RKB 2P-448A - 4594' RKB We are planning to have 15 sundries/wells will this type of SC shoe cement plug. Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 -----Original Message----- From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, September 25, 2024 1:48 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451 For the three sundries, please send me the C80 bottom depths, RKB. I'm assuming the depths provided are the top of the C-80? Also, how many sundries(wells) will have this type of plug at the SC shoe? -----Original Message----- From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Tuesday, September 17, 2024 9:11 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Victoria, I attached a PDF version of the slides I created for the 3 wells. Each well has a slide with its log and the desired annotations described below. Please let me know if you have any questions. Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 -----Original Message----- From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, September 13, 2024 3:08 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Shane, Please provide for each well a log showing the C-80 and the depths of the SC shoe, retainer, cement plug TOC, TOC outside PC and PC cut. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 1 Christianson, Grace K (OGC) From:Loepp, Victoria T (OGC) Sent:Monday, October 21, 2024 4:07 PM To:Christianson, Grace K (OGC) Subject:Fwd: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag Please PDF this email and add it to the 3 2P sundries in the Commissioners folders Thank you Sent from my iPhone Begin forwarded message: From: "Germann, Shane" <Shane.Germann@conocophillips.com> Date: October 21, 2024 at 3:57:14ௗPM AKDT To: "Loepp, Victoria T (OGC)" <victoria.loepp@alaska.gov> Cc: "Hobbs, Greg S" <Greg.S.Hobbs@conocophillips.com>, "O'Connor, Katherine" <Katherine.OConnor@conocophillips.com> Subject: RE: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag Hi Victoria, See below table for the data requested. This should cover the sundries submitted so far except for the 2P-434 which we’re checking pressures on. These pressures are the latest I had available which is from the most recent work done on the well. If more recent pressures are desired, please advise as we’ll have to request somebody take the readings. Keep in mind that other prep work being done on the wells may affect the T&IA pressures due to U-tubing, circ outs, temperature changes, etc. I’ll make sure to include this data for future submissions as well as show the actual TOC depths for previous plugs on the schematics. Well Name Previous plug tag depth (RKB) PT Result PT/Tag Date Tubing Pressure IA Pressure OA Pressure Date of Pressures 2P-451 3785' Pass 9/2/2024 50 psi 50 psi 75 psi 9/5/2024 2P-449 7187' Pass 9/2/2024 0 psi 75 psi 190 psi 9/3/2024 2P-448A 5076' Pass 10/5/2024 0 psi 0 psi 220 psi 10/6/2024 2P-443 3789' Pass 9/2/2024 0 psi 0 psi 175 psi 9/4/2024 2P-441 3846' Pass 10/5/2024 0 psi 0 psi 230 psi 10/17/2024 2P-438 6495' Pass 9/2/2024 0 psi 0 psi 175 psi 9/3/2024 Thanks, Shane Germann CTD/RWO Engineer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, October 21, 2024 12:36 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Shane, Please provide the following information for each 2P well abandonment sundry. 1. Date and results of passing state witnessed PT and tag of previous plug. 2. Current pressures of all annuli and tubing. Please provide for 2P-448A, 2P-449 and 2P-451 asap and follow with the others. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Suspend-Intermediate Plug 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7593'None Casing Collapse Structural Conductor Surface Intermediate Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9/10/2024 3-1/2" Packer: Baker seal Assy SSSV: None Perforation Depth MD (ft): L-80 2947' 7195-7210' (below cement plug) 7560' 5436-5448' (below cement plug) 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 110' 2976' 5746'7586' 16" 7-5/8" 81' 6884' MD 110' 2440' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 202-005 P.O. Box 100360, Anchorage, AK 99510 50-103-20396-01-00 Kuparuk River Field Meltwater Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6880' MD and 5181' 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-448A 5752' 7118' 5374' 7118' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU= Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.08.21 14:20:45-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor By Grace Christianson at 7:58 am, Aug 22, 2024 DSR-8/26/24 10-407X SFD 8/28/2024VTL 9/3/2024 X June 30, 2025 0 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.03 16:33:01 -08'00' 09/03/24 RBDMS JSB 090524 Procedure Wireline & Pumping 1. Punch tubing at ±6800’ RKB 2. Pump the following schedule taking returns up the IA: a. ±50 bbls surfactant wash b. ±150 bbls KWF c. ±31 bbls cement d. ±46 bbls KWF 3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 5300’ MD 4. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed) Eline/Relay 5. Cut tubing at ±3140’ RKB Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3-1/2" tubing 0 6800 3.5" 9.3# 2.99" 0.0087 6800 59.1 115.1 from punch depth 3-1/2" x 5-1/2" Annulus 0 6800 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 6800 80.9 84.0 from punch depth Tubing Cement 5300 6800 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1 Annular Cement 5300 6800 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0 2P-448A Suspension Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-448A was a producer shut-in in mid 2021. It has no known tubing or IA integrity issues. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 7/04/2018 = 1259 psi at 5400’ TVD = 0.233 psi/ft MASP = 719 psi Suspended with passing MIT-T 8/9/24 Patch set in 2013, leak 0.5 bpm @ 925 psi. 2P-448A Well Suspension Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 56 bbls of 15.8# Cement Calculated TOC @ 4,635' KB Production Casing: 5.5" x 3.5" @ 6,894' KB, 15.5# x 9.3#, L-80 BTCM Set @ 7,585.7’ KB T-3 Peforations: @ 7,195'– 7,210' KB (15') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,976.3' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,883.7' KB 1 2 4 7 5 6 Item Depth - tops (KB) 1 FMC GEN V Tubing Hanger 23.8' 2 Camco Landing DS Nipple 522.8' 3 Tubing Leak in GLM 6,770' 4 Baker CMU Sliding Sleeve w/ 2.81" DS Profile (closed 9/26/12)6,820' 5 Camco D Nipple 6,835.9' 6 Baker Seal Assembly w/ G-22 Locator 6,880.4' 7 Plug Catcher set in 3.5" casing 7,463.6' C80 @ 2980' KB C80 @ 2980' KB Plug #1 – Reservoir TOC ±7118' RKB 3 Plug #2 – Intermediate TOC ±5300' RKB BOC @ ±6800' RKB CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:O"Connor, Katherine To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]RE: DS-2P Intermediate plug sundries Date:Tuesday, September 3, 2024 2:08:14 PM Yes - MASPS should all be zero. My perspective for having MASP there was just thinking about KWF and force of habit for calculating surface pressure. Here is a table of data requested. All witnessed tests passed. Prod/Inj Well Tubing Size PC Size Fluid Weight Well Suspended Tag Depth Pressure Test MASP Prod 2P-406 3.5 5.5 8.6 6862 1500 0 Prod 2P- 424A 3.5 5.5 8.6 10599 1500 0 inj 2P-427 3.5 5.5 10.7 9569 1500 0 inj 2P-432 3.5 7 10.2 5683 1500 0 Prod 2P-441 3.5 5.5 8.6 6848 1500 0 inj 2P-447 4.5 7 10.9 7509 1500 0 Prod 2P- 448A 3.5 5.5 8.6 7118 1500 0 Thanks, Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) -----Original Message----- From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, September 3, 2024 11:30 AM To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Subject: [EXTERNAL]RE: DS-2P Intermediate plug sundries 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. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,219.0 2P-448A 12/28/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement on CIBP 2P-448A 7/28/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Mandrel Orientation: #1)9:30, #2)2:00, #3)11:00, #4)10:00 10/21/2013 hipshkf NOTE: LEAK FOUND AT 6770' MANDREL 10/28/2012 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 110.0 110.0 63.00 WELDED SURFACE 7 5/8 6.87 28.8 2,976.3 2,440.2 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 6894' 5 1/2 4.95 25.9 7,585.7 5,745.8 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 6,883.7 Set Depth … 5,183.8 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) 23.8 23.8 0.04 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 522.8 522.7 3.18 NIPPLE 4.520 CAMCO LANDING DS NIPPLE CAMCO DS 2.875 2,527.8 2,203.1 56.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,921.1 3,612.5 41.11 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,096.3 4,543.5 36.38 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,770.3 5,091.7 35.55 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,820.0 5,132.0 35.61 SLEEVE-C 4.530 BAKER CMU SLIDING SLEEVE w/2.81" DS PROFILE (CLOSED 9/26/12) BAKER CMU 2.810 6,835.9 5,145.0 35.63 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,880.4 5,181.2 35.81 SEAL 4.000 BAKER SEAL ASSY w/G-22 LOCATOR BAKER 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) 7,155.3 5,403.8 36.21 CIBP CIBP MID-ELEMENT AT 7156' RKB, OAL 1.37' 7/25/2024 0.000 7,203.3 5,442.5 36.36 CIBP CIBP MID-ELEMENT AT 7204' RKB, OAL 1.37' (PLUG MOVED DOWNHOLE ~34' FROM ORIGINAL SET DEPTH OF 7170' RKB) 7/23/2024 0.000 7,463.6 5,649.8 37.97 Plug Catcher PLUG CATCHER SET IN 3.5" CASING 1/9/2002 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,527.8 2,203.1 56.91 1 GAS LIFT DMY DK1 1 0.0 1/22/2002 0.000 4,921.1 3,612.5 41.11 2 GAS LIFT DMY DK1 1 0.0 1/22/2002 0.000 6,096.3 4,543.5 36.38 3 GAS LIFT OV DK1 1 5/21/2018 0.313 6,770.3 5,091.7 35.55 4 GAS LIFT PATCH 1 0.0 2/16/2013 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,195.0 7,210.0 5,435.8 5,447.9 T-3, 2P-448A 1/27/2002 6.0 IPERF 2.5" HSC PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,195.0 7,210.0 1 FRAC 2/3/2002 0.0 0.00 0.00 7,195.0 7,210.0 1 RE-FRAC 12/4/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,118.0 7,155.3 5,373.7 5,403.8 Cement Plug Slickline dump bailed cement on top of CIBP 7/28/2024 2P-448A, 8/15/2024 10:28:44 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6894'; 25.9-7,585.7 FLOAT COLLAR; 7,493.5- 7,494.5 PROD w/Landing Plate; 7,462.0- 7,493.5 Plug Catcher; 7,463.6 CIBP; 7,203.3 RE-FRAC; 7,195.0 FRAC; 7,195.0 IPERF; 7,195.0-7,210.0 CIBP; 7,155.3 Cement Plug; 7,118.0 ftKB CSR; 6,874.1-6,893.5 SEAL; 6,880.4 LOCATOR; 6,873.0-6,874.1 SBE; 6,862.8-6,873.0 NIPPLE; 6,835.9 SLEEVE-C; 6,820.0 GAS LIFT; 6,770.3 GAS LIFT; 6,096.3 GAS LIFT; 4,921.1 SURFACE; 28.8-2,976.3 FLOAT SHOE; 2,974.8-2,976.3 FLOAT COLLAR; 2,886.1- 2,887.4 GAS LIFT; 2,527.8 PORT COLLAR; 970.7-973.2 NIPPLE; 522.8 CONDUCTOR; 29.0-110.0 HANGER; 28.8-31.7 HANGER; 25.9-28.2 HANGER; 23.8 KUP PROD KB-Grd (ft) 33.01 RR Date 1/8/2002 Other Elev… 2P-448A ... TD Act Btm (ftKB) 7,593.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039601 Wellbore Status PROD Max Angle & MD Incl (°) 59.90 MD (ftKB) 3,380.68 WELLNAME WELLBORE2P-448A Annotation Last WO: End DateH2S (ppm) 50 Date 12/6/2016 Comment SSSV: NIPPLE 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" B 110' 7-5/8" L-80 2440' 5-1/2" L-80 5192' 3-1/2" L-80 5746' 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 6880' MD/ 5181' TVD (seal assembly) 6894' SIZE DEPTH SET (MD) 7586' 26' 5192' 62.5# 29.7# 110' 26' Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 7118' -7155' MD 0.26 bbl Class G Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing SUSPENDED 7195-7210' MD and 5436-5448' TVD (below cement plug) Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information PACKER SET (MD/TVD) 42" 9-7/8" 64.9 bbls AS I 29'391 sx AS Lite, 202 sx LiteCrete 9.3# 29' 6894' 2976'29' 29' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 15.5# WT. PER FT.GRADE 1/13/2002 CEMENTING RECORD 5866144 1488' MD/ 1458' TVD SETTING DEPTH TVD 5865859 TOP HOLE SIZE AMOUNT PULLED 441000 441007 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM Kuparuk River Field/ Meltwater Oil Pool- Suspended N/A 9. Ref Elevations: KB: 30' 50-103-20396-01-00 KRU 2P-448A ADL0373112 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM 1240' FSL, 931' FEL, Sec. 18, T8N, R7E, UM ALK 4998 1/9/2002 7593' MD/ 5752' TVD 7118' MD/ 5374' TVD P.O. Box 100360, Anchorage, AK 99510-0360 443543 5868859 1525' FSL, 949' FEL, Sec. 18, T8N, R7E, UM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 8/9/2024 ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, included above6.75" TUBING RECORD 56 bbls Class G6.75" 6884' MD3-1/2" CASING Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 14. Permit to Drill Number / Sundry: 202-005/ 323-599 By James Brooks at 3:56 pm, Aug 15, 2024 Suspended 8/9/2024 JSB RBDMS JSB 081624 xG DSR-8/27/24 Susp SFD 3/25/2025 253' SFD Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1488' 1458' 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 Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Authorized Name and Authorized Title: Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A- Suspended Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.08.15 15:24:19-08'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,219.0 2P-448A 12/28/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Dump bailed cement on CIBP 2P-448A 7/28/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: Mandrel Orientation: #1)9:30, #2)2:00, #3)11:00, #4)10:00 10/21/2013 hipshkf NOTE: LEAK FOUND AT 6770' MANDREL 10/28/2012 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 110.0 110.0 63.00 WELDED SURFACE 7 5/8 6.87 28.8 2,976.3 2,440.2 29.70 L-80 BTCM PRODUCTION 5.5"x3.5" @ 6894' 5 1/2 4.95 25.9 7,585.7 5,745.8 15.50 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 6,883.7 Set Depth … 5,183.8 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) 23.8 23.8 0.04 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 522.8 522.7 3.18 NIPPLE 4.520 CAMCO LANDING DS NIPPLE CAMCO DS 2.875 2,527.8 2,203.1 56.91 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 4,921.1 3,612.5 41.11 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,096.3 4,543.5 36.38 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,770.3 5,091.7 35.55 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900 6,820.0 5,132.0 35.61 SLEEVE-C 4.530 BAKER CMU SLIDING SLEEVE w/2.81" DS PROFILE (CLOSED 9/26/12) BAKER CMU 2.810 6,835.9 5,145.0 35.63 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,880.4 5,181.2 35.81 SEAL 4.000 BAKER SEAL ASSY w/G-22 LOCATOR BAKER 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) 7,155.3 5,403.8 36.21 CIBP CIBP MID-ELEMENT AT 7156' RKB, OAL 1.37' 7/25/2024 0.000 7,203.3 5,442.5 36.36 CIBP CIBP MID-ELEMENT AT 7204' RKB, OAL 1.37' (PLUG MOVED DOWNHOLE ~34' FROM ORIGINAL SET DEPTH OF 7170' RKB) 7/23/2024 0.000 7,463.6 5,649.8 37.97 Plug Catcher PLUG CATCHER SET IN 3.5" CASING 1/9/2002 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,527.8 2,203.1 56.91 1 GAS LIFT DMY DK1 1 0.0 1/22/2002 0.000 4,921.1 3,612.5 41.11 2 GAS LIFT DMY DK1 1 0.0 1/22/2002 0.000 6,096.3 4,543.5 36.38 3 GAS LIFT OV DK1 1 5/21/2018 0.313 6,770.3 5,091.7 35.55 4 GAS LIFT PATCH 1 0.0 2/16/2013 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,195.0 7,210.0 5,435.8 5,447.9 T-3, 2P-448A 1/27/2002 6.0 IPERF 2.5" HSC PJ Chgs, 60 deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,195.0 7,210.0 1 FRAC 2/3/2002 0.0 0.00 0.00 7,195.0 7,210.0 1 RE-FRAC 12/4/2004 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 7,118.0 7,155.3 5,373.7 5,403.8 Cement Plug Slickline dump bailed cement on top of CIBP 7/28/2024 2P-448A, 8/15/2024 10:28:44 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6894'; 25.9-7,585.7 FLOAT COLLAR; 7,493.5- 7,494.5 PROD w/Landing Plate; 7,462.0- 7,493.5 Plug Catcher; 7,463.6 CIBP; 7,203.3 RE-FRAC; 7,195.0 FRAC; 7,195.0 IPERF; 7,195.0-7,210.0 CIBP; 7,155.3 Cement Plug; 7,118.0 ftKB CSR; 6,874.1-6,893.5 SEAL; 6,880.4 LOCATOR; 6,873.0-6,874.1 SBE; 6,862.8-6,873.0 NIPPLE; 6,835.9 SLEEVE-C; 6,820.0 GAS LIFT; 6,770.3 GAS LIFT; 6,096.3 GAS LIFT; 4,921.1 SURFACE; 28.8-2,976.3 FLOAT SHOE; 2,974.8-2,976.3 FLOAT COLLAR; 2,886.1- 2,887.4 GAS LIFT; 2,527.8 PORT COLLAR; 970.7-973.2 NIPPLE; 522.8 CONDUCTOR; 29.0-110.0 HANGER; 28.8-31.7 HANGER; 25.9-28.2 HANGER; 23.8 KUP PROD KB-Grd (ft) 33.01 RR Date 1/8/2002 Other Elev… 2P-448A ... TD Act Btm (ftKB) 7,593.0 Well Attributes Field Name MELTWATER Wellbore API/UWI 501032039601 Wellbore Status PROD Max Angle & MD Incl (°) 59.90 MD (ftKB) 3,380.68 WELLNAME WELLBORE2P-448A Annotation Last WO: End DateH2S (ppm) 50 Date 12/6/2016 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 7/18/2024 CHANGE WELL TYPE MOBILIZE CTU #11 TO 2P. SPOT UP RIG UP. RIH WITH LIMAR SPEAR, 2.3-2.4" CATCH, RIH TO MIDNIGHT DEPTH OF 6,700'. - JOB IN PROGRESS 7/19/2024 CHANGE WELL TYPE UNABLE TO LATCH UPPER PATCH PACKER. POOH AND RECONFIGURE LIMAR SPEAR WITH 3.437-2.562' COLLETS. RIH AND LATCH UPPER PATCH PACKER @ 6748", HIT 11 30 K LBS OVER JAR LICKS, CAME FREE. PULLED MIDDLE SPACER PIPE, PULLED LOWER PACKER @ 6799', DRIFT FOR CIBP DOWN TO 7220'. WELL READY FOR SLICKLINE. 7/23/2024 CHANGE WELL TYPE LOAD IA W/ 68 BBLS CISW & 24 BBLS DIESEL, LOAD TBG W/ 55 CISW AND 18 BBLS DIESEL. SET CIBP MID-ELEMENT AT 7170' RKB. LRS PUMPED 93 BBLS DIESEL POST PLUG SET AND NEVER CAUGHT PRESSURE, LRS RELOADED AND PUMPED AN ADDITIONAL 72 BBLS DIESEL (165 BBLS TOTAL PUMPED AFTER PLUG SET) AND NEVER CAUGHT PRESSURE. JOB POSTPONED FOR PLAN FORWARD 7/23/2024 CHANGE WELL TYPE LOAD TBG & IA PUMPED 93 BBLS DSL DWN TBG WHILE ASSISTING E-LINE PUMPED 72 BBLS DSL DWN TBG FOR A TOTAL OF 165 BBLS DSL PUMPED NO PRESSURE INCREASE OBSERVED DURING PUMPING OPERATIONS JOB COMPLETE 7/25/2024 CHANGE WELL TYPE LOAD IA W/ 68 BBLS CISW & 24 BBLS DIESEL, LOAD TBG W/ 45 CISW AND 18 BBLS DIESEL. PREVIOUS PLUG MOVED DOWN HOLE 34', TAGGED PLUG AT 7204'. SET CIBP MID-ELEMENT AT 7156' RKB. AFTER PLUG SET LRS PUMPED 30 BBLS DIESEL DOWN IA AND PRESSURED UP TO 1500 PSI. TBG PRESSURE STAYED AT 0 PSI. IA LLR ESTABISHED AT 0.65 BPM AT 1500 PSI. SWAP TO TUBING AND PUMP 4 BBLS AND CAUGHT PRESSURE, IA SLOWLY CLIMBING. PERFORM 1500 PSI CMIT-TxIA (PASS). JOB COMPLETE, READY FOR SLICKLINE 7/26/2024 CHANGE WELL TYPE TAG CIBP @ 7155' RKB, DUMP BAIL ONE (10' X 2.50'') BAILER OF CEMENT ON TOP OF CIBP @ 7155' RKB, LDFN. JOB IN PROGRESS 7/27/2024 CHANGE WELL TYPE DUMP BAIL SIX (10' X 2.50'') BAILERS OF CEMENT ON TOP OF CEMENT TAG @ 7148' RKB (ESTIMATED TOP OF CEMENT @ 7126' RKB) LDFN. JOB IN PROGRESS 7/28/2024 CHANGE WELL TYPE TAG TOP OF CEMENT @ 7113' RKB (42' OF CEMENT ON TOP OF CIBP), RDMO. 8/9/2024 CHANGE WELL TYPE AOGCC WITNESSED STATE WITNESS (AUSTIN McLEOD) TAG TOC @ 7118' RKB. PERFORM PASSING CMIT TO 1500 PSI. READY FOR NEXT P&A STEPS. 2P-448 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: 7593 ft MD Lease No.: ADL 0373112 Operator Rep: Suspend: X P&A: NA Conductor: 16" O.D. Shoe@ 110 Feet Csg Cut@ NA Feet Surface: 7-5/8" O.D. Shoe@ 2976 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@ 7586 Feet Csg Cut@ NA Feet Liner: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet Tubing: 3-1/2" O.D. Tail@ 6884 Feet Tbg Cut@ NA Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Tubing Bridge plug 7155 ft MD 7118 ft MD 10.9/6.7 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 1730 1680 1670 IA 1780 1750 1740 OA 355 339 329 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Mike Scoles Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to location to witness the tag and mechanical integrity test (MIT) of the bottom perforation isolating plug inside the wells production casing. The cement plug on top of the cast iron bridge plug (7155 ft MD) was dumped bailed on 7/26/24. Using a generic 2-1/4 inch slickline string they tagged the plug at 7118 ft MD (inclination 36°) with multiple hard set downs. A passing MIT was then done to a target of 1500psi. Top perforation at 7195 ft MD. August 9, 2024 Austin McLeod Well Bore Plug & Abandonment Kuparuk River Unit 2P-448A ConocoPhillips Alaska, Inc. PTD 2020050; Sundry 323-599 none Test Data: CMIT-TxIA P Casing Removal: rev. 3-24-2022 2024-0809_Plug_Verification_KRU_2P-448A_am 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 99 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.24 15:10:59 -08'00' ORIGINATED TRANSMITTAL DATE: 8/8/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4954 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4954 2P-448A 50103203960100 Plug Setting Record 25-Jul-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 202-005 T39385 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.08 13:26:07 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com ORIGINATED TRANSMITTAL DATE: 7/24/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4950 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4950 2P-448A 50103203960100 Plug Setting Record 23-Jul-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 202-005 T39274 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.24 11:29:47 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com 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): 7593'None Casing Collapse Structural Conductor Surface Intermediate Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-3718 Well Interventions Engineer KRU 2P-448A 5752' 7593' 5752' None N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: katherine.oconnor@conocophillips.com AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6880' MD and 5181' TVD 6749' MD and 5074' TVD 6799' MD and 5115" TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0373112 202-005 P.O. Box 100360, Anchorage, AK 99510 50-103-20396-01-00 Kuparuk River Field Meltwater Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Meltwater Oil Pool - Suspended TVD Burst 6884' MD 110' 2440' 110' 2976' 5746'7586' 16" 7-5/8" 81' 2947' 7195-7210' 7560' 5436-5448' 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 11/20/2023 3-1/2" Packer: Baker seal Assy Packer: WFD WidePac LE Patch Packer Packer: WFD WidePac LE Patch Packer SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:15 am, Nov 06, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU =Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.11.06 07:37:37-09'00' Foxit PDF Editor Version: 12.1.2 Katherine O'Connor 323-599 SFD 11/8/2023 X 10-407 12/31/24 X DSR-11/8/23VTL 11/14/2023*&:JLC 11/17/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.17 13:13:04 -09'00'11/17/23 RBDMS JSB 112023 2P-448A Suspension Date Wrien: 10-03-23 Execu on Date: Nov 20, 2023 Prepared by: Katherine O’Connor (214-684-7400) Background & Objecve 2P-448A was a producer shut-in in mid 2021. It has no known tubing or IA integrity issues. This well is ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024. Well Data Reservoir pressure 7/04/2018 = 1259 psi at 5400’ TVD MASP = 719 psi Last TD tag 12/28/2017 @ 7219’ KB Well has history of parrafin Procedure Wireline & Pumping 1. Pull patch from 6748’ – 6799’ KB 2. Drift with dummy CIBP to TD. If unable to get within 50’ of perforations, contact Katherine O’Connor 3. Fluid pack tubing & IA as necessary with KWF and freeze protect 4. Set CIBP @ ±7,170’ RKB (must be set within 50’ of the top of perforations). 5. Perform CMIT-TxIA to 1500 psi, record results 6. Dump bail at least 30’ of cement on top of CIBP 7. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance 8. RIH and tag TOC, approx. 7,140’ RKB (MUST BE AOGCC WITNESSED) 9. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED) 10. Perform DDT to 0 psi and record results DHD 1. Schedule wellsite inspection within 12 months of suspension approval 2P-448A Well Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 56 bbls of 15.8# Cement Calculated TOC @ 4,635' KB Production Casing: 5.5" x 3.5" @ 6,894' KB, 15.5# x 9.3#, L-80 BTCM Set @ 7,585.7’ KB T-3 Peforations: @ 7,195'– 7,210' KB (15') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,976.3' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,883.7' KB 1 2 4 7 5 6 3 Item Depth - tops (KB) 1 FMC GEN V Tubing Hanger 23.8' 2 Camco Landing DS Nipple 522.8' 3 56' Patch 6,748.6' 4 Baker CMU Sliding Sleeve w/ 2.81" DS Profile (closed 9/26/12)6,820' 5 Camco D Nipple 6,835.9' 6 Baker Seal Assembly w/ G-22 Locator 6,880.4' 7 Plug Catcher set in 3.5" casing 7,463.6' C80 @ 2980' KB C80 @ 2980' KB 2P-448A Well Suspension Schematic Conductor: 16" Conductor 110' KB Production Casing Cement: 56 bbls of 15.8# Cement Calculated TOC @ 4,635' KB Production Casing: 5.5" x 3.5" @ 6,894' KB, 15.5# x 9.3#, L-80 BTCM Set @ 7,585.7’ KB T-3 Peforations: @ 7,195'– 7,210' KB (15') Surface Casing: 7-5/8", 29.7#, L-80 BTCM Set @ 2,976.3' KB Production Tubing: 3 ½”, 9.3# L-80 EUE-8rd Set @ 6,883.7' KB 1 2 4 7 5 6 Item Depth - tops (KB) 1 FMC GEN V Tubing Hanger 23.8' 2 Camco Landing DS Nipple 522.8' 3 Tubing Leak in GLM 6,770' 4 Baker CMU Sliding Sleeve w/ 2.81" DS Profile (closed 9/26/12)6,820' 5 Camco D Nipple 6,835.9' 6 Baker Seal Assembly w/ G-22 Locator 6,880.4' 7 Plug Catcher set in 3.5" casing 7,463.6' C80 @ 2980' KB C80 @ 2980' KB Plug #1 – Reservoir TOC ±7140' RKB 3 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. ¿J~2 1rJ~ Well History File # ~ ~ /&1je3 , Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes. No DVD's - # Diskettes - # - Oversized Material Added to LaserFiche File Other #- Yes No Yes No Yes No Maps #- Mud Logs # - General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us SCANNED JUL 2 6 2004 • l z-,'— 446 A P Z©zc a 5u Regg, James B (DOA) From: Regg, James B (DOA) 4-11q((,5 Sent: Friday, April 19, 2013 5:34 PM (1 To: 'NSK Problem Well Supv'; Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Cc: Nenahlo, Thomas L Subject: RE: 2P -448A Weekly Report 4 -19 -2013 You may discontinue sending weekly reports. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 SCANNED Jul, 0 8 2 013 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617C.conocophillips.com] Sent: Friday, April 19, 2013 7:58 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Cc: Nenahlo, Thomas L Subject: 2P -448A Weekly Report 4 -19 -2013 All, Attached is the weekly report for 2P -448A. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 • • � . ZP 44-8A P1 Z uz00 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, April 19, 2013 7:58 AM � 4 1 ( � To: Regg, James B (DOA); Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Cc: Nenahlo, Thomas L Subject: 2P -448A Weekly Report 4 -19 -2013 Attachments: 2P -448A 4- 19- 2013.pptx; 2P -448A 4- 19- 2013.xlsx All, Attached is the weekly report for 2P -448A. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 Kett Zi'- 446A ZgavoSG OA Injectivity Tests w/ Diesel 2P -448A Bleed Events 2P -448A 1600 120 III 1400 - - 100 T e 1200 e - so 4 E MO ■ // - 6 4 .. ! 800 \ a Or g 600 4. i ` 20 _ -- - IA Pressure N° 400 --- -OA Pressure —T I 200 _ —Choke Setting - 0 5 • -- Product ion Temp 0 , -20 S � \i 1 ��' <� � �' \� 1� 1 � 13 11 13 1. 13 1 by a1`O1 AT al ° � a n1 0 IA a� I • ►< & ZP 44-6A PP 2U zso t Regg, James B (DOA) Sent: Tuesday, April Thomas 16 2013 8 19 AM enahlo @conocophillips.com] S � c} ¢If((t3 To: Regg, James B (DOA); NSK Problem Well Supv l Cc: Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Subject: RE: KRU 2P -448A Weekly Report Jim - Please find our response to your questions below pertaining to Meltwater well 2P -448A: Are there plans to further evaluate 2P -448A based on repressure cycle and bleed frequency observed? What has been done to minimize operational risk and improve future operations? ConocoPhillips is currently evaluating the feasibility of conducting testing to determine the potential volume of the gas that is charging the outer annuli in wells 2P -431 and 2P -448A. For the near term, Operations has instituted a policy to shut in any well at Meltwater that has an outer annulus pressure greater than 950 psi and increasing. These outer annuli will continue to be monitored through use of pressure transducers with alarm set points to alert operators of pressure increases. Please let me know if you have any further questions! Thanks, Thomas Nenahlo Drill Site Petroleum Engineer 2T (Kuparuk & Tabasco) & 2P (Meltwater) North Slope Operations & Development ConocoPhillips Alaska Anchorage: (907) 265 -6934 Mobile: (720) 273 -2685 From: Regg, James B (DOA) [mailto:jim.regg@ alaska.gov] Sent: Monday, April 15, 2013 12:23 PM To: NSK Problem Well Supv Cc: Nenahlo, Thomas L; Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: KRU 2P -448A Weekly Report KRU 2P -448A PTD 2020050 "The wellhead pressures will continue to be monitored for pressure build up and further evaluation if needed." (CPAI, 3/11/13 email) "The events of March 4 -9, challenged us find solutions that minimized operational risk to the field. We learn from this type of event in order to improve our operations in the future." (CPAI, 3/15/13 email) Thank you for providing the monitored TIO pressures data for the past 4 weeks. Data indicates that CPAI continues to bleed OA pressures to maintain below 1000psi. Bleed frequency has been inconsistent , occurring up to once every 8 1 • • days. Before AOGCC decides to replace the weekly reporting obligation (established 3/12/134) with the monthly reporting obligation included in A1O 21.001, CPAI will need to address the following: Are - there plans to further evaluate 2P -448A based on repressure cycle and bleed frequency observed? - What has been done to minimize operational risk and improve future operations? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: NSK Problem Well Supv [ mailto :n1617@conocophillips.com] Sent: Friday, April 12, 2013 4:14 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Cc: Nenahlo, Thomas L Subject: KRU 2P -448A Weekly Report All, Attached is the weekly report for 2P -448A. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 2 PTA 201-0050 Regg, James B (DOA) From: Regg, James B (DOA) �� 113 Sent: Monday, April 15, 2013 12:23 PM To: 'NSK Problem Well Supv' Cc: Nenahlo, Thomas L; Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Subject: RE: KRU 2P -448A Weekly Report KRU 2P -448A PTD 2020050 "The wellhead pressures will continue to be monitored for pressure build up and further evaluation if needed." (CPAI, 3/11/13 email) "The events of March 4 -9, challenged us find solutions that minimized operational risk to the field. We learn from this type of event in order to improve our operations in the future." (CPAI, 3/15/13 email) Thank you for providing the monitored TIO pressures data for the past 4 weeks. Data indicates that CPAI continues to bleed OA pressures to maintain below 1000psi. Bleed frequency has been inconsistent , occurring up to once every 8 days. Before AOGCC decides to replace the weekly reporting obligation (established 3/12/134) with the monthly reporting obligation included in AIO 21.001, CPAI will need to address the following: - Are there plans to further evaluate 2P -448A based on repressure cycle and bleed frequency observed? - What has been done to minimize operational risk and improve future operations? Jim Regg AOGCC SCANNED jut 0 8 2013 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: NSK Problem Well Supv [ mailto :n1617@conocophillips.com] Sent: Friday, April 12, 2013 4:14 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Cc: Nenahlo, Thomas L Subject: KRU 2P -448A Weekly Report All, Attached is the weekly report for 2P -448A. Please let me kn if you have any questions. i Brent Rogers / Kelly Lyons / Problem Wells Supervisor ConocoPhillips Alaska, Inc. i Desk Phone (907) 659 -7224 / Pager (907) 659 -7000 pgr. 909 r/ 1 rat 2Y pm z-0 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, April 12, 2013 4:14 PM 2 l 1 �J(3 To: Regg, James B (DOA); Wallace, Chris D (DOA); Schwartz, Guy L (DOA) Cc: Nenahlo, Thomas L Subject: KRU 2P -448A Weekly Report Attachments: 2P -448A 4- 11- 2013.pptx; 2P -448A 4- 11- 2013.xlsx All Attached is the weekly report for 2P -448A. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor Conoco Phillips Alaska, Inc. SCANNED Jul 0 8 Z013 Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 1 au zp - g46/k Pr Z Oo C 4( +Z(t3 2P -448A Bleed Events 2P-448A —' 1600 - - 120 1400 — 100 Ti 1200 - - 80 3 ..dire" el E 1000 60 G a 800 - a - 20 0 __,....1•..-Atile amid puma.' I A - 40 3 400 —.— IA Pressure �, ......e u ---OA Pressure I a 200 —Choke Sett ing - 0 u — Product ion Te m p • 0 - r— — - , — ■ ■ -20 Q�V' �Q �� A � A � A� A 4 P � A� �� � Q0 AO ,� �,1l 413 � 3�3 A �ti� 1 b.\ \ DO A a \ p� A� 1�`1 Kg--ft z ?— 4 415A, Th 2,� P s Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, April 05, 2013 4:48 PM To: Regg, James B (DOA) i` , Cc: NSK Problem Well Supv; Nenahlo, Thomas L ti Subject: 2P -448A Weekly report Attachments: 2P -448A 4- 4- 2013.pptx; 2P -448A 4- 4- 2013.xlsx Jim, Attached are copies of the 2P -448A weekly report. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 SCANNED JUL 0 2013 ■ L<Rk.t '- 4463A P7 z 4 11 i 2P -448A Bleed Events • 2P -448A 140D _ 160 — IA Pressure 1200 —OA Pressu re .1 - 140 € • • Choke Setting s I Prod ud ion Tem p - 120 S 1000 f ' , ii i • 100 s s 800 - -�;:� ! "�� a I I� ► Mme" a ,� i _...r �..r.� .•mi 1 __ MI s 600 IIPPIIIIIIIIIIIIIIIIIt - 60 u. 400 - 40 1 1 200 - 20 u • 0 O p Q O V 4 PO ° P� P� P� JCV 1"I' 1 1�' 3 1 I ' ,�1ti ,,,'4 ,01:. 3S1' ,, y 1� 1 � ,L 3�1� �l�y 1L'1�1 3`��11 ,3 A�11 0" AO K&( z?-tea. • • Pit 2 07_00 .5c e James B R 9g, . DOA � From: NSK Problem Well Supv (n1617 @conocophillips.com] Sent: Friday, March 29, 2013 1:52 PM To: Regg, James B (DOA) . f 4 3i ( 3 Subject: 2P -448A (PTD 202 -005) Weekly Report 03 -29 -13 Attachments: 2P -448A 3- 28- 2013.pptx; 2P -448A 3- 28- 2013.xlsx Jim, Attached is the weekly report for 2P -448A (PTD 202 -005). Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 SCANNED JUL 1 0 2013 2D zo05c 2P -448A Bleed Evel 2P-448A 1400 - __ 1 • CIA Pressure •OA Pressure ( 1 1200 - Choke Setting - Product ion Temp ' 1 1000 1a l • 800 f - �M � �.� killigr ' ` up a * 600 ` o s s C 400 V . le! , , � • Or e r' • . .•.- - I -,R- w "���! 1 x I ■ M ii 200 - 20 i • . 0 ,1 y1 1 � 11 , 1 � ; . ' 0 ' . 1.t,. • • • 2P-48A 2 wY V Date & Time Choke Setting Production Temp MI Lift Rate IA Pressure OA Pressure (F) (MSCFD) (PSIG) (PSIG) 3/13/09 11:59 AM 96 50 0 655 819 3/13/09 12:59 PM 96 46 0 646 812 3/13/09 1:59 PM 96 45 0 643 809 3/13/09 2:59 PM 96 43 0 642 809 3/13/09 3:59 PM 96 41 0 643 810 3/13/09 4:59 PM 96 41 0 647 813 3/13/09 5:59 PM 96 45 0 654 820 3/13/09 6:59 PM 96 50 0 668 834 3/13/09 7:59 PM 96 47 0 658 829 3/13/09 8:59 PM 96 45 0 654 826 3/13/09 9:59 PM 96 42 0 654 825 3/13/09 10:59 PM 96 41 0 655 826 3/13/09 11:59 PM 96 42 0 655 827 3/14/09 12:59 AM 96 41 0 655 828 3/14/09 1:59 AM 96 42 0 655 829 3/14/09 2:59 AM 96 41 0 656 830 3/14/09 3:59 AM 96 39 0 658 832 3/14/09 4:59 AM 96 39 0 662 836 3/14/09 5:59 AM 96 44 0 672 844 3/14/09 6:59 AM 96 53 0 690 864 3/14/09 7:59 AM 96 47 0 676 856 3/14/09 8:59 AM 96 46 0 672 852 3/14/09 9:59 AM 96 42 0 672 850 3/14/09 10:59 AM 96 41 0 673 852 3/14/09 11:59 AM 96 42 0 673 853 3/14/09 12:59 PM 96 42 0 673 853 3/14/09 1:59 PM 96 41 0 674 854 3/14/09 2:59 PM 96 42 0 675 856 3/14/09 3:59 PM 96 42 0 675 856 3/14/09 4:59 PM 96 40 0 678 859 3/14/09 5:59 PM 96 42 0 685 865 3/14/09 6:59 PM 96 53 0 709 886 3/14/09 7:59 PM 96 48 0 696 882 3/14/09 8:59 PM 96 46 0 691 876 3/14/09 9:59 PM 96 41 0 690 874 3/14/09 10:59 PM 96 41 0 692 876 3/14/09 11:59 PM 96 42 0 693 877 3/15/09 12:59 AM 96 42 0 694 879 3/15/09 1:59 AM 96 42 0 694 880 3/15/09 2:59 AM 96 42 0 695 881 3/15/09 3:59 AM 96 42 0 695 882 3/15/09 4:59 AM 96 42 0 696 883 3/15/09 5:59 AM 96 41 0 698 885 3/15/09 6:59 AM 96 41 0 702 889 3/15/09 7:59 AM 96 49 0 723 904 3/15/09 8:59 AM 96 48 0 721 910 3/15/09 9:59 AM 96 45 0 712 902 3/15/09 10:59 AM 96 42 0 710 899 3/15/09 11:59 AM 96 41 0 710 899 ICl/ 3/15/09 12:59 PM 96 42 0 709 899 3/15/09 1:59 PM 96 44 0 708 898 3/15/09 2:59 PM 96 41 0 709 899 3/15/09 3:59 PM 96 41 0 712 901 3/15/09 4:59 PM 96 42 0 716 905 3/15/09 5:59 PM 96 44 0 721 910 3/15/09 6:59 PM 96 47 0 727 916 3/15/09 7:59 PM 96 47 0 729 919 3/15/09 8:59 PM 56 125 0 734 938 3/15/09 9:59 PM 28 106 0 727 939 3/15/09 10:59 PM 30 89 0 723 927 3/15/09 11:59 PM 45 76 0 724 923 3/16/09 12:59 AM 99 52 0 744 934 3/16/09 1:59 AM 99 53 0 738 934 3/16/09 2:59 AM 99 53 0 732 928 3/16/09 3:59 AM 99 53 0 730 926 3/16/09 4:59 AM 99 51 0 729 925 3/16/09 5:59 AM 99 48 0 730 925 3/16/09 6:59 AM 99 46 0 730 925 3/16/09 7:59 AM 99 45 0 731 926 3/16/09 8:59 AM 99 43 0 733 927 3/16/09 9:59 AM 99 42 0 744 933 3/16/09 10:59 AM 99 52 0 766 569 3/16/09 11:59 AM 99 49 0 751 687 3/16/09 12:59 PM 99 49 0 745 752 3/16/09 1:59 PM 99 46 0 744 754 3/16/09 2:59 PM 93 43 0 745 758 3/16/09 3:59 PM 99 45 0 753 766 3/16/09 4:59 PM 99 47 0 757 773 3/16/09 5:59 PM 99 47 0 755 776 3/16/09 6:59 PM 99 46 0 752 777 3/16/09 7:59 PM 99 44 0 751 779 3/16/09 8:59 PM 99 43 0 752 782 3/16/09 9:59 PM 99 42 0 753 785 3/16/09 10:59 PM 99 41 0 755 788 3/16/09 11:59 PM 99 42 0 759 793 3/17/09 12:59 AM 99 44 0 761 797 3/17/09 1:59 AM 99 44 0 759 798 3/17/09 2:59 AM 99 44 0 760 800 3/17/09 3:59 AM 99 43 0 759 802 3/17/09 4:59 AM 99 42 0 760 804 3/17/09 5:59 AM 99 40 0 763 807 3/17/09 6:59 AM 99 42 0 767 811 3/17/09 7:59 AM 99 43 0 766 814 3/17/09 8:59 AM 99 42 0 765 815 3/17/09 9:59 AM 99 45 0 762 815 3/17/09 10:59 AM 99 42 0 769 819 3/17/09 11:59 AM 99 41 0 772 823 3/17/09 12:59 PM 99 43 0 774 827 3/17/09 1:59 PM 99 43 0 774 829 3/17/09 2:59 PM 99 43 0 773 830 3/17/09 3:59 PM 99 41 0 775 831 3/17/09 4:59 PM 99 42 0 779 835 3/17/09 5:59 PM 99 43 0 780 839 3/17/09 6:59 PM 99 45 0 779 840 3/17/09 7:59 PM 99 44 0 779 839 3/17/09 8:59 PM 99 47 0 784 843 3/17/09 9:59 PM 99 50 0 787 847 il z/.7 • • 3/17/09 10:59 PM 99 52 0 790 851 3/17/09 11:59 PM 99 55 0 788 852 3/18/09 12:59 AM 99 58 0 786 852 3/18/09 1:59 AM 99 56 0 787 854 3/18/09 2:59 AM 99 52 0 792 857 3/18/09 3:59 AM 99 53 0 795 861 3/18/09 4:59 AM 99 53 0 800 866 3/18/09 5:59 AM 99 56 0 799 867 3/18/09 6:59 AM 99 57 0 796 867 3/18/09 7:59 AM 99 52 0 798 868 3/18/09 8:59 AM 99 51 0 800 871 3/18/09 9:59 AM 99 52 0 801 681 3/18/09 10:59 AM 99 51 0 800 465 3/18/09 11:59 AM 99 52 0 802 345 3/18/09 12:59 PM 99 50 0 804 355 3/18/09 1:59 PM 99 48 0 805 363 3/18/09 2:59 PM 99 48 0 804 371 3/18/09 3:59 PM 99 47 0 805 379 3/18/09 4:59 PM 99 45 0 806 387 3/18/09 5:59 PM 99 44 0 806 394 3/18/09 6:59 PM 99 43 0 810 401 3/18/09 7:59 PM 99 45 0 810 408 3/18/09 8:59 PM 99 45 0 807 414 3/18/09 9:59 PM 99 43 0 807 419 3/18/09 10:59 PM 99 41 0 810 425 3/18/09 11:59 PM 99 41 0 813 431 3/19/09 12:59 AM 99 42 0 817 438 3/19/09 1:59 AM 99 44 0 813 442 3/19/09 2:59 AM 99 45 0 811 446 3/19/09 3:59 AM 99 44 0 811 450 3/19/09 4:59 AM 99 40 0 813 455 3/19/09 5:59 AM 99 39 0 827 462 3/19/09 6:59 AM 99 44 0 826 469 3/19/09 7:59 AM 99 44 0 823 472 3/19/09 8:59 AM 99 43 0 825 477 3/19/09 9:59 AM 99 43 0 829 482 3/19/09 10:59 AM 99 44 0 834 488 3/19/09 11:59 AM 99 46 0 836 493 3/19/09 12:59 PM 99 45 0 835 497 3/19/09 1:59 PM 99 45 0 836 501 3/19/09 2:59 PM 99 45 0 840 506 3/19/09 3:59 PM 99 47 0 848 512 3/19/09 4:59 PM 99 51 0 871 524 3/19/09 5:59 PM 99 50 0 861 528 3/19/09 6:59 PM 99 47 0 854 529 3/19/09 7:59 PM 99 46 0 851 531 3/19/09 8:59 PM 99 46 0 852 534 3/19/09 9:59 PM 99 47 0 856 539 3/19/09 10:59 PM 99 47 0 859 544 3/19/09 11:59 PM 99 46 0 856 546 3/20/09 12:59 AM 82 45 0 852 548 3/20/09 1:59 AM 91 43 0 850 550 3/20/09 2:59 AM 99 41 0 851 554 3/20/09 3:59 AM 99 42 0 855 558 3/20/09 4:59 AM 99 43 0 854 561 3/20/09 5:59 AM 99 45 0 852 563 3/20/09 6:59 AM 99 43 0 854 566 3/20/09 7:59 AM 99 42 0 858 571 • • '3/20/09 8:59 AM 99 43 0 858 574 3/20/09 9:59 AM 99 43 0 858 577 3/20/09 10:59 AM 99 44 0 857 580 3/20/09 11:59 AM 99 44 0 855 583 3/20/09 12:59 PM 99 41 0 858 586 3/20/09 1:59 PM 99 43 0 866 591 3/20/09 2:59 PM 99 44 0 863 594 3/20/09 3:59 PM 99 43 0 862 597 3/20/09 4:59 PM 99 44 0 860 599 3/20/09 5:59 PM 99 45 0 859 601 3/20/09 6:59 PM 99 42 0 864 605 3/20/09 7:59 PM 99 44 0 873 611 3/20/09 8:59 PM 99 44 0 868 613 3/20/09 9:59 PM 56 86 0 668 628 3/20/09 10:59 PM 30 142 0 780 646 3/20/09 11:59 PM 27 112 1131 948 641 3/21/09 12:59 AM 76 62 735 1253 644 3/21/09 1:59 AM 99 62 0 766 656 3/21/09 2:59 AM 99 60 0 832 651 3/21/09 3:59 AM 99 58 0 857 647 3/21/09 4:59 AM 99 57 0 870 647 3/21/09 5:59 AM 99 56 0 878 647 3/21/09 6:59 AM 99 52 0 884 649 3/21/09 7:59 AM 99 50 0 887 651 3/21/09 8:59 AM 99 47 0 894 654 3/21/09 9:59 AM 99 44 0 907 656 3/21/09 10:59 AM 99 46 0 918 664 3/21/09 11:59 AM 99 53 0 892 678 3/21/09 12:59 PM 99 47 0 920 675 3/21/09 1:59 PM 99 46 0 934 675 3/21/09 2:59 PM 99 46 0 946 677 3/21/09 3:59 PM 99 46 0 958 678 3/21/09 4:59 PM 99 45 0 967 679 3/21/09 5:59 PM 99 45 0 975 681 3/21/09 6:59 PM 99 45 0 982 682 3/21/09 7:59 PM 99 43 0 993 685 3/21/09 8:59 PM 99 44 0 995 687 3/21/09 9:59 PM 99 43 0 999 688 3/21/09 10:59 PM 99 41 0 1007 691 3/21/09 11:59 PM 99 43 0 1011 694 3/22/09 12:59 AM 99 41 0 1017 695 3/22/09 1:59 AM 99 41 0 1022 698 3/22/09 2:59 AM 99 42 0 1022 700 3/22/09 3:59 AM 99 39 0 1035 703 3/22/09 4:59 AM 99 42 0 1044 708 3/22/09 5:59 AM 99 43 0 1047 710 3/22/09 6:59 AM 99 44 0 1046 711 3/22/09 7:59 AM 99 43 0 1047 712 3/22/09 8:59 AM 99 45 0 1049 714 3/22/09 9:59 AM 99 47 0 1051 715 3/22/09 10:59 AM 99 47 0 1051 717 3/22/09 11:59 AM 99 45 584 1112 719 3/22/09 12:59 PM 99 43 676 1091 732 3/22/09 1:59 PM 99 48 668 768 745 3/22/09 2:59 PM 99 51 671 731 507 3/22/09 3:59 PM 99 51 667 695 415 3/22/09 4:59 PM 99 50 675 681 422 3/22/09 5:59 PM 99 49 675 668 428 Pi 4/7 • • ' 3/22/09 6:59 PM 99 48 672 659 433 3/22/09 7:59 PM 99 46 671 651 437 3/22/09 8:59 PM 99 45 670 647 442 3/22/09 9:59 PM 99 44 673 645 446 3/22/09 10:59 PM 99 43 680 642 450 3/22/09 11:59 PM 99 43 681 642 454 3/23/09 12:59 AM 99 42 683 640 458 3/23/09 1:59 AM 99 42 684 639 462 3/23/09 2:59 AM 99 41 681 636 466 3/23/09 3:59 AM 99 41 679 637 469 3/23/09 4:59 AM 99 41 680 635 473 3/23/09 5:59 AM 99 41 683 635 476 3/23/09 6:59 AM 99 40 690 636 480 3/23/09 7:59 AM 99 40 691 635 483 3/23/09 8:59 AM 99 40 696 634 487 3/23/09 9:59 AM 99 40 695 635 490 3/23/09 10:59 AM 99 40 692 633 494 3/23/09 11:59 AM 99 40 691 633 497 3/23/09 12:59 PM 99 40 686 630 501 3/23/09 1:59 PM 99 40 686 630 504 3/23/09 2:59 PM 99 40 683 629 507 3/23/09 3:59 PM 99 41 676 617 511 3/23/09 4:59 PM 99 40 674 617 515 3/23/09 5:59 PM 99 41 666 618 518 3/23/09 6:59 PM 99 40 663 615 521 3/23/09 8:59 PM 99 41 663 614 527 3/23/09 9:59 PM 99 41 662 609 531 3/23/09 10:59 PM 99 41 660 606 535 3/23/09 11:59 PM 99 41 662 611 538 3/24/09 12:59 AM 99 40 666 611 541 3/24/09 1:59 AM 99 40 660 610 544 3/24/09 2:59 AM 99 40 659 609 547 3/24/09 3:59 AM 99 40 660 609 550 3/24/09 4:59 AM 99 41 656 607 553 3/24/09 5:59 AM 99 40 654 608 556 3/24/09 6:59 AM 99 40 654 607 559 3/24/09 7:59 AM 99 41 653 608 561 3/24/09 8:59 AM 99 41 651 611 564 3/24/09 9:59 AM 99 41 649 613 567 3/24/09 10:59 AM 99 41 651 613 570 3/24/09 11:59 AM 99 41 648 611 573 3/24/09 12:59 PM 99 42 653 615 575 3/24/09 1:59 PM 99 41 655 616 578 3/24/09 2:59 PM 99 40 651 618 581 3/24/09 3:59 PM 99 42 654 618 584 3/24/09 4:59 PM 99 42 652 631 586 3/24/09 5:59 PM 99 41 654 634 589 3/24/09 6:59 PM 99 42 647 631 592 3/24/09 7:59 PM 99 42 650 624 595 3/24/09 8:59 PM 99 42 647 622 598 3/24/09 9:59 PM 99 42 646 627 600 3/24/09 10:59 PM 99 42 648 634 603 3/24/09 11:59 PM 99 41 646 627 606 3/25/09 12:59 AM 99 41 645 633 608 3/25/09 1:59 AM 99 42 644 631 611 3/25/09 2:59 AM 99 41 643 637 613 3/25/09 3:59 AM 99 40 642 647 615 3/25/09 4:59 AM 99 42 640 639 618 P5 C77 • • ' 3/25/09 5:59 AM 99 42 639 632 621 3/25/09 6:59 AM 99 41 641 633 623 3/25/09 7:59 AM 99 43 642 693 624 3/25/09 8:59 AM 99 45 644 877 622 3/25/09 9:59 AM 99 39 645 795 627 3/25/09 10:59 AM 99 41 645 647 634 3/25/09 11:59 AM 99 40 644 642 638 3/25/09 12:59 PM 99 42 643 636 641 3/25/09 1:59 PM 99 41 642 633 644 3/25/09 2:59 PM 99 42 642 641 646 3/25/09 3:59 PM 99 46 634 803 642 3/25/09 4:59 PM 99 39 628 697 648 3/25/09 5:59 PM 99 42 625 626 654 3/25/09 6:59 PM 99 42 622 630 656 3/25/09 7:59 PM 99 41 623 622 659 3/25/09 8:59 PM 99 41 620 641 660 3/25/09 9:59 PM 99 39 620 647 665 3/25/09 10:59 PM 99 42 623 622 667 3/25/09 11:59 PM 99 41 621 618 669 3/26/09 12:59 AM 99 39 621 622 671 3/26/09 1:59 AM 99 37 624 637 674 3/26/09 2:59 AM 99 39 626 618 677 3/26/09 3:59 AM 99 40 625 623 679 3/26/09 4:59 AM 99 39 625 638 679 3/26/09 5:59 AM 99 44 620 797 676 3/26/09 6:59 AM 99 38 619 696 682 3/26/09 7:59 AM 99 41 619 633 688 3/26/09 8:59 AM 99 40 617 626 691 3/26/09 9:59 AM 99 41 620 628 694 3/26/09 10:59 AM 99 40 618 638 695 3/26/09 11:59 AM 99 43 619 782 691 3/26/09 12:59 PM 99 42 621 642 699 3/26/09 1:59 PM 99 42 621 629 702 3/26/09 2:59 PM 99 40 623 626 705 3/26/09 3:59 PM 99 39 764 639 707 3/26/09 4:59 PM 99 39 994 671 711 3/26/09 5:59 PM 99 39 1000 670 715 3/26/09 6:59 PM 99 39 997 664 717 3/26/09 7:59 PM 99 39 994 659 720 3/26/09 8:59 PM 99 39 996 656 722 3/26/09 9:59 PM 99 40 997 654 724 3/26/09 10:59 PM 99 41 995 658 725 3/26/09 11:59 PM 99 41 931 649 727 3/27/09 12:59 AM 99 41 899 642 728 3/27/09 1:59 AM 99 39 899 663 728 3/27/09 2:59 AM 99 39 899 676 731 3/27/09 3:59 AM 99 39 895 676 732 3/27/09 4:59 AM 99 41 891 765 731 3/27/09 5:59 AM 99 44 883 948 728 3/27/09 6:59 AM 99 46 878 1026 726 3/27/09 7:59 AM 99 46 872 1079 727 3/27/09 8:59 AM 99 44 864 1116 728 3/27/09 9:59 AM 99 41 863 1142 728 3/27/09 10:59 AM 99 42 858 1165 730 • • I — 1 2P-448A 1400 — _- --- - - -- 160 —IA Pressure 1 —OA Pressure 1200 140 u —Choke Setting 2. Production Temp 120 y 1000 -- --- -_. - ..._.-- — -.... - -- a 1 A I tU ~ F,2 _ — I . 100 c N 800 I � �- _ . _ . .g o a` 80 1 a QS :::. � 8 5 60 •. i _. • • IP • IP. be S 1 ao rw t a o 200 _.. 20 i o 0 0Q`� e�' e� e�' e 1 1 1 11 ,i ',I NT �\1� \ °a -,,v ,,,v, �\1-� °a 3�19\� 3\ry1`°A 3 �ti3`°•' ��tih` ° PI 7/7 • Er( zP 8A Prb ZoZOoso Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] ce.€1�, 31 141 13 Sent: Friday, March 15, 2013 5:20 PM To: Regg, James B (DOA) Cc: Dethlefs, Jerry C; Nenahlo, Thomas L; Wallace, Chris D (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA); CPF1&2 Ops Supt; CPF2 Ops Supv; Bradley, Stephen D; NSK Problem Well Supv; Fleming, Gavin; CPF2 Prod Engrs Subject: RE: KRU 2P-448A(PTD 202-005) Report of OA SCP Attachments: 2P-448A 3-15-2013.pptx; 2P-448A OA data 03-15-13.xlsx Jim, SCAM ED E11.. 2U1 The attached Excel file contains a table and graph with the data that you have requested. ConocoPhillips will provide the AOGCC with an update of this data on Friday of each week, as requested. ConocoPhillips Well Operating Guidelines are utilized to ensure compliance with CO 494, Rule 6 by requiring "For producing wells, the Sustained Casing Pressure (SCP) Conservation Orders, rule 6, require that "...before a shut-in well is placed in service, any annulus pressure must be relieved to a sufficient degree (a) that the inner annulus pressure at operating temperature will be below 2000 psig and(b) that the outer annulus pressure at operating temperature will be • below 1000 psig."Essentially this means that bleeding the annuli may be required prior to putting a well in service so the resulting stabilized pressure does not exceed the annuli maximum limits of 2000/1000 psi." We fully understand the imperative to operate all of our wells within regulations. In this particular case, we faced multiple significant challenges that required us to assess risks associated with various scenarios and execute work in a manner that best ensured personnel safety and environmental protection. We attempted to mitigate the overall risk to the field as best we could, based upon the information we had available at the time. Some of the factors that resultedin the OA pressure • • 48A exc--•••• •- S u u • maximum, between 3/4/2013 and 3/9/2013 include the following (please also see the attached annotated graph): Weil�, htst j of 4j4 PresS� 50 sk.eQ Le a- ,7 61eed Ic 40 5 cti 1 G1ecdrom • Prior to bringing the well online the OA had remained at 906 psig for several weeks. This well is known to have a charging OA that typically remains -900 psig when the well is online. This was believed to be the normal operating pressure for the OA which led to the decision to not_perform an extended bleed prior to bringing the well on production. The thermal effects were expected to be minimal and suspected to be relieved through the open OA shoe to formation. -A-OGCC n4eS ref LAi,se (ems toc4re ("11 t ex 00164 4'r--h ( ak. • The weather began to deteriorate on 3/4 including high winds and drifting snow that r'sulted in vehicle travel restrictions until 3/9. • Within 1 hour of the OA pressure exceeding 1000 psig, high winds caused a power line to go down resulting in loss of high line power to 6 drillsites, including DS2P. To ensure the integrity of piping for all of the wells and pipelines associated with those drillsites, installation of portable generators on those six pads was given top priority. The loss of electrical power at DS2P also resulted in the shut down of the drillsite line heater. The cross- country produced oil pipeline from DS2P is susceptible to cooling temperatures without that line heater and the fluid produced by 2P-448A was beneficial to maintaining that pipeline temperature until we could determine that power and the line heater could be restored at DS2P. • We SI 2P-448A at 18:50 on 3/4 and conducted the first of 5 OA bleeds that occurred 3/4- 3/5. After each of these bleeds the OA pressure rapidly rose and 2P-448A was determined to be a problem well that required an extended bleed and potential downhole diagnostics. Prior to 3/9, consideration was given to shutting in the well since personnel were not able to conduct an extended bleed of the OA. Shutting in the well was determined to be more risky than leaving it online since drifting snow did not allow crews to travel to DS2P to freeze protect the well. An extended bleed was conducted on 2P-448A on 3/9, as soon as improving weather and available personnel allowed it to be accomplished. • Between 3/4 and 3/9, Operations personnel and euipment were fully utilized to maintain power at eleven CPF2 drillsites in order to minimize_the overall risks to nurlerells and facilities. Significant activities also included restoring water injection to three drillsites on 3/8. L cf, -bro itJ- tie(( c Vfte 64b R°Sbvtrces i vl Dkce_ 4v 1 cel b lYZR44, 4. t\ ? - - . 4 • • ConocoPhillips takes seriously the responsibility to operate the Kuparuk field in a safe manner that protects people and the environment. The events of March 4-9, challenged us find solutions that minimized operational risk to the field. We learn from this type of event in order to improve our operations in the future. Please let us know if you would like additional information. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907)659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, March 12, 2013 10:01 AM To: NSK Problem Well Supv Cc: Dethlefs, Jerry C; Nenahlo, Thomas L; Wallace, Chris D (DOA); Roby, David S (DOA); Schwartz, Guy L(DOA) Subject: [EXTERNAL]RE: KRU 2P-448A (PTD 202-005) Report of OA SCP AOGCC requires more details about this. - Need table of OA pressures, particularly in the time of interest beginning just prior to when pressures spiked (return to production?) - Updates shall be provided to AOGCC weekly(first update due 3/15/13)with results of IA and OA pressure monitoring and production; document all bleeds - Describe how your startup procedures comply with Conservation Order 494, Rule 6: o "Except as otherwise approved by the AOGCC under paragraph 4 or 5 of these rules, before a shut-in well is placed in service, any annulus pressure must be relieved to a sufficient degree (a)that the inner annulus pressure at operating temperature will be below 2000 psig and (b)that the outer annulus pressure at operating temperature will be below 1000 psig. However, a well that is subject to paragraph 3, but not paragraph 5, of these rules may reach an annulus pressure at operating temperature that is described in the operator's notification to the AOGCC under paragraph 3, unless the AOGCC prescribes a different limit." If you have questions, contact Chris Wallace (793-1250) or me. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 r' From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Monday, March 11, 2013 8:31 AM To: Schwartz, Guy L (DOA); Wallace, Chris D (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; Dethlefs, Jerry C; Nenahlo, Thomas L Subject: KRU 2P-448A (PTD 202-005) Report of OA SCP Jim, Chris, Guy Meltwater gaslifted producer 2P-448A(PTD 202-005)was repo •d with SCP on the OA on 03/07/13. The initial TIO pressures were 200/600/1035. The well had just been retur -: to production on 03/04/13 following a tubing patch that was set to repair TxIA communication. Immediate OA ble-ding was attempted however due to deteriorating weather conditions and high winds an extended bleed was una• e to be completed. The high winds caused multiple power failures resulting in immediate attention required by the ope =tor. On 03/09/13 an extended bleed was performed and the OA was 2 a • • o N 0 J (j)aan�eiadwai uo!PnpoJd/(00i-0)2u!;ias ajoy� N 0 0 0 0 0 .-1 N 00 co V N O 4Ga ao. a co r 9l F` J aO. ,t 1 es r II Al J n — I a. 4 v o5n H 4 O. JI ` ,5 ._ Co v a Y -a Cr il a a t o ,n I I I I Fla a 11L_....6,L,, , F i Q r► 00 1 1 -_ ; 1 as a es NI i 4 co co i I •ors _- t a _' as III,I 1 F `so. 4 i 0 0 0 O 0 0 0 0-4 0 0 s 0 ti Fr (8!sd)aanssaJd vo'8 vi (-' 0 • • t J) 8 00:0 £Z/SZ/£ E 00:0 £Z/tit/£ 00:0 £Z/£Z/£ 000 £Z/ZT/£ 00:0 £Z/ZZ/£ CD L y �N 00.0 £Z/OZ/£ Cl)A C7 @ -� N N 3N a M W a -oo_, p_ E c c N m --- 0 L a) a� d3 J0 �a 00:0 £Z 16/£ to **" c.6(7) o C o) 7N C20 O C N J 03 ON . 0 U a N 3 O c Y 00:0 £Z/8/£ (.'O a) 0 Q ro a "N 00.0 £Z/L/£ L °„,'cn dp @0 N urts 4.0 CL ca 0'O 00L 00- — o� o� N �, 00:0 £Z 19/£ CO co E N � a Tr o 0 -I 00:0 £Z/S/£ c C i',, m � moi N • �j �o c a CD s CO o 3 g _ — 00:0 £Z/ti/£ a o) a) r-- a) a) 3 l c . O)• a) (7) (‘) •c w ' •- a o_ o M ° 00:0 £1/£/£ a tea) - ci50•• 00:0 £Z/Z/£ 00:0 £Z/Z/£ 0 0 0 0 0 0 0 0 N 00 00 0 0° CNI (Sisd) ainssaid dO • • 2P-448A (PM 7 0-z-o0So) Date&Time Choke Setting Production Temp MI Lift Rate IA Pressure OA Pressure (F) (MSCFD) (PSIG) (PSIG) 2/28/13 3:59 PM 1 72 0 465 905 2/28/13 4:59 PM 1 72 0 465 905 2/28/13 5:59 PM 1 73 0 465 905 2/28/13 6:59 PM 1 73 0 466 905 2/28/13 7:59 PM 1 74 0 466 905 2/28/13 8:59 PM 1 74 0 466 905 2/28/13 9:59 PM 1 74 0 467 905 2/28/13 10:59 PM 1 74 0 467 905 2/28/13 11:59 PM 1 74 0 467 905 3/1/13 12:59 AM 1 74 0 467 905 3/1/13 1:59 AM 1 74 0 468 905 3/1/13 2:59 AM 1 74 0 468 905 3/1/13 3:59 AM 1 74 0 468 905 3/1/13 4:59 AM 1 74 0 468 905 3/1/13 5:59 AM 1 75 0 469 905 3/1/13 6:59 AM 1 75 0 469 905 3/1/13 7:59 AM 1 76 0 469 905 3/1/13 8:59 AM 1 76 0 469 905 3/1/13 9:59 AM 1 76 0 470 905 3/1/13 10:59 AM 1 76 0 470 906 3/1/13 11:59 AM 1 74 0 471 906 3/1/13 12:59 PM 1 70 0 470 906 3/1/13 1:59 PM 1 66 0 470 906 3/1/13 2:59 PM 1 63 0 470 906 3/1/13 3:59 PM 1 60 0 470 906 3/1/13 4:59 PM 1 57 0 470 906 3/1/13 5:59 PM 1 55 0 471 906 3/1/13 6:59 PM 1 52 0 471 906 3/1/13 7:59 PM 1 50 0 471 906 3/1/13 8:59 PM 1 49 0 471 906 3/1/13 9:59 PM 1 47 0 471 906 3/1/13 10:59 PM 1 46 0 471 906 3/1/13 11:59 PM 1 44 0 471 906 3/2/13 12:59 AM 1 43 0 472 906 3/2/13 1:59 AM 1 42 0 472 906 3/2/13 2:59 AM 1 40 0 472 906 3/2/13 3:59 AM 1 39 0 472 906 3/2/13 4:59 AM 1 38 0 473 906 3/2/13 5:59 AM 1 38 0 473 906 3/2/13 6:59 AM 1 37 0 473 906 3/2/13 7:59 AM 1 36 0 473 906 3/2/13 8:59 AM 1 36 0 474 906 3/2/13 9:59 AM 1 35 0 474 906 3/2/13 10:59 AM 1 31 0 474 906 3/2/13 11:59 AM 1 26 0 474 906 3/2/13 12:59 PM 1 21 0 474 906 3/2/13 1:59 PM 1 19 0 474 906 3/2/13 2:59 PM 1 17 0 474 906 3/2/13 3:59 PM 1 15 0 474 905 3/2/13 4:59 PM 1 14 0 475 906 3/2/13 5:59 PM 1 13 0 475 905 3/2/13 6:59 PM 1 12 0 475 905 3/2/13 7:59 PM 1 13 0 475 905 3/2/13 8:59 PM 1 15 0 476 905 KRU 2P-448A Page 1 of 6 • • 3/2/13 9:59 PM 1 17 0 476 905 3/2/13 10:59 PM 1 19 0 477 905 3/2/13 11:59 PM 1 19 0 477 905 3/3/13 12:59 AM 1 20 0 477 905 3/3/13 1:59 AM 1 20 0 478 905 3/3/13 2:59 AM 1 21 0 478 905 3/3/13 3:59 AM 1 21 0 478 905 3/3/13 4:59 AM 1 21 0 479 905 3/3/13 5:59 AM 1 21 0 479 905 3/3/13 6:59 AM 1 21 0 479 905 3/3/13 7:59 AM 1 21 0 480 905 3/3/13 8:59 AM 1 21 0 480 906 3/3/13 9:59 AM 1 16 0 481 906 3/3/13 10:59 AM 1 11 0 480 905 3/3/13 11:59 AM 1 10 0 542 906 3/3/13 12:59 PM 1 10 0 613 906 3/3/13 1:59 PM 1 11 0 614 906 3/3/13 2:59 PM 1 12 0 336 905 3/3/13 3:59 PM 1 13 0 353 905 3/3/13 4:59 PM 1 14 0 357 905 3/3/13 5:59 PM 1 22 0 357 905 3/3/13 6:59 PM 1 29 0 358 905 3/3/13 7:59 PM 1 35 0 359 905 3/3/13 8:59 PM 1 39 0 360 905 3/3/13 9:59 PM 1 44 0 360 905 3/3/13 10:59 PM 1 47 0 361 906 3/3/13 11:59 PM 1 50 0 361 905 3/4/13 12:59 AM 1 52 0 362 906 3/4/13 1:59 AM 1 55 0 363 906 3/4/13 2:59 AM 1 57 0 363 906 3/4/13 3:59 AM 1 58 0 363 906 3/4/13 4:59 AM 1 59 0 364 906 3/4/13 5:59 AM 1 60 0 364 906 3/4/13 6:59 AM 1 62 0 365 906 3/4/13 7:59 AM 2 63 0 365 906 3/4/13 8:59 AM 22 53 5 435 928 3/4/13 9:59 AM 23 56 491 995 974 3/4/13 10:59 AM 28 73 0 909 1000 3/4/13 11:59 AM 34 77 0 794 1018 3/4/13 12:59 PM 37 77 0 705 1028 3/4/13 1:59 PM 37 75 0 665 1036 3/4/13 2:59 PM 37 74 0 655 1044 3/4/13 3:59 PM 60 74 0 631 1056 3/4/13 4:59 PM 97 73 0 614 1068 3/4/13 5:59 PM 97 72 0 608 1080 3/4/13 6:59 PM 96 71 0 600 1090 3/4/13 7:59 PM 72 61 0 595 993 3/4/13 8:59 PM 70 68 0 610 711 3/4/13 9:59 PM 97 69 0 614 851 3/4/13 10:59 PM 97 69 0 616 868 3/4/13 11:59 PM 97 69 0 618 883 3/5/13 12:59 AM 97 68 0 593 896 3/5/13 1:59 AM 97 68 0 569 908 3/5/13 2:59 AM 97 68 0 569 919 3/5/13 3:59 AM 97 67 0 564 929 3/5/13 4:59 AM 97 67 0 561 939 3/5/13 5:59 AM 97 66 0 562 948 3/5/13 6:59 AM 97 65 0 563 956 KRU 2P-448A Page 2 of 6 . • • 3/5/13 7:59 AM 97 65 0 556 965 3/5/13 8:59 AM 97 65 0 552 972 3/5/13 9:59 AM 97 64 0 559 979 3/5/13 10:59 AM 97 63 0 560 986 3/5/13 11:59 AM 97 63 0 557 992 3/5/13 12:59 PM 97 63 0 560 999 3/5/13 1:59 PM 97 62 0 561 845 3/5/13 2:59 PM 97 62 0 565 963 3/5/13 3:59 PM 97 61 0 564 961 3/5/13 4:59 PM 97 60 0 575 736 3/5/13 5:59 PM 97 60 0 570 932 3/5/13 6:59 PM 97 60 0 568 939 3/5/13 7:59 PM 97 60 0 574 945 3/5/13 8:59 PM 97 60 0 554 928 3/5/13 9:59 PM 97 59 0 545 554 3/5/13 10:59 PM 97 58 0 546 703 3/5/13 11:59 PM 97 58 0 547 894 3/6/13 12:59 AM 97 58 0 549 900 3/6/13 1:59 AM 97 57 0 550 907 3/6/13 2:59 AM 97 57 0 551 913 3/6/13 3:59 AM 97 57 0 553 919 3/6/13 4:59 AM 97 56 0 554 924 3/6/13 5:59 AM 97 56 0 555 930 3/6/13 6:59 AM 97 56 0 556 935 3/6/13 7:59 AM 97 55 0 556 935 3/6/13 8:59 AM 90 38 0 547 929 3/6/13 9:59 AM 30 42 0 552 932 3/6/13 10:59 AM 95 55 0 561 949 3/6/13 11:59 AM 96 55 0 563 955 3/6/13 12:59 PM 96 54 0 566 961 3/6/13 1:59 PM 96 55 0 568 966 3/6/13 2:59 PM 96 55 0 571 971 3/6/13 3:59 PM 96 55 0 573 976 3/6/13 4:59 PM 96 54 0 575 980 3/6/13 5:59 PM 96 54 0 576 984 3/6/13 6:59 PM 96 54 0 578 988 3/6/13 7:59 PM 96 54 0 580 992 3/6/13 8:59 PM 96 53 0 581 996 3/6/13 9:59 PM 96 53 0 583 999 3/6/13 10:59 PM 96 53 0 584 1002 3/6/13 11:59 PM 96 53 0 586 1005 3/7/13 12:59 AM 96 52 0 587 1008 3/7/13 1:59 AM 96 52 0 588 1011 3/7/13 2:59 AM 96 52 0 590 1015 3/7/13 3:59 AM 96 51 0 591 1017 3/7/13 4:59 AM 96 51 0 592 1020 3/7/13 5:59 AM 96 51 0 593 1023 3/7/13 6:59 AM 96 52 0 596 1026 3/7/13 7:59 AM 96 49 0 595 1027 3/7/13 8:59 AM 96 49 0 597 1030 3/7/13 9:59 AM 96 51 0 599 1033 3/7/13 10:59 AM 96 49 0 599 1036 3/7/13 11:59 AM 96 50 0 602 1039 3/7/13 12:59 PM 96 50 0 603 1042 3/7/13 1:59 PM 96 48 0 603 1042 3/7/13 2:59 PM 96 48 0 605 1046 3/7/13 3:59 PM 96 45 0 602 1042 3/7/13 4:59 PM 96 49 0 607 1049 KRU 2P-448A Page 3 of 6 • • 3/7/13 5:59 PM 96 42 0 601 1044 3/7/13 6:59 PM 96 40 0 598 1040 3/7/13 7:59 PM 96 38 0 598 1038 3/7/13 8:59 PM 96 38 0 598 1039 3/7/13 9:59 PM 96 41 0 602 1041 3/7/13 10:59 PM 96 52 0 617 1063 3/7/13 11:59 PM 96 48 0 615 1064 3/8/13 12:59 AM 96 48 0 617 1067 3/8/13 1:59 AM 96 47 0 619 1069 3/8/13 2:59 AM 96 47 0 620 1072 3/8/13 3:59 AM 96 47 0 621 1074 3/8/13 4:59 AM 96 46 0 621 1074 3/8/13 5:59 AM 96 47 0 624 1078 3/8/13 6:59 AM 96 47 0 624 1079 3/8/13 7:59 AM 96 47 0 626 1081 3/8/13 8:59 AM 96 46 0 627 1083 3/8/13 9:59 AM 96 46 0 627 1083 3/8/13 10:59 AM 96 46 0 630 1087 3/8/13 11:59 AM 96 46 0 631 1089 3/8/13 12:59 PM 96 46 0 632 1090 3/8/13 1:59 PM 96 43 0 630 1088 3/8/13 2:59 PM 96 48 0 636 1095 3/8/13 3:59 PM 96 41 0 629 1088 3/8/13 4:59 PM 96 39 0 626 1083 3/8/13 5:59 PM 96 37 0 624 1080 3/8/13 6:59 PM 96 41 0 629 1083 3/8/13 7:59 PM 96 48 0 642 1101 3/8/13 8:59 PM 96 40 0 633 1093 3/8/13 9:59 PM 96 38 0 630 1087 3/8/13 10:59 PM 96 36 0 629 1085 3/8/13 11:59 PM 96 35 0 629 1084 3/9/13 12:59 AM 96 37 0 630 1085 3/9/13 1:59 AM 96 51 0 651 1107 3/9/13 2:59 AM 96 44 0 646 1109 3/9/13 3:59 AM 96 39 0 640 1101 3/9/13 4:59 AM 96 36 0 637 1095 3/9/13 5:59 AM 96 35 0 636 1093 3/9/13 6:59 AM 96 38 0 640 1094 3/9/13 7:59 AM 96 49 0 658 1118 3/9/13 8:59 AM 96 40 0 648 1109 3/9/13 9:59 AM 96 37 0 644 1102 3/9/13 10:59 AM 96 35 0 643 917 3/9/13 11:59 AM 96 35 0 643 1077 3/9/13 12:59 PM 96 34 0 641 520 3/9/13 1:59 PM 96 32 0 642 229 3/9/13 2:59 PM 96 50 0 666 247 3/9/13 3:59 PM 96 47 0 665 270 3/9/13 4:59 PM 96 41 0 656 267 3/9/13 5:59 PM 96 40 0 653 294 3/9/13 6:59 PM 96 42 0 654 306 3/9/13 7:59 PM 96 42 0 656 318 3/9/13 8:59 PM 96 47 0 666 330 3/9/13 9:59 PM 96 55 0 685 347 3/9/13 10:59 PM 96 51 0 673 355 3/9/13 11:59 PM 96 51 0 669 362 3/10/13 12:59 AM 96 49 0 668 370 3/10/13 1:59 AM 96 46 0 669 379 3/10/13 3:59 AM 96 45 0 672 388 KRU 2P-448A Page 4 of 6 • • • 3/10/13 4:59 AM 96 57 0 678 405 3/10/13 5:59 AM 96 53 0 727 411 3/10/13 6:59 AM 96 52 0 758 416 3/10/13 7:59 AM 96 52 0 775 422 3/10/13 8:59 AM 96 52 0 788 428 3/10/13 9:59 AM 96 45 0 805 434 3/10/13 10:59 AM 96 48 0 799 443 3/10/13 11:59 AM 96 57 0 662 459 3/10/13 12:59 PM 96 53 0 715 462 3/10/13 1:59 PM 96 53 0 744 465 3/10/13 2:59 PM 96 53 0 762 470 3/10/13 3:59 PM 96 52 0 777 475 3/10/13 4:59 PM 96 46 0 792 480 3/10/13 5:59 PM 96 46 0 800 487 3/10/13 6:59 PM 96 54 0 725 501 3/10/13 7:59 PM 96 54 0 693 509 3/10/13 8:59 PM 96 53 0 732 510 3/10/13 9:59 PM 96 53 0 752 512 3/10/13 10:59 PM 96 52 0 768 504 3/10/13 11:59 PM 96 48 0 783 509 3/11/13 12:59 AM 96 44 0 797 521 3/11/13 1:59 AM 96 52 0 756 536 3/11/13 2:59 AM 96 55 0 626 546 3/11/13 3:59 AM 96 52 0 617 546 3/11/13 4:59 AM 96 52 0 614 548 3/11/13 5:59 AM 96 52 0 614 551 3/11/13 6:59 AM 96 45 0 615 555 3/11/13 7:59 AM 96 45 0 621 562 3/11/13 8:59 AM 96 55 0 639 577 3/11/13 9:59 AM 96 51 0 628 577 3/11/13 10:59 AM 96 51 0 625 578 3/11/13 11:59 AM 96 52 0 624 581 3/11/13 12:59 PM 96 50 0 624 584 3/11/13 1:59 PM 96 46 0 625 588 3/11/13 2:59 PM 96 44 0 630 594 3/11/13 3:59 PM 96 53 0 649 608 3/11/13 4:59 PM 96 52 0 644 612 3/11/13 5:59 PM 96 52 0 638 610 3/11/13 6:59 PM 96 52 0 636 611 3/11/13 7:59 PM 96 48 0 636 614 3/11/13 8:59 PM 96 44 0 639 617 3/11/13 9:59 PM 96 46 0 648 623 3/11/13 10:59 PM 96 54 0 662 637 3/11/13 11:59 PM 96 51 0 651 635 3/12/13 12:59 AM 96 50 0 648 634 3/12/13 1:59 AM 96 50 0 647 635 3/12/13 2:59 AM 96 46 0 647 637 3/12/13 3:59 AM 96 44 0 651 642 3/12/13 4:59 AM 96 50 0 667 652 3/12/13 5:59 AM 96 52 0 670 661 3/12/13 6:59 AM 96 50 0 661 658 3/12/13 7:59 AM 96 50 0 659 658 3/12/13 8:59 AM 96 49 0 658 659 3/12/13 9:59 AM 96 43 0 661 662 3/12/13 10:59 AM 96 44 0 665 667 3/12/13 11:59 AM 96 54 0 687 682 3/12/13 12:59 PM 96 50 0 676 681 3/12/13 1:59 PM 96 50 0 671 679 KRU 2P-448A Page 5 of 6 0 • 3/12/13 2:59 PM 96 50 0 669 680 3/12/13 3:59 PM 91 49 0 669 681 3/12/13 4:59 PM 96 43 0 672 684 3/12/13 5:59 PM 96 46 0 682 692 3/12/13 6:59 PM 96 53 0 697 707 3/12/13 7:59 PM 96 50 0 685 702 3/12/13 8:59 PM 96 49 0 681 701 3/12/13 9:59 PM 96 49 0 680 701 3/12/13 10:59 PM 96 44 0 681 703 3/12/13 11:59 PM 96 43 0 686 708 3/13/13 12:59 AM 96 54 0 676 724 3/13/13 1:59 AM 96 50 0 645 724 3/13/13 2:59 AM 96 48 0 640 721 3/13/13 3:59 AM 96 48 0 638 721 3/13/13 4:59 AM 96 47 0 638 721 3/13/13 5:59 AM 96 41 0 640 723 3/13/13 6:59 AM 96 43 0 645 729 3/13/13 7:59 AM 96 53 0 666 745 3/13/13 8:59 AM 96 48 0 654 743 3/13/13 9:59 AM 96 47 0 650 740 3/13/13 10:59 AM 96 46 0 649 740 3/13/13 11:59 AM 96 43 0 649 741 3/13/13 12:59 PM 96 41 0 652 743 3/13/13 1:59 PM 96 45 0 658 749 3/13/13 2:59 PM 96 54 0 695 766 3/13/13 3:59 PM 96 49 0 746 761 3/13/13 4:59 PM 96 48 0 771 759 3/13/13 5:59 PM 96 47 0 785 759 3/13/13 6:59 PM 96 44 0 798 759 3/13/13 7:59 PM 96 41 0 811 762 3/13/13 8:59 PM 96 42 0 825 765 3/13/13 9:59 PM 96 42 0 839 767 3/13/13 10:59 PM 96 43 0 847 769 3/13/13 11:59 PM 96 44 0 852 770 3/14/13 12:59 AM 96 44 0 860 771 3/14/13 1:59 AM 96 39 0 872 774 3/14/13 2:59 AM 96 42 0 885 780 3/14/13 3:59 AM 96 52 0 806 796 3/14/13 4:59 AM 96 52 0 648 806 3/14/13 5:59 AM 96 47 0 637 797 3/14/13 6:59 AM 96 46 0 634 794 3/14/13 7:59 AM 96 44 0 632 793 3/14/13 8:59 AM 96 41 0 633 794 3/14/13 9:59 AM 96 40 0 636 797 3/14/13 10:59 AM 96 47 0 647 805 3/14/13 11:59 AM 96 50 0 655 819 3/14/13 12:59 PM 96 46 0 646 812 3/14/13 1:59 PM 96 45 0 643 809 3/14/13 2:59 PM 96 43 0 642 809 3/14/13 3:59 PM 96 41 0 643 810 KRU 2P-448A Page 6 of 6 • • z-P-4-4 i&A Pit 202 cocci Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, March 12, 2013 10:00 AM 2�1� �I� Z✓I 3 To: 'NSK Problem Well Supv' j Cc: Dethlefs, Jerry C; Nenahlo, Thomas L; Wallace, Chris D (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA) Subject: RE: KRU 2P-448A(PTD 202-005) Report of OA SCP AOGCC requires more details about this. - Need table of OA pressures, particularly in the time of interest beginning just prior to when pressures spiked (return to production?) - Updates shall be provided to AOGCC weekly(first update due 3/15/13)with results of IA and OA pressure monitoring and production; document all bleeds - Describe how your startup procedures comply with Conservation Order 494, Rule 6: o "Except as otherwise approved by the AOGCC under paragraph 4 or 5 of these rules, before a shut-in well is placed in service, any annulus pressure must be relieved to a sufficient degree (a)that the inner annulus pressure at operating temperature will be below 2000 psig and (b)that the outer annulus pressure at operating temperature will be below 1000 psig. However, a well that is subject to paragraph 3, but not paragraph 5,of these rules may reach an annulus pressure at operating temperature that is described in the operator's notification to the AOGCC under paragraph 3, unless the AOGCC prescribes a different limit." If you have questions, contact Chris Wallace (793-1250) or me. CANNED iUL. 42 41 '�,� Jim Regg S AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617Caconocophillips.com] Sent: Monday, March 11, 2013 8:31 AM To: Schwartz, Guy L (DOA); Wallace, Chris D (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; Dethlefs, Jerry C; Nenahlo,Thomas L Subject: KRU 2P-448A(PTD 202-005) Report of OA SCP Jim, Chris, Guy Meltwater gaslifted producer 2P-448A(PTD 202-005)was reporte• ith SCP on the OA on 03/07/13. The initial TIO pressures were 200/600/1035. The well had just been returnee o production on 03/04/13 following a tubing patch that was set to repair TxIA communication. Immediate OA blee•• g was attempted however due to deteriorating weather conditions and high winds an extended bleed was unabl: o be completed. The high winds caused multiple power failures resulting in immediate attention required by the oper- •r. On 03/09/13 an extended bleed was performed and the OA was bled down to 276 psi. The wellhead pressures wi ontinue to be monitored for pressure build up and further evaluation if needed. Attached is a 90 day TIO plot. Please let me know if you have an, questions. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, c. Desk Phone (907)6 -7224 Pager(907) 65900 pgr. 909 IP • Kiztk a446A w2d^O Regg, James B (DOA) From: NSK Problem Well Supv[n1617 @conocophillips.com] Sent: Monday, March 11, 2013 8:31 AM )767.1 31 1t,(13 To: Schwartz, Guy L (DOA); Wallace, Chris D (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; Dethlefs, Jerry C; Nenahlo, Thomas L Subject: KRU 2P-448A(PTD 202-005) Report of OA SCP Jim, Chris, Guy Meltwater gaslifted producer 2P-448A(PTD 202-005)was reported with SCP on the OA on 03/07/13. The initial TIO pressures were 200/600/1035. he well had just been returned to •roduction .• I S, • • i• - •••• •atch that was set to repair TxIA communication. Immediate OA bleeding was attempted however due to deteriorating weather conditions and high winds an extended bleed was unable to be completed. The high winds caused multiple power failures resulting in immediate attention required by the operator. On 03/09/13 an extended bleed was performed and the OA was bled down to 276 psi. The wellhead pressures will continue to be monitored for pressure build up and further evaluation if needed. - Attached is a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons 1�JI- 2 2 20V3 Problem Wells Supervisor SCANN� ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907)659-7000 pgr. 909 , KRU 2P-448A PTD 2020050 3/11/2013 TIO Pressures Plot \Kup.3tukSC4D.4'\WD_TREND WELL TRENDS 2P 448 GAS LIFT OIL ig I infD HOUSE NIT/ WELLS WLHD CURRENT VALUE CURRENT VALUE CURRENT VALUE CURRENT VALUE OPERATOR NOTES SET CHOKE CHOKE 96. LIFT RATE 0. STATIC PR FTP 227. ROR OIL 7777777 LG CHOKE 0 `?TT 55. ROR LG 7777777 LG SETPT :LGV/OGV LG ORIF 0.650 LG ORI DP —2. II CASING PRE 644, LG CPRIME WEL STATUS 2000 __.— — / ON 2000. ___--r lirERT OPEN/SI 100. 1794 EVENT AT 2.000. j f PICK TIME 7. 1588 1 GENERAL PURPOSE 1302 l EVENT AT 2000. il 1 PICK TIME 1 11 (V/ - 1176 CREATE WELL "" III NOTE AT PIREIK PICK TIME 0 . + — 970 pr FREEZE E Iwo 764 � �' PROTECTION G R 1 - PREV WELL 558 1,all. Olt NEXT WELL 352 pr VIEW SDL —6p_ 146 illi CREATE SDL 0.00 _60 3.00 t. pi 0.00 VIEW EPDDL 0.00 ER SCALE DESC PICK VALUE LATEST pir CREATE EPDDL cog CHOKE 36. 96. 2160.0 r 11—MAR-13 08:32 flf ANNCOM PROBLEMS - FTT 228. 46. 255. I I I I I TT 1 7I 1 I I Flags: RIM CASING P 796. 644. TBG: 01111 LIFT RATE 0. 0. -� 12 r r i- ti t»: ..r. 1 ORIF—DP —2. —2. MINU7 r „n MP"?P TIM WEEK IA: HOURLY r 0A: 0A charging pith gas fro. open shoe. 110 IA PRES 794. 642. 00A/Tree: OA PRES 482. 578. DATE r PICK TlM 10—MAR-13 17:12:36 • STATE OF ALASKA • ALSPA OIL AND GAS CONSERVATION COMIRSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell 7 Rug Perforations r Perforate r Other . Set tubing patch Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r 202 -005 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r a 50-103-20396-01' QC) 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0373112 ■ l ' 2P -448A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Meltwater Oil Pool 11. Present Well Condition Summary: Total Depth measured 7593 feet Plugs (measured) None true vertical 5752 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6749, 6769, 6800 true vertical 0 feet (true vertical) 5074, 5091, 5116 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 110 110' SURFACE 2948 7.625 2976 2440 PRODUCTION 6964 5.5 6894 5192 PRODUCTION 690 3.5 7584 5745 RECEIVED MAR 0 5 2013 Perforation depth: Measured depth: 7195' -7210' J\ O�'" True Vertical Depth: 5436' -5448' SCANNED APR 17 2013 �°l�✓ Tubing (size, grade, MD, and TVD) 3.5, L -80, 6884 MD, 5184 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD WIDEPACK PACKER @ 6749 MD and 5074 TVD PATCH - SPACER PIPE & TIE BACK @ 6769 MD and 5091 TVD PACKER - WEATHERFORD WIDEPACK PACKER @ 6800 MD and 5116 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development P 0 Service r strati r 16. Well Status after work: , 011 r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Kelly Lyons / Brent Roger" Email n1617Ca)conocophillips.com Printed Name // KOI Lyons : ' J Title Problem Wells Supervisor Signature '' Phone: 659 -7224 Date 2 -28 -13 Form 10 -404 Ised 10/2012 RBDMS MAR 0 5 iik 441// 40 ,/ 1 3 S ubmit Original Only T • • • RECEIVED Iry ConocoPhillips MA? 0 P 2013 Alaska P.O. BOX 100360 AOGCC ANCHORAGE, ALASKA 99510 -0360 February 28, 2013 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2P -448A (PTD 202 -005) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659 -7224 if you have any questions. Sincere; Kelly Lyons Conocol ps Problem Wells Supervisor Enclosures . • • • 2P -448A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/28/12 PERFORM LEAK DETECT / 24 ARM CALIPER LOG. FIND LEAK IN GLM AT 6770', POSSIBILITY OF SMALLER LEAK AT 6794'. PUMPED DOWN IA, UP TUBING INTO FLOWLINE. LEAK FOUND PUMPING 0.5 BPM AT 925 PSI. 01/28/13 SET WEATHERFORD 2.74" WIDE PAC LE PACKER AT 6800' WITH BAKER 10 SETTING TOOL. LOG CORRELATED TO HES LEAK DETECT LOG DATED 28 OCT 2012. READY FOR SLICKLINE. 02/15/13 RAN 3 1/2 WIDE PACK PACKER TEST TOOL TO LOWER PACKER @ 6800' RKB; CMIT TxIA TO 2500 PSI GOOD TEST 02/16/13 STING INTO LOWER WP LE PACKER AND SET LOWER PATCH ASSEMBLY W/ SO TIE BACK ( 32.73' OAL / 1.75 " ID) @ 6769' RKB ( GOOD COMBO TEST ); STING INTO SO TIE BACK AND SET UPPER PATCH ASSEMBLY W/ WP LE PACKER ( 19.68' OAL / 1.75" OD ) @ 6749' RKB ( PASSED MIT IA TO 2500 PSI ) Summary (Set 51' retrievable tubing patch. Integrity verified with passing MITIA. • • 21 to 202. WELL LOG TRANSMITTAL G.l� To: Alaska Oil and Gas Conservation Comm. September 14, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2P -448A Run Date: 9/1/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Perforating, Klinton Wood, Halliburton Wireline & Perfo g, 6900 Arctic Blvd., Anchorage, AK 99518 2P -448A e file 1 CD Rom Digital Data in LAS format, Digital Log Ima g 50- 103 - 20396 -01 1 Color Log Bottom Hole Pressure Survey Log 50- 103 - 20396 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating SCANNED APR 1 7 2.013 Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -352 Fax: 907 - 273 -353 klinton.wood @halliburto Date: ‘,19.. 30 `% Signed: gt. • Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139 @conocophillips.com] Sent: Thursday, January 27, 2011 9:09 AM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); Colombie, Jody J (DOA); NSK Prod Engr & Optimization Supv; NSK Fieldwide Operations Supt; Bradley, Stephen D Subject: FW: RE: Request for Approval 73 0 Cr..) Attachments: Kuparuk Gas Injector Flow back Volumes.xls Tom, e - Attached you will find the Kuparuk Gas Injector Flowback information per your request. `.�. Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7535 S FEB 2 8 LU 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) [mailto tom.maunder(aalaska.govl 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. Call or message with any questions. 1/27/2011 Page 2 of 3 • Tom Maunder, PE AOGCC x i From: NSK Prod Engr & Optimization Supv jmailto :n2046CTconocophillips.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 i.J From: Maunder, Thomas E (DOA) [ mailto;tom.maunder @alaska.g_ox Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv Imailto:n2046©conocophillips.comj 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 Adjacent Estimated Prod ;as Injector PTD# SI Producer PTD# (Mscfd) ?P -420 201 -182 2P -422A 202 -067 4,500 a1P -447 203 -154 2P -448A 202 -005 2,000 3U - 185 -006 2U -02 185 -005 3,500 202 -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 • • Page 2 of 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 wqiNED JAN 1 8 ZOl 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) ;P -420 201 -182 2P -422A 2 -067 4,500 ;P -447 203 -154 2P -448A 202 -005 -- 9�, ,U -03 185 -006 2U -02 185 -005 3,500 IS -09 202 -205 3S -08C 207 -163 7,500 ■S -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: N5K -47 1/1 1/201 1 • • Page 1 of Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, 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 KRU 2P-448A (PTD# 202-005) Report of TxIA Communication Page 1 of l ~ ~ Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, September 20, 2009 1:39 PM '`c~C ~~lS~~,~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA) Cc: CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; NSK Problem Well Supv; NSK Well Integrity Proj; Lyons, Kelly A Subject: KRU 2P-448A (PTD# 202-005) Report of TxIA Communication Attachments: 2P-448A Wellbore Schematic.pdf; 2P-448A TIO Plot.pdf Jim/Tom/Guy, ~ Kuparuk (Meltwater) gaslifted producer 2P-448A (PTD# 202-005) is suspected of having TxIA communication based upon a failed TIFL on 09/18/09. A leaking aslift valve is the likely source of communication so s~ckfine will troubleshoot and repair if possible. The wel will be added to the SCP report and will be fixed or shut in by 10/16/09. Attached is a wellbore schematic and 90 day TIO plot. «2P-448A Wellbore Schematic.pdf» «2P-448A TIO Plot.pdf» ~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 1;y';~ ~~p ~~~9q"~p~~ ;~r~ lt ~.- 4' G.L`Vy.~d ~t7 •~4" 1i~' wr •~ 11/5/2009 End Date Days Start Date 1400 1200 1000 800 .Q 600 400 200 0 Jun-09 a ~ s a 5 J m Q O LL ~ 3 2 1 0 Jun-09 10/1 /2009 120 6/3/2009 Jul-09 Aug-09 Sep-09 (~j z~~~-cv ~ so 70 60 50 LL 40y ~ 30 20 10 0 • . Annular Communication Surveillance Jul-09 Aug-09 Sep-09 Date ~ KUP r 2P-448A ~ Ct~t"~t~cc~'ti~~ip~ ~~~,~ ~, ~ttE~~~x,~ , G~ ~ .-~~ ~, °> ~<< , ~~~ `§ `~ ~ ~~ f r~~ ~ ,;_.~ ~. ~j~~~ ~~~ Walibore API/UWI Fieltl Name Well Stetua Protl/Inj Type Incl (°) MD (ftKB) Act Btm (ftKB) I ' " 501032039601 MELTWATER PROD 59.90 3,380.68 7,593.0 ~ Comment H25 (ppm) Data Annotation End Date K8~{'ird (ft) Rig Release Data w~ Ganr~ :-2R ~x~s~2twa~Q.3a~A .. SSSV: NIPPLE 15 7/1/2008 Last W0: 33.01 1/8/2002 ematir:- :~; Annotation Depth (itKB) End Data Annotation Entl Date Last Tag: SLM 7 ,195.0 1 1/30@008 Rev Reason: TAG fILL 12/5R008 Y~r~.! ~#1'~I~I $ , _ " ~ ai .h, -'= H ~'i; "*,~,'v"'.- ~. ~ , k? . ~~ , ~r I " , String OD 9tring ID Set Uepth Set Depth (ND) String Wt String , Casing Description (in) (in) Top (nKB) (RKB) (RKB) (Iba/R) 6rade gtring 7op Thrd '` coN~ucroR is ie.osz o.o i~o.o iio.o ss.oo coNOUCroR, SURFACE 75/8 6.875 0.0 2,976.0 2,440.0 29J0 L-80 BTCM ~~a E, PRODUCTION S V2 4.950 0.0 6,894.0 5,192.1 15.50 L-80 EUEBTCM LINER 31/2 2.992 6,894.0 7,584.0 5,~44.6 9.30 1-80 EUEBTCM ~`lt~ " ~~~s #~3R S ' ! ~ " String OD String ID Set Depth Set Depth (ND) String Wt String Tubing Description (~n) (~~) Top ftKB) (flKB) (ftKB) (16slft) Orede String Top Thrtl TUBING 31/2 2.992 0.0 6,880.0 5,180.8 9.30 L-80 EUE C~~`~..~~ ~ ~!f31:c!@~~'i L:"~l~~1S ~Ti~fliSLli@~$1t4~ €'`~SEq $L i~ . ~ ., ~': ~ a~„ "~~`23i~ }r, i; NIPPLE, 523 Top Depth (ND) Top Incl a Tap (RKB) (nKB1 (°) Deseription Comment Run Date I~ (in) 523.0 522.9 3.46 NIPPLE CAMCO LANDING'DS' NIPPIE W2.875" PROFIIE 122/2002 2.875 2,528.0 2,203.3 57.73 GAS LIFT CAMCO/KBG-2-9/1/DMY/DK-1/// CommenC STA 1 7/22/2002 2.900 "= 4,921.0 3,612.4 41.11 GAS LIFT CAMCO/KBG-2-9/1/DMY/DK-1/// Canment: STA 2 1/22/2002 2.900 6,096.0 4.543.2 36.38 GAS IIFT CAMCOMBG-2-9/1/DMY/DK-1/// Comment: STA 3 1/22/2002 2.900 ' 6,770,0 5,091.3 35.37 GAS LIFT CAMCO/KBG2-9/1/OVlDK-3/.313//Comment: STA4 12/7/2004 2.900 6,820.0 5,132.1 35.56 SLEEVE BAKER CMU SLIDING SLEEVE W/2.81" DS PROFILE 1/222002 2.810 "" 6,836.0 5,145.1 35.63 NIPPLE CAMCOW/2J5PROFILE 1/22/2002 2.750 6,880.0 5,180.8 35.80 SEAL BAKER SEAL ASSEMBLY W/G-22 LOCA70R i/22/2002 3.000 GA5 5 ~. F ~ a ~t ~ °;i ~ ';t _ .~,a ~ ~ ~ t~ i r ~ i ;~. ~~~ ~ ~ ~ t • „- - = 2,528 c _ i .i _ i ,. _ 4 Shot Top (ND) Btm (ND) Dens Top (ttKB) B4n (ttKB (RKB) (RKB) Zone Date (°M1~° 7ype Comme~t 7,195.0 7,210.0 5,435.8 5,447.9 ~ 727/2002 6.0 IPERF 2.5" HSC PJ Chgs, 60 deg phase SIIRFAGE, 2~976 py$ t74€~~~ p~ ~~Qf{~clt^ ~ ~~ m~ ~ n'~I kr " au ~:~ _ i, ~, ~1 ~' b~ g~ t~~ :: s, S. rir ~ . " eottom Min Tap Max Btm Top Depth Depth . ~ Depth Deptlt (ND) (ND) ~~;~ ~ftKB) ~ftKB) ~RKB) ~ftHB) T pe Date Comment 7,195.0 7,210.0 5,435.8 5,447.9 F RAC 2/32002 BERMUDA FRAC, 91,000# 16/20 CARBOLITE, 9.5 PPA ON PERFS , s 7,195.0 7,210.0 5,435.8 5,447.9 RE-FRAC 12/4/2004 197,000# 16/20 CARBOLITE w/10.1 PPA @ PERFS ;`r ~~88; ~&~l~fH~- ~k.~d'~@ _`'~"' ` i i ; ,~-, ~, -€=z" i __ " - 'v End D ate Annota tion t~ 6/25/2004 NOTE: WAIVERED WELL: OA PRESSURE CHARGING FROM RESERVOIR GAS LIfT, 4.921 - GAS LIFT, 6,0% i~j ;II GAS UF~, 6,770 SLEEVE,fi,B20 ~ NIPPlE,6,B36 i SEAL, 6,BB0 PRODUCTION, I 6,894 IPERF, 7.1957.210 FRAC,7,195 RE-FRAC 7.195 LINER, 7,SB4 TD (2P-048A), 7,593 L ~iChr~l~~~~1' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # g~[(~,R '~ ~: 100i Log Description N0.4617 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD o2i2s/os 1A-02 (REVISED) 11994615 INJECTION PROFILE ~- _.. ___.___ _. --.- ~ 02111108 1 1C-27 11970632 WFL t) 02121/08 1 3R-21 11970633 LDL ( 02/22/08 1 2P-451 11996604 SBHP SURVEY O ~~ 02/22/08 1 1C-11 11968846 LDL ~ - j 02/20108 1 2P-438 11964581 SBHP SURVEY c7U 1 -~ 02/26/08 1 2P-448A 11964582 SBHP SURVEY 02/27/08 1 r ~ L J • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Sc~lullbel'ge.. NO. 4343 ~\/E Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth dUL 3 0 2007 5CANNED AUG 0 1 2007 f\18$ka Œ & Coos. Commission Anchorage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~Ûd -cDS- Field: Kuparuk Well Job# BL Color CD Log Description Date 1H-08 11850414 INJECTION PROFILE 07/23/07 1 2L-327 11665460 SBHP SURVEY 07/21/07 1 2M-28 11850413 PRODUCTION PROFILE 07/22/07 1 2M-32 11850415 GLS 07/24/07 1 2P-448A 11850403 SBHP SURVEY 07/21/07 1 1H-03 11632739 INJECTION PROFILE 07/23/07 1 2T-37 11632740 PRODUCTION PROFILE 07/24/07 1 2H-14 11632738 PRODUCTION PROFILE 07/22107 1 t6 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/27/07 . . e ConocJ>'hillips Afaska e JUL 05 Z006 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 & ¡\üût~orage June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, 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 st, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. Sincerely, \(..~~~J.. d~ C>6/~ù/06 Attachment -- ~Od-C50~ _./ " e e ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Well Initial top Vol. of cement Final top of Cement top Name PTD # of cement um ed cement off date ft bbls ft · ConocJ'Phillips Alaska aCEi!'(\jF JUi\! 1 '2 ¡,~ Alaska Dil & Gas Cons. Coo~r¡¡Si)i1)íì Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ [r¿) -CÛ? June 06, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 I tJ ~:;: t.^ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, 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 18th, 19th and 31 S\ 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Marie McConnell or myself at 907-659-7224, if you have any questions. ConocoPhillips Problem Well Supervisor Attachment . . , ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field June 6,2006 Vol. of cement Final top of Cement top urn ed cement off date bbls ft Corrosion inhibitor/ sealant date 5/19/2006 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs_ Inserts\Microfilm _ Marker.doc ') Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 3, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2P-448A (APD # 202-005) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 2P-448A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, /j ¡j~ M. Mooneý Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED JAN 0 4 2005 Alaska Oil & Gal COOI~ Commission Anchorage SCAN~\jED JAN 0 6 2005 ORIGINAL Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 30', Pad 253' 8. Property Designation: ADL 3731121 ALK4998 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PRODUCTION Perforation depth: ') ) REceIVED JAN 0 4 Z005 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS i\\askICI & GfiE1'~ìjHL Time Extensio~r'B' Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Ope rat. ShutdownD Re-enter Suspended Well 0 Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development - 0 Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill Number: 202-005 6. API Number: 50-103-20396-01 9. Well Name and Number: 2P-448A 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk River Oil Pool measured 7593' feet true vertical 5752' feet measured 7211' feet true vertical 5449' feet Length Size MD 110' 16" 110' 2946' 7-5/8" 2976' 6964' 5-1/2" 6894' 690' 3-1/2" 7584' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 2440' 5192' 5745' Measured depth: 7195'-7210' true vertical depth: 5436'-5448' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6880' MD. RBDMS BFL JAN 04 2DD5 Packers & SSSV (type & measured depth) no packer Cameo Landing 'OS' nipple @ 523' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7195'-7210' 197,000# 16/20 carbolite w/1 0.1 ppa @ perfs 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X 3333 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Printed Name Signature Oil-Bbl SI 1883 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Tubinç¡ Pressure Casinç¡ Pressure 34 263 WDSPL 0 Mike Mooney @ 263-4574 Mike Mooney AI/:J )Ij ~ Title Wells Group Team Leader Phone . 907 -263-457 4 Date;j 5/0!Zl- 0 RIG I N A L fuoaœd b, Sh,ron Anw~kE263-4612 Submit Original Only Form 10-404 Revised 04/2004 ) 2P-448A Well Events Summary Date Summary 11/27/04 TAGGED FILL @ 7211'RKB, REPLACED 1" OV @ 6770'RKB WITH 1" DV, LOADED IA WITH 65 BBLS SEAWATER/FOLLOWED BY 25 BBLS DIESEL, PT TUBING AND IA TO 3500#, PRE-FRAC SLlCKLlNE COMPLETE. Tag, PT Tbg-Csg 12/03/04 PULLED 1" DV @ 6770'RKB, SET 1" SPARTEK SIDE POCKET GAUGE @ SAME DEPTH, PT IA 2500# [PT Tbg-Csg] 12/04/04 PUMP BREAKDOWN, SCOUR, DATFRAC. ISIP=971 psi. Pump BRACKETFRAC, pad at 30 bpm using 30# x-linked gel, TP = 4946 psi. Pump bracketfrac material (0.25 ppt J423 and 0.5 ppa 20/40) using 20# linear gel at 30 bpm, TP = 3060 psi. Decrease rate to 20 bpm, then to 15 bpm to flush bracketfrac using 20# linear gel. Refrac Bermuda formation. 800 bbl pad using 30# x-link gel 4990 TP. Pump 300 bbls of 1-4 ppa, 5024 TP. 100 bbls 4 ppg flat, then start to ramp to 10 ppa in 600 bbls 6102 TP, 30 bpm, hold 10 ppa. TP=6330 with 10 ppa on perfs. Pump 137 bbls into 450 bbl 10 ppa. NWB screen-out - 218,101 total prop. Pumped with 197,021# 10.1 ppa @ perfs. 12/06/04 CLEANED OUT FRAC SAND TO 7438' CTD UTILIZING A 2.3" JET SWIRL NZL. PUMPED 1,097 GALLONS N2, 770 BBLS SLICK DIESEL, AND 160 BBLS DIESEL GEL. GOOD RETURNS TO TANKS THROUGHOUT JOB, RECOVERED LARGE AMOUNT OF FRAC SAND - 10 CUBIC YARDS. 12/07/04 TAGGED @ 7449' RKB, EST. 239' RATHOLE. PULLED 1" SPARTEK @ 6770' RKB, REPLACED WITH 5/16" OV. DISPLACED TBG & IA WITH 140 BBL DSL. [GL V, Tag] ) ) KRU 2P-448A ConocoPhillips Alaska,1I1ç. 2P-448A TUBING (0-6880, OD:3.500. ID:2.992) SURFACE (0-2976. OD:7.625. Wt:29.70) , \1 ! !. I :>RODUCTlON ~. (0-6894, OD:5.500, Wt:15.50) I Gas Lift 11:1 !ndrel/Dummy Valve 2 (4921-4922, OD:4.725) f~' ~ ~ Gas Lift !ndrel/Dummy Valve 3 (6096-6097, ~ OD:4.725) Gas Lift )!- !ndrel/Dummy I Valve 4 i! (6770-6771, I~ OD:4.725) }.. SLEEVE (6820-6821, OD:4.530) NIP ! IIJIIIIII11 (6836-6837. OD:3.750) i SEAL (6880-6881, OD:4.000) RE-FRAC '\ ~ (7195-7210) +- ./ Perf '\ ---'-,.- > (7195-7210) -r- ~ FRAC --y-- / (7195-7210) -<- ----r- "- :>RODUCTlON (6894-7584, j OD:3.500, ~ Wt:9.30) API: 501032039601 SSSV Type: Nipple Well Type: PROD Orig 1/16/2002 Completion: Last w/o: Angle @ TS: deg @ Angle @ TD: 38 deg @ 7593 Annular Fluid: Rev Reason: Waivered Well, Tag, Set DMY, RE-FRAC Last Update: 12/5/2004 Reference Log: Last Tag: 7211 Last Tag Date: 11/27/2004 Casing String - ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION PRODUCTION Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 7195 - 7210 5436 - 5448 Ref Log Date: TD:7593 ftKB Max Hole Angle: 60 deg @ 3381 Size 16.000 7.625 5.500 3.500 Top 0 0 0 Bottom 110 2976 6894 TVD 110 2440 5192 Wt 63.00 29.70 15.50 Grade Thread L-80 BTCM L-80 EUEBTCM Bottom 6880 Zone Date 15 6 1/27/2002 Stimulations & Treatments Interval Date 7195 -7210 2/3/2002 FRAC Type Comment BERMUDA FRAC, 91,000# 16/20CARBOLlTE, 9.5 PPA ON PERFS 7195 - 7210 12/4/2004 RE-FRAC Gas lift MandrelsNalves St MD TVD Man Man Type Mfr 1 2528 2203 CAMCO 2 4921 3612 CAMCO 3 6096 4543 CAMeO 4 6770 5091 CAMCO Other (plugs, equip., etc.) - Depth TVD Type 523 523 NIP 6820 5132 SLEEVE 6836 5145 NIP 6880 5181 SEAL General Notes Date I Note 6/25/2004 WAIVERED WELL: OA PRESSURE CHARGING FROM RESERVOIR DMY DMY DMY 1.0 DK-1 0.000 1.0 DK-1 0.000 1.0 DK-1 0.000 Description CAMeO LANDING 'DS' NIPPLE W/2.875" PROFILE BAKER CMU SLIDING SLEEVE W/2.81" DS PROFILE CAMCO W/2.75 PROFILE BAKER SEAL ASSEMBLY W/G-22 LOCATOR ID 2.875 2.810 2.750 3.000 ~) ~JL, ^~C1 DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permit to Drill 2020050 Well Name/No. KUPARUK RIV UNIT 2P-448A Operator CONOCOPHILLlPS ALASKA INC Ç'r¿ ~j~~<JCJ A API No. 50-103-20396-01-00 MD 7593....-' TVD 5752 ~ Completion Date 1/27/2002 ,/" Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional surv~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ! W C Pdf 11358 f£nD troD Log Log Run Scale Media No 1 10776 10777 Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Y/~ Chips Received? ~ Well Cored? Daily History Received? Formation Tops Analysis Received? ï I I-J (data taken from Logs Portion of Master Well Data Maint) --, Interval OH/ Start Stop CH Received Comments 110 7593 Case 12/6/2002 Digital Well Log data i ¡ 52 7538 Open 4/26/2002 52 1982 Open 4/26/2002 Sample Set Number Comments aN ß/N ~ Comments: 1Ul ~ ~ ~ ~ JtL C fevf--~ ~ìJ",tVLÀð~~ ~\'~- 7)60 ~ r1k~~. Compliance Reviewed By: h Date: ~:) p-~~ '1 (' ( ~ 0;) --ODS 1/55\( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 03, 2002 RE: MWD Formation Evaluation Logs 2P-448A, AK-MM-11214 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI( 99518 2P-448A: Digital Log Images 1 CD ROITI RECEIVE'D DEe 06 2uv'c A.laska O~ & Gaa Ct, ',0', I I,mssion Anchor~t,,~\?' qOa-005 ~, (' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tJ1 Avenue, Suite 100 Anchorage, Alaska April 23, 2002 RE: MWD Formation Evaluation Logs 2P-448A, AK-MM-11214 1 LDWG formatted Disc with verification listing. API#: 50-103-20396-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 RËŒI\tEtJ Sign~~ ~,rn f'\ ~ "lr\O? j. ...'i,. I D . II "..,\~ l" L..... i-~"'" AlaskaOU& Gas Cons. Commissian Anchorage ó1 Oð-oQ,5 ( f WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West ih Avenue, Suite 100 Anchorage, Alaska April 18, 2002 RE: MWD Formation Evaluation Logs 2P-448 PB 1, AK-J\1M-11214 1 LDWG formatted Disc with verification listing. API#: 50-103-20396-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 AfiCEIVED Sign~<.-Qoo'P{n f' pp ? 6 L"OO? t-~. ~ \ 6-.. v .... AlaIkaOiJ&GasCons.CommissiDn Anchorage ,'Y, .) ",,"":) f ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas ' Phone (907) 265-6830 Fax: (907) 265-6224 March 21, 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-448 and 2P-448A (201-229/302-009) ¿OZ....DùS Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Meltwater well 2P-448. It includes the P&A report for 2P-448 and the report for the sidetrack well 2P-448A. If you have any questions regarding this matter, please contact Pat Reilly at 265-6048. Sincerely, ~~~ l~ \ R. Thomas Greater Kuparuk Team Leader P AI Drilling RT/skad RECEIVED r"~ J' P ? rj "002 . ir\; ~ '- '- L AlalkaOil&GasCons.Ccmnillion AndIIfaøe ()F~' I~IJAL ( 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 0 Gas D Suspended D Abandoned D Service D 2. Name of Operator 7.~~r Phillips Alaska, Inc. 1ôcAtJoNs 1 302-009 3. Address -~, 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20396-01 4. Location of well at surface '~~~'::::-.-:. * ¡¿. !~]/" 9. Unit or Lease Name 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UMr'wO:'i::JU~ ¡ :Oi1 (ASP: 443543, 586885gr!~'~"""""<""'"';~ Kuparuk River Unit AtTop Produdng Interval I DATi: ~ 10. Well Number 1525' FSL, 949' FEL, Sec. 18, T8N, R7E, UM :' ~~:~~~-t(ASP: 440999.9, 5866144) 2P-448A At Total Depth ~. ~u ~ 11. Field and Pool ~ 1240' FSL, 931' FEL, Sec. 18, T8N, R7E, UM t:-:~ .._,,~:::::::-:':-J(ASP: 441007, 5865859) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Meltwater Oil Pool RKB 30', Pad 253' ADL 373112 1 ALK 4998 12. Date Spud<;¡d z... ft 13. Date T.D. Reached I 14. Date Comp., Susp. Or Ab~. 15. Water Depth, if offshore 16. No. of Completions I- .t:) ~ Dec , ~001 January 13, 2002 January 16, 2002 NIA feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7593' MD 15752' TVD 7460' MD 15647' TVD YES 0 No D N/A feet MD 1488' (approx) 22. Type Electric or Other Logs Run G R/Res/Den/Neu 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# B Surface 110' 42" 64.9 bbls AS 1 7.625" 29.7# L-80 Surface 2976' 9-7/8" 391 sx AS Lite, 202 sx LiteCrete 5.5" x 15.5# L-80 Surface 6894' 6.75" 56 bbls Class G 3.5" 9.3# L-80 6894' 7586' 6.75" (included above) 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6880' 6874' (CSR) 7195' - 7210' MD 5436' - 5448' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7195' - 7210' 91 M# 16/20 carbolite behind pipe 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 20, 2002 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 2/23/2002 8.5 hours Test Period> 610 544 15 100 603 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 273 psi 908 psi 24-Hour Rate> 1721 1537 41 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A t.1 .J¡ D ? r¡ "002 i:~\[ ~ .... L L Alaska Oil & Gas Cons.Commillion Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 0 RIG I N A L RODMS OFl Mi\R 22 2Dœ G r i ( 29. 30. ( GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS.DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T3.1 6894.5' 5193' T3 7029.5' 5302' T2 7212' 5449' 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? Call Pat Reilly 265-6048 ~'---:.:::> '"... . - ..-?( tc lÖL Signed \ ~ ~---.~ KUDaruk Team Leader Date R. Thorn Prepared by Sharon AI/sup-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. Item 28: If no cores taken, indicate "none". Form 10-407 PHILLIPS ALASKA INC. Operations Summary Reþort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Sub HoursCodè Code Phase 3.00 MOVE RURD MOVE 13.00 MOVE MOVE MOVE 12/21/2001 00:00 - 03:00 03:00 - 16:00 16:00 - 22:00 6.00 MOVE RURD SURFAC 22:00 - 00:00 2.00 DRILL PULD SURFAC 12/22/2001 00:00 - 05:00 5.00 DRILL PULD SURFAC 05:00 - 06:00 1.00 DRILL PULD SURFAC 06:00 - 07:00 1.00 WELCT BOPE SURFAC 07:00 - 08:00 1.00 DRILL SFTY SURFAC 08:00 - 10:00 2.00 DRILL PULD SURFAC 10:00 - 11 :00 1.00 DRILL CIRC SURFAC 11 :00 - 00:00 13.00 DRILL DRLG SURFAC 12/23/2001 00:00 - 14:00 14.00 DRILL DRLG SURFAC 14:00 - 15:00 1.00 DRILL CIRC SURFAC 15:00 - 19:00 4.00 DRILL TRIP SURFAC Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Spud Date: 12/22/2001 End: 1/3/2002 Group: Prep rig for rig move to 2P-448, Move rig from 2P-429 to 2P-448, spot modul es and R/U Accept rig at 1600 hrs. 12/21/01. R/U divert er system, install 4" valves on conductor pi pe, install bell nipple and flow lines, Ready rig floor for 4" DP, Load4" DP in pipe shed and strap pipe. P/U 4" DP and stand back in derrick P/U and stand back in derrick 4" DP.- total 7500' of pipe P/U and stand back in derrick HWDP Test diverter and accumulator, hold diverter and accum. drills, witnessed by AOGCC ins pector. Hold Pre-spud meeting with crews and servi ce personal involved in well P/U BHA Fill stack, check for leaks on flowline, mud lines and associated equipment. Test lines Drill ahead to 843' MD ART = 4.3 hrs. AST = 2.0 hrs. Drill from 843' to 2040' MD, 1898' TVD ART = 5.9 hrs. AST = 4.3 hrs. Circ. sweep and clean up hole While making wiper trip at 2041', we pul led the first 2 stands with no drag or swabbi ng. The third stand pulled good the first 30' the n s tar t e d tog e t t i g h tat 1 8 5 1 '. W e work ed the pipe up to 75k over pull on a couple strokes, but it cleaned up and pulled free. T he forth stand started to get tight after pullj ng 15', worked the pipe in 25k increments u p to 125k overpull. We opted to pump out of the hole. Screwed into the top drive and br oke circ. and started rotation, as we were p ulling up we packed off and stalled rotation. Attempted to go back down, but couldn't. W orked 4th stand out of hole pulling up in 25k increments to 125k overpull. Worked 5th st and up 25' (1632') working up and down pull ing in 25k increments to 175k overpull. Pipe is good for 50 Ok tensile. Started to torque and slump pipe to see if it would work down and start turning, torque up to 20k ft. Ibs. P ipe started to turn 2 different times, then pi pe spun backwards because brake was not 0 n and unscrewed pipe 45' from surface. Scre wed back into pipe and torque pipe to 20k ft . Ibs. Continue torque and slump method, ja rs were working on the up stroke. Pipe start ed rotating, work pipe while rotating to get some free area to try and regain circulation. Printed: 1/21/2002 10:27:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/23/2001 15:00 - 19:00 19:00 - 23:00 23:00 - 00:00 12/24/2001 00:00 - 02:00 02:00 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 08:00 08:00 - 10:30 10:30 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 16:00 16:00 - 18:30 18:30 - 19:30 19:30 - 20:30 20:30 - 00:00 12/25/2001 00:00 - 04:00 ( PHILLIPS ALASKA INC. Operations Summary Report 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Sub Hours .. Code Code Phase 4.00 DRILL TRIP SURFAC 4.00 FISH 1.00 FISH 2.00 FISH 2.00 FISH 0.50 FISH 0.50 FISH 1.00 FISH 2.00 FISH PULD SURFAC PULD SURFAC PULD SURFAC WASH SURFAC FISH SURFAC JAR SURFAC CIRC SURFAC TRIP SURFAC 2.50 WAlTON EQIP SURFAC 1.50 FISH 1.50 FISH 0.50 FISH 2.00 FISH 2.50 FISH 1.00 FISH 1.00 FISH 3.50 FISH 4.00 FISH PULD SURFAC WASH SURFAC MILL SURFAC JAR SURFAC TRIP SURFAC PULD SURFAC WASH SURFAC JAR SURFAC JAR SURFAC Page 2 of 12 Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 [)êScriptionofOþerations Pull pipe up until we had overpull and pipe started bouncing like it was up against a ro ck. The pipe then came free and we regaine d circulation. Brought pumps up to drilling r ate and seen we had lost 900 psi circ. press ure. String weight didn't seem any different than when we were drilling. POOH and found the drilling jars were parted in the threads on the hydraulic pressure chamber of the jar s. Jars had never went off with more than 5 Ok overpull. Top of fish is at 1264.13'. P/U 6 3/4" Drill collars to be used for fishin g, while waiting on Baker Fishing out of Dea dhorse Offload fishing tools and P/U to go in the ho Ie M/U fishing assembly, 8 1/4" overshot w/4 3 14" grapple, bumper sub, oil jars, 9 - 6 '1/2" DC's, and excellerator RIH, washed from 500' to 1264', (top of fish ) Work control head and 4 3/4" grapple over fi sh Jar down on fish with bumper sub, fish didn' t move Attempt to jar up on fish, grapple slipped of f fish, set back over fish, but grapple would n't hold, circ bottoms up Trip out of hole with overshot, control head had circular wear marks on it with a 5 1/4" pattern. Grapple was worn smooth Having a overshot built with mill section ins ide to dress top of fish back to 4 3/4". Wait on tool to be delivered frQm Deadhorse M/U fishing assembly to mill and catch 4 3/4 " fish, TIH to 500' Wash overshot to top of fish, from 500' to 1 264' Dress off top of fish to 4 3/4", engage grapp Ie over fish Jar down on fish, found no movement down, attempt to jar up, after third jar up the grap pie come off fish attempt to grab fish, but w ouldn't hold POOH with fishing assembly Change out grapple to a 4 5/8" RIH, wash overshot from 500' to 1264', slip over top of fish Jar on fish, pulling up to 150k over, made 4' coming up, but couldn't get fish to jar back down. Waiting on Schlumberger wire line to run free point and back off. Jar on fish, made another 2' up but couldn't Printed: 1/21/2002 10:27:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: « PHILLIPS ALASKA INC. Operations Summary Report 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Sub From-To Hours Code COde Phase 12/25/2001 00:00 - 04:00 04:00 - 07:00 4.00 FISH JAR SURFAC 3.00 FISH CPBO SURFAC 07:00 - 08:00 1.00 RIGMNT RGRP SURFAC 08:00 - 13:30 5.50 FISH JAR SURFAC 13:30 - 15:30 2.00 FISH CPBO SURFAC 15:30 - 17:00 1.50 FISH TRIP SURFAC 17:00 - 19:00 2.00 FISH PULD SURFAC 19:00 - 20:30 1.50 FISH RURD SURFAC 20:30 - 21 :00 0.50 RIGMNT RSRV SURFAC 21 :00 - 23:00 2.00 FISH TRIP SURFAC 23:00 - 00:00 1.00 FISH FISH SURFAC 12/26/2001 00:00 - 01 :30 1.50 FISH TRIP SURFAC 01 :30 - 03:00 1.50 FISH TRIP SURFAC 03:00 - 06:30 3.50 FISH TRIP SURFAC 06:30 - 09:30 09:30 - 11 :00 11 :00 - 12:00 3.00 FISH TRIP SURFAC 1.50 FISH TRIP SURFAC 1.00 RIGMNT RSRV SURFAC 12:00 - 13:30 1.50 WAlTON EQIP SURFAC 13:30 - 15:00 1.50 FISH TRIP SURFAC 15:00 - 15:30 0.50 FISH ELlN SURFAC Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description. of. Qperé\ti()ns god 0 w n. Tot a I 0 f 6' has bee n mad e j a"r i n g up, top of fish at 1258' R/U Schlumberger wireline to free point pipe , made a dummy run to see if we could get t hrough the top of the fish. Made 3 attempts with various configurations on bottom of too I, but couldn't get through separated drillin g jars. RID wireline Attempt to release from overshot. Top drive kept kicking out breakers while torquing. Attempt to release overshot from fish, but g rapple wouldn't release, torque and jar with no movement R/U wireline, run string shot in overshot, to rque pipe, shot string shot and overshot rei eased. POOH LID fishing tools, M/U new overshot w/4 5/8" grapple, bumper sub and jars Change out top drive saver sub and grabber s to 5" Rig service, check drill line and top drive RIH with fishing tools, picking up 5" DP, tor quing DP to 25,000 ft. Ibs. Work over fish with 4 5/8" grapple, had prob lems getting it to grab.Latch onto fish and w ork left hand torque, getting ready for a me chanical (blind) back off. POOH, found we had backed off on top of fis hing jars, left fishing assembly in hole. TIH with screw in sub, screw into fishing jar s, POOH with fishing tools. Replace 4 5/8" grapple in overshot, RIH, Lat ch onto fish and attempt a mechanical back off, POOH, recovered a 5.35' section of the drilling jars, the top of fish had a split appr ox. 6" long through the female threads. TIH with 4 3/4" grapple in overshot, latch on to fish and attempt a mechanical backoff POOH, no recovery Service rig and top drive, inspect drilling Ii ne and check for loose fittings, bolts and c onnections which could had been caused by jarring. Wait on fishing tools from Baker fishing in Deadhorse. TIH with 4 5/8" grapple in overshot, latch on to fish, attempt mechanical backoff, acted a s if we had a back off, pull up hole 30' RIH with collar locator and sinker bar on wir eline, tagged up in overshot and couldn't go deeper. It was thought we had some of the fish in overshot. Printed: 1/21/2002 10:27:43 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PHILLIPS ALASKA INC. Operations. Summary Report 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Date Sub From-To Höürs. ..Code Code Phase 12/26/2001 15:30 - 16:30 1.00 FISH TRIP SURFAC 16:30 - 19:00 2.50 FISH PULD SURFAC 19:00 - 21 :30 2.50 DRILL TRIP SURFAC 21 :30 - 00:00 2.50 DRILL CIRC SURFAC 00:00 - 02:00 2.00 WAlTON EQIP SURFAC 02:00 - 03:30 1.50 CEMEN TRIP SURFAC 03:30 - 04:30 1.00 CEMEN CIRC SURFAC 04:30 - 05:30 1.00 CEMEN PLUG SURFAC 12/27/2001 05:30 - 08:30 08:30 - 09:00 09:00 - 10:00 3.00 CEMEN CIRC SURFAC 0.50 CEMEN TRIP SURFAC 1.00 CEMEN PLUG SURFAC 10:00 - 11 :00 1.00 CEMEN TRIP SURFAC 11 :00 - 18:00 7.00 WAlTON CMT SURFAC 18:00 - 21 :00 3.00 WAlTON CMT SURFAC 21 :00 - 21 :30 0.50 DRILL REAM SURFAC 21 :30 - 00:00 2.50 DRILL DRLG SURFAC 12/28/2001 00:00 - 15:00 15.00 DRILL DRLG SURFAC 15:00 - 16:00 1.00 DRILL CIRC SURFAC 16:00 - 19:30 3.50 DRILL WIPR SURFAC 19:30 - 00:00 4.50 DRILL DRLG SURFAC 12/29/2001 00:00 - 11 :30 11.50 DRILL DRLG SURFAC 11 :30 - 13:00 1.50 DRILL CIRC SURFAC 13:00 - 15:00 2.00 DRILL WIPR SURFAC 15:00 - 18:00 3.00 DRILL WIPR SURFAC Page 4>01 12 Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description.of..Qperatiol1s POOH, no recovery Brake out and LID all fish tools and wireline equipment. Make up 9 7/8" bit and RIH to 1264', wash ti ght hole from 600' to 1264' Circ. and cond mud for setting balanced cem ent plugs. LID 5" DP, while waiting on Dowell Schlumb erger for cementing RIH w/4" DP and mule shoe to 1260' Circ. while waiting on cementers Hold pre-job safety meeting, pump 7 bbls wa ter, test lines to 2000 psi, pump 52 bbls CI. G cement at 17 ppg. (280 sx), pump 1 bbl w ater and displace for a balanced plug, pull u p hole with DP to 690' Circ while waiting on cement to cure, didn't see any cement in returns RIH to 865' and tag hard cement Circ. bottoms up, pump 7 bbls water, 20 bbl s CI. G cement at 17 ppg. (110 sx), pump 1 bbl water and displace for a balanced plug, pull up hole to 480' Circ. bottoms, no cement in returns, POOH Wait on cement to cure, LID 6 1/2" DC's, ch ange TDS saver sub back to 4" HT-38, Slip and cut drill line P/U side track BHA while waiting on cement to cure Wash and ream to 738', found good cement Drill cement from 738' to 935' Drill from 935' to 1955' MD, 1840 TVD ART = 6.8 hrs AST = 3.4 hrs Circ, and cond for wiper trip Wiper trip to 700', started pulling tight at 1 860' and had to work pipe out of hole to 147 8'. Worked pipe up to 30,000 overpull and 3 0,000 set down, pipe pulled free from 1478' to 700'. Pipe went to bottom with no proble m, no fill. Drill from 1955' to 2244' MD, 2040' TVD AR T = 0.9 hrs AST = 1.9 hrs Drill from 2244' to 2990' MD, 2447' TVD AR T = 7.3 hrs AST = 1.5 hrs Circ. and cond mud and hole for wiper trip, pump 2 sweeps, shakers cleaned up. Short trip pipe, hole started getting tight at 2790', work pipe with 30k up and back down , pipe became stuck at 2736' with 30 k over pull and wouldn't go back down. Jar down on BHA, had problems getting jars to fire going down, had to work jars in the n eutral position several time before setting d Printed: 1/21/2002 10:27:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page50f12 PHILLIPS ALASKA INC. Operations Summary Report 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Spud Date: 12/22/2001 End: 1/3/2002 Group: Sub From-To Hours ...Code Code 12/29/2001 15:00 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 00:00 12/30/2001 00:00 - 02:00 02:00 - 04:00 04:00 - 06:00 06:00 - 08:00 08:00 - 11 :00 11 :00 - 12:00 12:00 - 15:30 15:30 - 00:00 12/31/2001 00:00 - 02:30 02:30 - 05:00 05:00 - 07:00 07:00 - 10:30 3.00 DRILL WIPR SURFAC 1.00 DRILL WIPR SURFAC 3.00 DRILL WIPR SURFAC 2.00 FISH 2.00 FISH 2.00 FISH 2.00 FISH 2.00 FISH 3.00 FISH 1.00 FISH 3.50 FISH 8.50 FISH ELlN SURFAC ELlN SURFAC CPBO SURFAC TRIP SURFAC RURD SURFAC PULD SURFAC CIRC SURFAC PULL SURFAC PULL SURFAC 2.50 FISH TRIP SURFAC 2.50 DRILL TRIP SURFAC 2.00 DRILL CIRC SURFAC 3.50 DRILL TRIP SURFAC own to get them to fire. Started using the to rque and slump method going down and got pipe to start rotating with 10,000 to 13,000 ft Ibs of torque. Worked pipe while rotating with 10,000 ft Ib s of torque, pipe wouldn't go down but could rotate up. Attempt to regain circ. with slow rate, pipe immediatly stuck when drill pipe caught pressure. Now pipe is stuck at 2716' Attempt to torque and slump pipe, jar down on pipe and seen no movement, Baker Fishin g tool man showed and attempted his magic, but could not get pipe movement. R/U Schlumberger, run free point tool in hol e, found pipe free all the way to the Sperry Sun MWD tool. Finish free point with Schlumberger, found p ipe free all the way to the MWD tools, POOH with wire line RIH W/backoff shot, back pipe off one DC a bove to MWD tool, 2612', POOH with wire lin e. POOH, LID 2 non-mag DC's Change TDS saver sub to 4 1/2" IF connecti on for 5" DP, bring fishing tools to rig floor P/U fishing assembly, 4 1/2 IF screw in sub, bumper sub, fishing jars, 6 1/2" DC's, exce lIerator and 5" DP, RIH to 2600' Circ and cond mud and hole at 2601, rotatin g and reciprocating pipe Screw into fish, torque connection to 25,000 ft Ibs, fish started to rotate, rotate and ba ck ream without circ, torque running from 15 ,000 to 7,000 ft Ibs. Backream out of hole w ithout circ to 2600' bit depth, overpull from 10 to 30k, pipe stuck a few times with DP pr essure when trying to circ. At 2600' bit dept h we seen a free spot, stopped and worked p ipe in free spot, this is where we had circ. prior to screwing into fish. Brought mud pum p on and regained circulation. Circulate and back ream tight hole to 800', pipe came free where we were able to pull p ipe without reaming, pull to DC's at report t ¡me POOH and LID fish, (Directional BHA) RIH with 9 7/8" hole opener on 5" drill pipe to bottom, had one slight tight spot that too k 20k and wiped right out at 2600' to 2630' and nothing else to bottom Circ and cond hole for casing run POOH LID 5" DP and 6 1/2" DC's Printed: 1/21/2002 10:27:43 AM ( PHILLIPS ALASKA INC. Operations>.SummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Sub From - To Hours Code Code Phase 12/31/2001 10:30 - 12:00 1.50 DRILL RIRD SURFAC 12:00 - 16:00 4.00 CASE RUNC SURFAC 16:00 - 19:00 3.00 CASE CIRC SURFAC 19:00 - 19:30 0.50 CEMEN RURD SURFAC 19:30 - 20:00 0.50 CEMEN SFTY SURFAC 20:00 - 22:30 2.50 CEMEN PUMP SURFAC 22:30 - 00:00 1.50 CEMEN PULD SURFAC 1/1/2002 00:00 - 02:30 2.50 CASE NUND SURFAC 02:30 - 04:30 2.00 CASE NUND PROD 04:30 - 08:30 4.00 CASE NUND PROD 08:30 - 09:30 1.00 CASE RURD PROD 09:30 - 15:30 6.00 WELCT BOPE PROD 15:30 - 19:30 4.00 DRILL PULD PROD 19:30 - 21 :00 1.50 DRILL TRIP PROD 21 :00 - 22:00 1.00 CASE DEQT PROD 22:00 - 23:00 1.00 CASE CIRC PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 1/2/2002 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 02:30 0.50 WELLS NUND PROD 02:30 - 03:30 1.00 WELLS NUND PROD 03:30 - 04:30 1.00 WELLS NUND PROD 04:30 - 07:30 NUND PROD Page 60t 12 Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 DescriptiQnof Qperations R/U to run 7 5/8" casing, hold pre-job safet y meeting RIH with 69 jts 7 5/8" 29.7# L-80 BTCM casi ng and set at 2976.3', had no tight hole goi n gin. Circ. and Cond hole for cementing, thin out mud, reciprocate pipe while circulating R/U Franks fill up tool and cement head Hold pre-job safety meeting With Schlumberger Dowell Well, we pumped 10 bbls CW-100, test lines to 3500 psi, pum p 30 bbls CW-100, drop bottom plug, pump 5 0 bbls 10.5 ppg Mud Push, 316 bbls lead ce ment at 10.7 ppg, 65 bbls tail cement at 12 ppg, drop top plug, pump 5 bbls water and d is place with rig pump, bump plug with 500 p si over, floats held. We was suppose to pum p 90 bbls of tail cement, but cement silo's a nd hopper line became plugged and couldn't mix. We were short 25 bbls of tail cement. r ecover 55 bbls of good 10.7 ppg cement to s urface. Reciprocated pipe until it started to get sticky, half way thru cement job. Clean cement out of stack and related equip ment, LID cement head and casing equipmen t, clear floor, LID casing landing jt. NID Diverter System N/U Csg head & orient - Test to 1000psi hol d 5 min "OK" B/U BOPs CIO Saver Sub on TD Test BOPs - Test BOPs & choke manifold 25 0/3000 psi - Hold ea. test 5 min - Chart for AOGCC - AOGCC did not respond back from notification to Rig - Pull test plug - Install wear ring P/U BHA #4 - P/U Bit & Motor and orient - S cribe tolls - up load MWD - Load RA sources TIH - (Rotate slowly thru TPC @ 1013') Tag up @ 2884' Circu air from system - R/U to Test Csg - At tempt Csg Integrity Test - Pack off failed @ 600 psi. Blew seal and thread lock ring on FMC Gen V Csg Head Circu to balance mud system for TOH TOH - SIB all possible BHA Con't TOH - LID MWD & HO sub Pull wear bushing - clear floor N/D BOPs CIO leaking Csg Head - Top seal bad - Lock nut ring not inguaged N/U BOPs Printed: 1/21/2002 10:27:43 AM (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( Page 70f 12 PHILLIPS ALASKA INC. Operations Summary Report 1/212002 07:30 - 08:30 1.00 WELCT BOPE PROD 08:30 - 10:00 1.50 DRILL PULD PROD 10:00 - 11 :00 1.00 DRILL TRIP PROD 11 :00 - 12:00 1.00 CASE DEOT PROD 12:00 - 13:00 1.00 CASE DEOT PROD 13:00 - 15:00 2.00 DRILL OTHR PROD 15:00 - 15:30 0.50 DRILL DRLG PROD 15:30 - 16:00 0.50 DRILL CIRC PROD 16:00 - 17:00 1.00 DRILL FIT PROD 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 07:00 - 12:00 5.00 DRILL DRLG PROD 12:00 - 19:00 7.00 DRILL DRLG PROD 19:00 - 20:30 1.50 DRILL CIRC PROD 20:30 - 21 :30 1.00 DRILL WIPR PROD 21 :30 - 22:30 1.00 DRILL WIPR PROD 22:30 - 23:30 1.00 DRILL CIRC PROD 23:30 - 00:00 0.50 DRILL DRLG PROD 1/6/2002 00:00 - 12:00 12.00 DRILL DRLG PROD Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 [)escription . of QpE!rati()ns Sub From-To Hours Code Code Phase 17:00 - 19:00 2.00 DRILL DRLG PROD 19:00 - 19:30 0.50 DRILL OTHR PROD 19:30 - 00:00 4.50 DRILL DRLG PROD 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 00:00 - 05:30 5.50 DRILL DRLG PROD 05:30 - 07:00 1.50 DRILL CIRC PROD 07:00 - 08:00 1.00 DRILL WIPR PROD 08:00 - 08:30 0.50 RIGMNT RSRV PROD 08:30 - 09:30 1.00 DRILL WIPR PROD 09:30 - 12:00 2.50 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 00:00 - 06:00 6.00 DRILL DRLG PROD 06:00 - 07:00 1.00 DRILL CIRC PROD 1/3/2002 1/4/2002 115/2002 Re-Test Body & Choke line breaks P/U MWD & HO sub - Orient - Load RA sourc es TIH to 2872' Circu air from system Test Csg to 2500 psi -Hold 30 min on chart - Loss 30 psi Drlg FC,CMT & FS to 2990' (Old TD) Drlg 2990' to 3020' MD (2463' TV D) Circu Hole clean - C/O mud to good conditio ned 9.7ppg clean system Preform FIT - Pressure to 807psi @ 2463' T VD w/ 9.7ppg mud = 16.0 EMW - hold 10min - loss 80 psi Drlg & Slide 3020' to 3160' MD CBU to clean hole - Preform Base line test f or PWD tools Drlg & Slide 3160' to 3450' MD (2688' TV D) ART 2.7 hrs, AST 0.5 hrs Drlg & Slide 3450' to 4080' MD (3026' TV D) ART 8.6 hrs , AST 1.2 hrs Drlg & Slide 4080' to 4700' MD (3363' TV D) ART 9.3 hrs , AST 0.3 hrs Drlg & Slide 4700' to 4982' MD (3512' TV D) ART 3.4 hrs , AST 1.5 hrs Pump Wt sweep - Circu hole clean Wiper Trip - TOH to 7 5/8" Shoe - No Swab - No overpull - Hole in good shape Service Rig & TD Wiper Trip - TIH to 4982' - No tight hole - N 0 fill Drlg & Slide 4982' to 5130' MD (3590' TV D) ART 2.1 hrs , AST 0.0 hrs Drlg & Slide 5130' to 5750' MD (3918' TV D) ART 8.2 hrs , AST 1.3 hrs Dir Drlg & Slide 5750' to 6063' MD (4085' T VD) ART 3.9 hrs , AST 0.8 Tool failed- No signal from pulsor - Work to 01 & cycle pumps in attempt to regain signal - Pump sweep - Re-Gained Signal from tool s Dir Drlg & Slide 6063' to 6422' MD ( 4274' T V D) Dir Drlg & Slide 6422' to 6806' MD ( 4472' T VD) ART 5.0 hrs , AST 0.5 hrs Pump Wt I Hi vis sweep - Circu hole clean TOH to 4800' - No excss drag - No swab TIH - Wash 90' to Bttm - No fill CBU - Clean hole - MAX ECD 10.85 - BU Gas 73 units Dir Drlg & Slide 6806' to 6820' MD ( 4479' T VD) AST 0.2 hrs Dir Drlg & Slide 6820' to 7574' MD ( 4876' T Printed: 1/21/2002 10:27:43 AM ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From-To Hours . Code Sub . Phase Code 1/6/2002 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 13:30 1.50 DRILL CIRC PROD 13:30 - 00:00 10.50 DRILL DRLG PROD 1/7/2002 00:00 - 04:00 4.00 DRILL DRLG PROD 04:00 - 06:00 2.00 DRILL CIRC PROD 06:00 - 08:00 2.00 DRILL WIPR PROD 08:00 - 08:30 0.50 DRILL CIRC PROD 08:30 - 16:00 7.50 DRILL DRLG PROD 16:00 - 18:30 2.50 DRILL CIRC PROD 18:30 - 00:00 5.50 DRILL TRIP PROD 1/8/2002 00:00 - 02:30 2.50 DRILL PULD PROD 02:30 - 05:30 3.00 CEMEN PLUG PROD 05:30 - 06:30 1.00 CEMEN TRIP PROD 06:30 - 07:30 1.00 RIGMNT RSRV PROD 07:30 - 08:30 1.00 CEMEN TRIP PROD 08:30 - 09:30 1.00 CEMEN OTHR PROD 09:30 - 10:00 0.50 CEMEN TRIP PROD 10:00 - 10:30 0.50 CEMEN CIRC PROD 10:30 - 11 :30 1.00 CEMEN PLUG PROD 11 :30 - 12:30 1.00 CEMEN TRIP PROD 12:30 - 13:30 1.00 CEMEN CIRC PROD 13:30 - 14:30 14:30 - 17:00 1.00 CEMEN TRIP PROD 2.50 CEMEN PULD PROD 17:00 - 17:30 17:30 - 21 :00 0.50 WELCT BOPE PROD 3.50 WELCT BOPE PROD 21 :00 - 21 :30 21 :30 - 00:00 0.50 WELCT BOPE PROD 2.50 DRILL PULD PROD Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description..of..Opefé~tions VD) ART 9.1 hrs , AST 1.1 hrs Circu Hole clean pryor to drilling Bermuda p er well plan - Clean hole ECD 10.6 Dir Drlg & Slide 7574' to 8115' MD (5169' T VD) ART 6.8 hrs , AST 1.5 hrs Max BU Gas 206 units Dir Drlg & Slide (Control ROP 80' FPH Max) 8115' to 8330' MD (5279' TV D) Pump Hi Vis Sweep - Circu hole clean Wiper Trip to 6425' - No excess drag - No s wab Pump Hi Vis Sweep - Circu hole - Logs show ed no Bermada sands- Dicission was made b y Engineers to drill 200' TVD more hole to c heck for sands. Dir Drlg & Slide 8330' to 8663' MD ( 5458' T VD) ART 4.0 hrs , AST 1.9 hrs ** Note**Stop ped early - Engineer ( Steve Moothart)called and said they had seen enough - Stop drillj ng - Will plug back for Side Track Pump Hi Vis Sweep - Circu Hole clean - Pum p Dry job - Monitor well TOH - LID BHA Con't LID BHA -PJSM - Remove RA scources - LID HOS & MWD - SIB Motor and MWD P/U CMT Stinger - P/U Mule shoe & 20 jts 2 7/8" EUE 8rd Tbg & 2 XOs TIH wI Tbg CMT stinger on 4" DP to 2940' Cut drill line TIH to 4800' Spot 10 ppg Gel pill from 4800' to 4400' TOH to 4400' Circu BU Cement - Lay balanced CMT Plug from 4400' to 3800' - Pump 10 bbl H2o ,30.7 bbl 17.0p pg CMT , 2.9 H2o - Displace with Rig 343 st ks 9.6ppg mud.- Pressures while pumping @ 13.5 bbls ,20spm , 2730 psi @ 25.3 bbls 5 spm, 3100 psi ,@ 34.6 bbl , 40spm , 870 P si TOH -Slowly pulling out of CMT to 3300' (5 00' above calcu TOC) Circu and clear drill string - Saw contaminat ed Mud - No CMT TOH - SIB 4" DP R/U Tbg tools - LID 2 7/8" Tbg CMT stinger & mule shoe Pull wear bushing - Install test plug Test BOPs & Choke Manifold - test 250 130 OOpsi - Chart for 5min/5min - AOGCC John S paulding waived witness test Pull test plug - Install wear bushing P/U BHA #7 Printed: 1/21/2002 10:27:43 AM PHILLIPS ALASKA INC. Operations Summary Report ( Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From.. To Hours ..Code Sub Phase Code 1/9/2002 00:00 - 02:30 2.50 DRILL DRLG PROD 02:30 - 04:00 1.50 DRILL TRIP PROD 04:00 - 04:30 0.50 DRILL CIRC PROD 04:30 - 05:30 1.00 DRILL TRIP PROD 05:30 - 06:30 1.00 DRILL CIRC PROD 06:30 - 08:30 2.00 DRILL CIRC PROD 08:30 - 10:00 1.50 DRILL CIRC PROD 10:00 - 11 :00 1.00 DRILL DRLG PROD 11 :00 - 12:00 1.00 DRILL DRLG PROD 12:00 - 19:30 7.50 DRILL DRLG PROD 19:30 - 21 :00 1.50 DRILL CIRC PROD 21 :00 - 22:00 1.00 DRILL WIPR PROD 22:00 - 00:00 2.00 DRILL DRLG PROD 1/10/2002 00:00 - 04:30 4.50 DRILL DRLG PROD 04:30 - 05:30 1.00 DRILL CIRC PROD 05:30 - 12:00 6.50 DRILL DRLG PROD 12:00 - 13:30 1.50 DRILL DRLG PROD 13:30 - 15:00 15:00 - 19:00 19:00 - 19:30 1.50 DRILL CIRC PROD 4.00 DRILL TRIP PROD 0.50 DRILL TRIP PROD 19:30 - 20:00 0.50 DRILL SFTY PROD 20:00 - 22:00 2.00 DRILL PULD PROD 22:00 - 22:30 0.50 DRILL PULD PROD 22:30 - 23:30 1.00 DRILL TRIP PROD 23:30 - 00:00 0.50 DRILL PULD PROD Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 DescriptionofOpërations P/U BHA # 7- PJSM RA sources - Initialize MWD (repair CIM connection) Install RA sco urces -P/U Std NM DCs TIH to 2996' Fill Pipe - Break Circu - Pulse Test MWD TIH to 3590' M/U TD - Circu slowly - Wash to 3910' (CMT stringers & Soft CMT @ 3870' ) Circu hole clean - Preform PWD baseline Te st - Clean Hole ECD = 10.4+ Waiting on State to approve PTD - Rotate & Pump at a reduced rate ( 20 RPMs & 1.5 BP M) recip DP Drlg CMT 3910' - 4000' Time Drlg Side Track well @ 4000' to 4051' ( Departure point 4000') Dir Drlg & Slide 4051' to 4406' ( 3240' TVD) ECDs = 10.8 Pump sweep - Circu hole clean WiperTrip back thru KO point - Work KG poi nt clean Dir Drlg & Slide 4406' to 4480' ( 3290' TVD) ECDs = 11.0 D i r D rig & Slide 4 4 8 0 I to 4 7 1 2 ' ART 2. 0 h r s , AST 0.5 hrs - Control drlg fl ECDs + LWD logs - ROP 120 fph High ECDs 11.17 - Circu & Condition hole t 0 lower ECDs - Recip & Rotate 120 RPMs to maximize hole cleaning - Start wi 11.22 - Fi na110.8 Dir Drlg & Slide 4712' to 4982' MD ( 3657' T VD) ART 4.5 hrs , AST 1.0 hrs Control drlg FI ECDs @ 75 fph - ECDs = 10.9 Dir Drlg & Slide 4982' - 5030' MD ( 3694' TV D) ART 0.9 hrs , AST 0.0 hrs Tool failure - No signal from pulsor - 650 extra SPP (pos sible plugged jet) Pump Sweep - Circu Hole clean TOH - No Swab - No Tight hole Broke connection on Top of Pulsor sub - Ha d a large amount of CMT debris setting on t op of puis or from inside DP - Large pieces some 2"X4" & 3/8" thick. PJSM - Discuss plan to LID and clean Cmt fr om tools LID MWD & PWD - Brk Bit,guage and clean ( 1 plugged jet) - SIB remaining BHA in derric k Move HWDP from Right to Left side of derric k TIH open ended with CMT affected 4" DP - 2 5 stds total (75 jts) TOH LID CMT affected 4" DP Printed: 1/21/2002 10:27:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( PHILLIPS ALASKAJNC. Operations Summary Report 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Page100f 12 Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Spud Date: 12/22/2001 End: 1/3/2002 Group: Süb From -To Hours. . Code COde Phase 1/11/2002 00:00 - 01 :30 01 :30 - 05:00 05:00 - 07:30 07:30 - 08:00 08:00 - 09:30 09:30 - 10:00 10:00 - 12:00 12:00 - 00:00 1/12/2002 00:00 - 12:00 12:00 - 16:30 16:30 - 18:00 18:00 - 19:00 19:00 - 21 :00 21 :00 - 22:30 22:30 - 23:30 1/13/2002 23:30 - 00:00 00:00 - 00:30 00:30 - 02:30 02:30 - 12:00 12:00 - 19:00 19:00 - 23:30 1.50 DRILL DRLG PROD 3.50 DRILL TRIP PROD 2.50 DRILL TRIP PROD 0.50 DRILL CIRC PROD 1.50 DRILL TRIP PROD 0.50 DRILL CIRC PROD 2.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 4.50 DRILL DRLG PROD 1.50 DRILL CIRC PROD 1.00 DRILL WIPR PROD 2.00 DRILL CIRC PROD 1.50 DRILL WIPR PROD 1.00 DRILL WIPR PROD 0.50 DRILL TRIP PROD 0.50 DRILL TRIP PROD 2.00 DRILL CIRC PROD 9.50 DRILL DRLG PROD 7.00 DRILL DRLG PROD 4.50 DRILL CIRC PROD 23:30 - 00:00 0.50 DRILL WIPR PROD 1/14/2002 00:00 - 03:30 3.50 DRILL WIPR PROD 03:30 - 06:00 2.50 DRILL TRIP PROD Con't LID 4" HT 38 DP (CMT coating inside pipe) LID total off 75 jts P/U BHA - P/U Mtr & MWD ,M/U Bit wi turbo back stab + Fit - P/U & orient PWD , HOS - Install prob -initialize MWD -Load scources TIH to 3050' Brk Circu - Pulse test MWD - "OK" TIH to 4982' Circu BU to minimize ECDs - Pre circu ECDs 11.4 , post ECDs 10.5+ Dir Drlg & Slide 5030' to 5101' MD (3749' T VD) ART 0.7 hrs, AST 0.3 hrs Dir Drlg & Slide 5101' to 5750' MD (4262' T VD) ART 5.9 hrs, AST 3.1 hrs Dir Drlg & Slide 5750' to 6471' MD ( 4848' T VD) ART 9.3 hrs , AST 0.3 hrs Dir Drlg & Slide 6471' to 6709' MD ( 5040' T VD) ART 3.3 hrs , AST 0.2 hrs Pump Sweep - Circu hole clean - 4 BUs - Re cip & Rotate (120 RPMs) pre circu ECDs 11. 0 , post ECDs 10.6 - Monitor well TOH f/ WiperTrip - 30K overpul 6210' - 615 0' - Return to 6330' Pump Wt/ Hi Vis Sweep - 3+ BUs - Circu hol e clean - ECDs 10.5 T 0 H - T i g h t (4 0 K 0 v e r pull) - P u m p & B a c k r eam 3 stds ( 6130' to 5850') Pulling free TOH - 5850' to 4800' - No drag - No Swab - Proper hole fill Monitor well - Static- TIH TIH to 6616 -No Tight hole - M/U TD - Wash to Bttm 6709' - No fill Circu BU followed by tandum sweeps - pre-ci rcu ECDs 10.75 , post ECDs 10.44 (Calcu cl ean hole ECDs 10.4) Dir Drlg & Slide 6709' to 7226' MD ( 5460' T VD) ART 7.8 hrs , AST 0 hrs MAx BU Gas 1 347 units @ 7112' - Pumping a Hi Vis sweep as we drill each std down. This appears to keep the hole clean and ECDs to a minimum . We will continue doing this thru TD of well Dir Drlg & Slide 7226' to 7593' MD ( 5750' T VD) ART 5.4 hrs , AST 0 hrs Circu Hole Clean - Pump a pair of tandum Hi Vis sweeps (4 total, 2- 20 bbl + 2- 10 bbl) Recip & Rotate 110 RPM to maximize hole c leaning, post ECDs 10.45 Shut Down Monitor well - Pump Dry job - Blo w down TD Con't wiperTrip to 7 5/8" Shoe - No Swab - No excess drag TIH to Bttm - No tight hole Printed: 1/21/2002 10:27:43 AM I" ~, PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From.. To Hours Code Sub Phase Code 1/14/2002 06:00 - 08:30 2.50 DRILL CIRC PROD 08:30 - 13:30 5.00 DRILL TRIP PROD 13:30 - 18:00 4.50 DRILL TRIP PROD 18:00 - 18:30 0.50 DRILL TRIP PROD 18:30 - 21 :30 3.00 CASE RUNC PROD 21 :30 - 00:00 2.50 CASE RUNC PROD 1/15/2002 00:00 - 01 :30 1.50 CASE RUNC PROD 01 :30 - 02:00 0.50 CASE CIRC PROD 02:00 - 06:00 4.00 CASE RUNC PROD 06:00 - 07:00 1.00 CASE CIRC PROD 07:00 - 08:30 1.50 CASE RUNC PROD 08:30 - 09:30 1.00 CASE CIRC PROD 09:30 - 10:00 10:00 - 14:30 0.50 CEMEN RURD PROD 4.50 CEMEN CIRC PROD 14:30 - 16:00 1.50 CEMEN PUMP PROD 16:00 - 16:30 0.50 CEMEN RURD PROD 16:30 - 17:30 1.00 WELCT NUND PROD 17:30 - 00:00 6.50 CMPL TN RUNT PROD 1/16/2002 00:00 - 02:00 2.00 CMPL TN RUNT CMPL TN 02:00 - 04:00 2.00 CMPL TN CIRC CMPL TN 04:00 - 06:00 2.00 CMPL TN SOHO CMPL TN Page 11. of 12 Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 PescriptiQo.of'.Operéitions CBU - Pump tandem Hi Vis sweeps - Circu h ole clean ECDs 10.38 TOH - SLM - Flow check well per PHI policy LID SWDP & Jars - LID BHA - Remove RA s ources - Down load MWD logs -LID remainin g BHA & Bit Clear all Tools & Equip from Rig Floor - Pul I wear bushing R/U & Run 3.5" 9.3# L80 EUE 8 rd Tbg - S lim hole completion (21 jts) - RID Tbg tools R/U 5.5" Csg tools - Run 5.5" 15.5# LBO B TCM Csg per well plan Run 5 1/2" casing to shoe, 2976' Circ. bottoms up Run 5 1/2" casing to 5600' Circ. bottoms up, no fluid loses Run 5 1/2" casing to 7585.65' - attempt to c irc at 6800', but seen fluid losses to hole at 2 1/2 bbl per min circ. rate, decided to go on to bottom to fight losses. Circ. and cond mud, having loses to hole, 3 0 to 40 bbls per hr. R/U cementing head Circ and cond mud before cementing, contin ue to slow down mud loses to hole with addi tion of bara fiber. Losses when we quit circ. was down to approx 15 bbls per hr. Lost ap prox 125 bbls fluid to hole while circ. Hold pre-job, test lines to 3600 psi, batch m ix cement with Dowell Schl., mix and pump 4 8 bbls CW-100, mix and pump 33 bbls 12 pp g Mud Push, pump 56 bbls 15.8 ppg cement slurry with 1/4 Ib per sk cello flake for lose control, drop cement plug and wash up line s, pump 12 bbls 9.9 ppg brine water and dis place with rig pump using 9.6 ppg mud. Bum p plug with calculated displacement at 1400 psi. Seen no fluid loses to hole during ceme nt job RID cement head, LID landing jt. Install well head pack off and test to 5000 p si Run in hole with completion equipment and t ubing. We are in hole with 187 jts of 3 1/2" tubing, have 28 left to run at report time. Run in hole with Completion equip. and 3 11 2" tubing to 6828', circ. down to find top of SBE at 6873' Reverse Circ. mud out of hole with clean fre sh water RIH and tag top of SBE, run in and tag locat ors, space out with 2' of space out between Printed: 1/21/2002 10:27:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/16/2002 04:00 - 06:00 06:00 - 07:30 07:30 - 09:00 09:00 - 12:00 12:00 - 17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 00:00 PHILLIPS ALASKA INC. Operations Summary Report 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Sub Hours. »Code Code Phase 2.00 CMPL TN SOHO CMPL TN 1.50 CMPL TN DEQT CMPL TN 1.50 WELCT NUND CMPL TN 3.00 WELCT NUND CMPL TN 5.50 DRILL PULD CMPL TN 2.00 DRILL RIRD CMPL TN 0.50 DRILL RIRD CMPL TN 4.00 MOVE DMOB DEMOB Page 12 of 12 Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description (>fQperations locators, hang off tubing in hanger, run in I ock down screws R/U and pressure tubing to 500 psi, test cas ing to 3000 psi for 30 mins, bleed off press ure in tubing and shear down hole Camco sh ear valve, set back pressure valve Hold Pre-job meeting, N/D BOP's N/U Tree and test seals to 5000 psi, test tre e body to 250 low and 5000 psi high. Pull B PV LID 7000' of 4" drill pipe. Freeze protect tu bing, 3.5 x 5.5 annulus with 53 bbls diesel. Perform annular LOT down 5.5 x 7.625 annul us and freeze protect with 51 bbls diesel. CI eaning pits ongoing. Change out bad saver sub and grabbers on t op drive Install BPV in tubing hanger Prepare rig for move, trucks to be here and ready to move rig at midnight. Rig was rele ased at 2200 hrs. 01/16/2002 Printed: 1/21/2002 10:27:43 AM Date 01/26/02 01/27/02 02/03/02 02112/02 02/13/02 02/14/02 02/15/02 02/16/02 ( ( 2P-448A Event History Comment PULLED BPV F/ TBG HANGER, DRIFTED TBG W/ 2.80" SWAGE, TAGGED FILL @ 7339' RKB, PULLED DV F/6770' RKB, SET H.E.S. SIDE POCKET GAUGES, PIT TBG, GOOD TEST, PIT CSG FAILED, DUE TO COMPANION FLANGE/CSG VALVE, LEAKING BAD, COMPLETE. [TAG] PERFORATED W/ 2.5" HSD 6 SPF, PJ (7195'-7210') AT 3500 PSI SITP, MADE JEWELRY LOG, LOGGED -- STATIC BHP= 2291 PSI AND TEMP= 140 DEGF, POOH, RDMO, LEFT WELL SI. VALVE CREW ARRIVED, FIXED LEAKING COMPANION FLANGE, PT IA TO 3000 PSI. [PERF] PUMPED INITIAL FRAC TREATMENT. PLACED 91M# 16/20 CARBOUTE BEHIND PIPE, HAD NWBSO WITH 9.6 PPA ON PERFS,37% OF DESIGN. LEFT 20M# IN WELLBORE. ALL TREESAVER RUBBERS RECOVERED. [FRAC-REFRAC] UNIT PREP / EQUIPMENT STANDBY FOR POST-FRAC FILL CLEANOUT [FCO] TESTED BOP, DRIFTED NEW COILED TBG. JOB DELAYED DUE TO MECHANICAL PROBLEMS. WILL RESUME IN THE A.M. [FCO] JETTED THROUGH SLUSH/ICE "STRINGERS" TO 15001 USING 2" DOWN-JET NOZZLE W/ HOT S. DIESEL. SWAPPED TO 2" JET-SWIRL NOZZLE AND CLEANED OUT TO 7400' CTM W/ S. DIESEL AND DIESEL GEL (EST. 150' OF RATHOLE). WELL LEFT SHUT IN AND FREEZE PRorD TO 2500' W/ DIESEL TAGGED FILL @ 73231 RKB, EST. 113' RAT HOLE, PULLED 1" SIDE POCKET GAUGE @ 6770' RKB, INSTALLED 1" X 5/16" OV W/ CK, LEFT IN HOLE VALVE CATCHER @ 6836' RKB. [TAG] PULLED 2.75'1 CATCHER SUB F/6836' RKB COMPLETE [TAG] Page 1 of 1 2/25/2002 ( ~ ~'~'")'~~~"!("~' ,""r~I','" ""I':-:~"\íf.i ,.,¡", . '}0ð:~.';~"'" , 30-Jan-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2P-448A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 3,957.19' MD Window / Kickoff Survey 4,051.52' MD (if applicable) Projected Survey: 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED FEB 0 1 2002 Alaska Oil 8: Gas Cons, Commission Anchorage DEFINITIVE '- Kuparuk River Unit North Slope, Alaska Kuparuk 2P, Slot 2P-448 2P-448A Job No. AKMM11214, Surveyed: 13 January, 2002 - SURVEY REPORT 28 January, 2002 Your Ref: API 501032039601 Surface Coordinates: 5868858.45 N, 443542.95 E (700 03' 08.4766" N, 1500 27' 06.4661" W) Kelly Bushing: 252.50ft above Mean Sea Level '-', '-- Spe""'Y-SUI! DRILLING SERVIc:es A Halliburton Company Survey Ref: s,vy9827 Sperry-Sun Drilling Services . Survey Report for 2P-448A Your Ref: API 501032039601 Job No. AKMM11214, Surveyed: 13 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (')/1 OOft) 3957.19 57.330 242.540 2708. 1 0 2960.60 998.70 S 1882.75 W 5867873.73 N 441652.85 E 2011.99 Tie On Point "-c 4051.52 54.940 240.900 2760.66 3013.16 1035.79 S 1951.72 W 5867837.15 N 441583.60 E 2.916 2086.07 Window Point ~ 4147.13 52.270 237.050 2817.40 3069.90 1075.40 S 2017.67 W 5867798.03 N 441517.37 E 4.278 2159.94 -.' 4243.03 49.310 231.750 2878.05 3130.55 1118.57 S 2078.08 W 5867755.31 N 441456.63 E 5.277 2232.66 4337.57 46.680 227.870 2941.32 3193.82 1163.85 S 2131.76 W 5867710.44 N 441402.62 E 4.127 2302.35 4433.87 45.890 227.500 3007.87 3260.37 1210.70 S 2183.23 W 5867663.96 N 441350.81 E 0.866 2371.70 4530.53 45.220 226.360 3075.55 3328.05 1257.82 S 2233.64 W 5867617.22 N 441300.05 E 1.091 2440.53 4626.42 44.410 225.070 3143.58 3396.08 1305.01 S 2282.02 W 5867570.39 N 441251.32 E 1.270 2508.02 4722.60 43.430 220.480 3212.87 3465.37 1353.93 S 2327.32 W 5867521.80 N 441205.65 E 3.463 2574.70 4818.09 42.150 219.400 3282.95 3535.45 1403.66 S 2368.97 W 5867472.39 N 441163.64 E 1.545 2639.49 4914.36 41 .170 218.470 3354.87 3607.37 1453.43 S 2409.19 W 5867422.91 N 441123.05 E 1.204 2703.33 5008.77 40.300 215.130 3426.42 3678.92 1502.74 S 2446.09 W 5867373.88 N 441085.78 E 2.485 2764,58 5105.61 39.770 211.600 3500.57 3753.07 1554.74 S 2480.35 W 5867322.14 N 441051.14 E 2.408 2826.01 5201.26 39.310 205.950 3574.36 3826.86 1608.06 S 2509.65 W 5867269.04 N 441021.45 E 3.790 2885.04 5297.50 38.860 199.650 3649.09 3901.59 1663.93 S 2533.15 W 5867213.34 N 440997.54 E 4.152 2942.00 5392.99 38.320 192.050 3723.77 3976.27 1721.12 S 2549.41 W 5867156.27 N 440980.85 E 4.994 2995.02 5489.16 37.560 184.830 3799.65 4052.15 1779.52 S 2558.11 W 5867097.94 N 440971.72 E 4.681 3043.77 5584.99 35.400 178.020 3876.74 4129.24 1836.40 S 2559.61 W 5867041.08 N 440969.80 E 4.786 3086.52 5682.50 35.720 178.210 3956.06 4208.56 1893.07 S 2557.75 W 5866984.39 N 440971.24 E 0.347 3126.84 ,-.. 5778.07 35.760 178.590 4033.63 4286.13 1948.87 S 2556.19 W 5866928.58 N 440972.39 E 0.236 3166.73 5873.65 35.920 177.660 4111.12 4363.62 2004.81 S 2554.36 W 5866872.63 N 440973.80 E 0.594 3206.52 5969.62 35.980 178.290 4188.81 4441.31 2061.11 S 2552.37 W 5866816.31 N 440975.38 E 0.390 3246.48 6064.48 36.380 178.090 4265.37 4517.87 2117.08 S 2550.60 W 5866760.33 N 440976.73 E 0.440 3286.35 6161.06 36.380 177.990 4343.13 4595.63 2174.33 S 2548.64 W 5866703.07 N 440978.27 E 0.061 3327.02 6256.43 35.380 177.350 4420.40 4672.90 2230.18 S 2546.37 W 5866647.20 N 440980.12 E 1.120 3366.46 6353.25 35.500 176.870 4499.29 4751.79 2286.25 S 2543.54 W 5866591.11 N 440982.54 E 0.313 3405.68 6449.88 35.910 177.620 4577.75 4830.25 2342.58 S 2540.83 W 5866534.77 N 440984.83 E 0.621 3445.17 6545.38 35.090 177.110 4655.50 4908.00 2397.98 S 2538.28 W 5866479.35 N 440986.96 E 0.913 3484,08 6639.80 35. 11 ° 176.930 4732.75 4985.25 2452.20 S 2535.46 W 5866425.11 N 440989.38 E 0.112 3521.95 6738.28 35.520 177.590 4813.11 5065.61 2509.06 S 2532.74 W 5866368.23 N 440991.68 E 0.569 3561.82 28 January, 2002 - 15:12 Page 20f4 DrillQuest 2.00.08.005 Spefry-Sun Drilling Services . Survey Report for 2P-448A Your Ref: API 501032039601 Job No. AKMM11214, Surveyed: 13 January, 2002 North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6833.90 35.620 177.560 4890.89 5143.39 2564.63 S 2530.39 W 5866312.65 N 440993.62 E 0.106 3601.00 -~ 6929.50 36.000 177.180 4968.41 5220.91 2620.51 S 2527.82 W 5866256.75 N 440995.78 E 0.461 3640.25 7024.85 35.690 177.600 5045.70 5298.20 2676.29 S 2525.28 W 5866200.96 N 440997.91 E 0.415 3679.45 7121.62 36.110 177.550 5124.09 5376.59 2732.98 S 2522.87 W 5866144.25 N 440999.89 E 0.435 3719.41 7217.37 36.400 178.220 5201.30 5453.80 2789.56 S 2520.79 W 5866087.65 N 441001.56 E 0.513 3759.51 7313.70 37.030 178.210 5278.52 5531.02 2847.12 S 2518.99 W 5866030.08 N 441002.92 E 0.654 3800.53 7410.63 37.780 178.490 5355.52 5608.02 2905.98 S 2517.30 W 5865971.21 N 441004.18 E 0.793 3842.56 7506.08 38.130 178.230 5430.78 5683.28 2964.66 S 2515.62 W 5865912.52 N 441005.43 E 0.403 3884.4 7 7524.24 38.160 178.080 5445.06 5697.56 2975.87 S 2515.26 W 5865901.30 N 441005.70 E 0.536 3892.45 7593.00 38.160 178.080 5499.13 5751.63 3018.33 S 2513.83 W 5865858.83 N 441006.81 E 0.000 3922.64 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.3210 (28-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 222.800° (True). ,~~. Based upon Minimum Curvature type calculations, at a Measured Depth of 7593.00ft., The Bottom Hole Displacement is 3928.06ft., in the Direction of 219.789° (True). 28 January, 2002 - 15:12 Page 30f4 DrillQ/Jest 2.00.08.005 . ,,;.f';" . ;¡.T£,:: > $pefty-Sun Drilling Servic'es Survey Report for 2P-448A Your Ref: API 501032039601 Job No. AKMM11214, Surveyed: 13 January, 2002 .':.:.' ~ Kuparuk River Unit North Slope, Alaska Kuparuk 2P Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) -. Comment 3957.19 4051.52 7593.00 2960.60 3013.16 5751.63 998.70 S 1035.79 S 3018.33 S 1882.75 W 1951.72 W 2513.83 W Tie On Point Window Point Projected Survey Survey tool program for 2P-448A From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 7593.00 5751.63 MWD Magnetic (2P-448PB1) ~~ 28 January, 2002 - 15:12 Page 4 0'4 DrillQuest 2.00.08.005 -"-' 1 Ciö ../51 ~~. ðC5 I q 1,{)'50 a 01 -ICJ;l Cc~--- 02/06/02 Scb.bepgep NO. 1788 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503.5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Sepia Color CD 1A-17 PRESSITEMP SURVEY 01/28/02 1 1 2P-448A PERF RECORD/SBHP 01/27/02 1 1 3N-19 22046 USIT 01/14/02 1 2P-429 22045 SCMT 01/13/02 1 \ /ì SIGNED(/~~ {, OOrl{1t D RECEIVED DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. FEB 0 C 2002 AJaskaat & Gas Cons. Commission Anchorage '" , ~V~VŒ (ID~ fA\~fA\~[K\fA\ f ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TH 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 99510-0360 Re: Kuparuk River Unit 2P-448A Phillips Alaska, Inc. . Pennit No: 202-005 Sur Loc: 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM Btmhole Loc. 1316' FSL, 942' FEL, Sec. 18, T8N, R7E, UM Dear Mr. Mallary: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations 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 confinned by a valid Fonnation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on fonn 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 of20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. ( ( Permit No: 202-005 January 9,2002 Page 2 of2 Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, G~ {2Lti1/~' ~L, Cammy~echsli Taylo!3 Chair BY ORDER OF THE COMMISSION DATED this~ day of January, 2002 jjcÆnc10sures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 6. Property Designation ADL 373112 ALK 4998 7. Unit or property Name Kuparuk River Unit 8. Well number 2P-448A 9. Approximate spud date January 8, 2002 14. Number of acres in property .266()çÇ33 17. Anticipated pressure (see 20 MC 25.035 (e)(2» Maximum surface 1814 psig At total depth (TVD) 2385 psig Setting Depth ( (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Re-entry 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM At top of productive interval 1534' FSL, 950' FEL, Sec. 18, T8N, R7E, UM At total depth 1316' FSL, 942' FEL, Sec. 18, T8N, R7E, UM 12. Distance to nearest property line 13. Distance to nearest well 1534' @ Target 2P-438 198' @ 487.5 16. To be completed for deviated wells Kickoff depth: 4000 MD 18. Casing program size 1b. Type of well. Exploratory Stratigraphic Test Service 0 Development Gas 0 Single Zone 5. Datum elevation (OF or KB) RKB = 254 feet AMSL [:]ß> 0 feet Maximum hole angle 57 Top Bottom MD TVD MD TVD D 0 6947' 5229' Hole Casin G:. 5.5 î5,SI L-fJo 6.75" 3.5" 9.3# L-80 'vJGI\- , I q /O'L- Development Oil J Multiple Zone 0 10. Field and Pool Kuparuk River Field Meltwater Oil Pool 11. Type Bond (see 20 MC 25.0251) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 7501' MD / 5681' TVD 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 8663 feet true vertical 5458 feet measured 8663 feet true vertical 5458 feet Plugs (measured) Effective Depth: Junk (measured) Casing Conductor Surface Production Size Cemented 16" 9 cu yds High Early 7.625" 391 sx AS Lite, 202 sx LiteCrete Length Measured depth 120' 2976' Perforation depth: None measured True Vertical depth 120' 2440' RECEIVED JAN 0 8 2002 true vertical Alaska Oil & Gas Cons. Commis.c;ïon Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis OSeabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and rr ct to the best of my knowledge uest/ons. a at e/ y c{L Signed Title: Drilling Engineering Supervisor .,' Permit Number, 7'.Æ\/"""'-, .?-.D;-v .- ~ /03- 2b:f1'-0 Conditions of approval Samples required 0 Yes I8J No Hydrogen sulfide measures 0 Yes ~ No Required working pressure for BOPE 02M; 0 3M; 0 5M; Other: Test- B" ~ E .tö 3SoL'? l' <><.:. ~~l\:- Original Signed By Mud log required Directional survey required 0 10M; 0 JKI Yes 0 0 by order of the commission Approved by Commissioner HluHVM Form 10-401 Rev. 12/1/85. No Date Submit in triplicate If ,( 2P-448 Plug Back Procedure (balanced plug) Calculations assume 7.25" hole 1. Contact inspector to witness job. 2. PU 636' of 2 7/8" tubing to use as cement stinger. 3. RIH with stinger and DP to planned bottom of high vis pill 4800'. 4. CBU Pump High Vis Pill 5. Pump 5 bbl fresh water spacer. 6. Pump 20.4 bbl (400') high vis pill. (fresh water aqua gel 25 Ib/bbl weighted to 10 ppg) 7. Pump 0.64 bbl fresh water to balance plug. Plug # 1 (Kick Off Plug) 1""'" 8. POOH to planned bottom of plug #1 (kick off plug) 4400'. 9. Pump 10 bbl fresh water spacer. 10. Pump plug # 1, 30.7 bbl cement as per design below. 11. Pump 2.9 bbls fresh water to balance plug. 12. Pull stinger and DP out of plug to 500' above planned top of plug 3300' no faster than 1 stand / 3 minutes while pulling out of cement. 13. Circulate up spacers and contaminated mud/cement. 14. POOH to PU side track BHA. 15. CONFIRM COMPRESSIVE STRENGTH DEVELOPMENT WITH lAB BEFORE DRilLING ON PLUG. 16. IF PLUG IS NOT FIRM AFTER DRilLING 200', STOP DRilLING, PUll UP AND CIRCULATE. CAll DRilLING ENGINEER. 0'7 Meltwater 2P-448 Plug Back Requirements D \ Cement Plug #1 (Kick-Off Plug) : 3800' MD to ~ MD = 600'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. ~P-448 Plug Back Verbal approval ( ~' Subject: 2P-448 Plug Back Verbal approval Date: Mon, 7 Jan 2002 18:34:09 -0900 From: "Patrick Reilly" <preilly@ppco.com> To: winton_Aubert@admin.state.ak.us CC: tom- maunder@admin.state.ak.us, Jane - williamson@admin.state.ak.us Winton, Thank you for Per our phone kick off plug hydrocarbons. plug. the verbal approval to proceed with the 2P-448 plug back. conversation, we will plug back the original 2P-448 with a for a sidetrack. 2P-448 had no log indications of I will fax a sketch of the planned plug back and kick off Thanks, Pat Reilly Phillips Alaska (907) 265-6048 (907) 244-5558 (907) 265-1535 preilly@ppco.com Drilling & Wells WORK CELLULAR FAX 1 oft 1/8/02 6:46 AM (: I( 2P-448 Plug Back Procedure (balanced plug) Calculations assume 7.25" hole 1. Contact inspector to witness job. 2. PU 636' of 27/8" tubing to use as cement stinger. 3. RIH with stinger and DP to planned bottom of high vis pill 4800'. 4. CBU Pump High Vis Pill 5. Pump 5 bbl fresh water spacer. 6. Pump 20.4 bbl (400') high vis pill. (fresh water aqua gel 25 Ib/bbl weighted to 10 ppg) 7. Pump 0.64 bbl fresh water to balance plug. Plug # 1 (Kick Off Plug) 8. POOH to planned bottom of plug #1 (kick off plug) 4400'. 9. Pump 10 bbl fresh water spacer. 10. Pump plug # 1, 30.7 bbl cement as per design below. 11. Pump 2.9 bbls fresh water to balance plug. 12. Pull stinger and DP out of plug to 500' above planned top of plug 3300' no faster than 1 stand 13 minutes while pulling out of cement. 13. Circulate up spacers and contaminatedmud/cement. 14. POOH to' PU side track BHA. 15. CONFIRM COMPRESSIVE STRENGTH DEVELOPMENT WITH LAB BEFORE DRilLING ON PLUG. 16. IF PLUG IS NOT FIRM AFTER DRilLING 200', STOP DRilLING, PUll UP AND CIRCULATE. CALL DRilLING ENGINEER. Meltwater 2P-448 Plug Back Requirements Cement Plug #1 (Kick-Off Plug) : 3800. MD to 4400. MD = 6001. Cement with Class G + additives @17 ppg. Assume 15% excess on open hole volume. ORIGINAL PHILLIPS PHILLIPS Alaska, Inc. W A Subsidiary 01 PHILLIPS PETROLEUM COMPANY ( ( Calculations Charj Subject ()1 f'L- í w~ 2 {>.... 4 '-I ~ P L U 6, ßA vI<.... R~ By Sheet number Date I of I . mD TVD 380DI .c~ tP ,,/000 I '-1/' ó1} I I Co 00 I +- 1< \ <.. k ð F ç: P.L U..G,. ß..~/""O M. 1 roo . I TD ~fplo ~ . Q.L. PRINTING (907) 563-4743 ....OR1Glt~1tt 159-5881 ( (' Phillips Alaska, Inc. Drill Site 2P 448B slot #448 Meltwater North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 448B Version #1 Our ref: prop5061 License Date printed: 8-Jan-2002 Date created: 7-Jan-2002 Last revised: 8-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 8.477,w150 27 6.466 Slot Grid coordinates are N 5868858.493, E 443542.954 Slot local coordinates are 1021.01 S 1586.70 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ( f Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,448B Your ref : 448B Version #1 Meltwater,North Slope, Alaska Last revised : 8-Jan-2002 Measured Inclin . Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN A T E S Deg/100ft Sect 4000.00 57.45 242.52 2983.67 1015.30 S 1914.75 W 0.00 2045.93 KOP - Sidetrack pt 4100.00 55.30 240.00 3039.05 1055.31 S 1987.76 W 3.00 2124.89 4200.00 53.21 237.36 3097.47 1097.47 S 2057.10 W 3.00 2202.93 4300.00 51.17 234.57 3158.78 1141. 65 S 2122.56 W 3.00 2279.83 4400.00 49.21 231. 61 3222.81 1187.75 S 2183.99 W 3.00 2355.39 4500.00 47.32 228.48 3289.39 1235.64 S 2241. 20 W 3.00 2429.39 4600.00 45.53 225.16 3358.32 1285.17 S 2294.04 W 3.00 2501. 64 4700.00 43.84 221. 64 3429.43 1336.22 S 2342.36 W 3.00 2571.93 4800.00 42.26 217.90 3502.51 1388.65 S 2386.04 W 3.00 2640.08 4900.00 40.82 213.93 3577.37 1442.32 S 2424.95 W 3.00 2705.89 5000.00 39.51 209.74 3653.80 1497.07 S 2458.98 W 3.00 2769.19 5100.00 38.37 205.33 3731. 59 1552.75 S 2488.05 W 3.00 2829.80 5200.00 37.40 200.71 3810.53 1609.22 S 2512.08 W 3.00 2887.55 5300.00 36.61 195.90 3890.41 1666.32 S 2530.99 W 3.00 2942.30 5400.00 36.03 190.93 3971.00 1723.89 S 2544.73 W 3.00 2993.88 5500.00 35.66 185.84 4052.08 1781.78 S 2553.28 W 3.00 3042.15 5600.00 35.50 180.69 4133.43 1839.82 S 2556.59 W 3.00 3086.99 5655.85 35.51 177.81 4178.90 1872.25 S 2556.17 W 3.00 3110.50 EOC 6000.00 35.51 177.81 4459.04 2071.99 S 2548.52 W 0.00 3251.86 6500.00 35.51 177.81 4866.06 2362.19 S 2537.40 W 0.00 3457.23 7000.00 35.51 177.81 5273.07 2652.39 S 2526.29 W 0.00 3662.60 7047.82 35.51 177.81 5312.00 2680.14 S 2525.23 W 0.00 3682.25 Top Bermuda 7125.21 35.51 177.81 5375.00 2725.06 S 2523.51 W 0.00 3714.03 448B Tgt (Bermuda Midpt) 7-Jan-02 7201.38 35.51 177.81 5437.00 2769.27 S 2521.81 W 0.00 3745.32 Base Bermuda 7500.00 35.51 177.81 5680.09 2942.59 S 2515.17 W 0.00 3867.98 7501. 38 35.51 177.81 5681. 21 2943.39 S 2515.14 W 0.00 3868.54 TD All data is in feet unless otherwise stated. Coordinates from slot #448 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea Bottom hole distance is 3871.63 on azimuth 220.51 degrees from wellhead. Total Dogleg for wellpath is 49.68 degrees. Vertical section is from wellhead on azimuth 222.80 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ORIGINAL ( ( Phillips Alaska, Inc. Drill Site 2P,448B Meltwater/North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: 448B Version #1 Last revised: 8-Jan-2002 Comments in we11path -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 4000.00 2983.67 1015.30 S 1914.75 W KOP - Sidetrack Pt 5655.85 4178.90 1872.25 8 2556.17 W EOC 7047.82 5312.00 2680.14 8 2525.23 W Top Bermuda 7125.21 5375.00 2725.06 8 2523.51 W 448B Tgt (Bermuda Midpt) 7-Jan-02 7201. 38 5437.00 2769.27 8 2521.81 W Base Bermuda 7501. 38 5681.21 2943.39 8 2515.14 W TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- nla nla 2983.67 2983.67 1015.308 1015.308 1914.75W 8307.66 5681.21 1914.75W nla 2983.67 2943.398 1015.308 2515.14W 3 1/2" Liner 1914.75W 7 5/8" Casing Targets associated with this we11path ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- 448B Tgt (Bermuda Mi 440999.000,5866153.000,0.0000 5375.00 2725.068 2523.51W 7-Jan-2002 lJ ORIGINAL C :x:J ----- ~ ---- ~ ~ r--- 0 400 800 1200 1600 -:2' Q) Q) - 2000 '-..-/ ..r: +- Q. 2400 Q) 0 - 2800 0 .~ +- I.... Q) 3200 > Q) ::J 3600 I.... I- I V 4000 4400 4800 5200 5600 --------------._--------------------------------------------------------------------------------. , , , , L_-_~_Q~_l ~_!,P_,~_,__!\l_~ s ~ ~~,-,--,,_!,!! c ~--, ! Structure: Drill Site 2P , Field: Meltwater \ \\~\ \~~ ~ " "~, "~, 7 5/8 Casing "'-, ""'-, " "''''-." 6000 0 400 800 1200 1600 Well: 4488 Locati~,~ North Slope, Alaska 6000 5000 3500 <- West (feet) 2000 4500 4000 5500 3000 2500 IJ&íì8 BAKER HUGHES INTEQ 1500 500 1000 ,.",- ,g<~ 7 5/8 Casing V;,// /1'" ..,/#/"/ /' --/ KOP - Sidetrack pt //7' // //' /,/ // // ///// // ..,.f'/ [3'// KOP - Sidetrack pt 3 1/2 Liner ~~"., """ "'-'" , ""'~'" " '-"""''-- '",- ""''''' ""'."-"""'" """",,-, ", ""-'-,. ~'" Top Bermuda '''' 448B Tgt (Bermuda Midpt) 7-Jan-Ò2" Base Bermuda '~ 3 1/2 Liner ~~TD 2000 4400 5200 5600 2400 4000 4800 2800 3200 3600 Vertical Section (feet) -> Azimuth 222.80 with reference 0.00 N, 0.00 W from slot #448 6000 Midpt) 7-Jan-02 0 500 500 0 -', 500 (f) 0 1000 C -+ :r ,-.... 1500 -+. <T> ~ '-..-/ 2000 I V 2500 3000 3500 ---~ Created by hnctiuk Dote plotted: 8-Jon-2DD2 Plot Reference is 4488 Version '1. Coordinates ore in feet reference slot '448. Vertical Depths orc reference RKB (Doyon --- Boker Hughe. IHT[Q --- Meltwater 2P-448 A ~~je Track Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String 16" 62.6# @ +1- 120' MD Depths are based on Doyon 141 RKB Surface csg. 7-5/8" 29.7# L-80 STCM +1- 2976' MD I 2440' TVD 12' Pup (Critical) Intermediate csg. 5-1/2" 15.5# L-80 STCM run CSR to surface +1- 6947' MD 15229 TVD Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD TD to CSR +1-7501' MD 15681' TVD 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 'KBUG-2-9' Mandrels wI DVs and RK latch's (Max. OD 4.725", ID 2.90"), 1ST box x box, 3-1/2" X 6' L-80 EUE8RD box x 1ST pin handling pup installed above, 3-1/2" x 6' L-80 1ST pin x EUE8RD pin handling pup installed below. Spaced out wI 3-1/2" 9.3# L-80 EUE8RD tubing as follows: Q.bMjf. TVD-RKS MD-RKS GLM Numbers and Spacing To Se Determined 3-1/2" X 1" Camco 'KBG-2-9' mandrel wI DCK-3 shear valve and bottom latch (Max. OD 4.725", ID 2.90"), 1ST box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x 1ST pin handling pup installed above, 3-1/2" x 6' L-80 1ST 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 w/2.813" Cameo NO-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 3-1/2" Camco 'D' nipple wI 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly wi 15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" X 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" OD x 4" ID 17' Seal Bore Extension CSR set at +1- 100' above top of the Bermuda. ORIGINAL PJR, 01/08/02 Schlumberger CernCADE PreHminaryJob Design 5 .1/2"x3112" 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: 1/8/2002 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 Slurrv (minimum thickening time 126 min.) GasBLOK wI Class G + 053,0600,0135,0800,0047,0065, per lab testing @ 15.8 ppg, 1.2 fe/sk ~ ~ - '1~O~ 0.0835 ft3/ft x 00 x 1. ~o excess) = 0.1817 fe/ft x - 6947') x 1.75 (75% excess) = 0.0488 fe/ft x 80' (Shoe Joint) = 73.1 fe + 32.1 fe + 3.9 fe = 109.1 fel 1.2 fe/sk = Round up to 100 sks Pre\ßous Csg. < 75/8",29.7#, L-80 grade BTC, AB Modified at 3,000 ft. MD < 51/2", 15.5#, L-80 grade BTC, AB Modified in 63/4" OH < Top of Tail at 6,447 ft. MD < X-o\er at 6,947 ft. MD < Top of Bermuda Fm. at 7,047 ft. MD < 3 1/2", 9.3#, L-80 grade EUE, 8rd Modified in 63/4" OH 1D at 7,048 ft. MD (5,312 ft. TVD) . Mark of Schlumberger 73.1 fe 32.1 fe 3.9 fe 109.1 fe ~sks 'z..¡ l S~ BHST = 132°F, Estimated BHCT = 113°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Stage Cumulative Pump Rate Volume Stage Time Time (bpm) (min) (bbl) (min) CW 100 6 60 10.0 10.0 MudPUSH XL 6 40 6.7 16.7 Tail Slurry 6 21 3.5 20.2 Drop Top Plug 3.0 23.2 Displacement 6 156 26.0 49.2 Bump Plug 3 9 3.0 52.2 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv z 19-22, T y z 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ' ORIGINAL (' ( 2P-448 Proposed Sidetrack procedure. 1. Place kick off plug as per approved plug back procedure. 2. POOH and test BOPE to 3000 psi. (pressure from approved permit to drill) 3. Rlli to planned top of kick off plug (3800'). 4. Drill out 200' of the cement plug to planned kick off point (4000'). Lógs, 5. Directionally drill 6-3/4" hole to well total depth (+1- 7501' MD) according to Ì>¡~\ ~:R. \ e8?-\ directional plan. Run MWD 1 LWD logging tools in drill string for directional /\Iï=U \ DCIV\ pilJþ monitoring and formation data gathering. Circulate and condition hole. POOH. I. g .6'2.....j~ I:::> 6. Run open hole e-line or drill pipe conveyed logs as needed. 7. Run and cement 5.5" 15.5# L-80 BTCM x 3-1/2 9.3# L-80 8RD tapered production casing string with Baker casing seal receptacle crossover (CSR). Place CSR +1- 100' MD above the Bermuda interval. 8. Run and land 3-1/2" tubing. Displace well to completion brine. 9. 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. 10. Freeze protect well. Set BPV. Release rig and turn well over to production. 11. Clean location and RDMO in preparation for coiled tubing c1eanout and perforating. ORIGINAL PHILLlr 3 Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (' Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 January 8, 2002 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: 2P-448A Surface Location: Target Location: Bottom Hole Location: 1022'FNL,1583'FWL,Sec.17,T8N,R7E 1534' FSL, 950' FEL, Sec. 18,T8N,R7E 1316' FSL, 942' FEL, Sec. 18,T8N,R7E Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill to drill a sidetrack development well 2P-448A. This sidetrack is due to the absence of productive pay. 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. Sincerely, (!Pl RECE.\\lEO J~N 0 8 2G02 s coos. cororo,ss\on Ä\as\C.a 0\\ & ~~c"Ofage C. Mallary . Drilling Engineeri ORIGINAL 111'0000 ~O'~,i~ 7 lilli' , ,1:08'3 gO ~ 2 ß21: 0 Ii gDDOOIII \ 'It ?, .;,. CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL ,/ EXPLORATION INJECTION WELL INJECTION WELL REDRILL ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K/2úl ¿f2 Ý¥?/1 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL L...JNO ANNULAR DISPOSAL <---> YES ANNULAR DISPOSAL THIS WELL DJSPOSA~IN . OTHER ANNULUS YES + SPACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, ,API No. . ' Production should continue to be reported as a function of the original API number stated above. ' In accordance with 20 AAC 25.005(f), 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 (n8:me on permit). , Annular disposal has ~ot been requested. . . Annular Disposal, of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . Please note that an disposal of fluids generated. '. . .2f Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved. sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION "e ,ett COMPANY WELL NAME;2¡:?- í/B'" ,4PROGRAM: exp - dev ~ redrll ~ serv - wellbore seg _ann. disposal para req - INIT CLASS ./ ()/ ¿ GEOL AREA UNIT# // / ¿; ON/OFF SHORE {y/? 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells. . . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N, 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . ' N 10. Operator has appropriate bond in force. . . . . . . . . . . . . ' N 11. Permit can be issued without conservation order. . . . . . . . 'N ~R DATE C) ~ 12. Permit ca~.be issued without administrativ~ approval.. . . . . ) N I ,g- . D ~ 13. Can permit be approved before 15-day walt.. . . . . . . . . . N ENGINEERING 14. Conductor string provided .. . . . . . . .. . . . . . . . ~ Y N ;.1//\ 15. Surface casing protects all known USDWs. . . . . . . . . . . Y N ¡.¡.¡!T 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N f'JfA 17. GMT vol adequate to ,tie-in long string to surf csg. . . . . . . . iN N/A 18. CMT will cover all known productive horizons. . . . . .. . . " ' N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ' N OC<.-\Ð-^-- ,4t 21. If a re-drill, has a 1 Q..403 fo! abandonment been approved. . . . N VWÐ (.. ~ 22. Adequate wellbore separation proposed.. . . . . . . . . . .. . N HIf/!f 23. If diverter required, does it meet regulations. . . . . . . . . . Y N ¡;:¡¡¡ç 24. Drilling ,fluid program schematic & equip list adequate. . . . . $ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Nt> 1<4.1 APPRq~ 1§ 26. BOPE press rating appropriate; test to Dsig. N WGA- ~ 2. . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . &1 N 28. Work will occur without operation shutdown. . . . . . . . . . . ~ N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ 30. Permit can be issued wlo hydrogen sulfide measures. . . . ,. m.tt- 31. Data presented on potential overpressure zones. . . . . . . X~ 32. Seismic anal~~is of shallow gas zones. . . . . . . . . . . . . p:A Y N ARPR DATE 33. Seabed condlüon survey (If off-shore). . . . . . . . . . . . Y N {. t¡? '02.-- 34. Contact name/phone for weekly progress reports [ex~ tory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface;.. .. (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annular COMMISSION: ~Þ8 .irirJr V" WM '8~St' t'JI(,?C-?ðÓ Z- +~~ JMH q 7i c 0 Z 0 -t :E ::0 ( -t m APPR DATE t¡J6A- ' ¡ 1ft¡ lOlL Y N Y N 0 -!t-eý tì(Åtti/J~r ~ s PCJ>cJ( . Z -t :I: en » ~ ( » GEOLOGY Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process. but is part of the history file. . To improve the readability of the Well History file and to simplify finding infonnation information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically" . organize this category of information. Ii ( ~: õ?O~-OO5 I077&J Sperry-Sun Drilling Services LI S Sea n Ut i 1 it \" $Revision: 3 2 LisLib $Revision: 4 $ Mon Apr 22 15:26:05 2002 Reel Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0::: / 04 / ::: ::: Origin. . . . . . . . . . . . . . . . . . . STS Reel Name - - . . - . . . . - - - . . . - UN]{NOI-JN Continuation Nurnber......Ol Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name.............LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 02! 04 ! 2:= Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Nunmer......Ol Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF' Comment Record TAPE HEADER Kuparuk River Field IV¡WD!MAD LOGS # HELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATJ.\ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TO\iiJNSHI P: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FI.,OOE: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRI.NG PRODUCTION STRING # REMARKS: MWD RUN 1 AK-MM.-11214 J. STRAHAN D. PRESNELL MWD RUN E) AK-MM-1l214 ,}. PANTER D. GLADDEN MSL 0) Writing Library. Scientific Technical Services Writing Librar:y. Scientific Technical Services 2P-448A 501032039601 Phillips Alaska, Inc. Sperry-Sun Drilling Services 22-APR-02 MWD RUN 2 AK-MM-11214 J. PAN'I'ER D. PRESNEU, MWD RUN 4 AI<-MM-1l214 B. ZIEMKE D. GLADDEN MHD HI)N 6 AK-.MM-11214 J. STRAHAN D. GLADDEN 17 eN 7E 1022 1583 252..50 225.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 110.0 6.750 7.625 2976.0 if ( 1. ALL DEPTHS ARE HEl\SURED DEPTH (Ì"ID) UNLESS OTHERlriJISE NOTED. " ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. 2P-448 WAS DRY - IT WAS SIDETN\CKED AT 4000'HD / :2984' TVD. 4. HWD RUNS 1 AND 2 COHPRISED DIRECTIONAL WITH NATURAL GAMHA PROBE (NGP, UTILIZING SCINTILLATION DETECTORS). THERE IS A DATA GAP OF UNKNOWN ORIGIN IN THE RUN 1 SGRD FROH 149'-167'MD. THERE IS ALSO A GAP BETWEEN MWD RUNS :2 AND 4 (2927.51-:2935.5'MD) DUE TO DIFFERENT TOOL STRING LENGTHS. 5. REAL-TIME SGRD DATA ARE PRESENTED FOR RUN 1 (52' - 848'), DUE TO THE FACT THAT THE BHA BECAME STUCK AT ABOUT 2000', AND TtJ.ll,.S NOT RETRIEVED. 848' IS THE PLUG-BACK 'I'D. THE COMPLETE RUN 1 DATA SE'I' IS PRESENTED SEPARATELY AS 2P-448 PB1. 6. MWD RUN 3 WAS ABORTED DUE TO A FAILED CASING TEST. 7. ~1WD RUNS 4, 5, AND 6 COMPRISED DIRECTIONAL, DUAL GAMJvL1l,. RAY (DGR, UTILIZING GEIGER-HUELLER TUBE DETECTORS), ELECTR.oMAGNETIC 1i\ìAVE RESISTIVITY - PHASE 4 (EWR4), STABILIZED LITHO-DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 8. MWD DATA ARE CONSIDERED PDC PEE E-MAIL FEOM D. SCHWARTZ (PHILLIPS ALASKl\) TO R. KALISH (SSDS) DATED 2/18/02, QUOTING AUTHORIZATION FROM GI\A GROUP. 9. MWD RUNS 1, 2, 4, 5, AND 6 REPRESENT WELL 2P-448A WITH API# 50-103-20396-01. THIS WELL REACHED A TOTAL DEPTH OF 7593'MD / 5751'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOO'rI-IED GAMMA RIW COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHJ\LLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMf\TION EXPOSURE TIME (DEEP RESISTIVITY) . TNPS = SJvIOOTHED THERM.AL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA = SJvIOOTHED AVERAGE OF FAH DETECTOR'S COUNT RATE. CTNA = SMOOTHED IWERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 -= SMOOTllED BUl,K DENSITY - COMPENS.ATED (l,OTtJ-COUNT BIN) . SC02 = SMOOTHED ST}\NDOFF CORfŒCTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSl,IDE = NON-ROTATED INTERVAL,S ADJUSTED FOR BIT-TO-SENSOR DISTANCE. ,( { PAR~¡ETERS USED IN PROCESSING POROSITY LOGS: fIXED HOLE SIZE: JvlUD WEIGHT: MUD SALINITY: CHLORIDES fORMATION WATER FLUID DENSITY: MATRIX: MATRIX DENSITY: " ~, 6.75" 9.6 - 9.65 PPG 26,000 - 32,000 PPM SALINITY: 22,727 PPM CHLORIDES 1. 0 G/CM3 SANDSTONE 2.65 G/CM3 File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........1.0.0 Date of Generation...... .02/04/22 Maximum Physical Record..65535 File Type......"......... LO Previous File Name.. .... .ST8LIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Dep'th shi f'led DEPTH INCREl'1ENT: # FI LE SUMl'1ARY PBU 'rom, CODE GR ROP NCNT FCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB $ 1 and clipped curves; all bit runs merged. .5000 S'rJ.\RT DEPTH 52.0 110.0 2900.0 2900.5 2900.5 2960.0 2960.0 2960.0 2960.0 2960.0 2972.5 2972.5 2972. .5 STOP DEPTH 7538.0 7593.5 7501. 5 7502.0 7501. E> 7545.5 7545.5 7545.5 7545.5 7545.5 7517.0 7517.0 7517.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIr'r DJ\'I'A (MEJ\SUI'\ED DEPTH) --------- EQUIVALENT UNSHH"J'ED DEPTH --------- BASELINE DEPTH $ # HERGED PBU l'1WD MWD HWD HWD HWD $ DATA SOURCE TOOL CODE ~ REHARIŒ : BIT RIJN NO 1 2 4 5 6 MERGED HAIN PASS. $ ME,RGE TOE' 52.0 848.0 2900.0 4000.S 4938.0 MERGE BASE 847.5 2990.5 4000.0 5031.0 7593.5 # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units..... ... ...Feet Data Reference Point...... ..... ...Undefined Frame Spacing...... """" ...... .60 .lIN Hax frames per record... ..........Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . - . {, ( Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP M,(ÑD FT/I-I 4 1 68 ,.., - GR tvH^IO API 4 1 68 8 .J RPX MWD OHf'v[M 4 1 68 12 RPS tvHtiJD OI-lMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 G RPD MWO OHMN 4 1 68 24 ï FET MWO HOUR 4 1 68 28 8 NPHI Mí^I 0 PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT M~\)D CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRI-IO MWD G/CM 4 1 68 48 L~ PEF M,(^ID BARN 4 1 68 52 14 First Last Name Service Unit Jvlin Max f'v[ean Nsam Reading Reading DEPT FT 52 7593.5 3822.75 15084 52 7593.5 EOP MWD FT/H 2.34 1812.93 92.6768 14968 110 7593.5 GE MWD API 27 . ~)5 290.42 12.3.'718 14919 52 7538 RPX HWO OHMM 0.7 1395.98 4.60395 9172 ;.~ 960 7545.5 RPS MWD OHHM 0.9 925.78 4.96738 9172 2960 7545.5 RPM MWD OHMM 0.21 1432.52 6.25054 9172 2960 7545.5 RPD MWD OHMM 0.17 2000 7.26031 9172 2960 7545.5 FET ~IIWO HOUR 0.39 145.55 2.02206 9172 2960 7545.5 NPHI MWO pu-s 11.13 58.29 33.9918 9203 2900.5 7501. 5 FCNT MWD CNTS 101.1 972. en 265.228 n04 2900.5 7502 NCNT MWD CNTS 13377.2 33112.9 19643.~) 9204 2900 7501. 5 RHOB M~'JD G/CM 1. 64 :2.897 :2.3513~) 9090 2972.5 7517 DRHO MWD G/CM -O.ll 0.595 0.0409399 9090 29'72 . 5 7517 PEF ~1WD BARN 0.73 B.02 2.4~:)33 9090 2972.:) 7517 First Reading For Entire F11e..........52 Last Reading For Entire Fi1e...........7593.5 File TraLLer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number...........1. O. () Date of Generation.......02/04/22 Maximum Physical Record..65535 File Type................ LO Next File Name.. .........STSLIB.002 Physical EOF File Header Service name.............STSLIB.OO2 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......02/04/22 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOl Comment Reco,cd FILE HEADEE fILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR 2 header data for each bit run in separate files. 1. .5000 Sn\RT DEPTH 52.0 STOP DEprI'H 847.5 { ROP S 110.0 847.5 Ii LOG HEADER DATA DATE LOGGED: SOFTWARE SURF,II.CE SOFTWARE VERSION: DŒ'VNHOLE SOFT~\].II.RE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: M,II.XIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OJ-TMM) AT TEMPER7;"T1JRE (DEGF) MUD AT MEASURED TEMPERATURE (MT): HUD AT HAX CIRCULATING TERMPERATURE: HUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: HATRIX DENSI'rY: HOLE CORREC'I'ION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REÞ1ARKS : $ H Data Format Specification Record Data Record Type.................. 0 Data Specificat.ion Block Type.....O Logging Direction. ..... ...........Down Optical log depth units. """" ..Feet Data Reference Point............ ..Undefined Frame Spacing... ........ ........ ..60 .1IN Hax frames per record... ... "'" ..Undefined AL')sent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 23-DEC-Ol Insite 66.16 Real-Time 848.0 52.0 848.0 . (I 40.5 TOOL NUMBER PB02375HAW4 9.875 EZ-Mud 9.60 68.0 8.9 26000 3.8 .000 .000 .000 .000 Name Se.rvice Order Units Size Nsam Rep Code Offset Channel DE.PT F'T' 4 1. 6¡3 0 1 ROP MIND010 FT/H 4 1 68 4 ,") GR MWD010 API 4 1. 68 8 3 Name Service Unit DE PT FT ROP MWD010 FT/H GR MíNDO 10 API JVlin 52 Max 847.5 435.84 27 5.52 2.34 27 . :')!:) Mean Nsam 449.75 1592 137.311 1476 "79.6024 1!:)55 .0 95.3 .0 .0 First Reading 52 110 52 Last Reading 847.5 847.5 847.5 { First Reading For Entire File..........5: Last Reading For Entire File...........847.5 E'jle Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.... .,.. ...1.0.0 Date of Generation. ... ...02/04/22 Maximum Physical Record..65535 File Type....... .........LO Next File Name..... ..... .STSLIB.003 Physical EOF File Header Service name.... .........STSLIB.003 Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation.......02/04/22 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBE.R: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 848.0 GR 848.0 $ :) .5000 header data for each bit run in separate files. ,~ STOP DEPTH 2990.5 2927.0 it LOG HEADEE DATJ.\ DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VEESION: DATA TYPE (]\1EMORY OE EEI\L-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING ('rOp TO BOT'I'OM) VENDor-~ 'rOOL CODE TOOL TYPE NG P NATUEAL Gl\MMA PROBE $ # BOREHOLE AND CASING DATJ\ OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (18/8): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT 'l'EMPERJ.\TURE (DEGF) ]\'!UD AT ¡VIEASURED TEMPERA,TURE (MT): MUD AT MAX CIRCULATING TERMPERAT'UHE: MUD FILTRA'rE A'r MT: 29-DEC-01 Insite 66.16 Memory 2990.0 848.0 2990.0 8.9 58.8 TOOL NUMBER PB0237 5HA~\]4 9.875 EZ-Mud 9.60 56.0 9.0 27 000 5.0 .000 .000 .000 .0 9.5. .3 .0 :( ( HUD CAKE AT MT: .000 .0 NEUTRON TOOL ¡V¡P\TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REHARKS: $ » Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing... ..................60 .lIN Max frames per record.............Undefined Absent value................... -. .-999 Depth Units....................... Datum Sped, fication Block sub-type... 0 Name Service Order Units S.izE-~ Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1. ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1. 68 n 3 F:l.,rst l,ast Name Service Un,it Min Max Mean Nsam Reading Reading DEPT FT 8.18 2990.5 1919.25 4286 848 2990.5 ROP ¡V¡WD020 FT/H 6.75 1812.93 116.769 4286 848 2990.5 GR MWD020 API 42.06 290.42 104.545 4159 848 2927 First Reading For Entire Fi1e..........848 Last Reading For Entire Fi1e...........2990.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/04/22 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.......... ...STSLIB.004 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/04/22 Maximum Physical Record..65535 File Type............... .1,0 Previous File Name.......STSLIB.OO3 Comment Record FILE HEADER FILE NUMBER: RATti! MWD Curves and :Log BIT RUN NUMBER: DEPTH INCREMENT: II FILE SUMMARY VENDOR TOOL CODE START DEPTH header data for each bit run in separate files. 4 .5000 STOP DEPTH {' NCNT 2900.0 4000.0 FCNT 2900.5 4000.0 NPHI 2900.5 4000.0 í3R 2936.0 4000.0 FET 2960.0 4000.0 RPD 2960.0 4 000 . (I RPM :2960.0 4000.0 RPS 2960.0 4000.U RI?X 2960.0 4000.0 PEF 2972.5 4000.0 DRHO 2972.5 4000.0 RHOB 2972.5 4000.0 ROP 2991.0 4000.0 $ # LOG HEADER D,I\TA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GJ.\MMJ.\ RJ\Y ELECTROMAG. EJ::SIS. 4 STABILIZED LITHO DEN COHP THERHAL NEUTRON # 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 (PPH): FLUID LOSS (C3): RESISTIVny (OHMH) AT TEMPEHA'rURE (DEGF) MUD AT MEASUHED TEMPERATURE (MT): MUD AT ¡VIJ.\X CIR.CULJ\TING TERMPERJ\TURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON 1'001" MATRIX: ¡VIATRIX DENSITY: HOLE COREECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.... .............Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing....... ............ ..60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . ,~ ( 07 - ,J AN - 0 ::: Insite 66.16 Memory 4000.0 2990.0 4000.0 56.0 60.1 TOOL Nm1BER PB02375HATÑ4 PB02375HAW4 PB02375HAW4 PB02375HAW4 6.'750 EZ-Mud 9.60 46.0 9.4 32000 4.8 .130 .081 .070 .240 70.0 116.6 70.0 70.0 I{ '( Datum Specification Block sub-type...O Name Send. ce Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 6::: (I 1 ROP MWD040 FT!H 4 1 68 4 ~ GR MWD040 API 4 1 68 8 3 RPX MWD040 0 Ht-'IH 4 1 68 12 4 RPS MWD040 OHMM 4 1 6::: 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD }.j\tJDO 40 OHHM 4 1 68 24 FET HWD040 HOUR 4 1 68 ~8 G ~, NPHI H\tJDO 4 0 PU-S '1 1 68 32 FCNT M'Þ'lD040 CNTS 4 1 68 36 10 NCNT M¡tJD040 CNTS 4 1 68 40 11 RHOB HWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN L1 1 68 52 14 FLrst Last Name Serv.ice Unit ¡Vlin Max Mean N8am Reading Reading DEPT FT 2900 4000 3450 2201 2900 4000 ROP MWD040 FT/H 3.71 184.08 81.6904 ::::0.:.1..9 2991 400CI GR MWD040 API 75.36 258.11 147.59 2129 2936 4000 RPX MWD040 OHMJv! 0.7 1395.98 5.76692 2081 2960 4000 RPS MWD040 OHMJv! 0.9 925.78 5.53335 2081 2960 4000 RPM MWD040 OHMM. 0.21 1432.52 10.303 2031 2960 4000 RPD MWD040 OHMM 0.17 2000 14 . 6823 2081 2960 4000 FET M\tJDO 40 HOUR 0.45 102. If.) 4.02941 :2081 2960 4000 NPHI HÍÑD040 PU-S 22.45 58.29 39.6602 2¿~00 2900.5 4000 FCNT M\I'JD040 CNTS 101.1 361. 3 187.834 2200 2900.5 4000 NCNT MWD040 CNTS 133Tl. 2 23835.4 171'71 :,:201 2900 4000 RHOB HWD040 G/CM 1. 897 2.897 2.23637 2056 2972.5 4000 DRI-IO MWD040 G/CM -0.065 0.595 0.0622296 2056 2972.5 4000 PEF MWD040 BARN 1. 81 5.94 2.45403 2056 2972.5 4000 First Reading For Entire File..........2900 Last Reading For Entire File...........4000 File Trailer Service name. ............STSLIB.004 Service Sub Level Name... Version Number...........1. O. 0 Date of Generation.......02/04/22 Maximum Physical Record..65535 File Type............... .LO Next File Name...... .... .STSLIB.005 Physical EOF File Header Service name........... ..STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/04/22 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.004 Comment Record FILE HE.ADER FILE NUHBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREHENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 4000.5 ~) :0> .5000 STOP DEPTH 4981.5 ( R.OP 4000.5 5031.0 GR 4000.5 4974 . 5 RPX 4000.5 4981.5 RPS 4000.5 4ge,1.5 RPM 4000.5 4981. 5 RPD 4000.5 4981.5 NPHI 4000.5 4937.5 FCNT 4000.5 4938.0 NCNT 4000.5 4937.5 RHOB 4000.5 4953.0 PEF 4000.5 4953.0 DRHO 4000.5 4953. 0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOH LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGl,E: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD C'I'N $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP 'I'HERMAI, NECJ1:'RON BOREHOLE AND CASING D1-\T]\ 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 TEMPER1\TURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: HUD FILTRATE AT MT: MUD CAKE 1-\'1' MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): if REMARKS: $ 11 Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction............ .....Down Optical log depth units.... ...... .Feet Data Reference Point... ...........Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Ii( 10-JAN-02 Insite 66.16 Memory 5030.0 4000.0 5030.0 41. 2 54. 9 TOOL NUMBER PB02375HAW4 PB02375HAW4 PB02375HAW4 PB02375HAW4 6.750 E-Z MUD 9.60 47.0 9.4 30000 4.6 .220 .015 .130 .180 66.0 105.8 77.0 77.0 ( I( Name Service Order Units Size Nsam Rep Code Offset Channel DE !?T FT 4 1 68 0 1 KO!? !'-1WD050 FT/H 4 1 68 4 <') I'ëìR MWD050 API 4 1 68 8 3 RE'Z MWD050 OHMM 4 1 68 12 4 R!?S MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD M¡tm050 0 Htvl.M 4 1 68 24 FET MWD050 HOUF:. 4 1 68 28 c' NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1. 68 36 10 NCNT MI'm050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO HWD050 G/CM 4 1 68 48 13 PEF HWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Hax Mean Nsam Reading Reading DEPT FT 4000.5 5031 4515.75 2062 4000.5 5031 ROP MWD050 FT/H 17.2 142.36 66.3029 2062 4000.5 5031 GR MWD050 API 82. en 259.97 152.813 1949 4000.5 4974 .5 RPX MWD050 OHMM 1. 31 11. 47 4.05926 1963 4000.5 4981. 5 RPS MWD050 OHMM 1.7 12.07 4.6E)839 1963 4000.5 4981. 5 RPM M\>'iJD050 OHMM 1.77 11. 99 4.86944 1963 4000.5 4981. 5 RPD MWD050 OHMM 2.04 9.86 E). 07 952 1963 4000.5 4981. 5 FET HWD050 HOUR 0.39 145.55 1. 38075 1963 4000.5 4981. 5 NPHI MWD050 PU-S 15.35 57.4 37.2896 1875 4000.5 4937.5 FCNT HWD050 CNTS 106.5 671.6 213.864 1876 4000.5 4938 NCNT HWD050 CNTS 14167.9 29821.8 18244.7 H3"75 4000.5 4937.5 RHOS HlND050 G/CM 1.64 2.58 2. 327 3 1906 4000.5 4953 DRHO HWD050 G/CH -0.11 0.36 0.0296537 1906 4000.5 4953 PEF HWD050 BAEN 0.73 6.06 2.34076 1906 4000.5 I~ 953 First Reading For Entire Fi1e..........4000.5 Last Reading For Entire File...........5031 File Trailer Service name.. .... .......STSLIB.OO5 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/04/22 Haximum Physical Record..65535 Fi 1 e Type................ 10 Next File Name.. ..... ....STSLIB.OO6 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.......02/04/22 Maximum Physical Record..65535 Fi 1 e Type................ 10 Previous File Name..... ..S'1'81IB.005 Cornment Eecord FILE HEADER FILE NUHBER: RAW MWD Curves and log BIT .RUN NUMBER: DEPTH INCREHEN'r: # FILE SUMHARY VENDOR TOOL CODE NPHI NCNT 6 header data for each bit run in separate files. 6 .5000 START DEPTH 4938.0 4938.0 STOP DEP'I'H '7501.5 7501. 5 ,~ FCNT 4938.5 7502.0 PEF 4953.5 7517.0 ::';HOB 4953.5 7517.0 DRHO 4953.5 7517 . 0 GR 4975.0 7538.0 RPH 4982.0 7545.5 RPS 4982.0 7545.~, RPD 4982.0 7545.5 FET 4982.0 7545.5 RPX 4982.0 7545.5 ROP 5031.5 7593.5 $ if 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 (E"l'): BIT ROTATING SPEED (RPM): HOLE INCLINA,TION (DEG MINIMUtvl ANGLE: MAXIMUM l-\NGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR E1'JR4 SLD CTN BOTTOM) 'rOOL TY PE DUAL (3AMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERM,L\L NEUTRON $ BOREHOLE AND CA.8ING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDI'l'IONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID I~OSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CI!~CUI.J.I.'I'ING 'I'ERMPERA'I'URE: MUD FILTRATE AT MT: MUD CAKE AT' MT: H NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Un:L ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( 13-I,FI.N-02 Insite 66.16 Memory 7593.0 5030.0 7593.0 35.1 40.3 TOOL NUMBER PB02375HAW4 PB02375HAW4 PB02375HAW4 PB02375HAW4 6.750 E-2, MUD 9.60 51.0 9.6 29000 3.8 .120 .050 .090 .190 68.0 127.0 68.0 68.0 ( ( Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 ROP MWD060 FT/H 4 1 68 4 GR ¡V¡1,-,JD060 API 4 ] 68 8 RPX MIIIJD060 OHMM 4 1 68 12 RPS ¡V¡WD060 OHMM 4 1 68 16 5 RPM MWD060 OHHM 4 1 68 20 6 RPD M1'JD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI M1'JD060 PU-S 4 1 68 32 ~, FCNT MWD060 CNTS 4 1 68 36 HI NCNT MI,-,JD060 CNTS 4 1 68 40 11 RHOB MWD060 G/Ct-1 c1 1 68 ,14 L: DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 First Last Name Serv.ice Unit Min Max Mean Nsam Reading Reading DEPT FT 4938 7593.5 6265.75 5312 4938 7593.5 ROP MTrI7D060 FTlH 9.43 120.45 74.6132 5125 5031.5 7593.5 GR MWD060 API '77.99 186.03 131.679 5127 4975 7538 RPX MWD060 OHMM 1. 36 17.37 4.34051 5128 4982 7545.5 RPS MWD060 OHMM 1. 45 23.7 4.85599 5128 4982 7545.5 RPM MWD060 OHMM 1.47 25.15 4.93179 5128 4982 7545.5 RPD MWD060 OI-lMM 1. 5:) 24.E)8 5.0832 E)128 4982 7545.5 FET M1'i1D060 HOUR 0.46 21. 75 1.45294 5128 4982 7545.5 NPHI MWD060 PU-S 11.13 43.7 30.3541 5128 4938 7501.5 FCNT M\IIìDO 6 0 CNTS 173.14 972. en 317.221 5128 4938.5 750:? NCNT MWD060 CNTS 16568.6 33112.9 21::-::16.2 5128 4938 7501.5 RHOB MWD060 G/CM 2.17 2.62 2.40638 5128 4953.5 7517 DRHO MWD060 G/CM -0.04 0.43 0.0365991 5128 4953.5 7517 PEF M\IIìD060 BARN 1. 89 8.02 2.49485 5128 4953.5 7517 First Reading For Entire File..........4938 Last Reading For Entire File...........7593.5 File 'rrailer Service name.............STSLIB.006 Service Sub Level Name... Version Number.. .... .... .1.0.0 Date of Generation. ......02/04/22 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO7 Physical EOF Tape Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/ 04/22 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......Ol Next 'l'ape Name........-._UNKNOWN Comments. . . . . . . . . . . - . . . . . ST'S LIS \117ri.ting LjJ)rary. Scientific Technical Services Reel Trailer Service name........ .....LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 0:2 /04/ :2:2 Origin.................. .S'I'S Reel Name............... . UNKNOWN Continuat,ion Number. - - -..01 Next Reel Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF { Physical EOr End Of LIS File ,,1 ( qoa-005 10777 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 18 15:16:08 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/04/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 / 04 / 18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Field MWD / MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2P-448 PB1 501032039670 Phillips Alaska Inc., Sperry-Sun Drilling Services 18-APR-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MM-11214 J. STRAHAN D. PRESNELL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 17 8N 7E 1022 1583 MSL 0) 252.50 225.00 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 110.0 6.750 7.625 2976.0 ( 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP,UTILIZING SCINTILLATION DETECTORS). REAL-TIME SGRD DATA ARE PRESENTED FOR RUN 1, DUE TO THE FACT THAT THE BHA BECAME STUCK AT ABOUT 2 0 0 0', WAS NOT RETRIEVED, AND THEREFORE NO RECORDED DATA ARE AVAILABLE. 4. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ (PHILLIPS ALASKA) TO R. KALISH (SSDS) DATED 2/18/02, QUOTING AUTHORIZATION FROM GKA GROUP. 5. MWD RUN 1 REPRESENTS WELL 2P-448 PB1 WITH API# 50-103-20396-70. THIS WELL REACHED A TOTAL DEPTH OF 2041'MD / 1995'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD , Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 52.0 110.0 STOP DEPTH 1982.5 2041.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD BIT RUN NO MERGE TOP 1 52.0 MERGE BASE 2041.0 { $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.... 0........ 0....0 Data Specification Block Type.....O Logging Direction. . . 0 . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point........ 0.... . Undefined Frame Spacing.... 0......0........ .60 olIN Max frames per record..... 0..0... . Undefined Absent value..................... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . 0 . . . . Datum Specification Block sub-type. 0.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 52 2041 1046.5 3979 52 2041 ROP MWD FT/H 2.34 435.84 141.901 3863 110 2041 GR MWD API 27.55 275.52 87.3933 3825 52 1982.5 First Reading For Entire File......... .52 Last Reading For Entire File.. 0.....0. .2041 File Trailer . Service name...... 0"'" .STSLIB.001 Service Sub Level Name.. . Version Number...... 0'0' .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. 0... .02/04/18 Maximum Physical Record. .65535 File Type. . . . . . . . . 0 . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 2 header data for each bit run in separate files. 1 .5000 ( FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 52.0 110.0 STOP DEPTH 1982.5 2041.0 # 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 NGP NATURAL GAMMA PROBE $ # 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ( 23-DEC-01 Insite 66.16 Real-Time 2040.0 52.0 2041.0 .0 40.5 TOOL NUMBER PB02375HAW4 9.875 110.0 EZ-Mud 9.60 68.0 8.9 26000 3.8 .000 .000 .000 .000 .0 95.3 .0 .0 !' ( ( Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 52 2041 1046.5 3979 52 2041 ROP MWD010 FT/H 2.34 435.84 141.901 3863 110 2041 GR MWD010 API 27.55 275.52 87.3933 3825 52 1982.5 First Reading For Entire File......... .52 Last Reading For Entire File.......... .2041 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02 / 04 / 18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 02 / 04 / 18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.............. .. .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
