The URL can be used to link to this page

Home My WebLink About213-0531a. 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: 23. BOTTOM 16" H-40 121' 9-5/8" L-80 3161' 7" L-80 5923' 5" L-80 6436' 2.375" L-80 6130' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng 523' MD/ 523' TVD Oil-Bbl: Water-Bbl: 0.1 bbls BiSn 7958-7964' (IA) 7 ft =0.19 bbl BiSN beads Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 40# 121' 39' 9140' 8746' Top of BiSN (Tubing) SUSPENDED Slotted Liner: 8971-10751' MD and 5770-6130' TVD Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. 18# 41' 8935' 5614'41' SIZE DEPTH SET (MD) 8935' MD/5738' TVD PACKER SET (MD/TVD) 8971' 24" 4.7# If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run):8979'3-1/2" 26# 9715' 39' 5739' 62.5# BOTTOM 1454' FNL, 628' FEL, Sec. 4, T10N, R9E, UM 50-029-22720-61-00 CASING WT. PER FT.GRADE 5/18/2013 CEMENTING RECORD 5942152 1650' MD/ 1525' TVD SETTING DEPTH TVD 5941361 TOP HOLE SIZE AMOUNT PULLED 518635 518977 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. 9602' MD/ 6135' TVD Kuparuk River Field/ Kuparuk River Oil Pool ALK 2587, ALK 283 5/17/2013 10751' MD/ 6130' TVD 7958' MD/ 4875' TVD P.O. Box 100360, Anchorage, AK 99510-0360 517519 5948608 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, KRU 2F-18L1-01 ADL0025666, ADL 0025657 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM 2246' FNL, 289' FEL, Sec. 4, T10N, R9E, UM 9. Ref Elevations: KB: 138' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 2/12/2025 213-053/ 324-062 10751' 130 sx Class G 5770' 8.5" 3" 12.25" 28 sx AS I 41'330 sx ASLW, 1220 sx Class G w/60 sx AS I tail 137 sx Class G6.125" TUBING RECORD Slotted Liner 41' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 2:50 pm, Mar 13, 2025 Abandoned 2/12/2025 JSB RBDMS JSB 032525 X xGDSR-4/7/25 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1650' 1525' Top of Productive Interval 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: 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 INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Authorized Title: 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. Authorized Name and Formation Name at TD: 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. 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). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov N/A - Suspended Digitally signed by Katherine O'ConnorDN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=USReason: I am the author of this documentLocation:Date: 2025.03.13 13:57:15-08'00'Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Identify Bead Location in IA and Melt Beads 2F-18 2/7/2025 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 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) 7,958.0 4,875.4 28.51 TUBING PUNCH 1 FT OF 2" TUBING PUNCH, 7 GRAM KNOCKOUT (#2), 4 SPF, 0 DEGREE PHASE, 0.61" HOLE SIZE 12/23/2024 2.992 7,958.0 4,875.4 28.51 TUBING PUNCH 1 FT OF 2" TUBING PUNCH, 7 GRAM KNOCKOUT, 4 SPF, 0 DEGREE PHASE, 0.61" HOLE SIZE 12/23/2024 2.992 8,727.0 5,553.3 27.72 PLUG MILLED & PUSHED 2/2/25, NSAK composite bridge plug (OAL 1.3') 2/2/2025 0.000 8,746.4 5,570.4 27.58 PLUG BiSN ALLOY PLUG, 2.58' OAL BiSN AOH 5/6/2024 0.000 8,885.0 5,693.6 27.06 TUBING PUNCH 3' x 1.56" TUBING PUNCHER, 4 SPF, 3.4g HMX, 0.43" EH GEODY NAMICS TG39CM 2 N/A 5/29/2023 2.992 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 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) 4,242.6 2,669.7 69.85 1 GAS LIFT DMY BK 1 0.0 11/30/2023 6:00 0.000 6,783.6 3,855.2 36.58 2 GAS LIFT DMY INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT DMY BK 1 0.0 10/28/2024 7:00 0.000 8,504.3 5,356.8 28.25 4 GAS LIFT DMY BK 1 0.0 11/28/2023 8:00 0.000 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 60 deg phase MULTIPLE LATERALS, 2F-18, 3/10/2025 12:35:36 PM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 FRAC; 9,325.0 APERF; 9,325.0-9,335.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,749.0 8,888.0 5,572.7 5,696.3 Cement Plug 6/3/2023 7,990.0 8,888.0 4,903.5 5,696.3 Cement Plug 6/3/2023 7,658.0 7,664.0 4,612.1 4,617.4 Remedial PRE-MELT BEADS IDENTIFIED AT 7658' TO 7664' 2/7/2025 7,960.0 7,975.0 4,877.2 4,890.3 Remedial 794 LBS OF BISN BEADS 1/25/2025 7,975.0 8,000.0 4,890.3 4,912.3 Remedial 5/1/2024 MULTIPLE LATERALS, 2F-18, 3/10/2025 12:35:37 PM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 FRAC; 9,325.0 APERF; 9,325.0-9,335.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD 2F-18 ... WELLNAME WELLBORE2F-18 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 10,206.6 13,112.0 6,236.6 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,206.6 6,145.3 86.87 BILLET 2.675 BAKER OH ANCHORED LINER BILLET Baker 1.000 10,218.3 6,146.0 86.91 DEPLOY 2.675 BAKER DEPLOYMENT SLEEEVE Baker 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,219.0 13,112.0 6,146.0 6,236.6 A-4, 2F-18L1 5/10/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1, 3/10/2025 12:35:38 PM Vertical schematic (actual) L1 Liner; 10,206.6-13,112.0 SLOTS; 10,219.0-13,112.0 L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1 ... TD Act Btm (ftKB) 13,306.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272060 Wellbore Status PROD Max Angle & MD Incl (°) 105.70 MD (ftKB) 13,268.50 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-01 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 01 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner (off main wellbore) 2 3/8 1.99 8,971.3 10,751.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,971.3 5,770.6 26.81 DEPLOY 2.625 BAKER DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,982.0 10,751.0 5,780.1 A-4, 2F-18L1-01 5/18/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-01, 3/10/2025 12:35:38 PM Vertical schematic (actual) L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-02 Liner; 9,598.8-12,522.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-01 ... TD Act Btm (ftKB) 12,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272061 Wellbore Status PROD Max Angle & MD Incl (°) 103.25 MD (ftKB) 9,720.70 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-02 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 02 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,598.8 12,522.0 6,189.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,598.8 6,135.2 89.81 BILLET 2.625 BAKER OH ANCHORED BILLET Baker 1.000 9,610.5 6,135.2 89.58 DEPLOY 2.675 BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,611.0 12,522.0 6,135.2 6,189.0 A-4, 2F-18L1-02 5/14/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-02, 3/10/2025 12:35:39 PM Vertical schematic (actual) L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,749.0 ftKB PLUG; 8,746.4 PLUG; 8,727.0 GAS LIFT; 8,504.3 Cement Plug; 7,990.0 ftKB Remedial; 7,975.0 ftKB Remedial; 7,960.0 ftKB TUBING PUNCH; 7,958.0 TUBING PUNCH; 7,958.0 GAS LIFT; 7,768.7 Remedial; 7,658.0 ftKB GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-02 ... TD Act Btm (ftKB) 12,544.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272062 Wellbore Status PROD Max Angle & MD Incl (°) 96.55 MD (ftKB) 10,290.16 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 1/30/2024 OPTIMIZE WELL PERFORM CBL TAG TOC IN TBG AT 8750' AND LOG MAIN PASS FROM 8750'-7750' TOC IN IA IDENTIFIED AT 7990' JOB COMPLETE 4/14/2024 ACQUIRE DATA PULL 1" DUMMY VLV FROM STA 3 @ 7768' RKB & REPLACE W/ CIRC VLV. BAIL CEMENT FROM TOP OF CATCHER @ 8751' RKB, JOB IN PROGRESS 4/15/2024 ACQUIRE DATA BAIL CEMENT FROM TOP OF AVA CATCHER @ 8751' RKB. PULL 3.5" AVA CATCHER FROM TOC @ 8751' RKB. READY FOR CIRC OUT. 4/19/2024 REPAIR WELL CIRC-OUT WELL PUMPED 311 BBLS INHIBITED SEAWATER DOWN TBG TAKING RETURN UP IA, FOLLOWED BY 200 BBLS DIESEL, ALLOW TBG AND IA TO U-TUBE FOR FREEZE PROTECT. JOB COMPLETE 5/1/2024 ACQUIRE DATA LOADED 794 LBS (180 KG) OF BISN BEADS INTO IA. 5/1/2024 ACQUIRE DATA CIRC OUT 200 BBLS SLICK CISW FOLLOWED BY 100 BBLS DSL DOWN IA TAKING RETURNS UP TBG. U-TUBE TBG AND IA. TEMP FREEZE PROTECT FLOWLINE WITH DSL FREEZE PROTECT FL WITH METH. JOB COMPLETE 5/5/2024 REPAIR WELL LOG CBL OVER INTERVAL 8090' - 7700', OVERLAY GR WITH CBL LOG DATED 30-JAN-2024 PRE BEAD DROP, NO CLEAR INDICATION OF BEAD LOCATION IN IA, LOG GR WHILE POOH TO SURFACE AND OVERLAY WITH LDL LOG DATED 27-AUG-2022 UPLOAD DATA FOR ANALYSIS AND PLAN FORWARD JOB CONTINUED NEXT DAY 5/6/2024 REPAIR WELL RUN BISN TUBING SEAL TOOL AND HEATER, SIT DOWN AT BTM @ 8749' AND ACTIVATE HEATER, GOOD INDICATION AFTER FIRING BY 6FT DEEPER PICKUP AND 100LBS LESS UP TENSION, NO ISSUES DRAGGING WHILE POOH JOB CONTINUED NEXT DAY 5/7/2024 REPAIR WELL LRS PUMP DOWN IA IN STAGES TAKING RETURNS OFF TUBING TO FLOWLINE TO TRY AND PUSH BISN BEADS TO DEPTH, SLB ELINE LOG GR AND OVERLAY BETWEEN PUMPING TO TRY AND IDENTIFY BEAD LOCATION, BISN BEAD LOCATION NOT SEEN ON GR OVERLAYS, UPLOAD DATA FOR FURTHER ANALYSIS, TOTAL OF 10 BBL HI-VIS PILL AND 160 BBL DIESEL PUMPED DOWN IA (U-TUBE WELL). JOB IN PROGRESS 5/10/2024 ACQUIRE DATA (AC EVAL) CDDT T X IA TO 0 PSI (IN PROGRESS) 6/18/2024 REPAIR WELL RUN BISN RUNNING TOOL & HEATER LOG CORRELATED TO AKE CBL DATED 30-JAN-2024 POSITION TOOLS W/ CCL OFFSET=23.8', HEATER BOTTOM=7987', CCL STOP DEPTH=7963.2' ACTIVATED HEATER & WAITED 30 MIN TOOLS STUCK AT MELTING DEPTH, PULLED OUT OF ROPE SOCKET, TOOLSTRING LEFT IN HOLE OAL: 26.3', OAW ~300 LBS, MAX OD: 2.625", FN: 1" DHD TO PERFORM DDT 6/19/2024 REPAIR WELL (AC EVAL) CDDT T X IA TO 0 PSI (IN PROGRESS) 8/10/2024 REPAIR WELL RECOVERED E-LINE TOOL STRING/ BISN HEATER TOOL FISH (OAL 26.3' ) @ 7960' RKB. RIG DOWN, WAIT FOR PLAN FORWARD. 10/1/2024 MAINTAIN WELL FREEZE PROTECT FLOWLINE PUMPED 20 BBLS METH DOWN FLOWLINE AND .5 BBLS METH DOWN TBG JOB COMPLETE 10/29/2024 REPAIR WELL TAG BiSn BEADS @ 8746' RKB. PULL HFCV FROM STA 3 @ 7768' RKB. ATTEMPT TO SET DUMMY VLV IN STA 3, JOB IN PROGRESS 10/30/2024 REPAIR WELL SET 1" DMY IN STA 3 @ 7768' RKB. ATTEMPT MIT-T TO 2500 PSI (FAILED), RIG DOWN FOR HIGHER PRIORITY WORK. 11/11/2024 REPAIR WELL RAN HOLE FINDER TO TOP OF BISN BEADS & APPEARED TO BE GETTING A GOOD TEST. PULLED OUT OF HOLE & ATTEMPTED MITT TO 2500 PSI **FAIL**. RE-RAN HOLE FINDER & SUSPECT LEAK IS DV IN STA #3 @ 7768' RKB, SET AVA CATCHER ON TOP OF BISN BEADS, PULL DV FROM STA #3 @ 7768' RKB. IN PROGRESS 11/12/2024 REPAIR WELL SET 1'' BK DMY VLV IN ST#3 @ 7768' RKB, PERFORMED MIT-T TO 2500 PSI **PASS**. PULLED CATCHER @ 8746' RKB, READY FOR STATE W. TAG & TEST 2F-18 BiSN Suspend Summary of Operations 11/15/2024 REPAIR WELL PERFORM STATE WITNESS TAG TOC @ 8245' RKB (RECOVER 1/2 GAL CEMENT), GET PASSING STATE WITNESS MIT-T 2500 PSI. RDMO. 11/18/2024 ACQUIRE DATA (PRE RWO) T DDT (COMPLETE) 12/23/2024 REPAIR WELL SHOT TUBING PUNCH INTERVAL 7958'-7959' TWICE W/ 2" PUNCHERS LOADED 1' W/ 7 GRAM KNOCKOUT CHARGES (.61" ENTRANCE HOLE OD) LOG CORRELATED TO TUBING TALLY DATED 1/16/1997 WELL LEFT S/I JOB CONTINUED 12/24/2024 12/24/2024 REPAIR WELL SET NORTHERN SOLUTIONS 350-273 COMPOSITE BRIDGE PLUG AT 7960' (1' BELOW BOTTOM TUBING PUNCH HOLES) LOG CORRELATED TO TUBING TALLY DATED 1/16/1997 WELL LEFT S/I. READY FOR CIRC OUT. 1/6/2025 REPAIR WELL CIRC OUT WELL PUMP 240 BBLS CISW DOWN TUBING TAKING RETURNS OFF IA TO ADJACENT WELL FLOWLINE, FOLLOWED BY 40 BBLS DSL AND U-TUBED FOR BALANCE. 1/21/2025 REPAIR WELL DRIFT TBG TAG TOP OF CBP @ 7960' RKB. DUMP BAIL BISN BEADS (2 RUNS) & PUMP DOWN TBG TAKING RETURNS FROM IA. LAST TD W/ BAILER @ 7957' RKB, U TUBE TBGxIA, JOB IN PROGRESS 1/22/2025 REPAIR WELL DUMP BAIL APPROX 6 GAL OF BISN BEADS & PUMP DOWN TBG TAKING RETURNS FROM IA @ 7958' RKB. FP & U TUBE TBGxIA JOB IN PROGRESS 1/23/2025 REPAIR WELL DUMP BAIL APRROX 6 GAL OF BISN BEADS & PUMP DOWN TBG TAKING RETURNS FROM IA @ 7987' RKB, FP & U TUBE TBGxIA, JOB IN PROGRESS 1/25/2025 REPAIR WELL DUMP BAIL ~6 GAL OF BISN BEADS & PUMP DOWN TBG TAKING RETURNS FROM IA @ 7,958' RKB, LRS U-TUBE TBGxIA, DRIFT TO AND TAG BISN BEAD ON TOP OF CBP @ 7,960' RKB. COIL UP NEXT TO MILL CBP. 1/30/2025 REPAIR WELL TRAVEL FROM 2M-PAD TO 2F-18. 1/31/2025 REPAIR WELL RIG UP CTU 6 W/ 11,476' OF 1.75" CT (21 BBLS FUV) & STAND BY DUE TO WEATHER TEMPERATURE IN EXCESS OF -35*F. IN PROGRESS. 2/1/2025 REPAIR WELL WEATHER DELAYED, AMBIENT TEMP BELOW -35*F; PERFORM WEEKLY BOP TEST. RIH W/ 2" DJN & TAG BiSn BEADS @ 7883' CTMD & PREPARE TO REVERSE CIRCULATE. IN PROGRESS. 2/2/2025 REPAIR WELL REVERSE CIRCULATED 33' OF BISN BEADS FROM 7883' TO HARD TAG @ 7916' CTMD. MILL COMPOSITE PLUG AT 7959' RKB AND PUSH TO 8730' RKB (TOP OF BISN/CEMENT PLUG). READY FOR CIRC OUT & ELINE 2/3/2025 REPAIR WELL CIRC OUT WELL PUMPED 280 BBLS SLSW DOWN TBG AND UP IA FOLLOWED BY 70 BBLS DSL. U-TUBED FOR FREEZE PROTECT JOB COMPLETE 2/7/2025 REPAIR WELL RUN 1: PERFORM GR/CCL LOG, BiSN BEADS LOCATED IN IA BETWEEN 7958'-7964'. (TOC IN IA AT 7990') CONFER WITH CWG, DECISION MADE TO PROCEED WITH MELTING BEADS. RUN 2: PLACE BOTTOM OF BiSN HEATER AT 7966'. APPLY POWER AND WAIT 30 MIN. TOOLSTRING STUCK WHEN READY TO POOH. PULLED TO WEAKPOINT BEAKING STRENGTH AND TOOLS STARTED MOVING. HEAVY TENSIONS OUT OF HOLE, PULLED TO UPPER WEAKOINT MULTIPLE TIMES. ALL TOOLS RECOVERED AT SURFACE. HEATER WAS BENT. JOB COMPLETE, READY FOR DHD 2/8/2025 REPAIR WELL (AC EVAL) : CMIT-TxIA PASSED TO 2500 PSI. T X IA DDT TO 0 PSI (IN PROGRESS). 2/9/2025 REPAIR WELL (AC EVAL) T X IA CDDT TO 0 PSI (PASSED) 2/12/2025 REPAIR WELL (SW) STATE WITNESSED ( AUSTIN MCLEOD) CMIT T X IA TO 2660 PSI (PASSED) 2/12/2025 REPAIR WELL (AC EVAL) T DDT TO 0 PSI (PASSED) IA DDT TO 0 PSI (PASSED) 1 Conklin, Amy A From:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent:Thursday, August 29, 2024 9:10 AM To:O'Connor, Katherine Subject:[EXTERNAL]RE: 2F-18 Suspension Plan Forward APPROVAL Follow Up Flag:Follow up Flag Status:Completed 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. Katherine, Approval is granted for the revised procedure below. Please include this approval with your approved sundry. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Sent: Thursday, August 15, 2024 10:48 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: 2F-18 Suspension Plan Forward Hi Victoria 2F-18 is a well that had a balanced plug pumped to abandon the reservoir. The tentative future of the well is to complete a RWO sidetrack. The cement passes a positive pressure test, but does not pass a drawdown test. We planned to repair the cement using a BISN plug place in the tubing with the WellLok tool, and in the IA by pumping beads. The beads in the IA never made it down, so we weren’t able to place BISN on opt of the cement in the IA – this was a known risk because of the deviation of the well. It is “S” shaped, and the beads are likely strung out at the highest deviation area from ~3300’ – 5600’, where the deviation is 68-70 degrees. The tubing plug was successfully set. I have been working with BISN on a path forward and am requesting approval to repair the well with the following steps: 1. Set retrievable plug @ ±7965’ KB 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 2. Punch tubing with big hole charges about 5’ above plug 3. Using wireline, RIH with bailer full of beads to top of plug 4. Drop beads and pump into IA 5. Place a ~10’ BISN plug on top of cement in the IA 6. Once beads are placed, RIH with heater and melt beads 7. Pull retrievable plug 8. Proceed with sundry steps to pressure test tubing and IA. Thanks Katherine O’Connor CPF2 Interventions Engineer 907-263-3718 (O) 214-684-7400 (C) From:Conklin, Amy A To:Guhl, Meredith D (OGC) Cc:Hobbs, Greg S; Taylor, Jenna; O"Connor, Katherine; Zwarich, Nola R Subject:RE: [EXTERNAL]RE: KRU 2F-18 10-407 Suspend Date:Thursday, March 27, 2025 9:03:04 AM Good Morning Meredith, I have discussed this with the engineers, and they agree with the P&A Status for the three laterals while maintaining the Suspended status for 2F-18 motherbore. We will update our records. Thank you, Amy Amy A. Conklin, Well Integrity Analyst ConocoPhillips Alaska 700 G St, ATO 1307 Anchorage, AK 99501 (907) 265-1484 amy.a.conklin@conocophillips.com From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Wednesday, March 26, 2025 10:50 AM To: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2F-18 10-407 Suspend 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. Hello Amy, A brief review by staff at the AOGCC has suggested that the well status for the laterals (L1, L1-01, L1-02) should be considered P&A rather than SUSP as the laterals are inaccessible after the well work completed. Does ConocoPhillips agree with the P&A status for the laterals? If so, AOGCC will update the three lateral 10-407s to P&A, and 2F-18 will remain in SUSP status. 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. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Sent: Thursday, March 13, 2025 2:27 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; O'Connor, Katherine <Katherine.OConnor@conocophillips.com> Subject: KRU 2F-18 10-407 Suspend Hello, I have attached the 10-407s for KRU 2F-18 and associated laterals, BiSN Suspend. Please let me know if you need any additional information. KRU 2F-18 (PTD 196-178) KRU 2F-18L1 (PTD 213-052) KRU 2F-18L1-01 (PTD 213-053) KRU 2F-18L1-02 (PTD 213-063) Thank you, Amy Amy A. Conklin, Well Integrity Analyst ConocoPhillips Alaska 700 G St, ATO 1307 Anchorage, AK 99501 (907) 265-1484 amy.a.conklin@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: BiSN Patch Susp 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): 10751'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng (907) 263-3718 Well Interventions Engineer KRU 2F-18L1-01 6130' 8535' 5384' 8535' 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): 8935' MD and 5738' TVD N/A Katherine O'Connor STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025657, ADL0025666 213-053 P.O. Box 100360, Anchorage, AK 99510 50-029-22720-61-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool - Suspended TVD Burst 8979' MD 121' 3161' 121' 5614' 5923'9142' 16' 9-5/8" 80' 5573' Slotted Liner: 8982-10751' 9103' 5" Slotted Liner: 5780-6130' 7" Perforation Depth TVD (ft): 2/21/2024 9715'780' 3-1/2" Packer: Baker Liner Top 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 Samantha Coldiron at 2:44 pm, Feb 07, 2024 324-062 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@ conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2024.02.07 08:44:35-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor May 23, 2028 X DSR-2/13/24 Suspend 10-407X p Suspended 4100 See AOGCC Industry Guidance Bulletin 21-002A for additional guidance. Well-site inspection is required within 12 months after THIS suspension approval. Monthly reporting of TIO pressures required post plug. SFD 2/9/2024VTL 2/14/2024*&:JLC 2/16/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.16 13:25:31 -06'00'02/16/24 RBDMS JSB 022024 Date: 31 January 2024 Subject: 2F-18 Reservoir Abandonment Remediation Prepared by: Katherine O’Connor (214) 684-7400 Well History 2F-18 was a gas lifted producer that had a balanced cement plug pumped into the tubing and IA in summer 2023 after the wellbore got plugged off with rocks/fill. The cement passed pressure tests on the tubing and the IA. When prepping the well for a suspension inspection, it was discovered that the tubing and IA had ~1900 psi. This wellbore is currently being evaluated for either a RWO sidetrack or rotary redrill. The objective of this procedure is to place BISN plug on top of the cement plug in the IA and tubing in order to remediate the current repressurization. Notes: Tagged TOC 8737’ (135’ = 1.17 tubing cement and 885 ft IA cement Inclination Max: 71 deg @ 3950’ RKB Min ID: 2.80” Camco landing nipple @ 8942’ RKB Last SBHP 09/17/22 || 4270 psi || 8971’ RKB Repressurization rate of 5 psi/hour 12/10/23 MIT-T passed 11/30/23 MIT-IA passed 12/16/23 TOC in IA @ 8000’ KB (per CBL run 1/30/2024) Calculations Procedure: Eline 1. Tag TOC in tubing 2. Pump bismuth beads down the IA (aim is to get ~5’ worth of beads above TOC in IA) 3. Run CBL to survey bead settling depth 4. Pump down IA if needed to push beads to depth 5. Run heater to melt beads into solid patch 6. Run CBL to survey top of BISN in annulus 7. RU and RIH with BISN “tubing seal” tool and heater 8. Tag TOC and pull up ~10’ KB String Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3.5" tubing 0 8979 3.5" 9.3# 2.99" 0.0087 8884 77.2 115 tubing volume calculated from tag depth 3.5" x 7" annulus 0 8935 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 8884 234.6 38 casing volume calculated from tag depth 9. Melt bismuth alloy beads and let fall on top of tubing cement plug – aim is to get at a ~5’ bismuth plug Slickline & Fullbore 1. RU Slickline and PT equipment as required 2. RIH to tag top of BISN (AOGCC witness) @ approx. 8730’ KB, record results 3. CMIT-TxIA to 2500 psi (AOGCC witness), record results 4. MIT-T to 2500 psi (AOGCC witness), record results 5. DDT-0 psi on tubing and IA, record results Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set catcher, DMY off 2F-18 11/30/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 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) 8,532.0 5,381.1 28.39 CATCHER Set catcher on cement top. 11/27/2023 0.000 8,885.0 5,693.6 27.06 TUBING PUNCH 3' x 1.56" TUBING PUNCHER, 4 SPF, 3.4g HMX, 0.43" EH GEODY NAMICS TG39CM 2 N/A 5/29/2023 2.992 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 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) 4,242.6 2,669.7 69.85 1 GAS LIFT DMY BK 1 0.0 11/30/2023 0.000 6,783.6 3,855.2 36.58 2 GAS LIFT DMY INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT DMY BK 1 0.0 11/29/2023 0.000 8,504.3 5,356.8 28.25 4 GAS LIFT DMY BK 1 0.0 11/28/2023 0.000 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 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) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,535.0 8,888.0 5,383.8 5,696.3 Cement Plug 6/3/2023 8,535.0 8,888.0 5,383.8 5,696.3 Cement Plug 6/3/2023 MULTIPLE LATERALS, 2F-18, 1/31/2024 11:16:25 AM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 APERF; 9,325.0-9,335.0 FRAC; 9,325.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 10,206.6 13,112.0 6,236.6 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,206.6 6,145.3 86.87 BILLET 2.675 BAKER OH ANCHORED LINER BILLET Baker 1.000 10,218.3 6,146.0 86.91 DEPLOY 2.675 BAKER DEPLOYMENT SLEEEVE Baker 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,219.0 13,112.0 6,146.0 6,236.6 A-4, 2F-18L1 5/10/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1, 1/31/2024 11:16:26 AM Vertical schematic (actual) L1 Liner; 10,206.6-13,112.0 SLOTS; 10,219.0-13,112.0 L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1 ... TD Act Btm (ftKB) 13,306.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272060 Wellbore Status PROD Max Angle & MD Incl (°) 105.70 MD (ftKB) 13,268.50 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-01 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 01 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner (off main wellbore) 2 3/8 1.99 8,971.3 10,751.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,971.3 5,770.6 26.81 DEPLOY 2.625 BAKER DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,982.0 10,751.0 5,780.1 A-4, 2F-18L1-01 5/18/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-01, 1/31/2024 11:16:26 AM Vertical schematic (actual) L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-02 Liner; 9,598.8-12,522.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-01 ... TD Act Btm (ftKB) 12,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272061 Wellbore Status PROD Max Angle & MD Incl (°) 103.25 MD (ftKB) 9,720.70 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-02 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 02 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,598.8 12,522.0 6,189.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,598.8 6,135.2 89.81 BILLET 2.625 BAKER OH ANCHORED BILLET Baker 1.000 9,610.5 6,135.2 89.58 DEPLOY 2.675 BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,611.0 12,522.0 6,135.2 6,189.0 A-4, 2F-18L1-02 5/14/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-02, 1/31/2024 11:16:27 AM Vertical schematic (actual) L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB CATCHER; 8,532.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-02 ... TD Act Btm (ftKB) 12,544.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272062 Wellbore Status PROD Max Angle & MD Incl (°) 96.55 MD (ftKB) 10,290.16 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 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 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: N/A 23. BOTTOM 16" H-40 121' 9-5/8" L-80 3161' 7" L-80 5923' 5" L-80 6436' 2.375" L-80 6130' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 9. Ref Elevations: KB: 138' Sr Res EngSr Pet GeoSr Pet Eng 523' MD/ 523' TVD Oil-Bbl: Water-Bbl: 8535-8888' 14 bbl 15.8 Cement Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing 40# 121' 39' 9140' SUSPENDED Slotted Liner: 8971-10751' MD and 5770-6130' TVD Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information ACID, FRACTURE, CEMENT SQUEEZE, ETC. 275' FNL, 1713' FEL, Sec. 33, T11N, R9E, UM 2246' FNL, 289' FEL, Sec. 4, T10N, R9E, UM SIZE DEPTH SET (MD) 8935' MD/5738' TVD PACKER SET (MD/TVD) 8971' 24" 4.7# If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run):8979'3-1/2" 26# 9715' 39' 5739' 62.5# 1454' FNL, 628' FEL, Sec. 4, T10N, R9E, UM 50-029-22720-61-00 CASING WT. PER FT.GRADE 5/18/2013 CEMENTING RECORD 5942152 1650' MD/ 1525' TVD SETTING DEPTH TVD 5941361 TOP HOLE SIZE AMOUNT PULLED 518635 518977 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. 9602' MD/ 6135' TVD Kuparuk River Field/ Kuparuk River Oil Pool KRU 2F-18L1-01 ADL0025666, ADL 0025657 18# 41' 8935' 5614'41' 41' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 6/15/2023 213-053/ 323-282 ALK 2587, ALK 283 5/17/2013 10751' MD/ 6130' TVD 8535' MD/ 5384' TVD P.O. Box 100360, Anchorage, AK 99510-0360 517519 5948608 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, 137 sx Class G6.125" TUBING RECORD Slotted Liner10751' 130 sx Class G 5770' 8.5" 3" BOTTOM 12.25" 28 sx AS I 41'330 sx ASLW, 1220 sx Class G w/60 sx AS I tail Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 4:30 pm, Nov 17, 2023 Suspended 6/15/2023 JSB RBDMS JSB 120523 GDSR-1/26/24 x X Abandoned Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1650' 1525' Top of Productive Interval 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 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: 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 TPI (Top of Producing Interval). Authorized Name and Formation Name at TD: N/A - Suspended Authorized Title: 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. INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. 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. Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Katherine O'ConnorDN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this documentLocation: Date: 2023.11.15 14:19:58-09'00' Foxit PDF Editor Version: 13.0.0 Katherine O'Connor Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled GLV, open pocket 2F-18 6/15/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 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) 8,885.0 5,693.6 27.06 TUBING PUNCH 3' x 1.56" TUBING PUNCHER, 4 SPF, 3.4g HMX, 0.43" EH GEODY NAMICS TG39CM 2 N/A 5/29/2023 2.992 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 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) 4,242.6 2,669.7 69.85 1 GAS LIFT OPEN 1 0.0 6/15/2023 0.000 6,783.6 3,855.2 36.58 2 GAS LIFT DV INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT GLV BK 1 1,352.0 9/18/2022 7:00 0.250 8,504.3 5,356.8 28.25 4 GAS LIFT OV BK 1 0.0 9/18/2022 8:00 0.250 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 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) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 8,535.0 8,888.0 5,383.8 5,696.3 Cement Plug 6/3/2023 8,535.0 8,888.0 5,383.8 5,696.3 Cement Plug 6/3/2023 MULTIPLE LATERALS, 2F-18, 11/15/2023 1:00:52 PM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 FRAC; 9,325.0 APERF; 9,325.0-9,335.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 10,206.6 13,112.0 6,236.6 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,206.6 6,145.3 86.87 BILLET 2.675 BAKER OH ANCHORED LINER BILLET Baker 1.000 10,218.3 6,146.0 86.91 DEPLOY 2.675 BAKER DEPLOYMENT SLEEEVE Baker 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,219.0 13,112.0 6,146.0 6,236.6 A-4, 2F-18L1 5/10/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1, 11/15/2023 1:00:53 PM Vertical schematic (actual) L1 Liner; 10,206.6-13,112.0 SLOTS; 10,219.0-13,112.0 L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1 ... TD Act Btm (ftKB) 13,306.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272060 Wellbore Status PROD Max Angle & MD Incl (°) 105.70 MD (ftKB) 13,268.50 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-01 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 01 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner (off main wellbore) 2 3/8 1.99 8,971.3 10,751.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,971.3 5,770.6 26.81 DEPLOY 2.625 BAKER DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,982.0 10,751.0 5,780.1 A-4, 2F-18L1-01 5/18/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-01, 11/15/2023 1:00:53 PM Vertical schematic (actual) L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-02 Liner; 9,598.8-12,522.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-01 ... TD Act Btm (ftKB) 12,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272061 Wellbore Status PROD Max Angle & MD Incl (°) 103.25 MD (ftKB) 9,720.70 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-02 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 02 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,598.8 12,522.0 6,189.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,598.8 6,135.2 89.81 BILLET 2.625 BAKER OH ANCHORED BILLET Baker 1.000 9,610.5 6,135.2 89.58 DEPLOY 2.675 BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,611.0 12,522.0 6,135.2 6,189.0 A-4, 2F-18L1-02 5/14/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-02, 11/15/2023 1:00:54 PM Vertical schematic (actual) L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 TUBING PUNCH; 8,885.0 Cement Plug; 8,535.0 ftKB Cement Plug; 8,535.0 ftKB GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-02 ... TD Act Btm (ftKB) 12,544.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272062 Wellbore Status PROD Max Angle & MD Incl (°) 96.55 MD (ftKB) 10,290.16 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE DTTMSTART JOBTYP SUMMARYOPS 5/28/2023 OPTIMIZE WELL RAN STIFF 2.125" TOOLSTRING W/ 2.6" ROLLERS TO SIMULATE ELINE, TAGGED FILL @ 8883' SLM (8918' RKB). TAGGED 2.812" NIPPLE @ 488' SLM (523' RKB) 5/29/2023 OPTIMIZE WELL DISPLACE TUBING WITH SLICK DIESEL TO ~6500' MD WHILE RIH W/ TUBING PUNCHER. TAGGED FILL AT 8912' RKB. SHOOT HOLES IN TUBING FROM 8885' - 8888' RKB. U-TUBE FREEZE PROTECT WHILE POOH. JOB COMPLETE, READY FOR FULLBORE CEMENT PLUG 6/3/2023 OPTIMIZE WELL DISPLACE 360BBL 9.8 BRINE, 5BBL FRESH, 14 BBL 15.8 CEMENT, 2 BBL FRESH, WIPER BALL PUMPED DOWN WITH 74 BBL BRINE, SHUT IN RIGGED OUT 6/6/2023 OPTIMIZE WELL TAGGED CEMENT @ 8737' SLM & OBTAINED SAMPLE OF CEMENT. PERFORMED PASSING MITT TO 2500 PSI. READY FOR STATE WITNESS. 6/14/2023 OPTIMIZE WELL STATE WITNESSED (SEAN SULLIVAN) TAG CEMENT @ 8535' SLM. PERFORMED PASSING MITT TO 2500 PSI, ATTEMPT TO PULL GLV IN STATION 1 @ 4242' RKB, & STATION 2 @ 6783' RKB UNALBLE TO LOCATE WITH KOT IN BOTH MANDRELS , BRUSH GLV MANDRELS 1,2& 3. PUMP DIESEL DOWN IA, ESTABLISHED FLOW FROM IA TO TBG. JOB IN PROGRESS 6/15/2023 OPTIMIZE WELL PULL GLV FROM STATION 1 @ 4242' RKB, READY FOR DIESEL FREEZE PROTECT. 6/15/2023 OPTIMIZE WELL FREEZE PROTECT/U-TUBE PUMPED 86 BBLS DSL DOWN TBG TAKING RETURNS UP IA AND DOWN FL OF 2F-22 U-TUBE ( JOB COMPLETE ) 7/23/2023 OPTIMIZE WELL (SW) 2F-18 : State witnessed (Guy Cook) CMIT-T X IA Passed to 2760/2800 psi. 11/14/2023 ACQUIRE DATA (AC-EVAL) BLEED T X IA FOR BUR (COMPLETE) 2F-18 Suspend Summary of Operations 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Suspend Reservoir 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10751'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718 Senior Well Intervention Engineer Tubing Grade: Tubing MD (ft): 8935' MD and 5738' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 5778' 5/22/2023 Packer: Baker Liner Top Packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025657, ADL0025666 213-053-0 P.O. Box 100360, Anchorage, AK 99510 50-029-22720-61-00 ConocoPhillips Alaska, Inc. KRU 2F-18L1-01 Kuparuk River Oil PoolKuparuk River Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6130' 10751' 6130' None MD 121' 3161' 121' 5614' 5923'9142' 16" 9-5/8" 80' 5573' Perforation Depth MD (ft): Slotted Liner: 8982-10751' 9103' 5" Slotted Liner: 5780-6130' 9715'780' 3-1/2" 7" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-282 By Kayla Junke at 3:55 pm, May 11, 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: 2023.05.11 15:14:50-08'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor SFD 5/17/2023 SFD Suspension is valid for 5 years from the date of the suspension approval(this 10-403). See AOGCC Industry Guidance Bulletin 21-002A for additional guidance. Well-site inspection is required within 12 months after this suspension approval VTL 5/23/2023 10-407 X SFD X DSR-5/12/23GCW 05/23/23JLC 5/23/2023 5/23/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.23 16:38:28 -05'00' RBDMS JSB 052423 Date: 5 April 2023 Subject: 2F-18 Reservoir Abandonment Prepared by: Katherine O’Connor (214) 684-7400 Well History 2F-18 is a gas lifted producer that has TxIA communication. It had a patch installed from 8883’ – 8910’ RKB. The well stopped surfacing fluid after a scale squeeze on 12/6/22. Slickline went into tag and found fill in the whole above the patch. Coil did a FCO and cleaned ~17’ into the patch, but was kept tagging up on hard fill and were not able to make any further hole. Coil then pulled the upper section of the patch, then ran a venturi to clean out before pulling the lower section. Returns from the venturi showed sand and large chunks of rock. They attempted to pull the lower section of the patch, got temporarily detained, but were ultimately able to POOH with the lower section of the patch. They ran back in hole and made multiple attempts to clean out to TD but were unable to make any progress past 8894’ CTMD due to extremely hard fill (rocks). It is suspected the rocks are either coming from failed casing below the tubing or through one of the laterals. After coil rigged down, the well was circulated with ~11.5ppg brine to keep down the WHP. This well has high bottomhole pressure (4270 psi), TBGxIA communication, and because of the fill we are unable to get below the packer to secure the well with a plug. This wellbore it is currently being evaluated for either a RWO sidetrack or a full rotary capital sidetrack. The objective of this procedure is to place a balanced cement plug to secure the well for risk mitigation. Deviation Request: Abandon reservoir from top of fill @ 8894’ CTMD. Notes: x Current TIO pressure= 1525/1475/190. IA FL at surface x Two tubing leaks @ 8890’ and 8908’ RKB x Inclination Max: 71 deg @ 3950’ RKB x Min ID: 2.80” Camco landing nipple @ 8942’ RKB x Last SBHP 09/17/22 || 4270 psi || 8971’ RKB Calculations String Top Bottom Size ID bbls/ft ft volume ft/bbl notes 3.5" tubing 0 8979 3.5" 9.3# 2.99" 0.0087 8884 77.2 115 tubing volume calculated from tag depth 3.5" x 7" annulus 0 8935 3.5" 9.3# x 7" 26# 6.28" x 3.5" 0.0264 8884 234.6 38 casing volume calculated from tag depth Procedure: Slickline 1. RIH with 5’ of 6 spf tubing punches and tag fill 2. PUH 10’ and shoot (expected depth ~8885’ MD) Pumping 1. RU cementers to pump down the tubing and take returns up the IA 2. Pump the following schedule: a. ±400 bbls 9.8 ppg brine b. 5 bbl FW spacer (ensure TBGxIA communication) c. 14 bbls cement d. 2 bbl FW Spacer e. 5” foam ball f. 74 bbls 9.8 ppg brine displacement Slickline & Fullbore 1. WOC for minimum 24 hours. Notify AOGCC inspector of cement timing and plug tag at least 24 hours in advance. 2. RU Slickline and PT equipment as required 3. RIH to tag TOC (AOGCC witness) @ approx. 8484’ RKB, record results 4. CMIT-TxIA to 2500 psi (AOGCC witness), record results Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTMD 8,894.0 2F-18 3/7/2023 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled patch 2F-18 3/7/2023 praffer Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 41.0 5,614.4 3,161.5 40.00 L-80 BTC PRODUCTION 7 6.28 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD L1-01 WINDOW 6 5.00 9,268.0 9,280.0 6,046.1 LINER 5 4.28 8,935.4 9,715.0 18.00 L-80 LTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.8 Set Depth … 8,979.4 Set Depth … 5,777.8 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD 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) 36.8 36.8 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.80 NIPPLE 4.540 CAMCO DS LANDING NIPPLE CAMCO DS 2.812 4,242.6 2,669.7 69.85 GAS LIFT 5.500 CAMCO KBMM 2.920 6,783.6 3,855.2 36.58 GAS LIFT 5.500 CAMCO KBMM 2.920 7,768.7 4,709.2 28.69 GAS LIFT 5.500 CAMCO KBMM 2.920 8,504.3 5,356.8 28.25 GAS LIFT 5.500 CAMCO KBMM 2.920 8,896.2 5,703.6 26.66 GAS LIFT 5.968 CAMCO MMM 2.920 8,942.0 5,744.4 26.95 NIPPLE 4.540 CAMCO D LANDING NIPPLE NO GO - MILLED TO 2.80" PRE-CTD CAMCO D 2.800 8,949.1 5,750.7 26.82 LOCATOR 5.125 BAKER GBH-22 LOCATOR BAKER GBH-22 3.000 8,951.2 5,752.6 26.80 SEAL ASSY 4.000 BAKER SEAL ASSEMBLY w/ 1.62' OF SEALS & MULE SHOE, (Mule Shoe) TTL ELMD @ 8972' SWS LDL 2/7/1997 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) 8,890.0 5,698.0 26.88 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8890' RKB 8/27/2022 2.992 8,908.0 5,714.1 26.76 LEAK - TUBING LEAK IDENTIFIED BY EL LDL AT 8908' RKB 8/27/2022 2.992 9,232.0 6,003.4 27.16 FISH LOST MILL AND GRAPPLE 11/13/2015 9,268.0 6,035.4 27.19 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 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) 4,242.6 2,669.7 69.85 1 GAS LIFT GLV INT 1 1,304.0 9/19/2022 6:00 0.188 6,783.6 3,855.2 36.58 2 GAS LIFT DV INT 1 0.0 9/18/2022 11:30 0.000 7,768.7 4,709.2 28.69 3 GAS LIFT GLV BK 1 1,352.0 9/18/2022 7:00 0.250 8,504.3 5,356.8 28.25 4 GAS LIFT OV BK 1 0.0 9/18/2022 8:00 0.250 8,896.2 5,703.6 26.66 5 GAS LIFT EXT DMY RK 1 1/2 0.0 7/23/2022 3:00 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,935.4 5,738.5 27.07 PACKER 5.875 BAKER TIEBACK SLEEVE w/ LINER TOP PACKER BAKER 4.408 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,325.0 9,335.0 6,086.2 6,095.1 A-5, 2F-18 6/14/2010 6.0 APERF 2.5" HSD Gun, 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) 9,325.0 9,335.0 1 FRAC 6/15/2010 0.0 0.00 0.00 MULTIPLE LATERALS, 2F-18, 5/5/2023 11:54:11 AM Vertical schematic (actual) LINER; 8,935.4-9,715.0 IPERF; 9,359.0-9,383.0 CMT PLUG; 9,351.0 ftKB CMT Retainer; 9,350.0 APERF; 9,325.0-9,335.0 FRAC; 9,325.0 L1-01 WINDOW; 9,268.0- 9,280.0 WHIPSTOCK; 9,268.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 SLOTS; 8,982.0-10,751.0 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18 ... TD Act Btm (ftKB) 9,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272000 Wellbore Status PROD Max Angle & MD Incl (°) 70.96 MD (ftKB) 3,950.00 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner 2 3/8 1.99 10,206.6 13,112.0 6,236.6 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,206.6 6,145.3 86.87 BILLET 2.675 BAKER OH ANCHORED LINER BILLET Baker 1.000 10,218.3 6,146.0 86.91 DEPLOY 2.675 BAKER DEPLOYMENT SLEEEVE Baker 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,219.0 13,112.0 6,146.0 6,236.6 A-4, 2F-18L1 5/10/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1, 5/5/2023 11:54:11 AM Vertical schematic (actual) L1 Liner; 10,206.6-13,112.0 SLOTS; 10,219.0-13,112.0 L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-01 WINDOW; 9,268.0- 9,280.0 LINER; 8,935.4-9,715.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1 ... TD Act Btm (ftKB) 13,306.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272060 Wellbore Status PROD Max Angle & MD Incl (°) 105.70 MD (ftKB) 13,268.50 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-01 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 01 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-01 Liner (off main wellbore) 2 3/8 1.99 8,971.3 10,751.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,971.3 5,770.6 26.81 DEPLOY 2.625 BAKER DEPLOYMENT SLEEVE Baker 1.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,982.0 10,751.0 5,780.1 A-4, 2F-18L1-01 5/18/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-01, 5/5/2023 11:54:12 AM Vertical schematic (actual) L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 L1-02 Liner; 9,598.8-12,522.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-01 ... TD Act Btm (ftKB) 12,523.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272061 Wellbore Status PROD Max Angle & MD Incl (°) 103.25 MD (ftKB) 9,720.70 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 2F-18L1-02 2/9/2013 osborl Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: FISH 2F-18L1- 02 12/2/2015 lehallf Notes: General & Safety Annotation End Date Last Mod By NOTE: ADDED LATERALS L1, L1-01 (OFF MAIN WELLBORE), L1-02 5/18/2013 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 9,598.8 12,522.0 6,189.0 4.70 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,598.8 6,135.2 89.81 BILLET 2.625 BAKER OH ANCHORED BILLET Baker 1.000 9,610.5 6,135.2 89.58 DEPLOY 2.675 BAKER DEPLOYMENT SLEEVE Baker 1.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,611.0 12,522.0 6,135.2 6,189.0 A-4, 2F-18L1-02 5/14/2013 32.0 SLOTS SLOTTED LINER MULTIPLE LATERALS, 2F-18L1-02, 5/5/2023 11:54:13 AM Vertical schematic (actual) L1-02 Liner; 9,598.8-12,522.0 SLOTS; 9,611.0-12,522.0 L1-01 Liner (off main wellbore); 8,971.3-10,751.0 SLOTS; 8,982.0-10,751.0 LINER; 8,935.4-9,715.0 L1-01 WINDOW; 9,268.0- 9,280.0 FISH; 9,232.0 PRODUCTION; 38.5-9,141.7 LEAK - TUBING; 8,908.0 GAS LIFT; 8,896.2 LEAK - TUBING; 8,890.0 GAS LIFT; 8,504.3 GAS LIFT; 7,768.7 GAS LIFT; 6,783.6 SURFACE; 41.0-5,614.4 GAS LIFT; 4,242.6 CONDUCTOR; 41.0-121.0 KUP PROD KB-Grd (ft) RR Date 1/19/1997 Other Elev… 2F-18L1-02 ... TD Act Btm (ftKB) 12,544.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292272062 Wellbore Status PROD Max Angle & MD Incl (°) 96.55 MD (ftKB) 10,290.16 WELLNAME WELLBORE2F-18 Annotation Last WO: End DateH2S (ppm) 50 Date 11/22/2015 Comment SSSV: NIPPLE Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 13 - __0 3 Well History File Identifier Organizing (done) ❑ Two-sided III 11111111 11111 111 ❑ Rescan Needed 111111111111 Ill III RESCAN DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: /reyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: M Date: Z/451`II. /s/ Pi I' Project Proofing 111111111111111111 BY: Maria) Date: 31,51/ /s/ 01 P Scanning Preparation a x 30 = (pc) + c23 = TOTAL PAGES C1'3 (Count does not include cover sheet)BY: Mari Date: 3 S /s/ vvi Production Scanning Ill lIllIllIll 11111 Stage 1 Page Count from Scanned File: likl-f' (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ✓YES NO BY: AM Date: 3/51 i Ll. /s1 04 p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 11 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. Iii 1111111111111 Ill ReScanned III Dliii liii! 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked Iii 111111 iii Ii11 iii 12/22/2011 Well History File Cover Page.doc G 9 o /z /z/Z N .. c) N Z C J } } } i 8 co Q m N a)a) v Q+ d r _c o N° O co a) N o o a) (� 0 0 J J C' .. U U -.1 0 48 1 N o 11 11.1.2,O ° . z c co co c co co U o a Q /Q Z E W W m d / ° c co I- U E ›- R v O N J N o J N a) V �/• � IX Q E 0 0 0 w Od c c 'c M M N M a w d To co --1 U ? N N N N E N E Q W a m o o v v) Z vi ai N o co a O 8 rc co co - co f6 O - c c c v en W O J O U O O O > o ° co a) Z o a m `° u) c°n o o co N 7 !o N I` ^ r- I` J nai }' O O O O v E J o i Z a o O of . 2 c U U r el OC w N a) °) O) °) N E a) 0 o co J J cez° /} >- >- c/ Q ao ., O f6 I— 11.N l6 c) G r E M J N Z o 2U U o a) a ‘, 5 N > 6) c) to 2 • a)In LO J V)N N C O 1- E iii w a c IN c) a Ci) CC a o c C o Y c a� ° •- °�a j z o 1 Q o z Eo I N w ' a) 1 Q d U o > > 0 2 O.N E -J g m 2 "ell /co d' Z = 0 a) _ w u) c c O 0 E } } �\ co �j ZO J i a) d CO ,O W' I /a: Q Z t C y 4 c N W O 0 O W QZ g) W ° d N O Q O R �+ Q Z fl. N N •> I� o ce c d o I y co W 2 O . I z E a U p_ a o y H w J l y O p d ° p o p o re LL ° a) ° _ U a 0 0 V a o y J J w Joy / I 1 / 4%,k,;,‘„,, f ,7 an n A STATE OF ALASKA 1L IN 1 2013 ` ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND I ' 3. la.Well Status: Oil 0• Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 5 • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: May 19,2013 • 213-053/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 May 17,2013 • 50-029-22720-61 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 275'FNL, 1713'FEL,Sec.33,T11N,R9E, UM May 18,2013 . 2F-18L1-01 . Top of Productive Horizon: 8.KB(ft above MSL): 138'RKB 15.Field/Pool(s): 1454'FNL,628'FEL,Sec.4,T1ON, R9E, UM GL(ft above MSL): 92.5'AMSL• Kuparuk River Field . Total Depth: 9.Plug Back Depth(MD+TVD): 2246'FNL,289'FEL,Sec.4,T1ON,R9E,UM 10751'MD/6130'TVD ' Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-517519 y- 5948608 Zone-4 10751'MD/6130'TVD ADL 25657,25666 TPI: x-518635 y- 5942152 Zone-4 . 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-518977 y- 5941361 Zone-4 nipple @ 523'MD/523'TVD • 2583,2587 18.Directional Survey: Yes 5 No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1650'MD/1525'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 9602'MD/6135'TVD • 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 41' 121' 41' 121' 24" 280 sx AS I 9.625" 40# L-80 41' 5614' .. 41' 3161' 12.25" 330 sx ASLW,1220 sx Class G,60 sx AS I 7" 26# L-80 39' 9142' 39' 5923' 8.5" 130 sx Class G 5" 18# L-80 8935' 9715' 5739' 6436' 6.125" 137 sx Class G 2.375" 4.7# L-80 8971' 10751' 5770' 6130' 3" slotted liner 24.Open to production or injection? Yes 5 No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 8979' 8935'MD/5739'TVD slotted liner from 8971'-10751'MD 5770'-6130'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. _ _ Was hydraulic fracturing used during completion? Yes El No Q I 'f. 1+'pLEr o$ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED A (3 I na C (F I , ____ .1r1 -_ I _........... __,_ 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting for facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 5 Sidewall Cores Acquired? Yes ❑ No 5 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RBDMS JUN 11 2013 Form 10-407 Revised 10/2012 CONTINUED ON R i\t3 � �, m � y 29. GEOLOGIC MARKERS(List all formations and mar,_.,encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Ezi Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1650' 1525' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk A4 9602' 6135' Kuparuk A5 Base/Top A4 9704' 6119' (inverted) Kuparuk A5 10751' 6129' N/A Formation at total depth: Kuparuk A5 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 32. I hereby certify that the foregoing is true and corr ect he best of my knowledge. Contact: Kai Starck @ 263-4093 ` Email: Kai.Starck @cop.com Printed Name Lamar Gantt Title: CT Drilling Supervisor Signature RAMALLA • Phone 263-4021 Date 4///O INSTRUCTIONS 111 tt J 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 i KUP 2F-18 • COnOC i$ Well Attributes Max Angle&MD TD Wellbore API/OWI Field Name Well Status Inc'(°) MD(ftKB) Act Btm MKS) Alaska,Inc. CCrlomnvl9Ds 500292272000 KUPARUK RIVER UNIT PROD 70.96 3,950.00 9,715.0 Comment H25(ppm) Data Annotation End Date KB-Grd(R) Rig Release Data .. Well cenr4 -zF-1e 615/2013 7 ou6 AN -SSSV:NIPPLE 130 10/12/2007 Last WO: 1/19/1997 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,334.0 2/9/2013 Rev Reason:ADD LATERALS,GLV C/O osborl 6/4/2013 HANGER,37 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 41.0 5,614.4 3,161.4 40.00 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(L.Set Depth(TVD)_.String Wt..String_.String Top Thrd PRODUCTION 7 6.276 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(11/D)...String Wt...String...String Top Thrd I L1-01 WINDOW 6 5.000 9,268.0 9,280.0 6,046.1 CONDUCTOR, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd I a1-121 LINER 5 4.276 8,935.4 9,715.0 18.00 L-80 LTC-MOD NIPPLE,523 ;II 1 T'( Liner Details . Top Depth • 1 Top(ftKB) (TVD) Top Intl Nonni... (ftKB) (°I Rem Description Comment ID(in) 8,935.4 5,738.5 26.79 PACKER BAKER TIEBACK SLEEVE w/LINER TOP PACKER 4.408 8,949.3 5,750.9 26.80 HANGER BAKER LINER HANGER 4.408 GAS LIFT, 4 8,955.8 5,756.7 26.86 SBE BAKER SEAL BORE EXTENSTION 4.000 4.243 Tubing Strings Tubing Description String 0... 'String ID...Top(MB) Set Depth(t..Set Depth(TVD)...String Wt..String...String Top Thrd I TUBING 31/2 2992 36.8 8,979.4 5,777.8 9.30 L-80 EUE8RDMOD Completion Details Top Depth II (TVD) Top Intl Nonni... 1I Top(RKB) (RKB) (°) Item Description Comment ID(in) 36.8 36.8 -0.16 HANGER FMC GEN IV TUBING HANGER 3.500 SURFACE, A l 523.0 522.6 5.82 NIPPLE CAMCO DS LANDING NIPPLE 2.812' 41-5,614 8,942.0 5,744.4 26.80 NIPPLE CAMCO D LANDING NIPPLE NO GO-MILLED TO 2.80"PRE-CTD 2.800 8,949.1 5,750.7 26.80 LOCATOR BAKER GBH-22 LOCATOR 3.000 GAS LIFT, (3.754 --I 8,951.2 5,752.6 26.87 SEAL ASSY BAKER SEAL ASSEMBLY w/1.67 OF SEALS 8 MULE SHOE,(Mule 3.000 Shoe)TTL ELMD @ 8972'SWS LDL 2/7/1997 Other In Hole Alkaline retrievable plugs,valves,pumps,fish,etc.) Top Depth GAS LIFT, (ND) Top Inc! 7,758 Top(ftKB) Vin) CI Description Comment Run Date ID(in) 9,268.0 6,035.4 27.22 WHIPSTOCK LATERAL WHIPSTOCK 4/28/2013 Perforations&Slots Shot GAS LIFT,_ __ _ Top(TVD) Btm(TVD) Dens 8,504 Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (oh„ Type Comment 9,325.0 9,335.0 6,086.2 6,095.2 A-5,2F-18 6/14/2010 6.0 APERF 2.5"HSD Gun,60 deg phase Stimulations&Treatments Bottom GAS LIFT,_, °_ Min Top Max Btm Top Depth Depth S,e96 Depth Depth (TVT D) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Type , Comment 9,325.0 9,335.0 6,086.2 6,095.2 FRAC 6/15/2010 A-SAND FRAC-placed 95,972 lbs.of 16/20 >< Carbolite behind Perfs @ 9325'-9335' NIPPLE,6,942 .. Notes:General&Safety End Date Annotation N. - 10/14/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR, 8,949 R. ME 5/18/2013 NOTE:ADDED LATERALS L1,L1-01(OFF MAIN WELLBORE),L1-02 SEAL ASSY. 5,951 II ANS ill PRODUCTION. 39-9,142 WHIPSTOCK, 9,268 L1-01 IMNDOW, 9,268-9,280 APERF, 9,325-9,335 FRAC.9.325 CUT Retainer, 9,350 CUT PLUG, 9,351 !PERF, Mandrel Details 9,359-9,383 LINER, Top Depth Top Port 8.935-9.715- S„- (TVD) not OD Valve Latch Site TRO Run TD(2FF.18). N...Top(ftKB) (ftKB) P) Make Model ('n) Sery Type Type (in) (ps') Run Date Com... SLOTS, 1 4,242.6 2,669.7 69.85 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,320.0 5/27/2013 6:00 8,982-10,751 1 L1-01 Liner 2 6,783.6 3,855.2 36.58 CAMCO KBMM 1 GAS LIFT GLV INT 0.156 1,308.0 5/27/2013 11:30 (of main a Ilbere), 3 7,768.7 4,709.1 28.59 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,333.0 5/27/2013 7:00 8,971-10,751 I11 4 8,504.3 5,356.8 28.60 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,319.0 5/27/2013 8:00 II 5 8,896.2 5,703.6 26.66 CAMCO MMM 1 1/2 GAS LIFT OV RK 0.250 0.0 5/26/2013 3:00 SLOTS, I 9,811-12,522 NI L1-02 Liner, 9.599-12,522 KUP 2F-18L1-01 Conoco Philli .7 *W Well Attributes Max Angle&MD _TD I'rX: Wellbore APUUWI Field Name Well Status Inc((°) MD(MB) Act atm(ftKB) Alaska, 5002922720061 KUPARUK RIVER UNIT PROD 12,523.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date ••• Well Gonna:-2F-18L7-01,R15120137:12:02AM SSSV:NIPPLE 130 10/12/2007 Last WO: 1/19/1997 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM Rev Reason:ADD LATERALS,GLV C/O osborl 6/4/2013 Casing Strings HANGER,37 - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String... String Top Thrd L1-01 Liner 2 3/8 1.992 8,971.3 10,751.0 4.70 L-80 ST-L (off main wellbore) ILiner Details Top Depth (ND) Top loci Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 8,971.3 DEPLOY BAKER DEPLOYMENT SLEEVE 1.000 Perforations&Slots snot CONDUCTOR, Top(ND) BOO(ND) Dena 47-127 Top(1R(B)Btm(RKB) (RKB) (RKB) Zone Date (ah-.. Type Comment 8,982.0 10,751.0 5/18/2013 32.0 SLOTS SLOTTED LINER NIPPLE.523 Notes:General&Safety End Date Annotation 5/18/2013 NOTE:ADDED LATERALS L1,L1-01(OFF MAIN WELLBORE),L1-02 GA5 LIFT, I F `,' 4243 F " e Li j 1 I SURFACE. 41-5614 a GAS LIFT, c 8,784 a a • GAS T, 7LIF,789 ` GAS LIFT,_ __ : --_p 5,504 B GAS LIFT, p 8,896 s G all IIII NIPPLE,8,942 Ne le LOCATOR. 8.949 SEAL ASSY. 8,951 Mandrel Details Top Depth Top Port (ND) loci OD Valve Latch SW TRO Run N...Top(RKB) (RKB) (°) Make Model On) Sery TYR. TYPe (to) (poi) Run Date Com... 1 4,242.6 2,669.7 69.85 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,320.0 5/27/2013 6:00 ' 2 6,783.6 3,855.2 36.58 CAMCO KBMM 1 GAS LIFT GLV INT 0.156 1,308.0 5/27/2013 11:30 1 PRODUCTION, 595,142 3 7,768.7 4,709.1 28.59 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,333.0 5/272013 7:00 WHIPSTOCK 8,288 4 8,504.3 5,356.828.60 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,319.0 5/27/2013 8:00 L1-01 WINDOW, 5 8,896.2 5,703.6 26.66 CAMCO MMM 1 12 GAS LIFT OV RK 0.250 0.0 5/26/2013 3:00 1 9.2685,280 LINER, 8.9355,715 SLOTS. 8,982-10,751-\ L1-01 Liner (off main welbore), 8,971-10,751 TD (2F-18L7-0t), 12,523 i CI N• pf y N C , N G&NI (0.-0 9 Q r ▪ O I I ) 11 A (C) co 11 ,.' Q G) 1 Y G co NE- 1 W ti L as CO o 0 c — r Co o Y Y cc N up co o U ��\\ : ❑� pj a0 co V co • N g N g o -o `) cc) y v o 0 CD � �' 0.m co Lo �'°~ \ �I Q Q o- age N a) o o m 0 8 = co Y ;-1 oo II I s 0 Q W -0 N / \ C0 it d J U Ui CO 2 (a I N O P N}-.J CO ❑ Y ❑ �� I co 0 t O O O O U (6 IL E It E E E N � � w N m ''') m m ca o 1 ID °o U ai U U U CO o ' _ U I C N GV CV N CV Y a Y Y Y \\\ O N O (6 (0 (6 N C)M CO r) c`7 M CCI J CO m m c m 0 Il— 0 i / E I (0 in -6 I -0 (j) J x O N CO Q / v V Q h 0 < LL c N E a) !I ,• U u_ r` E N I ca — f� a„ e L If :' \-1'\] g 1 m V, 1 Co g o N o 0 o d t to co V j 4 O NO iloO CO Lo i o N N 0 co V co _ Q O) d < O I *k (\ - V _ - I� O) (4 N N .- (9 U cu U) Q) @) CC 2F-18 Pre-Rig Well Work Summary DATE SUMMARY 1/9/2013 LOCATED 2.75" D-NIPPLE AT 8942' M.D. FLAG END OF PIPE AND CORRECTED DEPTH. TAGGED TOP OF FILL AT 9356' MD. WELL FREEZE PROTECETED. JOB IN PROGRESS. 1/10/2013 SET INFLATABLE CEMENT RETAINER AT 9350' MD. PUMPED 1 OF 5 BBLS OF CEMENT THROUGH RETAINER. PRESSURED UP TO 4000 PSI. DUMPED THE BACK SIDE OF COIL. PRESSURED UP TO 4500 PSI. DUMPED COIL AGAIN AND PRESSURED UP TO 4500 PSI. UNABLE TO PUMP ANYMORE THROUGH RETAINER. UNSTUNG FROM RETAINER AND WASHED OUT REMAINING CEMENT. MAINTAINED 1:1 RETURNS. FREEZE PROTECTED WELL TO 2000'TVD. JOB COMPLETE. 2/9/2013 TAG TOC @ 9344' RKB AND MEASURE BHP @ 9325' RKB. ( GLD PENDING ON BHP RESULTS ). 3/23/2013 INJECTIVITY TEST DOWN TBG WITH DIESEL. STARTED OUT @ .25 BPM 2025 PSI. PRESSURED TO MASP (2300 PSI)AFTER 6.2 BBLS @ .25 BPM. RDMO LRS. SEE PUMP REPORT IN ATTACHMENTS. 3/30/2013 DRIFTED TBG WITH 2.625"x 17' DUMMY WHIPSTOCK TO TOC ©9344' RKB. MEASURED BHP @ 9325' RKB: 4136 PSI. COMPLETE. 4/18/2013 TAGGED TOC @ 9350' RKB. MEASURED BHP ©9325' RKB: 4140 PSI (& FALLING). COMPLETE. 4/21/2013 DELAYED START DUE TO HIGH WINDS, RIH TAG NIPPLE AT 8917' CTMD (8942' RKB), 11 STALLS, DRY DRIFT THROUGH NIPPLE TO 8975'CTMD, F/P TBG W/ DIESEL TO 3000' CTMD WHILE POOH, MILL GAUGED AT 2.8", READY FOR ELINE, JOB IN PROGRESS. ICI ConocoPhillips Time Log & Summary Wel!view Web Reporting Report Well Name: 2F-18 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 4/27/2013 8:00:00 PM Rig Release: 5/20/2013 9:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/23/2013 24 hr Summary Stand by for trucking and extreme weather conditions 15:00 21:00 6.00 0 0 MIRU MOVE MOB T Trucks not available to move rig 21:00 00:00 3.00 0 0 MIRU MOVE MOB T Kuparuk(CPF1 &CPF2)now in Phase 3 conditions 04/24/2013 Stand by for extreme weather and Trucking 00:00 11:00 11.00 0 0 MIRU MOVE MOB T Stand by on 2Tfor move to 2F, Phase 3 11:00 00:00 13.00 0 0 MIRU MOVE MOB T Phase three conditions dropped, Waiting on trucks 04/25/2013 Stand by for trucking 00:00 00:00 24.00 0 MIRU MOVE MOB T Waiting on trucks to move CDR2 to 2F 04/26/2013 00:00 00:00 24.00 MIRU MOVE MOB T Stand by for trucks-Hold pre spud with day(Wheeler)and night (Poehler)crews 04/27/2013 Move rig to 2F-18. Spot rig, MIRU, Nipple up and start BOPE Test 00:00 10:00 10.00 0 0 MIRU MOVE MOB T Stand by for trucking, Hold prespud with incoming crew(maddy) 10:00 15:00 5.00 0 0 MIRU MOVE MOB P Trucks on location, High line disconnected,start rig move to 2F, not exception move 15:00 18:00 3.00 0 0 MIRU MOVE MOB P On 2 F pad, remove jeeps,prep cellar area and spot rigs 18:00 20:00 2.00 0 0 MIRU MOVE MOB P MIRU 20:00 23:00 3.00 0 0 MIRU WHDBO BOPE P Accept Rig,20:00, Start nipple up, Witness waived by Jeff Jones, AOGCC 23:00 00:00 1.00 0 0 MIRU WHDBO BOPE T T1 valve inoperable(original wing), call out valve truck to service valve. Unable to fluid pack tree 04/28/2013 Complete BOPE Test, M/U Whipstock and set @ 9280',TOWS=9268, 10° ROHS, Flush well, roll to flo pro 00:00 00:30 0.50 0 0 MIRU WHDBO BOPE T Greas crew here and working Tango 1 00:30 09:00 8.50 0 0 MIRU WHDBO BOPE P Good shell test,test new kill line and deployment cellar hoses to 5K, Procede with BOPE Test. Lower blind shears failed, replace seals and retest. Pass. BOPE test finished and R/D tesing equipment. Page 1 of 18 Time Logs Date From To Dur S.Depth E. Depth.Phase Code Subcode T Comment 09:00 09:30 0.50 0 0 MIRU WHDBO BOPE P Load up FMC lubricator. Conduct PJSM pull BPV. 09:30 11:00 1.50 0 0 MIRU WHDBO BOPE P R/U lubricator and test. Pull BPV 11:00 11:30 0.50 0 0 MIRU WHDBO BOPE P Conduct PJSM-R/D and load out FMC lubricator 11:30 12:00 0.50 0 0 MIRU WHDBO BOPE P P/T both PDL's,Tiger tank line. 12:00 13:30 1.50 0 0 MIRU WHDBO BOPE P Fill Coil with sea water. P/T inner reel valve and pac off. 13:30 13:45 0.25 0 0 MIRU WHDBO BOPE P Install BHI check valves into upper quick. 13:45 13:45 0.01 0 0 SLOT WELLPFCTOP P Time entry to make ROP graph work 13:45 16:44 2.99 0 0 PROD1 RPEQPI PULD P Conduct PJSM-Checking WHP and Deploying WS setting BHA. 16:44 20:14 3.50 75 9,170 PROD1 RPEQP1TRIP P Tag up and rezero depth, RIH to 170' Pull back up hole and check pipe (after changing out gripper blocks) EDC open 20:14 20:20 0.10 9,170 9,197 PROD1 RPEQP1DLOG P Log K1 marker for+5'correction to 9202.42, 20:20 20:26 0.10 9,197 8,940 PROD1 RPEQP1TRIP P PUH to 8940 for CCI pass, PUW=36K 20:26 20:50 0.40 8,940 9,338 PROD1 RPEQP1 DLOG P Log CCL pass 20:50 21:02 0.20 9,338 9,280 PROD1 RPEQP1TRIP P Tag TD @ 9338, PUW=36K, Pull to set depth 21:02 21:08 0.10 9,280 9,270 PROD1 RPEQP1WPST P At set depth 9280,TOWS=9268, 10° ROHS,shut EDC, Pumps on,see tool shift @ 2600 PSI,Set down 4K. Looks good 21:08 23:32 2.40 9,270 9,270 PROD1 RPEQPI CIRC P Open EDCFIush hole with seawater @ 1.6 BPM, 3500 PSI CCP, roll hole to 9.5 PPG Milling fluid,Obtain static pressure @ 4090 PSI 23:32 00:59 1.45 9,270 3,130 PROD1 RPEQP1TRIP P Trip out 04/29/2013 M/U, RIH and set TOWS @ 9268', POOH and M/U window milling BHA,RIH and mill window 00:00 00:48 0.80 3,130 80 PROD1 RPEQP1TRIP P Continue out of well, bleed IA and OA down 00:48 04:00 3.20 80 73 PROD1 RPEQPI PULD P Tag up and space out, PUD BHA#1 Whipstock setting tool, PD BHA#2 window milling BHA with.6°AKO Motor, 2.8"dimond window mill and 2.79 string reamer 04:00 06:18 2.30 73 9,170 PROD1 WHPST TRIP P Trip in EDC open 06:18 06:33 0.25 9,170 9,183 PROD1 WHPST DLOG P Tie into the K1 correction minus 1.5'. 06:33 06:48 0.25 9,183 9,272 PROD1 WHPST TRIP P Continue to bottom. RIW 13k 06:48 07:03 0.25 9,272 9,265 PROD1 WHPST TRIP P Dry tag WS at 9271.8'. PUW 33k, 07:03 07:18 0.25 9,265 9,271 PROD1 WHPST TRIP P Work back down to WS. Bring pump up 07:18 12:18 5.00 9,271 9,276 PROD1 WHPST MILL P Start milling window at 9271'. 1.41 bpm at 3800psi. BHP 3800, WHP 230, IA 680,OA 578. 12:18 12:27 0.15 9,276 9,276 PROD1 WHPST MILL P looks like mill exited the casing. Page 2 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:27 15:42 3.25 9,276 9,280 PROD1 WHPST MILL P Milling ahead, 1.40 bpm at 3920psi, BHP 3790,WHP 242, IA 388,OA 445 15:42 16:12 0.50 9,280 9,267 PROD1 WHPST MILL P PUH pumping bottoms up. Reaming window area. 16:12 16:27 0.25 9,267 9,280 PROD1 WHPST MILL P Ream back down through window area. RIW 20k 16:27 16:57 0.50 9,280 9,267 PROD1 WHPST MILL P PUH to 9267'PUW 34k-Shutdown pump,shut choke and perform static survey for 30 min. 3987psi-13.0 BHI ECD. 16:57 17:27 0.50 9,267 9,280 PROD1 WHPST DRLG P RBIH to bottom 9280'-continue milling formation. 17:27 19:45 2.30 9,280 9,293 PROD1 WHPST MILL P BOBM 1.42bpm FS 4150psi. BHP 4050,WHP 497, IA 409, OA 466 19:45 21:09 1.40 9,293 9,265 PROD1 WHPST MILL P TD rat hole. Back ream window area 60fph as per plan. 9282'to 9265' 21:09 21:24 0.25 9,265 9,265 PROD1 WHPST MILL P Dry drift window area 21:24 23:24 2.00 9,265 0 PROD1 WHPST TRIP P POOH 23:24 00:00 0.61 0 PROD1 WHPST PULD P Conduct PJSM-Undeploy Window milling BHA. 04/30/2013 PUD BHA#2 window mill assembly. PD BHA#3, build section assembly,drill build section from 9,294'to 9,475'. POOH, PUD BHA#3, PD BHA#4,tool failure at surface,troublshoot BHA. RIH w/BHA#4 with RSM assembly, unable to work BHA through window @ 9,278',called town,decision made to dress window. POOH w/BHA#4.Start PUD BHA#4. 00:00 01:00 1.00 0 0 PROD1 WHPST PULD P Continue undeploying window milling BHA#2. 01:00 02:18 1.30 0 62 PROD1 DRILL PULD P Deploy BHA#3, Build section BHA with 2.1°motor and RR Hycalog bi center 02:18 04:24 2.10 62 9,160 PROD1 DRILL TRIP P RIH, EDC Open 04:24 04:54 0.50 9,160 9,168 PROD1 DRILL DLOG P Log K1 counter stopped on first pass, Pull back up and relog after inspecting and cleaning counter wheel, +15'correction, Shut EDC, PUW=33K 04:54 05:06 0.20 9,168 9,294 PROD1 DRILL TRIP P Trip in well to drill build, Clean pass through window 05:06 05:42 0.60 9,294 9,301 PROD1 DRILL DRLG P Drill Ahead, 1.4 BPM @ 3975PS1 FS, BHP=4105,WHP=510 Swap to 9.9PPG Flo Pro 05:42 05:54 0.20 9,301 9,301 PROD1 DRILL WPRT T PUH into casing to check out HOT torguing up, looks good,end stops just in wrong spot 05:54 06:00 0.10 9,301 9,302 PROD1 DRILL DRLG P 9301 Drill ahead, 1.35 BPM @ 4230 PSI FS, BHP=4115 06:00 06:30 0.50 9,302 9,302 PROD1 DRILL WPRT T PUH for MWD reboot near bit inc corrupt data base 06:30 10:15 3.75 9,302 9,475 PROD1 DRILL DRLG P 9302' Drill Ahead, 1.34 BPM @ 4090 PSI FS, BHP=4110 10:15 12:39 2.40 9,475 56 PROD1 DRILL TRIP P Call end of build, PUW=33K 12:39 13:39 1.00 56 0 PROD1 DRILL PULD P At surface, PJSM PUD BHA#3, build section BHA Page 3 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:39 14:33 0.90 0 68 PROD1 DRILL PULD P PD BHA#4 RSM Lateral with new hughes bi center 14:33 17:15 2.70 68 0 PROD1 DRILL PULD T Unable to get surface, Break off and test UQC and LQC. No good, PUD BHA#4 Reconfig and test tools Start BHI Downtime End BHI Downtime 17:15 20:15 3.00 68 9,278 PROD1 DRILL TRIP P RIH with BHA#4, RSM with new Hughes bi center, log GR tie-in,-4' correction,close EDC,continue in hole,set down @ window @ 9,278'. 20:15 21:30 1.25 9,278 9,278 PROD1 DRILL TRIP T Made several attempts to work BHA through window without success, several ROP rates, pumping,etc... Called town,decision to POOH for crayola mill,open EDC. 21:30 23:42 2.20 9,278 62 PROD1 DRILL TRIP T POOH w/BHA#4,tag-up, space-out. 23:42 00:00 0.30 62 0 PROD1 DRILL PULD T PJSM.Start PUD 05/01/2013 PD BHA#5, RIH w/Crayola mill assembly, back ream window @ 9,278'.TOH PUD BHA#5, PD BHA#6, RIH w/RSM drilling assembly. Drill L1 lateral from 9,475'to 9,939'wiper 150'wiper trips,drilling in progress. 00:00 01:15 1.25 62 62 PROD1 DRILL PULD T Continue PUD BHA#4, break-out motor and bit 01:15 02:30 1.25 62 62 PROD1 DRILL PULD T PJSM. PD BHA#5,surface test tools. 02:30 04:42 2.20 62 9,165 PROD1 DRILL TRIP T RIH w/BHA#5 crayola mill assembly 04:42 04:54 0.20 9,165 9,185 PROD1 DRILL DLOG T Log GR tie in for-2.5'correction, Close EDC 04:54 05:00 0.10 9,185 9,258 PROD1 DRILL TRIP T RIH, Dry drift through window,saw nothing. 05:00 07:18 2.30 9,258 9,260 PROD1 DRILL REAM T Start reaming/back reaming passes per procedure 07:18 09:30 2.20 9,260 68 PROD1 DRILL TRIP T Open EDC and trip out 09:30 11:45 2.25 68 68 PROD1 DRILL PULD T At surface, PJSM, PUD BHA#5, PD BHA#6 RSM (20 Minutes Injector service time) 11:45 13:51 2.10 68 9,170 PROD1 DRILL TRIP T Trip in, EDC Open 13:51 14:03 0.20 9,170 9,201 PROD1 DRILL DLOG T Log K-1 for-4',shut EDC 14:03 14:15 0.20 9,201 9,300 PROD1 DRILL TRIP T Trip in to log RA, clean pass through window 14:15 14:21 0.10 9,300 9,310 PROD1 DRILL DLOG P Log RA marker in whipstock @ 9275,TOWS=9268 14:21 14:27 0.10 9,310 9,475 PROD1 DRILL TRIP P Trip in to drill 14:27 17:33 3.10 9,475 9,625 PROD1 DRILL DRLG P Drill Ahead, 1.35 BPM @ 4110 PSI FS, RIW=14.5K, BHP=4123, WHP=200 17:33 18:27 0.90 9,625 9,625 PROD1 DRILL WPRT P Wiper trip to window, WOB=31 K,Mad pass for res.data. Page 4 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:27 20:27 2.00 9,625 9,775 PROD1 DRILL DRLG P Drill Ahead, 1.32 BPM @ 4030 PSI FS, RIW=14.8K, BHP=4244, WHP=228 20:27 21:12 0.75 9,775 9,775 PROD1 DRILL WPRT P Wiper to window,WOB=32K. 21:12 22:54 1.70 9,775 9,925 PROD1 DRILL DRLG P Drill Ahead, 1.32 BPM @ 3955 PSI FS, RIW=12.9K, BHP=4121, WHP=230 22:54 23:48 0.90 9,925 9,925 PROD1 DRILL WPRT P Wiper to window,WOB=33K, log GR tie-in+1'correction. 23:48 00:00 0.20 9,925 9,939 PROD1 DRILL DRLG P Drill Ahead, 1.31 BPM @ 3955 PSI FS, RIW=14.0K, BHP=4137, WHP=320 05/02/2013 Continue to drill L1 lateral with BHA#6 RSM drilling assembly from 9,939'to 10,825'with 150'wiper trips pumping sweeps as needed, pump in new mud system @ 10,675'. Drilling in progress. 00:00 02:06 2.10 9,939 10,075 PROD1 DRILL DRLG P Drill Ahead, 1.31 BPM @ 3955 PSI FS, RIW=14.0K, BHP=4168, WHP=238 02:06 03:00 0.90 10,075 10,075 PROD1 DRILL WPRT P Wiper trip,WOB=32K, mini mad pass 03:00 05:45 2.75 10,075 10,225 PROD1 DRILL DRLG P Drill Ahead, 1.30 BPM @ 4030 PSI FS, RIW=12.5K, BHP=4195, WHP=238 05:45 06:30 0.75 10,225 10,225 PROD1 DRILL WPRT P Wiper trip to 9550', PUW=32K 06:30 08:36 2.10 10,225 10,375 PROD1 DRILL DRLG P 10225 Drill Ahead, 1.3 BPM @ 4030 PSi FS, BHP=4310,WHP=250PSI 08:36 09:48 1.20 10,375 10,375 PROD1 DRILL WPRT P Wiper trip to window with tie in, Pumped 5 x 5 Sweeps, PUW=33K, Correct+1', Clean trip up and down 09:48 13:12 3.40 10,375 10,525 PROD1 DRILL DRLG P 10375', Drill ahead, 1.3 BPM @ 3990 PSI FS, BHP=4220,WHP=240 13:12 14:06 0.90 10,525 10,525 PROD1 DRILL WPRT P Wiper trip to 9550, PUW=34K, Clean trip up and down 14:06 18:18 4.20 10,525 10,675 PROD1 DRILL DRLG P 10525, Drill ahead, 1.3 BPM @ 4000 PSI FS,WHP=150, BHP4213 18:18 19:33 1.25 10,675 10,675 PROD1 DRILL WPRT P Wiper trip to 9550, PUW=34K 19:33 23:33 4.00 10,675 10,825 PROD1 DRILL DRLG P Drill Ahead, 1.31 BPM @ 4102 PSI FS, RIW=12.3K, BHP=4283, WHP=223, New mud at bit. 23:33 00:00 0.45 10,825 10,825 PROD1 DRILL WPRT P Start wiper trip to 9,550, PUW=33k 05/03/2013 Continue to drill L1 lateral with BHA#6 RSM drilling assembly from 10,825'to 11,575'with 150'wiper trips pumping sweeps as needed,drilling in progress. 00:00 01:30 1.50 10,825 10,825 PROD1 DRILL WPRT P Continue wiper trip to 8,970', RBIH, saw btm of window, log GR tie-in 0' correction. 01:30 05:06 3.60 10,825 10,975 PROD1 DRILL DRLG P Drill Ahead, 1.31 BPM @ 4105 PSI FS, RIW=12.7K, BHP=4267, WHP=208 05:06 06:30 1.40 10,975 10,975 PROD1 DRILL WPRT P Wiper trip to 9,550', PUW=33K 06:30 09:30 3.00 10,975 11,125 PROD1 DRILL DRLG P 10975', Drill ahead, 1.3 BPM @ 4040 PSI FS, BHP=4245 09:30 10:30 1.00 11,125 11,125 PROD1 DRILL WPRT P Wiper to 10,000, PUW=32K Page 5 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 13:18 2.80 11,125 11,275 PROD1 DRILL DRLG P 11125'Drill Ahead 1.3 BPM @ 4090 PSI FS, BHP=4242,WHP=220, RIW=13K 13:18 15:30 2.20 11,275 11,275 PROD1 DRILL WPRT P Wiper trip with tie in for no correction, PUW=35K,Clean trip up and down 15:30 18:45 3.25 11,275 11,425 PROD1 DRILL DRLG P 11275', Drill Ahead, 1.3 BPM @ 4060 PSI FS, BHP=4290, WHP=170, BHA wiper @ 11,383', pulled heavy off btm 38K. 18:45 19:39 0.90 11,425 11,425 PROD1 DRILL WPRT P Wiper trip to 9,550', PUW=35K 19:39 23:39 4.00 11,425 11,575 PROD1 DRILL DRLG P Drill Ahead, 1.30 BPM @ 4115 PSI FS, RIW=12.0K, BHP=4329, WHP=115 23:39 00:00 0.35 11,575 11,575 PROD1 DRILL WPRT P Start wiper trip to 9,550', PUW=33K 05/04/2013 Continue to drill L1 lateral with BHA#6 RSM drilling assembly from 11,575'to 12,124'with 150'wiper trips pumping sweeps as needed,drilling in progress. 00:00 01:42 1.70 11,575 11,575 PROD1 DRILL WPRT P Continue wiper trip to 9,550', PUW=33 01:42 10:42 9.00 11,575 11,725 PROD1 DRILL DRLG P Drill Ahead, 1.30 BPM @ 4142 PSI FS, RIW=12.0K, BHP=4311, WHP=110, Ratty drilling 11690 to 11718. multiple stalls and BHA wipers. Pumped drum of drill zone into suction pit with no difference 10:42 13:12 2.50 11,725 11,725 PROD1 DRILL WPRT P Wiper trip to window with tie in for-.5' correction, PUW=43K clean trip up and down 13:12 17:00 3.80 11,725 11,875 PROD1 DRILL DRLG P 11725', Drill ahead, 1.27 BPM @ 4150 PSI FS, BHP=4350, RIW=9K, DHWOB=2K 17:00 18:18 1.30 11,875 11,875 PROD1 DRILL WPRT P 11875',Wiper to 10K, PUW=34K 18:18 20:42 2.40 11,875 12,025 PROD1 DRILL DRLG P 11875', Drill Ahead 1.27 BPM @ 4100 PSI FS, BHP=4355 20:42 21:48 1.10 12,025 12,025 PROD1 DRILL WPRT P Wiper trip to 10K, PUW=34K,Clean trip out and in 21:48 00:00 2.20 12,025 12,124 PROD1 DRILL DRLG P 12025', Drill Ahead 1,29 BPM @ 4100 PSI FS, BHP=4360 05/05/2013 Continue to drill L1 lateral with BHA#6 RSM drilling assembly from 12,124'to 12,262', unable to maintain sufficient build with RSM.TOOH LD BHA#6, PD BHA#7 low bend motor assembly.Continue to drill lateral from 12,262'to 12,565',with 150'wiper trips pumping sweeps as needed, pump in new mud system#3 @ 12,175'. Drilling in progress. 00:00 00:57 0.95 12,124 12,175 PROD1 DRILL DRLG P Drill Ahead 1.28 BPM @ 4218 PSI FS, BHP=4454 pumped to/hi vis sweeps. 00:57 03:45 2.80 12,175 12,175 PROD1 DRILL WPRT P Wrip trip to window, PUW=35K. RBIH, pump in new mud system. 03:45 05:15 1.50 12,175 12,262 PROD1 DRILL DRLG P Drill Ahead 1.31 BPM @ 4275 PSI FS, BHP=4365, RIW=10.7K, WHP=170,WOB=1.40. Decision made to TOOH, not able to achieve sufficient build. 05:15 09:00 3.75 12,262 64 PROD1 DRILL TRIP T TOOH w/BHA#6 Page 6 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:00 1.00 64 64 PROD1 DRILL PULD T PUD/LD BHA#6 10:00 11:00 1.00 64 64 PROD1 WHDBO BOPE T Function test BOPE,check Stripper. 11:00 12:00 1.00 64 64 PROD1 DRILL PULD T PJSM, PU/PD BHA#7 12:00 16:30 4.50 64 12,262 PROD1 DRILL TRIP T RIH w/BHA#7 low bend motor assembly 16:30 19:45 3.25 12,262 12,415 PROD1 DRILL DRLG P Drill Ahead 1.31 BPM @ 3950 PSI FS, BHP=4407, RIW=9.8K, WHP=198,WOB=1.70. 19:45 21:09 1.40 12,415 12,415 PROD1 DRILL WPRT P Wiper trip to 11,050, PUW=37K 21:09 23:45 2.60 12,415 12,565 PROD1 DRILL DRLG P Drill Ahead 1.31 BPM @ 4190 PSI FS, BHP=4450, RIW=9.8K, WHP=225,WOB=1.46 23:45 00:00 0.25 12,565 12,565 PROD1 DRILL WPRT P Start wiper trip to 11,050, PUW=36K 05/06/2013 Continue to drill L1 lateral with BHA#7 drilling assembly from 12,565'to 13,115'with 150'wiper trips, pumping sweeps as needed,started losing returns 30-40 bph @ 12,737',started making 100'wiper trips and BHA wipers,drilling in progress. 00:00 01:09 1.15 12,565 12,565 PROD1 DRILL WPRT P Continue wiper trip to 11,050', PUW=36K, RBIH. 01:09 03:54 2.75 12,565 12,715 PROD1 DRILL DRLG P Drill Ahead 1.31 BPM @ 4140 PSI FS, BHP=4397, RIW=9.4K, WHP=132,WOB=1.10 03:54 05:36 1.70 12,715 9,290 PROD1 DRILL WPRT P Wiper trip to 9290', PUW=37K. 05:36 05:42 0.10 9,290 9,315 PROD1 DRILL WPRT P Log GR tie-in; +3.5'correction. 05:42 07:24 1.70 9,315 12,718 PROD1 DRILL WPRT P RBIH 07:24 07:42 0.30 12,718 12,730 PROD1 DRILL DRLG P Drill ahead pumping 1.29-bpm; 4095-psi CTP;4350-psi BHP; 1k# WOB. 07:42 09:36 1.90 12,735 12,805 PROD1 DRILL DRLG P Begin incurring losses 30-40 bph. ROP drop of to 5-6 fph. Choke at 15%to maintain Ann pressure. ROP back to 60-fph at depth 12,745'. 09:36 09:54 0.30 12,805 12,355 PROD1 DRILL WPRT P Pull a wiper trip in attempt to curb losses. 37k#PUW. 09:54 10:12 0.30 12,355 12,805 PROD1 DRILL WPRT P RBIH. Set down 12730'running back in. No change in losses. 10:12 11:18 1.10 12,805 12,865 PROD1 DRILL DRLG P Drill ahead pumping 1.29-bpm; 0.55-bpm returns;4175-psi CTP; 4391-psi BHP;279-psi WHP; 1k# WOB. 11:18 13:18 2.00 12,865 9,550 PROD1 DRILL WPRT P Wiper trip#1 to build. 44k#PUW. Losses back to zero. 13:18 15:18 2.00 9,550 12,865 PROD1 DRILL WPRT P RBIH. 15:18 16:06 0.80 12,865 12,920 PROD1 DRILL DRLG P Drill ahead pumping 1.29-bpm; 0.9-bpm returns;4150-psi CTP; 4389-psi BHP;206-psi WHP; 1k# WOB. 16:06 16:18 0.20 12,920 12,920 PROD1 DRILL WPRT P BHA Wiper. PU 70':39k#PUW. Page 7 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:18 18:33 2.25 12,920 13,015 PROD1 DRILL DRLG P Drill ahead pumping 1.30-bpm; 0.63-bpm returns;4265-psi CTP; 4410-psi BHP;271-psi WHP; 1.45k# WOB. Still losing fluid returns at same rate. Made to short BHA wiper trips.GEO wants 105 deg inc. 18:33 21:09 2.60 13,015 13,015 PROD1 DRILL WPRT P Wiper trip to 9981', PUW=37K, able to get 1:1 returns above 11050'on each wiper trip. 21:09 23:09 2.00 13,015 13,115 PROD1 DRILL DRLG P Drill ahead pumping 1.30-bpm; 0.62-bpm returns;4270-psi CTP; 4416-psi BHP;233-psi WHP; 1.3 WOB. Made one BHA wiper trip, pump sweep ahead of next wiper trip. 23:09 00:00 0.85 13,115 13,115 PROD1 DRILL WPRT P Start wiper trip to above window, PUW=35K. 05/07/2013 Continue to drill L1 lateral with BHA#7 drilling assembly to called TD @ 13,306. POOH for long wiper trip to swab, RBIH for corrected TD depth, unable to get to tag depth,stack weight @ 13,239. POOH laying in beaded liner pill. 00:00 03:00 3.00 13,115 13,115 PROD1 DRILL WPRT P Continue wiper trip to 9,250', PUW=35K, log tie-in for+3.5' correction, RBIH. 03:00 04:00 1.00 13,115 13,165 PROD1 DRILL DRLG P Drill ahead pumping 1.30-bpm; 0.64-bpm returns;4220-psi CTP; 4436-psi BHP; 342-psi WHP; 1.57 WOB,pump sweep ahead of next wiper trip. 04:00 04:06 0.10 13,165 13,165 PROD1 DRILL WPRT P Short wiper. 36k#PUW. Pull up 50'. 04:06 05:30 1.40 13,165 13,215 PROD1 DRILL DRLG P Drill ahead pumping 1.30-bpm; 0.62-bpm returns;4230-psi CTP; 4449-psi BHP; 338-psi WHP;2.3k# WOB. 05:30 06:30 1.00 13,215 10,500 PROD1 DRILL WPRT P Wiper trip#1. 35.5k#PUW. Recover 1:1 returns above 11,000'. 06:30 08:00 1.50 10,500 13,215 PROD1 DRILL WPRT P RBIH 08:00 09:06 1.10 13,215 13,268 PROD1 DRILL DRLG P Drill ahead pumping 1.30-bpm; 0.62-bpm returns;4320-psi CTP; 4445-psi BHP; 335-psi WHP; 1.7k# WOB. 09:06 09:12 0.10 13,268 13,268 PROD1 DRILL WPRT P Short wiper. 38k#PUW. Pull up 50'. 09:12 11:30 2.31 13,268 13,306 PROD1 DRILL DRLG P Drill ahead pumping 1.31-bpm; 0.65-bpm returns;4165-psi CTP; 4451-psi BHP;332-psi WHP; 0.7k# WOB. Slow drilling,TD called @ 13306' 11:30 15:30 4.00 13,306 80 PROD1 DRILL WPRT P Wiper up to get back to 1:1,send 10 x 10 sweep. 12,280'close to 1:1 returns,get sweep at bit,chase up to swabs. Not much solids to surface. Page 8 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 19:45 4.25 80 9,320 PROD1 DRILL WPRT P IRIH, pumping.6 BPM,Tie-i to K1, plus 8'correction,continue in hole, Baker MWD depth counter issues @ 11,255, resolve counter issues. PUH to re-log RA, plus 26.5'correction 19:45 22:27 2.70 9,320 13,239 PROD1 DRILL TRIP P RBIH,start stacking weight, PU,try again several times, unable to get past 13,239',wait on liner pill. 22:27 23:59 1.54 13,239 9,550 PROD1 DRILL TRIP P POOH laying beaded liner pill, paint EOP flag @ 11,200',coontinue OOH. 05/08/2013 POOH laying in liner pill, performed flow check, minimal flow, shut in well and monitor wellhead pressure, after 40 minutes wellhead pressure 15 psi. Decision made from town to lay in another liner pill, RBIH to 9,250', maintain hole fill,total hole fill volume 7.8 bbls, continue waiting on new mud from Prudhoe. 9,550 62 PROD1 DRILL TRIP T Continue POOH laying liner pill, paint EOP flag @ 7,400',continue OOH. 00:00 01:45 1.75 62 62 COMPZ CASING OWFF P On surface,check well for flow, appear to be flow, shut in and monitor wellhead psi,wellhead psi 15 psi after 40 minutes,check well for flow,flow rate decreasing. Decision made to RBIH to window. 01:45 05:15 3.50 62 9,100 COMPZ CASING TRIP T RIH @ 60 FPM,start loosing fluid @ 5000'. Slow down RIH to 36 FPM. Stop @ 8608' ,shut in&monitor. 3687 BHP on MWD.WHP @ 0 but came up to 31 psi in short order. TVD @ this depth is 5310'.Watch for 5 minutes, BHP 3683 psi,WHP 29. RIH 05:15 05:30 0.25 9,100 9,194 COMPZ CASING DLOG T Tie in for a-5 correction, 05:30 05:45 0.25 9,194 9,250 COMPZ CASING OWFF T Continue down to just above window @ 9250'Stop&shut in.WHP 2 psi, BHP 4084 psi.After 15 minutes WHP 22 psi, BHP 4061 psi 05:45 06:30 0.75 9,250 9,250 COMPZ CASING CIRC T @ 9250' Begin circulating @.30 BPM. 13.1 heavy in; 12.7 coming out initiinally but switched to 13.1 after a couple bbls. Pump 12.8 bbls, 7.8 bbls returned. 06:30 12:00 5.50 9,250 9,250 COMPZ CASING OWFF T Shut down pump&Shut in.WHP @ 24 psi after 5 minutes. Open choke to bleed to 0.monitor.WHP @ 5 psi after 30 minutes.WHP to zero, BHP falling slowly.Wait on word from town. 12:00 13:00 1.00 9,250 9,250 COMPZ CASING OWFF T Check needle valve on lubicator,well on a strong vac.Circulate @.3 BPM,get returns after 3 bbls.Shut down&monitor. 13:00 00:00 11.00 9,250 9,250 COMPZ CASING OWFF T Final decession made to circulate well with new 13.1. Monitor well,wait on fluid.Open choke,fill hole with 4.8 bbls @ 21:30, continue to wait on new mud. Page 9 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/09/2013 24 hr Summary Continue monitoring hole fill. RBIH to corrected TD @ 13,308'. POOH laying in new 13.1 liner pill to surface, paint EOP flags @ 10,100; and 6,200'. Monitor well for flow, initial flow ended. LD BHA#7, PU/MU liner assembly, PU BHA#8,start in hole with liner assembly. 00:00 03:27 3.45 9,250 9,250 COMPZ CASING OWFF T Continue waiting on new mud from Prudhoe, maintain hole fill,pumped 6 bbls @ 01:30. 03:27 05:15 1.80 9,250 9,250 COMPZ CASING OWFF T Load pit#7 with new mud,fill hole 5.8 bbls,add beads for liner pill. PUW=33K. 05:15 08:30 3.25 9,250 13,308 COMPZ CASING TRIP T RBIH slowly, send liner running pill down coil. Pumping @.25 BPM, timing to have pill at bit on BTM.Tag BTM @ 13,308' 08:30 14:15 5.75 13,308 69 COMPZ CASING CIRC T @ 13308'.starting laying in liner running pill,with minimal returns at first. Returns increased while PUH. 40 bbls of pill, lay in 13.1 from window to surface. 14:15 16:15 2.00 69 72 COMPZ CASING OWFF T Tag up. Flow check.Watch for 20 minutes, no flow through whitety on lubicator.A consistant trickle in the pits. Shut in&watch for build up. No build up, open well and monitor for flow, no flow. 16:15 18:12 1.95 72 72 COMPZ CASING PULD P PJSM. LD BHA#7, prep to run liner, valve and equipment checklist 18:12 23:12 5.00 72 2,938 COMPZ CASING PUTB P PJSM. PU/MU Liner, Deploment sleeve,93 jts liner, bull nose.MU BHA#8,surface test,stab on. 23:12 00:00 0.80 2,938 3,147 COMPZ CASING TRIP P Start in hole with liner assembly 05/10/2013 RIH w/BHA#8 L1 lateral assembly to 13,112', release off of liner,top of liner @ 10218'. POOH and PUD BHA#8, PD BHA#9, RIH w/anchored billet assembly to 10,218', set achored billet,top of billet @ 10,206'. POOH and PUD BHA#9.Start full BOPE test. 00:00 03:00 3.00 3,147 13,106 COMPZ CASING TRIP P Continue in hole with liner assembly to 13,106', PUW=47K @ 13,094', RBIH to 13,106', bring pump online, pump off liner, PUW=36K. 03:00 03:30 0.50 13,106 9,250 COMPZ CASING TRIP P TOHtowindow 03:30 05:00 1.50 9,250 9,250 COMPZ CASING CIRC P Circulate out KWF 05:00 07:30 2.50 9,250 0 COMPZ CASING TRIP P TOOH to surface continue swap to 10.1 flow pro. 07:30 09:30 2.00 0 0 COMPZ CASING PULD P PJSM. PUD BHA#8 09:30 10:30 1.00 0 72 COMPZ CASING PULD P PJSM. PD BHA#9 10:30 13:15 2.75 72 9,130 COMPZ CASING RUNL P RIH W/Anchoed billet BHA EDC open, pumping .3 BPM with 1: 1 returns 13:15 13:22 0.13 9,130 9,194 COMPZ CASING DLOG P Tie in 9130'to 9194'for a-7 correction.shut EDC, Pick up wt 32k. Page 10 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:22 14:14 0.88 9,194 10,218 COMPZ CASING RUNL P RIH to not seeing liner @ 10212'. , RIH to 10215'. PUH, Retry,stack 1.24 WOB @ 10218'. Pull up to neural wt,WOB to.77.On line down coil,see WOB @ 1.24 with coil stroked out,set anchor,shear off. Stack 3k on Anchor. 14:14 16:59 2.75 10,218 61 COMPZ CASING TRIP P TOOH. 16:59 19:35 2.60 61 0 COMPZ CASING PULD P PJSM. PUD BHA#9, break-off injector, crew change,valve checklist. Unload PDL. 19:35 22:35 3.00 0 0 PROD2 WHDBO RURD P Pull checks, install nozzle and stab on,flush&grease tree. PT inner reel valve and pack-off. 22:35 23:58 1.39 0 0 PROD2 WHDBO BOPE P Start full BOPE test. 05/11/2013 Complete bi-weekly BOPE test. PU/MU BHA#10 and PD same. RIH w/milling assembly to 10,208'time mill anchored billet to 10,216'. Drill ahead L1-02 lateral to 10,430'. Start OOH for RSM assembly. 00:00 08:30 8.50 0 0 PROD2 WHDBO BOPE P Continue full BOPE test,250/4,500 psi,annular 2,500 psi.AOGCC waived witness by Bob Noble. 08:30 09:00 0.50 0 0 PROD2 WHDBO BOPE P BOPE test complete. RD down BOPE equip. 09:00 11:30 2.50 0 72 PROD2 STK PULD P PJSM. PD drilling BHA 11:30 14:15 2.75 72 10,208 PROD2 STK TRIP P RIH,tie in for a-7 correction. Dry tag billet @ 10208' 14:15 17:45 3.50 10,208 10,216 PROD2 STK KOST P Kick off billet per procedure. PUH to prep for time milling,time as per procedure. pumping @ 1.30 bpm @ 3945 psi, BHP=4125 psi, DHWOB=.5K ROP=1 PUW=35K.At 10,211'start milling @ 15'fph to 10,216'. 17:45 18:15 0.50 10,216 10,240 PROD2 DRILL DRLG P Drilling ahead, pumping 1.30 bpm @ 4115. BHP 4,200 psi, DHWOB=1K, ROP=63. PUW=33.5K, PUH,dry drift billet, RBIH. 18:15 21:30 3.25 10,240 10,360 PROD2 DRILL DRLG P Continue drilling ahead, pump rate 1.30 bpm @ 4081, BHP 4219 psi, DHWOB=1K, ROP=40. Had diffculty getting tools to drop 21:30 23:00 1.50 10,360 10,360 PROD2 DRILL WPRT P Wiper trip to window, PUW=36K, RBIH. 23:00 00:00 1.00 10,360 10,426 PROD2 DRILL DRLG P Drilling ahead, pump rate 1.35 bpm @ 4171, BHP 4225 psi, DHWOB=.7K, ROP=65. 05/12/2013 TOOH w/BHA#10 and PUD, PD BHA#11, RIH w/RSM drilling assembly. Drill L1-02 lateral from 10,430'to 10,880'with 150'wiper trips, pumping sweeps as needed,drilling in progress. 00:00 00:06 0.10 10,426 10,430 PROD2 DRILL DRLG P Drilling ahead, pump rate 1.35 bpm @ 4171, BHP 4225 psi, DHWOB=.7K, ROP=65. PUW=37K, POOH for RSM assembly.Chase sweep OOH. Page 11 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:06 05:15 5.15 10,430 59 PROD2 DRILL TRIP P TOOH w/BHA#10, plugged off choke three seperate times, RBIH to 2,000',till solids in returns decreased,continue OOH. 05:15 08:15 3.00 59 0 PROD2 DRILL PULD P PJSM. PUD BHA#10. 08:15 09:15 1.00 0 68 PROD2 DRILL PULD P PJSM. PD BHA#11 09:15 12:15 3.00 68 10,430 PROD2 DRILL TRIP P RIH,tie in for-9'correction, RIH to 10430' 12:15 14:15 2.00 10,430 10,580 PROD2 DRILL DRLG P Drill ahead 1.33 BPM 4186 psi,4239 BHP. ROP 60 14:15 15:15 1.00 10,580 10,580 PROD2 DRILL WPRT P Wiper,35k. 850'wiper. 15:15 17:15 2.00 10,580 10,730 PROD2 DRILL DRLG P Drill ahead, 1.31 BPM @ 4092 psi, 4190 psi BHP, 100'ROP 17:15 18:15 1.00 10,730 10,730 PROD2 DRILL WPRT P 850'wiper,37k off BTM. RBIH. 18:15 22:15 4.00 10,730 10,880 PROD2 DRILL DRLG P Drill ahead, 1.31 BPM @ 4254 psi, BHP 4273 psi, DHWOB=1.1K, ROP=40 22:15 00:00 1.75 10,880 10,880 PROD2 DRILL WPRT P Wiper to window, saw 1K WOB through billet, log RA marker, +3.5' correction, RBIH. 05/13/2013 Drill L1-02 lateral from 10,880'to 11,681'with 150'wiper trips, pumping sweeps as needed,pumped new mud system 9.7ppg heavy Power Pro,drilling in progress. 00:00 00:30 0.50 10,880 10,880 PROD2 DRILL WPRT P Continue RBIH, start pumping new mud system, 9.7 Power Pro. 00:30 03:30 3.00 10,880 11,030 PROD2 DRILL DRLG P Drilling ahead: 1.50 bpm @ 3995 psi, BHP 4250 psi,WHP=455, DHWOB=1K, ROP=60 03:30 05:15 1.75 11,030 11,030 PROD2 DRILL WPRT P Wiper trip to 9,550'to establish choke setting at window, PUW=38K. RBIH,will use choke setting for drilling operations. 05:15 07:00 1.75 11,030 11,180 PROD2 DRILL DRLG P Drill ahead 07:00 08:15 1.25 11,180 11,180 PROD2 DRILL WPRT P Wiper up,850'to 10330' 08:15 09:45 1.50 11,180 11,330 PROD2 DRILL DRLG P Drill ahead, 1.5 BPM 4200 psi,WHP 400 psi,4245 BHP, 93 ROP. 09:45 11:00 1.25 11,330 9,290 PROD2 DRILL WPRT P Wiper,37k off BTM,full wiper&tie in.Arrive @ 9460', slow down to 5 FPM,target inteq annular to 4115 psi.Get dialed in @ 4118 psi W/390 psi WHP. Tie in for a+3.5' 11:00 12:00 1.00 9,290 11,330 PROD2 DRILL WPRT P RBIH to BTM. 12:00 13:30 1.50 11,330 11,428 PROD2 DRILL DRLG P Drill ahead 1.5 BPM @ 4200 psi, maintain 400 WHP 13:30 15:15 1.75 11,428 11,480 PROD2 DRILL DRLG P @ 11428'. not getting good weight transfer, pull 50'BHA wiper, Run back to BTM,same thing.Over pull to 45k,came free. Pull wiper up to 11200', RBIH,drill ahead,stall @ 11436',pick up, continue drilling send 5 x 5 sweep down. Drill to 11480' 15:15 16:30 1.25 11,480 11,480 PROD2 DRILL WPRT P @ 11480'Wiper up, 36k off BTM, 850'to get sweep out of the hole. Page 12 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 20:03 3.55 11,480 11,630 PROD2 DRILL DRLG P Drill ahead 1.49 BPM @ 4250 psi, 405 WHP,4256 BHP 20:03 20:45 0.70 11,630 11,630 PROD2 DRILL WPRT P Wiper trip to 10,500', PUW=39, RBIH. 20:45 00:00 3.25 11,630 11,681 PROD2 DRILL DRLG P Drill ahead 1.49 bpm @ 4175 psi, BHP 4265 psi,WHP 385 psi, DHWOB=.6K, ROP=40. Stacked weight several times, poor ROP, made two BHA wiper trips, decide to pump 5 barrel slick pill, better drilling. 05/14/2013 Drill L1-02 lateral from 11,681'to 12,419 with 150'wiper trips, pumping sweeps as needed. 00:00 01:12 1.20 11,681 11,780 PROD2 DRILL DRLG P Drill ahead 1.49 bpm @ 4124 psi, BHP 4295 psi,WHP 410 psi, DHWOB=.6K, ROP=60.Add half percent lubricant(776)to mud system to improve drilling, better ROP. 01:12 04:42 3.50 11,780 11,780 PROD2 DRILL WPRT P Wiper to 9,250'for tie-in, PUW=35.5K, RBIH. 04:42 06:15 1.55 11,780 11,930 PROD2 DRILL DRLG P Drill ahead 1.48 bpm @ 4295 psi, BHP 4305 psi,WHP 415 psi, DHWOB=I.4K, ROP=90. 06:15 07:45 1.50 11,930 11,930 PROD2 DRILL WPRT P Wiper,40k off BTM,short wiper. 07:45 10:00 2.25 11,930 12,080 PROD2 DRILL DRLG P Drill ahead 1.49 BPM @ 4255 psi, 390 WHP. Started out good drilling, slowed for bit. Picked back up again. Send 5 X 5 sweep down to time out for the wiper. 10:00 11:07 1.13 12,080 12,080 PROD2 DRILL WPRT P Wiper,clean pick up,37.5k off BTM. sweep is at the bit. 11:07 12:30 1.39 12,080 12,230 PROD2 DRILL DRLG P Drill ahead 1.49 BPM 395 WHP, 4349 BHP 12:30 15:30 3.00 12,230 12,230 PROD2 DRILL WPRT P 12,230'Long wiper to window&tie in. +4' 15:30 17:00 1.50 12,230 12,380 PROD2 DRILL DRLG P Drill ahead, 1.45 BPM @ 4350 psi, 365 WHP,4339 BHP.Swap to new mud; new mud hit the bit @ 12308' 17:00 18:30 1.50 12,380 12,380 PROD2 DRILL WPRT P Wiper,850'to 11,500. Erratic PU wgt,40K. 18:30 19:48 1.30 12,380 12,419 PROD2 DRILL DRLG P Resume drilling. 1.7 WOB, 1.5 BPM, 4351 Ann,WHP=400 psi, PU WGTS=41K. 19:48 20:18 0.50 12,419 12,419 PROD2 DRILL DRLG P Attempt to make it back to bottom, hvy PU,45K. Continue OOH. 20:18 21:18 1.00 12,419 9,312 PROD2 DRILL WPRT P Pump 5/5 sweep. Sweep around, P/U wgt is a little improved,38K. WHP=450 psi. Increase LUBES to 2.8%. 21:18 23:48 2.50 9,312 11,850 PROD2 DRILL WPRT P PUH to window @ 40'/min. Slow speed to 5'.WHP=387 psi. RBIH. Pumping 1.4 bpm,CTP=3400 psi, RIW=8.6. RIW getting ratty again from--11,500 to 12000'. Drop rate to 1.11 bpm. No WOB.Stack out at 12,385. Heavy PUW,40-48K Page 13of18 it Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 23:48 23:59 0.19 11,850 12,419 PROD2 Drop rate to 1.1 BPM and RBIH 50'/min. RIW=8K. 12,419 PROD2 05/15/2013 Drilled ahead to 12544',pulled heavy off bottom.Worked pipe to 12458'; stuck. Pumped sweeps, layed in lube pill,then tried mineral oil pill. Finally able to free pipe with hole full of mineral oil.Wiper to surface; ran back in hole to lay in completion fluid. 00:00 01:00 1.00 12,419 12,485 PROD2 DRILL DRLG P Drill ahead. Check PU Wgt=37k. Continue drilling. 1.4 bpm, CTP=3800,WHTP=380 psi. 01:00 02:00 1.00 12,485 12,485 PROD2 DRILL DRLG T Stack wgt. PUH and attempt to make it back into hole,stack out again.Attempt 3 times, PUs 37-39K. Fourth attempt, PU sticky.Work pipe to 12,458.Stuck.Attempt to free by moving pipe, no good. Relax pipe to neutral wgt,40K and pump hi/low pill,followed by slick pill. Rate=1.6 bpm, CTP=4100, WGT=42K. 02:00 03:00 1.00 12,485 12,544 PROD2 DRILL DRLG T Slick pill spotted around BHA; let soak for 20 mins.Attempt to move pipe slowly up, no good. RIH to 15K, pick up and pop free. Pull steady out of hole. Note: lubricants seem to be be the issue;wgts cleaned up previously while RIH to cont drilling ahead with the addition of—1%776. 03:00 05:30 2.50 12,544 12,544 PROD2 DRILL DRLG P Run back in hole 40'/min. RIW=9K, Pump=1.4 bpm, CTP=3670 psi, Ann=4328,WHP=465.Tag up at 12483 and drilling ahead.TD well at 12650. 05:30 06:15 0.75 12,522 12,522 PROD2 DRILL DRLG T Shut down pumps. let sit for 20 minutes. BHP down to 4070 psi. Pull up to 60k, no movement. 06:15 07:00 0.75 12,522 12,522 PROD2 DRILL DRLG T Pump 10 bbl lube pill,spot 5 bbls around BHA. Shut down pumps, BHP @ 4073 psi.2 pulls up to 60k, no good. 07:00 09:30 2.50 12,522 12,522 PROD2 DRILL DRLG T Pump 7 bbls of LBT pill,spot around BHA. Shut down pumps, let sit for 40 minutes.4075 BHP,yard on pipe, no movement.Stop pulling on pipe, let sit some more. 09:30 12:15 2.75 12,522 12,522 PROD2 DRILL DRLG T Get LBT shipped out here from kic; load up 21 bbls in the pits. 12:15 14:15 2.00 12,522 12,522 PROD2 DRILL DRLG T Send 10 bbls lo vis sweep down coil. Pump pressure high, .75 bpm @ 4200 psi. Pump pressure slowlt decreasing.Get to 1.49 bpm @ 4200 psi. Kick up rate to 1.60 BPM @ 4300 psi pushing sweep thru bit& up. Line up LBT down the coil, pump 21 bbls spot in the open hole. Page 14 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 14:45 0.50 12,522 12,522 PROD2 DRILL DRLG T 15 bbls spotted in open up to window. Shut down pumps, let sit 30 minutes, Pulled free @ 51k. 14:45 16:00 1.25 12,522 12,520 PROD2 DRILL WPRT P 11900'. RBIH, coil pressure up to 4400, might be packing off, PUH, Wipe up. Unload LBT at surface,get pump&return rates dialed in. @ 11400', RBIH to 12520' 16:00 20:30 4.50 12,520 0 PROD2 DRILL WPRT P Turn around @ 12520,39k pick up. start wiper to the swabs. 20:30 23:30 3.00 0 11,000 PROD2 DRILL WPRT P At surface; RBIH.At 11000'at midnight, pumping 1.4 bpm, CTP=3400 psi, RIW=12.5K, WHTP=470 psi, 313, OA=584.Cont. in hole. Perform tie-in at marker=-8. 05/16/2013 Ran 94 jts of liner to 12522'. Pumped off and pulled to window to displace well to 9.7ppg PowerPro. Pulled to surface and undeployed liner running BHA. 00:00 01:30 1.50 11,000 11,600 COMPZ CASING WPRT P Cont. RIH to 12522'. Erratic wgts down to 2-4k; pull off bottom for wgt check,erratic swinging fro 42-47K. Call Eng to discuss. Have plan, discuss with Driller and DD. 01:30 03:00 1.50 11,600 12,522 PROD2 CASING WPRT P Rate 1.4 bpm, 3634 CTP, WHTP=520,WGT=38K. RBIH; RIW=11 K.Add drum of lube to active system. Start 38 bbl liner pill down CT. 03:00 07:30 4.50 12,522 68 PROD2 CASING WPRT P On bottom, 12522', 2 bbls of pill out of nozzle. POOH 40'/min,wgt looks good-41K, cont OOH pumping 0.44 bpm, return rate 0.22 bpm. CT press=1685.WHP=700. 07:30 08:00 0.50 68 68 PROD2 CASING SFTY P Flow Check, PJSM for BHA LD. 08:00 09:15 1.25 68 0 PROD2 CASING PULD P LD Drilling BHA#11, prep for liner. 09:15 12:00 2.75 0 2,910 COMPZ CASING PUTB P PJSM, Start picking up liner.94 jts. 12:00 13:45 1.75 2,910 2,955 COMPZ CASING PULD P Pick BHI tools. move cart back over well head&make up. 13:45 16:45 3.00 2,955 12,522 COMPZ CASING TRIP P RIH w/Liner pumping @ minimum rate 13.1 mud. Correct to window flag @ 6200'.-13'correction. CRIH,TD flag looked ok. RIH to 12522', 1.78 WOB.On line with pump, 1.25 BPM, pick off, 34k-2.98 WOB. PUH 100', RBIH,WOB stayed at negative, surface weight was 10k more, liner set. 16:45 17:15 0.50 12,522 9,235 COMPZ CASING TRIP P TRIP out to above the window. Correct depth to 9234.81' 17:15 19:45 2.50 9,235 9,235 COMPZ CASING CIRC P Swap well back to power pro 9.8 ppg. Pump spacer, prior tt... 19:45 21:45 2.00 9,235 0 COMPZ CASING TRIP P POOH 21:45 22:00 0.25 0 0 COMPZ CASING SFTY P PJSM-Undeploying liner running BHA 22:00 23:30 1.50 0 0 COMPZ CASING PULD P Undeploy BHA Page 15 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 23:45 0.25 0 0 COMPZ CASING SFTY P PJSM-Deploy Billet BHA 23:45 00:00 0.25 0 0 COMPZ CASING PULD P Deploy AL-01 anchored billet 05/17/2013 Deployed anchored billet. RIH and set on top of liner leaving the TOB at 9602'. POOH, undeployed setting BHA. M/U and deployed drilling/kickoff BHA#14. RIH and Kicked off of billet.drill AL-01 lateral 00:00 01:00 1.00 0 0 COMPZ CASING PULD P Continue deploying billet BHA. 01:00 03:30 2.50 0 9,170 COMPZ CASING TRIP P RIH with billet 03:30 03:45 0.25 9,170 9,202 COMPZ CASING DLOG P Tie into the K1 marker correction of- 3.5ft. Close EDC 03:45 04:15 0.50 9,202 9,614 COMPZ CASING TRIP P Continue RIH with anchored billet. 04:15 04:30 0.25 9,614 9,614 COMPZ CASING TRIP P Tag TOL at 9614ft. Set TOB at 9602' 04:30 06:45 2.25 9,614 0 COMPZ CASING TRIP P POOH 06:45 09:00 2.25 0 0 COMPZ CASING PULD P PJSM. PUD BHA#13,service injector. 09:00 09:30 0.50 0 0 COMPZ CASING BOPE P PJSM.function test BOPE 09:30 11:00 1.50 0 72 PROD3 STK PULD P PJSM. PD BHA#14 11:00 13:45 2.75 72 9,602 PROD3 STK TRIP P RIH,tie in for-10'correction.Tag TOB @ 9602' 13:45 16:00 2.25 9,602 9,610 PROD3 STK KOST P Pumps on, 1.42 BPM @ 3829 PSI F. Spin. Ease down time drill billet 16:00 18:24 2.40 9,610 9,760 PROD3 DRILL DRLG P Drill ahead, 1.45 4028 psi, 77 ROP, 4132 BHP,drill to 9650', PUH thru billet, clean. RBIH, Drill ahead 18:24 18:39 0.25 9,760 9,615 PROD3 DRILL WPRT P 9760'-wiper up hole to 9615'. PUW 33k. 18:39 18:54 0.25 9,615 9,760 PROD3 DRILL WPRT P RBIH RIW 11.5k 18:54 21:12 2.30 9,760 9,910 PROD3 DRILL DRLG P BOBD-1.43bpm at 4000psi. BHP 4158,WHP 392, IA 291,OA 546 21:12 21:42 0.50 9,910 9,615 PROD3 DRILL WPRT P 9910'-wiper up hole to 9615'. 21:42 22:00 0.30 9,615 9,910 PROD3 DRILL WPRT P 9615'-wiper back in hole RIW 11k 22:00 00:00 2.00 9,910 9,963 PROD3 DRILL DRLG P BOBD-1.44bpm at 4000psi. BHP 4156,WHP 326. IA 332, OA 554 05/18/2013 Drill L1-01 lateral as per plan to TD 10751'. Perform wiper to the swab valves.TBIH,tie into the K1 -9' correction,and continue in hole to confirm TD. POOH displacing well to 13.1 ppg. 00:00 01:45 1.75 9,963 10,060 PROD3 DRILL DRLG P Contine drilling ahead from 9963'. 01:45 02:30 0.75 10,060 9,290 PROD3 DRILL WPRT P Wiper up hole. PUW 36k 02:30 02:45 0.25 9,290 9,312 PROD3 DRILL DLOG P Tie into the RA marker correction of +1.5' 02:45 03:15 0.50 9,312 10,060 PROD3 DRILL WPRT P Wiper back in hole. RIW 12k 03:15 04:30 1.25 10,060 10,210 PROD3 DRILL DRLG P BOBD-1.46bpm at 4000psi, BHP 4165,WHP 332. IA 344, OA 562 04:30 05:00 0.50 10,210 9,615 PROD3 DRILL WPRT P 10210'-wiper up hole. PUW 36 05:00 05:30 0.50 9,615 10,210 PROD3 DRILL WPRT P 9615'wiper back in hole. RIW 05:30 06:30 1.00 10,210 10,360 PROD3 DRILL DRLG P BOBD-1.46bpm at 3930psi, BHP 4191,WHP 344, IA 387, OA 564. 06:30 07:30 1.00 10,360 10,360 PROD3 DRILL WPRT P 10360'-Wiper up hole. PUW Page 16 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:45 1.25 10,360 10,510 PROD3 DRILL DRLG P Drill ahead 1.41 4280 psi,400 WHP 4259 BHP. 08:45 09:25 0.68 10,510 9,295 PROD3 DRILL WPRT P 10,510'-Wiper up hole. PUW. 09:25 09:55 0.50 9,295 10,510 PROD3 DRILL WPRT P 9,295'-Wiper back in hole. RIW. 09:55 12:10 2.25 10,510 10,660 PROD3 DRILL DRLG P Drill ahead. 1.42 bpm 4239 bhp 12:10 12:55 0.75 10,660 9,700 PROD3 DRILL WPRT P 10,660'-Wiper up hole. PUW. 12:55 13:22 0.45 9,700 10,660 PROD3 DRILL WPRT P 9,700'-Wiper back in hole. RIW. 13:22 15:07 1.75 10,660 10,750 PROD3 DRILL DRLG P Drill ahead. 1.42 bpm 329 whp 4,159 bhp 15:07 15:29 0.38 10,750 10,750 PROD3 DRILL WPRT P @ TD-10,750. Pumping 10/10 Lo/Hi Vis Sweep pill while reciprocating pipe. 1.47 bpm 4,142 bhp 311 whp 15:29 17:59 2.50 10,750 72 PROD3 DRILL WPRT P Wiper to the swab. 17:59 19:59 2.00 72 9,155 PROD3 DRILL WPRT P RBIH 19:59 20:14 0.25 9,155 9,165 PROD3 DRILL DLOG P Tie into the K1 corrrection of-9' 20:14 20:59 0.75 9,165 10,750 PROD3 DRILL WPRT P Continue RIH RIW 15k 20:59 23:59 3.00 10,750 0 PROD3 DRILL TRIP P Confirm TD 10751'. PUW 37k. POOH laying in 13.1ppg liner pill with beads and without beads to surface. 05/19/2013 Finished wiper to the swab valves. RBIH and confirmed TD 10751'. Layed in 13.1 ppg completion fluid with beads up to above window. Displaced well to 13.1 ppg. Flow check,M/U 57 jts slotted liner with shorty beployment sleeve. Ran liner in hole and released on bottom. Displaced well to sea water and freeze protected well from 2500'to surface with diesel. Fllushed surface lines with fresh water. Set BPV. 00:00 00:30 0.50 0 0 PROD3 DRILL SFTY P Check well for flow,conduct PJSM- L/D drilling BHA. 00:30 01:30 1.00 0 0 PROD3 DRILL PULD P L/D drilling BHA. 01:30 02:00 0.50 0 0 COMPZ CASING SFTY P Conduct PJSM-M/U liner assy. 02:00 04:15 2.25 0 1,824 COMPZ CASING PUTB P Start M/U 57jts 2-3/8"slotted liner. 04:15 07:00 2.75 1,824 10,750 COMPZ CASING RUNL P TIH BHA#15, L1-01 liner competion. 57 jts 2-3/8"slotted liner 1 pup jt Shorty deployment sleeve Correct to flag-9.7'.Tag up @ 10750' PU WT. @ 43k.Set liner back down @ 10750'. Pump off, 34k PU WT. Page 17 of 18 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:00 2.00 10,750 8,958 COMPZ CASING CIRC P PUH to above window.Subtract liner from counter. Park at 8958'. Seawater loaded in the pits.Water is smelly(H2s) sniff pits @ 8 ppm. Start pumping seawater down coil recovering 13.1 KWF. Pump @.5 BPM seeing losses on micro motion .10 a minutes. a loss of a bbl every 10 minutes. Back rate down to.3, still loosing the same, back up to.5 BPM. 09:00 10:30 1.50 8,958 3,677 COMPZ CASING TRIP P Get seawater out of the bit&20 bbls ahead up back side. Start POOH @ 80 FPM pumping 1.5 BPM. 10:30 12:15 1.75 3,677 0 COMPZ CASING TRIP P Conduct PJSM W/LRS. Rig up LRS pump.On line with diesel down coil @ 1.5 BPM,displace water out of the coil, get diesel ahead, POOH. Pump 28 bbls of diesel in coil. Rig LRS down. Chase diesel with fresh water, continue freeze protect to surface. 12:15 14:00 1.75 0 0 COMPZ CASING PULD P PJSM. PUD BHA#15. 14:00 16:15 2.25 0 0 DEMOB WHDBO NUND P PJSM.Flush coil,jet stack. Blow down the coil with rig air. 16:15 16:30 0.25 0 0 DEMOB WHDBO SFTY P PJSM-Setting BPV 16:30 17:00 0.50 0 0 DEMOB WHDBO NUND P Load FMC lubricator into rig. M/U and P/T 17:00 17:30 0.50 0 0 DEMOB WHDBO NUND P Set BPV 17:30 18:00 0.50 0 0 DEMOB WHDBO NUND P R/D Lubricator and load out of rig. 18:00 21:00 3.00 0 0 DEMOB WHDBO NUND P RDMO 0 0 DEMOB 21:00-21:00-21:00-21:00-21:00 -21:00 xxxxxxxxxxxx RIG RELEASE xxxxxxxxxxxx Page 18 of 18 2F-18 Post-Rig Well Work Summary • DATE SUMMARY 5/26/2013 BRUSHED AND DRIFTED TBG TO WHIPSTOCK @ 8971' RKB. MEASURED BHP @ 8965' RKB: 3871 PSI. SET CATCHER SUB ON WHIPSTOCK. PULLED DV @ 8896' RKB AND REPLACED WITH 0.25" PORT OV. IN PROGRESS. 5/27/2013 PULLED DVs FROM GLMs 4, 3, 2 AND 1. INSTALLED NEW GLVs. DRAW DOWN IA, CONFIRMED INTEGRITY. PULLED CATCHER SUB FROM 8940' SLM. COMPLETE. III II Z W `M2 gX N Q 1 C i CZ O O. Q W 0 z a s •- 4, CO a .0 ._ 0 a ° 0) w O kJ O ' a N •- E N C t- r C 0 N 0 c � F. : d) may= U 00 N /w O n, n. � c CO i V N N I C4 I 43 =OO 7 C co - N N d CO , :ThO d R C)13 0 ^ co O O co O O en G N N k p rn C c v m [V N N- CO d W W m Lc, Y-, (n 0 i @ bi O o O .$ N co 3 ... N 0 O 0 0 O 0 2 N N O N N N y 1 d fn 0 01 VI 1 d J n 7 O « c OI 7 1 c o , a _ N. a Co i` o ( ��H ii 0) a r r r a N N 00 p0 I m m `5 m 1' I 0 Y ro 0 w 3 rn m N O O E Q — W 0 N d T. c c a a . j c 0 2 d I CO LO) v m N N r`- 2 W m y ? m m in to d N 3 d d O U 0 `O J d V T >. 0 0 2 2 H 00. d Cn > 0) Z f) c • c oL m t 00 U) C ` m o r d U N C) Fn T w d ?Lt-3- c o c rn cn tn CO m ui O 0 °' N 3 '2); v m 0 0 d I > a (.1 I E F aL a d m € .'c+. U U a 4) C O • m 0 dm c d 0 0 r a E CC n m j N C O Z 0 �J ~ r 2 W 2 i+ C . O 0. 0.FO O O aL oL I 4 m .0 E y 0 , .0 N E z u L N T (n N d d I Y4 R a M co O d i d p. N c E 0 _ fn V CO a ao .i o { IL- ! Q E N N .O R l6 r' v CL 3 z `O Li' Y L N Z .� LL V N d O O N, O X 0 O o o ,_ T T C O W U o O O ' N d N T (D J J c 117 z Z ■C> 00 CI i,� _ L O M ` m co o co Y C ,c,`,,, d R 3 Li LL LL LL N : U ° 0 CO N N N N Q d C Q 0 a > m Z d E N S'. m o � ' a c o Ll Y d N N Z N J 0 O C) .w L 2e N 2 (6 a' d co u) y O O (D Q i�i� a U N LL Z W O (J LL O F� N N O r L 1 O d f0 a� c0 W Z Q N T. + N rL CO N r O > > Li LL LL U Y Y N N N .. c € 0 E E p 1 i E 0 c 0 v c •+ d E :, m d d o 0 0 CI 0. E ei 0 d a I LL o 0 0 0 c d N c •N c - c E O O W N O 2 T R O c d O O 0)a y _ La y y 0 N _ a F l a c rn +• a d�J o .. _ n o a a E d N - a N r Z a` 3 3 o a ° 3 o a' > in m a Likil 0110 co O IM 0) 0 0 C N O CO C a 0 < F OY O i DC a E i co Z 0 q 0 I- r, M V V V V V V V V V Cr Cr Cr Cr V Cr V Cr V V O Cr V V V Cr V Cr V V m CO 2222 22222 22222 22222 222 22 22222 2 CO CO O IO r O- O m N 0 `r 0) 1� 0 CO ti M CO O CO) M CO 0- C OO) O O r O N CO CO h r N r N N O N M fl C N CI O CO C O r O V C) oi O M 6 of of o O V co co O o O CO 0 N CD CO O N •V CO CO 'Cr CO 0) N CO CO Cr N- 0 C) O • V 0 O O ,- .- .- s- N N N N N C) C C) C) C') V V V V co co o co co CO r A I- O 0 CO CO O CO O CO O CO CO O CO co O O CO CO CO O CO CO CO CO CO O CO O O 0 CO CO CO CO CO CO co CO 0 > O• (/) LL LL x N N O a = 0 V V CO O r CO N O O CO M M ti V O 0 CO CO O N m CO ti A V 8 V m CO V N O O O C Q CC n O O Cy N O V V V V O V Cr CO CO O r V V Cr V O C) V O [O O . J N CO CO O 6 0 CO v N 11 [ N 0 Q) Q N CO V C) N O N .- 0 O CO Cr V h 0- CO O ' CO C• O 0 O Is- CO CO N CO m CO E N7 m N N O m m m CO O CO m V 0 CO C� o CO 0 0 C) r V n O Cal 0: CO 'C r t0 O (O O m Oi O t0 0 CC m N- m O QQ O C) O CO O (O O O CV C) O LL LL C1 C) C) CO Ch C) C) N N O 0 m CO O O cco O co co CO U) CO O co CO 1- O) N N F W CD i CO CO CO CO CO CO CO CO CO CO Co O CO CO O CO O CO O CO 0 O CO O 10 O CO CO CO CO CO CO R N t OS m CO CO CO CO CO m m m aD co- m m co- CO CO CO m CO m co- CO co- o0 CO co- CO m 6. O co co O O O O O O O O O O O O O O O c0 O O O O CO O O O CO O O W F 8 u '0 N .- CO CO r CO CO Cr V n c0 0 V O r O N CO s- r 0 0 C m O 0 N O) Z Q C O m O 0 3 0 0 m O n O N I` C) m m CO (- O 0 1-- s- O) O I- CO V O O 00 n CO w CO c() N N CO tac) O m N. UOO N OM) CO O CO 0 A R N O m CO O I` Cr O CCO CO O .- N 0 ' 0 >+ w 0 C N N N '- ' 0 p 0 0 0 0 O) m CO CO CO N- h I- A CO CO CO cq O O CO V Cr S' 1 2 0 T OV) cn OV) Off) Off) a) OV) 0 OV) T or a) a) g a) W Cr OV) cn OV) on a Cr m OV) OV) Cr cn W OV) r N O Z O 1[i t co- U) b U) )[i ui ui )[i 15 ui h U) U) CO CO Ici CO )[i Ici t t CO i 1(i CO i CO i of U) to C C) ' C CC (U _ > 'C C ii OI U & C O C C) V 2 N O V CO CO 0 O CO m N V CO CO N CC O CO CO CO n 01 O O V Cr C) CO m 0,1 Q C) DC CO N Cr C) 0 m 0- O CO O N 0) a CO CO O CO m CO CO N O V N N- N CO f Y N (-1 K m ,C re 0 .0 0 0 0 0 0 00) OO) CO C NO 1N- CCO CO O CO CO O CO CO CO CO N CO O 0 CCO 003 CO ff CO co O IC 0 Zi >0 r m o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 COJ > 0 0 0 D W — ,- •- .- .- ,- .- ,- ,- .- •- ,- ,- ,- .- s- ,- .- ,- •• - - - - - - - .- co O V r O V co co co r- co m . .- co co O co O O O O O co Cl N S N O 0 m ' O O O CO C) co co CO O .- CO O O co r CO V CO O m co N- CO O O Cr CO N 0 0 I- CO CO 01 IV 0 0 0 O O O) N- V N- N O r to V O CO V V I- O O CO O CO C 8 O M CO O IO N O m O) O CO O O N V 8 O — C x — C C (9 W W W S' (9 C9 C9 W W W (4 Si W Si W W W W c' W W ' R R Ni- R R CO O O O 0) 0 0 CO CO C) O O CO CD V V co O N- CO CO V r 01 'c' N- m 1` 0 CO CCD CO O O O O .- O V . V O N 0 O CO CO O ' I- C O N) -. (/) 1- N- O CO Oi N 1- C`) 0) r 1- 0) C) CO CO O N M V CO 6 m N V CO n 0) O Cr) O O O 0 CO r 0- CO CO O CO CO O CO CO CO ti N. I- r N- n A CO CO CO CO CO CO Cn 0 = O 0 0) O O O O O 0) 0) O O 0) 0) O CD O O O O O O O O O O O) 0) 0) 0) O O O 0 O O co" O O of O O O O O O O co" O CO of 1f1 O. b O O co" O o N V_ 1- M O CO N Cr O_ O O_ O 0 CO CO CO O O CO CO Cr V CO 0 1s- CO CO V 0- a co 1- 0 CO CO CO O CO IC) O O V Cr CO N O CO C) CO O r C') O CC) 0 C) 01 V N O CC) 0 1- U') CO o.: V t0 CO O ." of R CO A 0) 0 N N N N N Y 0 C) co co N N 0 0 O 0, 0 O 0 0 O U CO O CD CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO c.. C U N 0 = CO Cr O N I- V Cr CO N O 0 r 0 N CO CO N CO O N Cr CO V Ch O N O V. N O C n h O O O O O CO 1n CO CO n U) CO CO V O m N V ,- 0 O 0 N O .- O m N c0 O CO O O G of m V O O N CO V O O 1- V Oi Q Q N 0 0 N^ CO CO m r m room 0 0 moo N O m o o m n n coo O O co V V C) co co C)- i 0. a 01 /L 0 Y -,e ) �p _ OU ` ` 1- O N O m 0 s- 0 O Cr CO O C) m N O V CO O 4 O O O COD N V N t08•• O. d O7 m m V m I- CO I- Cr N 0- m t` O CO CO I- m V CO C) N 0•o co es O •Oi •b •Oi •N C) CD •1- •CO CO •M •N •10 •O • •I- 0- •0 CO •CO •CO CO I` •CO •I- r o U Y Y N N N C ....... m CD 0 0 O O O 0 0 0 ar m m m m m CO m m m m CO CO CO CO m CO CO CO CO O r r r 0 O CO 0 N CO 0 m 0 m CO 0 CO O N 0 O 0 N C) V n 01 CO CO 01 0 O O O (O O cn r V r O CO f•) V Cr N- Cr V CO C) m CO CO CO N N m r O> m CO m m 0 or O N O O O O O 0 0 O O O O 0 N C 0 O O O O 0 0 O O O O co CO 0 C) CO m N O CO V r 0 CO CO O N O CO c- Cr C- O CO CO 0 N O CO QV C C• .. N 0 v O CO CO CO CO 1- I- N- CO CO CO m m 0 0 O O O N N N N CO CO CO V 0 O O t] O C >. E -" m CC Oi 0) m m of m of 0 of co' O m of 0 0 O O 0 0 0 O O 0 0 0 0 0 0 d N .Z) CS) N r r r r .- r r r ~O U ao .�. m m a v U d CO 'S O N • ■ 1 -o Oa CO 0 0 C N O V) M Q O Z i C 0 ri 0 E 0 ca I— Z 2 )- 0 o w I— I— W V Q C R R R V R vr & fl) 2222 22222 0- S GAD O u' O 0 O 8 N C09 C) 0 - V CD 0) M CO CO N. O co ;C U .�' A GO m co co 0) 0) 0) O) O m a0 a) a) —co l0 fo co O t0 Co co co r- ; ] N li Ll X a a `X `C +7.. 'C '' ti 841 c00 n ti O to N 8 O C z R N r r r 0 0 r O c0 GO m 0 ro co co U Y N CO 03 N 0 N O M r b O N := ru LL CL 3 — 0 6c1 A V co N N O r O co n I c' 0 F cG W L i=� n A A A co co co 0 0 01 G) N C co- GD co- co- CD GD co- CD m es �y 2 W 7) lA .7 Z) 1A , N LL� re; 1n V -L W o F Q C) .. p c B N V 8 10' m 83 N n Z ° N w p) O co 0 0) co C- N co O (n �' w C) [1 c co V a R co 0_ co a) at cao- co_ co_m a) E au 0 m rn rn co or or or or rn w m . i. Z 1n 1° 1n 1n LC) CO vi 1n 1l) m ils 3 ai u =° a1 c ei c I j 'a c u a u m Y o a m a • Q R 0 t N N 3 $ O N ' N N co co co.A V V C 00> m J F E Z co 0 W �" .- • • .- r CIO) V 0 0OD n COO CCOO a- N N .- N. 0 N N CO N N N Z x N.: N- N. n n N- ^ N. N. n + O co tmo co CD CO L CO CCO CCD CO N Ni O LC; CO r n CO v 1 co Q 0 00) O) 00) 00) 0 00) 0) 00) 00) — 10 10 10 10 co CO CO co V7 to 1 N ) [1 0 CO 0 CO i O 000 0 W. c0 c0 O, 0 0 I Q CO 0 CO CO CO m CO ccoo N Cl N ak ti 3; 1- c m co co co aD CO co m m CD cn Y p N 2 01 M O A GD O V O A A C N .-" N N ,- ,- •- O O O 0 O) U) = CO n d a in a Y Y °u O co 2 m m m M - m 1A0 N N Ca ch O 7 7 lL 7 I, C) ^ I, ri ri r m o O M a V U Y Y N N N , c G-. co co c0 c0 c0 c0 m rn rn DC O. I n. O QQ 0 V CO CO C CD CO N LI1 CO C p co 0 O co 0 0 0 0 0 0 0 0 0 0 co C C CC V 10 n h LL�'1 m C m of 0 — 0 0 0 0 0 0 0 0 0 0 a u ° c m o L) y _ a s ` N C O ;Si. v a) y v 0 it co 3 3 o CO N _ _ V ®�M® BAKER PRINT DISTRIBUTION LI S S T HuGHEs ii 3 - CI,' - zz6, -w COMPANY ConocoPhillips,Alaska Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 2F-18L1; 2F-18L1-01; 2F-18L1-02 RUN NUMBER (mandatory) FIELD Kuparuk BH SALESMAN Anyanwu,Okechukwu(OKEY) (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: TODAYS DATE:7 6/6/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: ConocoPhillips,Alaska Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? I COMPANY CD FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Or NHIN I S #OF COPIES #OF COPIES ` 4 4 4 4 4 4 1 ConocoPhillips Alaska,Inc. I I 1 I I I I I NSK Wells Aide,NSK 69 ATTN:MAIL ROOM 700 G Street, Anchorage,AK 99501 2 AOGCC I 1 I 1 I I I I Christine Mahnken 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 1 3BP I I 1 I 1 I I I I Petrotechnical Data Center,MB33 David Douglas 900 East Benson Blvd Anchorage,Alaska 99508 4 Chevron/KRU REP I I 1 I 1 I I I I Glenn Fredrick 3800 Center Point Drive,Suite 100 Anchorage,Alaska 99503 5 Brandon Tucker,NRT I I 1 I I I I State of Alaska;DNR,Div.of Oil and Gas 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501-3510 TOTALS FOR THIS PAGE: 0 A to 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 0 RECEIVED MAY 2 82013 Letter of Transmittal Ma II AOGCC 13 - 053 BAKER Date: May 24 2013 HUGHES f�7 . To: From: • Christine Mahnken Carl Ulrich/Michael Soper AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Anchorage,Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2F-18L1 <St 2F-18L1-01 2.t3-17 6 2F-18L1-02 2k3-063 D/W. tf/r P-f,6( al3 (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27)= 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of re ail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper @BakerHughes.com Carl.Ulrich, Baker Hughes, Survey Manager Carl.Ulrich @BakerHughes.com oF ,9t".`"\\ 1////,.4.s, THE STATE Alaska Oil and Gas ALASKA. Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF"�nm �P Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Lamar Gantt CT Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F-18L1-01 ConocoPhillips Alaska, Inc. Permit No: 213-053 (revised) Surface Location: 275' FNL, 1713' FEL, SEC. 33, T11N, R9E, UM Bottomhole Location: 2040' FNL, 671' FEL, SEC. 4, T1ON, R9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated April 19, 2013. The permit is for a new wellbore segment of existing well KRU 2F-18L1, Permit No 196-178, API 50-029-22720-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P oerster Chair DATED this/5 a y of May, 2013. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 10 2013 PERMIT TO DRILL ' 20 AAC 25.005 RE._1.SSt�F - 5//%0/3 A0G00 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil Q• Service-Winj ❑ Single Zone 2/ 1c.Specify if well is proposed for: Drill ❑ • Lateral El Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket• U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 . 2F-18L1-01 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10300'. TVDSS: 5979'• Kuparuk River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:275'FNL, 1713'FEL,Sec.33,T11 N, R9E, UM • ADL 25657,25666 • Kuparuk River Oil Pool. Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1300'FNL,617'FEL,Sec.4,T1ON,R9E, UM 2583,2587 5/13/2013 • Total Depth: 9.Acres in Property: 14.Distance to 2040'FNL,671'FEL,Sec.4,T1ON,R9E, UM . 5120 • Nearest Property: 2530 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 138 feet 15.Distance to Nearest Well Open Surface:x- 517519 y- 5948608 Zone- 4• GL Elevation above MSL: 92.5 feet to Same Pool: 2F-17,2975 16.Deviated wells: Kickoff depth: •9550 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: ,99° deg, Downhole:4582 psig . Surface:3979 psig . 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 SLT 1352' 8948' 5797' 10300' 5979' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 9715 6385 9350 9588 6270 none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 280 sx AS I 121' 121' Surface 5573' 9.625 330 sx ASLW, 1220 sx 5614' 3161' Intermediate Class G,60 sx AS I Production 9103' 7 130 sx Class G 9142' 5923' Liner 780' 5 137 sx Class G 9715' 6436' Perforation Depth MD(ft): Perforation Depth TVD(ft): 9325'-9335', 9359'-9383' 6086'-6095', 6117'-6138' 20.Attachments: Property Plat❑ BOP Sketch 0 Drilling Program pi ' Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program El ' 20 AAC 25.050 requirements El 21.Verbal Approval: Commission Representative: Date: ic 22. I hereby certify that the foregoing is true and correct. Contact Kai Starck @ 263-4093 Email Kai.Starck @conocop .com Printed Name Lamar Gantt Title CT Drilling Supervisor R Signature . (twilit ( ,(A,t Phone: 265-4021 Date .J/'f// 3 Commission Use Only Permit to Drill API Number: Permit Appr,-' '/y►�7—See cover letter Number: ig i. 3 50-tj 2 7-a q 7 a 0 -(a.( - 0 0 Date: y\\n 1 1 ✓ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbedrm�ethane,gas hydrates,or gas contained in shales: [r Other: 5_0 p 71_ f t0 4 5UG p 5 L Samples req'd: Yes ❑ No L� Mud log req'd: Yes❑ No H2S measures: Yes Er No ❑ Directional svy req'd: Yes El No❑ Spacing exception req'd: Yes ❑ No a Inclination-only svy req'd: Yes El No[✓J' / / AP OV D Y Ti Approved by: • :v IS O E}l?) nr is ON Date: —/S- (3 Form 10-401(Revi -d 10/2012) This permit is valid L4inbn> r t e I to gf eproval(20 AAC 25.005(g)) 1113.\)- C` V1-F 37/li/3 "�� RECEIVED Conoco Phillips MAY 10 2013 p Alaska AO G C Ca P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 17, 2013 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Due to complex faulting in the newly drilled 2F-18L1 lateral (PTD#213-052) ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD)applications to drill and complete 2F-18L1-02 lateral from Kuparuk well 2F-18L1 (PTD#196-178). The original planned 2F-18L1-01 lateral PTD (#213-053)will also need to be modified because the planned TD depth will be more than 500' short of the original plan. Coiled tubing drilling (CTD) operations are currently underway using the Nabors CDR2-AC rig. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. - Drilling program summary(Update for 2F-18L1-01 and 2F-18L1-02 in blue font) - Permit to Drill application forms for 2F-18L1-01 and 2F-18L1-02 - Directional plans for 2F-18L1-01 and 2F-18L1-02 - Current wellbore schematic - Proposed wellbore schematic after CTD operations If you have any questions or require additional information please contact me at my office 907-263-4093. Sincerely, ecl;frtA, Kai Starck ConocoPhillips Alaska Coiled Tubing Drilling Specialist Kuparuk CTD Laterals Na .. Drilling &Wells 2F-18L1 and 2F-18L1-01 and 2F-18L1-02 �j Application for Permit to Drill Document ZAAC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 2 (Requirements of 20 AAC 25.005(c)(6)) 2 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 5 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(6)) 6 Attachment 1: Directional Plans for 2F-18L1-01 and 2F-18L1-02 6 Attachment 2: Current Well Schematic for 2F-18 6 Attachment 3: Proposed Well Schematic for 2F-18 CTD Laterals 6 rr Page 1 of 6 I. "'' ] May 8,2013 PTD Application for t...0 2F-18L1-01 & 2F-18L1-02 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) There are three proposed laterals described in this document: KRU 2F-18L1 and 2F-18L1-01 and 2F-18L1-02. The L1 lateral will be drilled off the motherbore and the L1-01 and the L1-02 laterals will be drilled off the L1 lateral. Both will be classified as"Development-Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The 2F-18L1 lateral is planned to target the Kuparuk A4 sand to south of the existing well. The 2F-18L1-01 and 2F-18L1-02 laterals are planned to target the Kuparuk AS sand to the south of the existing well. See the attached 10-401 forms for surface and subsurface coordinates of each of the 2F-18 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4500 psi. Using a maximum potential formation pressure of 4582 psi, the maximum potential surface pressure is 3979 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The latest 2F-18 SBHP taken 3/30/13 was 4136 psi fora 13.1 EMW from the A4/A5 sands. The pressure has been on a steady decline since shutting in the nearby injectors and we anticipate the 2F-18 formation pressure to be a 12.9 EMW by the time drilling commences in May 2013. Injector 2F-17 to the west, shut in since June 2012, has rrca uu ent BHP of 4041, 12.8 EMW. The closest well is 2F-12 to the north, believed to be isolated from 2F-18 by a fault, with a BHP of 2679, 8.6 EMW. To the west is producer 2F-19, also isolated from 2F-18 by faults, with a BHP of 3824, 12.2 EMW. Injection wells in the area have had higher formation pressures. 2G-12 to the west was as high as 4700(6155' TVD, 14.6 EMW) in the past. Because we will be drilling to the south into an undeveloped area we will assume this to be maximum potential formation pressure. For 2F-18 this equates to a maximum formation pressure of 4582 psi (9268' MD, 6035' TVD). The maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft would be 3979 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled and there has been no gas or MI injection in the area Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 2F-18 laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target of 12.9 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Both of the 2F-18 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Page 2 of 6 May 8, 2013 C o l w t C c u PTD Application for r‘icU 2F-18L1-01 & 2F-18L1-02 New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD 2F-18L1 10,200' 13,550' 6137' 6185' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2F-18L1-01 8948' 10,300' 5797' 5979' 2%", 4.7#, L-80, ST-L slotted liner; Liner Deployment Sleeve on top 2F-18L1-02 9550' 13,850 5797' 5997' 23/", 4.7#, L-80, ST-L slotted liner; Liner Deployment Sleeve on top Existing Casing/Liner Information Weight Top Btm Top Btm Burst Collapse Category OD (PPf) Grade Connection MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 41' 121' 0' 121' Surface 9-5/8 40 L-80 BTC 41' 5614' 0' 3161' 5750 3090 Casing 7" 26 L-80 BTC-MOD 38.5' 9141' 0' 5923' 5410 7240 Liner 5" 18 L-80 LTC-MOD 8935' 9715' 5744' 6298' 9910 10,490 Tubing 3%" 9.3 L-80 EUE8rdMOD 36.8' 8979' 0' 5778' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.9 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.9 ppq). This mud weight alone will not hydrostatically overbalance formation pressure in the 2F-18 motherbore. MPD practices described below will used to maintain overbalance conditions while drilling. — Completion operations: The well will be loaded with 13.1 ppg Potassium Formate completion fluid in order to maintain pressure over-balance while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes(-200 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 2F-18 laterals we will target a constant BHP of 12.9 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Page 3of6 May 8,2013 Via.. e I t L y , L. PTD Application for Ilk. 2F-18L1-01 & 2F-18L1-02 Pressure at the 2F-18L1 Window(9268' MD, 6035' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.9 ppg) 4082 psi 4082 psi Mud Hydrostatic (9.9 ppg) 3107 psi 3107 psi Annular friction (i.e. ECD, 0.095 psi/ft) 880 psi 0 psi Mud + ECD Combined 3987 psi 3107 psi (no choke pressure) (underbalanced (underbalanced 95 psi) 975 psi) at Window(12.9 ppg) 4048 psi 4048 psi Choke Pressure Required to Maintain 61 psi 941 psi arget BHP 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AA C 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 2F-18 was originally completed in 1997 as a A4/A5-sand producer. It remained on production until it began producing sand through casing damage in the A4 interval. Remedial cementing through a cement retainer has plugged off the A4 perforations. The well is currently shut in for the CTD laterals. A mechanical whipstock will be placed in the 5" liner at the planned kickoff point. The 2F-18L1 lateral will exit the 5" liner at 9268' MD and target the A4 sand to the south of the existing well with a 4282' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,550' MD with an aluminum billet at 10,200' MD. The 2F-18L1-02 Lateral will kick off from an aluminum billet at 10,200' MD and will target the A5 sand south of the existing well with a 3650' lateral. The hole will be completed with a 2%' slotted liner to the TD of 13,850' MD with an aluminum billet at 9550' MD. The 2F-18L1-01 lateral will kick off from the aluminum billet at 9550' MD and will target the A5 sand south of the existing well with a 750' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,300' MD with a liner top deployment sleeve at 8970' MD, inside the 3W tubing. Page 4 of 6 (( i� R d t A' I May 8, 2013 PTD Application for r...0 2F-18L1-01 & 2F-18L1-02 Pre-CTD Work 1. MIRU E-line. Set Whipstock @ 9268'oriented 10 ROHS 2. MIRU Coiled tubing unit. Mill 2.75" nipple at 8942'to 2.80" 3. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2F-18L1 Sidetrack(A4 sand, South) a. Mill 2.80"window through 5" liner b. Drill 2.70"x 3" bi-center lateral to TD of 13,550' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 10,200' 3. 2F-18L1-02 lateral (A5 sand, south) a. Kick off of the aluminum billet at 10,200' MD b. Drill 2.70"x 3" bi-center lateral to TD of 13,850' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 9550' 4. 2F-18L1-01 Lateral (A5 sand, south) a. Kick off of the aluminum billet at 9550' MD p7-D 2/3-L 53 b. Drill 2.70"x 3" bi-center lateral to TD of 10,300' MD c. Run 2%" slotted liner with a liner deployment sleeve from TD to ab ve the 3W mule shoe at 8972' ELMD 5. Freeze protect. Set BPV, ND BOPE. 6. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP, Install gas lift valves 3. Put well on production Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Liner Running Page 5 of 6 3 d May 8,2013 PTD Application for KAU 2F-18L1-01 & 2F-18L1-02 — Fluid of sufficient density to over-balance the formation will be used to provide well control. See the "Drilling Fluids" section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — There are no other affected owners — Please see attached directional plans for each lateral. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to nearest property line and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 2F-18L1 02 2850' 2630' 2F-12 2F-18L1-01 01 2530' 2975' 2F-17 2F-18L1-02 01 2530' 2975' 2F-17 Attachment 1: Directional Plans for 2F-18L1-01 and 2F-18L1-02 Attachment 2: Current Well Schematic for 2F-18 Attachment 3: Proposed Well Schematic for 2F-18L1-01 and L1-02 CTD Laterals Page 6 of 6 ¢ ' E �, May 8,2013 m co N 0 co c a a� Ea; (U O 0 E v m Y ti Y Ct N in N Cfl N— CO CD V CD 0 LU C) co - CO g m V d- V Cll • o - m cC a Y Ta U CO -° C) E Qm N C E CO Cll Oil o_Y _ E Q cn O X V 1_,T) u c 6) C CU a) cc 0) E co Y o_ W 0) (V C N > �( C CU (p CO W CO■ cis = (u (u (r 0 09 Y 2 0 m x100 Y O O o O U • J E x* E E E `�' � w CO co c CO O . N m U (ri 0 U 0 cO o° .� = U) N N N N N N CL) a) CD CU Y Y Y C CO C CO CO CO Cll (`) A M M M CJmmm (T CO E N - U) (D c C CU i u)— d CO V U Q cCa III 1I E +L+ "I I" U ii 0 73 iulIiuiuiiiiiUIIi:ij , '4%... s: air- U m 0 o © CO (ll o C) o L cu • L2 co in 0 0 c) 0 Q oc It .- M o 00 -0 (h -0 C) (b c) - co _j 0 C rn c 1C 2i 0 0 © � � inrn CO _ ,— p � NN Lr) L � Lo LL N � vv - .- Q C < CA Cy co m Cow Ca Cr @.1 W ORIGINAL c 2 b N d �np:n 1 c cv po Y Q O a is;a`` 7 N �11 N b V O V W J Q C0 co r.n Lo II N co co N u p J 1 N L p II Q I— 0 0 C_ co m co CO CO to m Y co a) v II in rn o c m � 1 Y 0 D a� aco g p cn 03 a 0 E am co \ c') c E c3 a) CO 0_ �p°n I \I 0 'fl - E !? w O ix Q R ~ u) c4 rn C a`) o Q W -6 N a)© II I I .0 D C N c lJ(0 Li p.c CO W CO = O 009 N I-J I O O O O U 2 \1 J U _ E * E E E N Q W \O 10 B 0 O m U 0) 0 0 0 Q a) C co o — (0 \\ I N N N N (N N N N 0) C Y a) o 1' Y c a) \\ I w (6 C (6 (0 (0 (N N c() ch cc� (0 M mJmmm as A 0 / E N U I' V) X O / cp t C a) N- C1 U Q ✓ E d NI A IN U) II /AI It i .:[_ „ . . .. 0 F U �,I L� Cl) o @J a) N 0 O g Cr) o ' m 0 U") a a) 0 cl_ C � w 0 a) CO aa) —gyp 0 O o Y Iz co o s?(0 - O 00o CO o 00 M -0 0 CO �0a,co -CO 1- N Ja WN V N � Ena) _ k co N �n ch v Lo *k V V N V Q d7 a)" Q W LL V C N - O) N CO O w � m ORIGI 'r,, . ..tL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2F Pad 2F-18 2F-18L1-01 Plan: 2F-18L1-01_wp02 Standard Planning Report 09 May, 2013 BAKER HUGHES no I " d-' ConocoPhillips or its affiliates INS ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-18 @ 138.00ft(2F-18) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2 F-18 L 1-01_w p 02 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2F Pad Site Position: Northing: 5,949,341.82ft Latitude: 70°16'21.978 N From: Map Easting: 517,392.55ft Longitude: 149°51'33.576 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.13 ° Well 2F-18 Well Position +N/-S 0.00 ft Northing: 5,948,607.88 ft Latitude: 70°16'14.756 N +E/-W 0.00 ft Easting: 517,519.05 ft Longitude: 149°51'29.942 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 92.50 ft Welibore 2F-18L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2012 4/30/2013 15.57 79.87 57,347 Design 2F-18L1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,535.24 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) -96.80 0.00 0.00 180.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +El-W Rate Rate Rate TFO (ft) (0) (°) (ft) (ft) (ft) (1100ft) (°1100ft) (°/100ft) (°) Target 9,535.24 91.20 179.24 5,997.90 -6,290.85 1,104.07 0.00 0.00 0.00 0.00 9,550.00 91.06 179.95 5,997.61 -6,305.60 1,104.18 4.90 -0.95 4.81 101.15 9,650.00 99.06 179.95 5,988.79 -6,405.13 1,104.27 8.00 8.00 0.00 0.00 9,900.00 88.80 197.18 5,971.55 -6,650.46 1,067.07 8.00 -4.10 6.89 120.00 10,300.00 88.98 165.18 5,979.48 -7,045.12 1,058.94 8.00 0.05 -8.00 270.00 5/9/2013 8:57:49AM Page 2 COMPASS 2003.16 Build 69 0 R i '0,.: i F4 f b ., L r ConocoPhillips or its affiliates Conoco Phillips Planning Report ` E`R BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-18 @ 138.00ft(2F-18) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2F-18L1-01_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-try Section Rate Azimuth Northing Easting (ft) (0) (°I (ft) (ft) (ft) (ft) (°1100ft) (°1 (ft) (ft) 9,535.24 91.20 179.24 5,997.90 -6,290.85 1,104.07 6,290.85 0.00 0.00 5,942,320.25 518,637.65 TIP 9,550.00 91.06 179.95 5,997.61 -6,305.60 1,104.18 6,305.60 4.90 101.15 5,942,305.49 518,637.79 KOP 9,600.00 95.06 179.95 5,994.94 -6,355.52 1,104.22 6,355.52 8.00 0.00 5,942,255.58 518,637.95 9,650.00 99.06 179.95 5,988.79 -6,405.13 1,104.27 6,405.13 8.00 0.00 5,942,205.97 518,638.11 Start 8 dls 9,700.00 97.04 183.44 5,981.79 -6,454.61 1,102.80 6,454.61 8.00 120.00 5,942,156.50 518,636.76 9,800.00 92.94 190.34 5,973.07 -6,553.42 1,090.84 6,553.42 8.00 120.49 5,942,057.67 518,625.03 9,900.00 88.80 197.18 5,971.55 -6,650.46 1,067.07 6,650.46 8.00 121.09 5,941,960.58 518,601.49 4 10,000.00 88.81 189.18 5,973.63 -6,747.73 1,044.29 6,747.73 8.00 -90.00 5,941,863.27 518,578.94 10,100.00 88.85 181.18 5,975.67 -6,847.22 1,035.27 6,847.22 8.00 -89.83 5,941,763.77 518,570.15 10,200.00 88.91 173.18 5,977.64 -6,947.00 1,040.19 6,947.00 8.00 -89.67 5,941,664.02 518,575.30 10,300.00 88.98 165.18 5,979.48 -7,045.12 1,058.94 7,045.12 8.00 -89.51 5,941,565.95 518,594.28 Planned TD at 10300.00 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2F-18 CTD Polygon(cog 0.00 0.00 0.00 -6,061.01 893.72 5,942,549.57 518,426.78 70°15'15.146 N 149°51'3.946 W -plan misses target center by 5996.58ft at 9800.00ft MD(5973.07 TVD,-6553.42 N,1090.84 E) -Polygon Point 1 0.00 -6,061.01 893.72 5,942,549.57 518,426.78 Point2 0.00 -6,061.81 1,243.75 5,942,549.59 518,776.78 Point3 0.00 -8,010.92 1,205.31 5,940,600.59 518,742.88 Point4 0.00 -10,846.73 993.84 5,937,764.58 518,538.03 Points 0.00 -10,796.85 611.91 5,937,813.56 518,156.02 Point 6 0.00 -8,010.04 820.28 5,940,600.57 518,357.89 Point 7 0.00 -6,061.01 893.72 5,942,549.57 518,426.78 2F-18L1-01_T01(copy) 0.00 0.00 5,973.00 -6,541.49 1,083.62 5,942,069.58 518,617.79 70°15'10.420 N 149°50'58.424 W -plan misses target center by 9.21ft at 9789.06ft MD(5973.68 TVD,-6542.66 N,1092.73 E) -Point 2F-18L1-01_TD 0.00 0.00 5,990.00 -7,054.50 1,070.42 5,941,556.59 518,605.78 70°15'5.374 N 149°50'58.810 W -plan misses target center by 18.18ft at 10300.00ft MD(5979.48 TVD,-7045.12 N,1058.94 E) -Point 2F-18L1_Fault0l(copy) 0.00 0.00 0.00 -7,054.42 1,035.42 5,941,556.59 518,570.78 70°15'5.375 N 149°50'59.828 W -plan misses target center by 5978.60ft at 10189.61ft MD(5977.44 TVD,-6936.67 N,1039.03 E) -Rectangle(sides W370.00 H1.00 D0.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 9,140.00 5,783.31 7" 7 8-1/2 10,300.00 5,979.48 2 3/8" 2-3/8 3 5/9/2013 8:57:49AM Page 3 COMPASS 2003.16 Build 69 n p 1 r I mAl ConocoPhillips or its affiliates Irdi ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-18 @ 138.00ft(2F-18) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2F-18L1-01_wp02 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,535.24 5,997.90 -6,290.85 1,104.07 TIP 9,550.00 5,997.61 -6,305.60 1,104.18 KOP 9,650.00 5,988.79 -6,405.13 1,104.27 Start 8 dls 9,900.00 5,971.55 -6,650.46 1,067.07 4 10,300.00 5,979.48 -7,045.12 1,058.94 Planned TD at 10300.00 5/9/2013 8:57:49AM Page 4 COMPASS 2003.16 Build 69 ICI \ b C ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2F Pad 2F-18 2F-18L1-01 2F-18L1-01_wp02 Travelling Cylinder Report 09 May, 2013 BAKER HUGHES tr.) Dirm • ConocoPhillips or its affiliates Irak ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit TVD Reference: 2F-18 @ 138.00ft(2F-18) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18 @ 138.00ft(2F-18) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp02 Offset TVD Reference: Offset Datum Reference 2F-18L1-01_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,535.24 to 10,300.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,225.88ft Error Surface: Elliptical Conic Survey Tool Program Date 5/9/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 50.00 5,525.00 2F-18 GyroData(2F-18PB1) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 5,550.00 9,250.00 2F-18 GyroData(2F-18) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 9,268.00 9,535.24 2F-18L1(2F-18L1) MWD MWD-Standard 9,535.24 10,300.00 2F-18L1-01_wp02(2F-18L1-01) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') C') 9,140.00 5,921.31 7" 7 8-1/2 10,300.00 6,117.48 23/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2F Pad 2F-17-2F-17L1-2F-17L1_wp02 Out of range 2F-17-2F-17L1-01-2F-17L1-01_wp01 Out of range 2F-17-2F-17L1-02-2F-17L1-02_wp01 Out of range 2F-18-2F-18L1-2F-18L1 9,550.00 9,550.00 0.00 0.70 -0.53 FAIL-Major Risk 2F-18-2F-18L1-02-2F-18L1-02_wp01 9,550.00 9,550.00 0.00 0.70 -0.53 FAIL-Major Risk 2F-19-2F-19-2F-19 Out of range 2F-19-2F-19A-2F-19A Out of range 2F-19-2F-19AL1-2F-19AL1 Out of range 2F-19-2F-19AL2-2F-19AL2 Out of range 2F-19-2F-19AL3-2F-19AL3 Out of range 2F-19-2F-19PB1-2F-19PB1 Out of range 2F-19-2F-19PB2-2F-19PB2 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/9/2013 7:55:31AM QP Page 2 of 5 COMPASS 2003.16 Build 69 1 i s 0� l `64 tL. ConocoPhillips or its affiliates Fg"I ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit ND Reference: 2F-18©138.00ft(2F-18) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18©138.00ft(2F-18) Site Error: O.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp02 Offset ND Reference: Offset Datum Offset Design Kuparuk 2F Pad- 2F-18-2F-18L1-2F-18L1 Offset Site Error: 0.00 ft Survey Program: 50-Copy of GYD-CT-CMS,5550-Copy of GYD-CT-CMS,9268-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 If Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth ON/-S +El-W Hole Size Centre Distance Deviation (0) (ft) (ff) (ft) (ft) (ft) ('I (nj (ft) (ft) (ft) (ft) (ft) 9,550.00 6,135.61 9,550.00 6,135.61 0.32 0.02 143.21 -6,305.60 1,104.18 0.22 0.00 0.70 -0.53 FAIL-Major Risk,CC,ES,SF 9,574.99 6,134.71 9,575.00 8,135.21 0.33 0.06 -28.08 -6,330.60 1,103.95 0.22 0.56 1.07 -0.48 FAIL-Major Risk 9,599.87 6,132.95 9,600.00 6,135.16 0.33 0.10 -22.10 -6,355.59 1,103.32 0.22 2.39 1.45 0.99 Pass-Major Risk 9,624.55 6,130.35 9,625.00 6,135.35 0.33 0.14 -23.59 -6,380.55 1,102.05 0.22 5.49 1.86 3.75 Pass-Major Risk 9,649.00 6,128.95 9,650.00 6,135.54 0.33 0.19 -23.81 -6,405.50 1,100.44 0.22 9.51 2.31 7.43 Pass-Major Risk 9,673.97 6,123.22 9,675.00 6,135.67 0.33 0.24 -19.70 -6,430.46 1,098.98 0.22 13.50 2.80 11.18 Pass-Major Risk 9,699.15 6,119.89 9,700.00 6,135.72 0.33 0.30 -14.28 -6,455.42 1,097.66 022 16.74 3.31 14.18 Pass-Major Risk 9,724.45 6,117.00 9,725.00 6,135.68 0.33 0.35 -9.48 -6,480.36 1,095.92 022 19.42 3.86 18.65 Pass-Major Risk 9,749.77 6,114.56 9,750.00 6,135.97 0.38 0.41 -2.63 -6,505.32 1,094.54 0.22 21.79 4.40 18.77 Pass-Major Risk 9,775.05 6,112.58 9,775.00 6,136.31 0.44 0.47 5.42 -6,530.29 1,093.38 022 23.83 4.99 20.55 Pass-Major Risk 9,80020 6,111.06 9,800.00 6,136.50 0.51 0.54 15.05 -6,555.28 1,092.64 0.22 25.56 5.60 21.99 Pass-Major Risk 9,825.13 6,110.01 9,825.00 8,136.38 0.59 0.62 25.97 -6,580.28 1,092.17 0.22 27.18 6.25 23.18 Pass-Major Risk 9,849.85 6,109.41 9,850.00 6,135.99 0.66 0.70 37.13 -6,605.26 1,091.51 0.22 28.96 6.89 24.06 Pass-Major Risk 9,874.38 6,109.25 9,875.00 6,135.64 0.74 0.78 47.71 -6,630.23 1,090.36 0.22 31.22 7.54 25.39 Pass-Major Risk 9,898.55 6,109.52 9,900.00 6,135.39 0.82 0.86 58.14 5,655.21 1,089.20 0.22 34.32 8.18 27.51 Pass-Major Risk 9,923.64 6,110.04 9,925.00 6,135.05 0.90 0.94 64.09 -6,680.18 1,088.17 022 37.97 8.90 30.16 Pass-Major Risk 9,94927 6,110.58 9,950.00 6,134.86 0.98 1.03 6720 -6,705.14 1,086.77 022 41.29 9.65 32.56 Pass-Major Risk 9,975.32 6,111.12 9,975.00 6,135.03 1.05 1.12 68.09 -6,730.06 1,084-77 022 43.82 10.37 34.29 Pass-Major Risk 10,001.61 6,111.66 10,000.00 6,135.61 1.13 1.21 67.49 -6,754.96 1,082-61 022 45.75 11.10 35.48 Pass-Major Risk 10,028.00 6,11221 10,025.00 6,136.54 121 1.30 66.20 -6,779.89 1,081.05 022 47.62 11.84 36.62 Pass-Major Risk 10,054.50 6,112.75 10,050.00 6,137.63 1.30 1.40 64.21 -6,804.83 1,079.60 022 48.87 12.60 37.17 Pass-Major Risk 10,081.05 6,113.29 10,075.00 6,138.84 1.40 1.50 61.83 -6,829.78 1,078.64 0.22 49.81 13.38 37.41 Pass-Major Risk 10,107.63 6,113.83 10,100.00 6,140.04 1.50 1.61 59.12 -6,854.74 1,078.03 0.22 50.25 14.18 37.16 Pass-Major Risk 10,134.17 6,114.36 10,125.00 6,141.22 1.61 1.72 55.89 -6,879.71 1,077.43 0.22 49.92 15.00 36.18 Pass-Major Risk 10,160.60 6,114.88 10,150.00 6,142.41 1.72 1.83 51.91 -6,904.67 1,076.67 022 48.73 15.80 34.42 Pass-Major Risk 10,186.82 6,115.38 10,175.00 6,143.62 1.83 1.95 47.03 -6,929.62 1,075.70 022 46.71 16.60 31.95 Pass-Major Risk 10,212.69 6,115.88 10,200.00 6,144.98 1.95 2.07 40.70 -6,954.55 1,074.37 022 43.96 17.39 28.96 Pass-Major Risk 10,238.30 6,116.36 10,225.00 6,146.33 2.07 2.19 33.33 5,979.49 1,073.41 022 41.14 18.18 26.13 Pass-Major Risk 10,263.61 6,116.83 10,250.00 6,147.63 220 2.32 24.71 -7,004.45 1,072.82 022 38.39 18.97 23.67 Pass-Major Risk 10,288.45 6,11728 10,275.00 6,148.69 2.32 2.45 13.87 -7,029.41 1,072.00 022 35.50 19.74 21.61 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/9/2013 7:55:31AM Page 3 of 5 COMPASS 2003.16 Build 69 ii �� „. r . ConocoPhillips or its affiliates FA" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit TVD Reference: 2F-18 @ 138.00ft(2F-18) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18 @ 138.00ft(2F-18) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp02 Offset ND Reference: Offset Datum Offset Design Kuparuk 2F Pad- 2F-18-2F-18L1-02-2F-18L1-02_wp01 Offset Site Error: 0.00 ft Survey Program: 50-Copy of GYD-CT-CMS,5550-Copy of GVD-CT-CMS,9268-MWD,10190-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (5) (ft) (ft) lff) (ft) (ft) 9,550.00 6,135.61 9,550.00 6,135.61 0.32 0.02 143.21 -6,305.60 1,104.18 0.22 0.00 0.70 -0.53 FAIL-Major Risk,CC,ES,SF 9,574.99 8,134.71 9,575.00 6,135.21 0.33 0.06 -26.08 -6,330.60 1,103.95 022 0.56 1.07 -0.48 FAIL-Major Risk 9,599.87 6,132.95 9,600.00 6,135.16 0.33 0.10 -22.10 -6,355.59 1,103.32 0.22 2.39 1.45 0.99 Pass-Major Risk 9,624.55 6,130.35 9,625.00 6,135.35 0.33 0.14 -23.59 -6,380.55 1,102.05 0.22 5.49 1.86 3.75 Pass-Major Risk 9,649.00 6,126.95 9,650.00 6,135.54 0.33 0.19 -23.81 -6,405.50 1,100.44 022 9.51 2.30 7.43 Pass-Major Risk 9,673.97 6,123.22 9,675.00 6,135.67 0.33 024 -19.70 -6,430.46 1,098.98 0.22 13.50 2.80 11.18 Pass-Major Risk 9,699.15 6,119.89 9,700.00 6,135.72 0.33 0.30 -14.28 -6,455.42 1,097.66 0.22 16.74 3.32 14.18 Pass-Major Risk 9,724.45 6,117.00 9,725.00 6,135.68 0.33 0.35 -9.48 -8,480.36 1,095.92 0.22 19.42 3.85 16.64 Pass-Major Risk 9,749.77 6,114.56 9,750.00 6,135.97 0.38 0.41 -2.83 -8,505.32 1,094.54 0.22 21.79 4.40 18.77 Pass-Major Risk 9,775.05 6,112.58 9,775.00 6,136.31 0.44 0.47 5.42 -6,530.29 1,093.38 0.22 23.83 4.99 20.55 Pass-Major Risk 9,800.20 6,111.06 9,800.00 6,136.50 0.51 0.54 15.05 -6,555.28 1,092.64 0.22 25.56 5.60 21.99 Pass-Major Risk 9,825.13 6,110.01 9,825.00 6,136.38 0.59 0.62 25.97 -6,580.28 1,092.17 0.22 27.18 6.25 23.18 Pass-Major Risk 9,849.85 6,109.41 9,850.00 6,135.99 0.66 0.70 37.13 -6,605.26 1,091.51 022 28.96 6.89 24.07 Pass-Major Risk 9,874.38 6,109.25 9,875.00 6,135.64 0.74 0.78 47.71 -6,630.23 1,090.36 022 31.22 7.54 25.39 Pass-Major Risk 9,898.55 6,109.52 9,900.00 6,135.39 0.82 0.86 58.14 -6,655.21 1,089.20 022 34.32 8.18 27.52 Pass-Major Risk 9,923.64 6,110.04 9,925.00 8,135.05 0.90 0.94 64.09 -6,680.18 1,088.17 0.22 37.97 8.90 30.16 Pass-Major Risk 9,949.27 6,110.58 9,950.00 6,134.86 0.98 1.03 67.20 -6,705.14 1,086.77 0.22 41.29 9.64 32.56 Pass-Major Risk 9,975.32 6,111.12 9,975.00 6,135.03 1.05 1.12 68.09 -6,730.06 1,084.77 0.22 43.82 10.37 34.29 Pass-Major Risk 10,001.61 6,111.66 10,000.00 6,135.61 1.13 1.21 67.49 -6,754.96 1,082.61 0.22 45.75 11.09 35.48 Pass-Major Risk 10,028.00 6,112.21 10,025.00 6,136.54 121 1.30 6620 -6,779.89 1,081.05 022 47.62 11.84 36.62 Pass-Major Risk 10,054.50 6,112.75 10,050.00 8,137.63 1.30 1.40 64.21 -6,804.83 1,079.60 0.22 48.87 12.59 37.17 Pass-Major Risk 10,081.05 8,113.29 10,075.00 6,138.84 1.40 1.50 61.83 -6,829.78 1,078.64 0.22 49.81 13.37 37.42 Pass-Major Risk 10,107.83 8,113.83 10,100.00 8,140.04 1.50 1.61 59.12 -6,854.74 1,078.03 0.22 50.25 14.17 37.17 Pass-Major Risk 10,134.17 6,114.36 10,125.00 6,141.22 1.61 1.72 55.89 -6,879.71 1,077.43 0.22 49.92 14.99 38.19 Pass-Major Risk 10,160.60 6,114.88 10,150.00 6,142.41 1.72 1.83 51.91 -6,904.67 1,076.67 022 48.73 15.79 34.43 Pass-Major Risk 10,186.82 6,115.38 10,175.00 8,143.62 1.83 1.95 47.03 -6,929.62 1,075.70 022 46.71 16.59 31.96 Pass-Major Risk 10,212.69 6,115.88 10,200.00 6,144.98 1.95 2.06 40.70 -6,954.55 1,074.37 0.22 43.96 17.37 28.97 Pass-Major Risk 10,23824 6,116.36 10,225.00 6,145.92 2.07 2.16 33.44 -6,979.50 1,073.11 022 40.64 18.11 25.68 Pass-Major Risk 10,263.39 6,116.82 10,250.00 6,145.99 2.20 2.26 25.07 -7,004.46 1,071.86 022 36.51 18.82 21.87 Pass-Major Risk 10,288.05 6,117.27 10,275.00 6,145.19 2.32 2.37 14.68 -7,029.42 1,070.61 022 31.79 19.53 17.94 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/9/2013 7:55:31 AM Page 4 of 5 COMPASS 2003.16 Build 69 p��l� (r t c r. 1 ConocoPhillips or its affiliates FAR ConocoPhillips Travelling Cylinder Report B,AICER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit ND Reference: 2F-18 @ 138.00ft(2F-18) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18 @ 138.00ft(2F-18) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp02 Offset ND Reference: Offset Datum Reference Depths are relative to 2F-18 @ 138.00ft(2F-18) Coordinates are relative to:2F-18 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.13° Ladder Plot , I , I 1 60 I ■I 1 1 , 45 1 c j 0 Q 0 J J J J a J U) U) ac) 30 I U I o i a) ' 4-c- a) I I U I 15 I J J J J J I 0 I 0 2000 4000 6000 8000 10000 12000 Measured Depth LEGEND -e- 2F-18,2F-18L1,2F-18L1 VO —+— 2F-18,2F-18L1-02,2F-18L1-02 wp01 VO CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/9/2013 7:55:31AM Page 5 of 5 COMPASS 2003.16 Build 69 0 RI GIN/., ! q ' m' 11/ , 5 5 N o r a '8 n m ^ Q E.. °o n N e o ao n a O a. 'O y. u. '" .'n. Cp I G�C F �G Q .U' Z.', FI ry n 5 1 - a ^ @ w ± 4 FAVA1 11 N N ro n .g udy�cea 0 11 1 N St73n3 ' o `/ p 111' I N s Jai! , ' s3 Q ' n : p N. . N. 4 4 a s a. '.; JN ^ N m N N m c J n O E ao 8 F, - h S i b 8 8 8 8 < C w 3� _ '4 V $ 4 $ R F,' n n 00 m t. (m/U OM(+)g110N/�-)IPaS a O P1 a •-. �n "I t7 Ti m _ '8 o 0 P81 a a e co a c a,S e.'^ to n c 4 , 7 V J °O g 2 =1a ° °oR m IC w • Y Y H ^ "N F a.c .tn 133 o 2 2 m m . n nm.-LL o.ommm r N C yz o 6; .447) 1 E omNOg ' 25.7 #o�°a =4 3: N H . go $ LL `3 ° A F zRLA'42° r E rno I IPA m s L' Awe yaz.T,gnw 2 �n121a 8 VI s ,c7;%,:talmm a0 38 ,�0000� 6 :8" ' e e 6o .0000 Fi O 0 ° m0o lanaiees ueaN 0O +g (U?/13 S£)g1dau Isat aA an.a 1 � , „ I :., i F G 6 L. • N W him wm QZ bill ■■ii■a■■iia/'---iiiii i -\,.•T i t t -a9 9p� _ 1, M s£,U...I■ii.M ewswa■ ,. I flu.. IB _ : :: MU := :ate uq�--■rraiHr-■/$�: o W rn■q-a...afW MMM qMq-AMIB I::m■■-N--q■■■----itl/lu----i■■-�■r-W-w.tli■on ma■■-----0/mma-W tltlm:agowui:sMho ::::mMM::■q-tea O.° CJ ■........................ tlPI Mtl.r..!.r_ MOM---Mn.MqN■■■WNMrrM.N-.\M....MMNr......-N.MEMM ■tl■■qW■■n■ ■■.■■■ • ..tl■■■.-■■n q■■■■/M■■■W••• MMA..■N■■■NW■■.■.M..■8■ N•••••W ...••••••• ---------a----\-n W■.1tlW1.■■M.■■WMl■1 Ntl.■■ ■1W-■ O MIME 11111 ,IIMIE,TAIBRAMINIMULt,-- HWru_.r■.■n.tl.M\■ ■■■■.NI1...■■• •• - ®.- ::::::::::::111111 "1"111111 somergaml.-W M ■ - AA\NW M. 7M.tlN q N Hq ■ ■ .■... . 1 C- o o a-q..r V w m ■ ■.�IIW MW■M.■.■Mnu■ MnugMMq H.M . mw _ :�:ia�$$: ..tl.■. l 1111111111111111111111111 _ i$�:: -T o 0 m ■ ......�W MNHW N.N m■.MM..\.MM ■qM mom ■ 9■BJ/I■.aa■■■■Mr.M■tl■■Wn.-. ■ W -UUW-■-a:m ■: 6 t a L O■'L...W ....M..M..W _.Wpq■■M.■n.■r■tlM/ _ ■■W■ ■g0 ///\r 11111 N■/.M ■ci N m c m I . . .�.....W - ....::/.■q...i t W$ � . �$$$$ � � ■•a � $$ +;-, �-mu ... !Fitt I. I �r. LL P� .$�.. � N. m 1 aaama. :U:::a:UUU:E:UUU:::a::a::::::::a m:•UUUmm.L t aa_ w $..m°. II ■1MA $ ..Wqa.nl.Nn1\-Mq - . .. � - V L M/".■. M _.... ..Wtl■M-g1N1tl.M.B -- ammo- -- - .■ m :. •mm.9gamm■e�■-mN•mmmNn■•nN�a:mrM aaaW ■■_ • C n� .`o I fi...Mmm .■ ./...".n.-■■.MMMM...Mq■r■.....r$.N .■■B. a: o kg y 5 m ■■ .■■\■■1M ■■ qqrWn■ W ■■■ -. -_ � +11111111111 mfr Mm?'U. mm ::m M■■ $$aa:--: -.■ ..■ ..mI $$ g, i O / UU .. a a • :m .B: °. :W:: mbl.._ ::: m �s■!v I: WM ::.:mm: ■ n .r.aM. UU:;-■■■n mm. _ mmom . . - 99M E v ! $ $W_.. $$ . _ p WqW -1 M $ aaUU . •$ �' • u :m $ $$U r •$$ $ U$$ 8$; - q$$�$$$+ $$$•UUU?BIF I - •r .11nr■Mnr -.aA.q.M .:r ■■r■ n.r..NMUNMWAIMM.■.l1WNq■W ■■ HM.■■n . tl -UUM- :aa a: : qmaa- . m: NHr. W-►a8m:Na:.. n. .. amm a:■- E n.......a■ - HN ::aa: ::U ■ aaNNqq U. ----■n� a:mWu .-m �-:mmU :•Um: p Mn M■.-H■■1N:mmM MUM Li m O I I : . SUas ■■■Amtm: a. 8gUm . H:mm a / ■.■ -■■■■M■.■OMrM" i a�...r. . .. �amN . .Mamaa : aa: maaaamaa : mmmUaga: m : aM$$Maaaaaa: a :: . ; aaaa:aa IN N _ J j d i 1 �mmaaa:m::a:m:asa :am::m:aa$::a:a::::a:::UU:mmmaam�m INEMI m:Uaamaam:: :aa�mmaaammaaamammaaEIaaaam:aaamm:aa::ma °° O ' r/M.q.■/HH■■■l./n/tlM■. ■.H■■■W■NHgq■..■-./■■MM■H■■. M.MW■M■r.//MMgM-a i"� W ... a M■MM■■■Ntl.■.■tlM.MUU■Mtl■■M■/-.-MMN■..■..tl■..M■Mq■.■ H■..WM■..M■■■gtl.MNM.■n.■n.tl V C "r I r.Wgr..n...-MN■rW 1...-Hr--M.M-MM-M.-.N-■W-■■aW tl.MW..■.tl.M-tla....1..M.-.■M.H O . ■■N■M■■1M■■.■B_N■-W_N■-.UM!NU■■■M--■WM■M■.■■■=■-W_■■■M_W--■■■■■ WM■.r.---M.q■■--MqM■r■-.MMW!!--MM . 4•_,▪ a I If.._.._--. _---mM $$n11..W:::::':::::::.■■utl„u.•` ■i■.■W■-MaWU-.■.■ WMU.WM$ $-:HHM.-■tlMiiu:M WI .J mmmpmma M.■■■■MM■..■/. �.� a■1■000N:gUUUOam m :mmma■M■-■mm \NBamm/O m: -am o . MM MM.MM■■.M .W•••nn•••W•• Wn.■.rn■r■ ■■■na.■■■glgtl■■ ■ r. $ Hm$m--n.M mm;mm:m$$:am$■.N■$ambalUN.■a::::a.-N -W:ma:aii-::$N`J.$$:NBammgq$l ■rrB O `/ E- s4...: -�_ �/.tlq M aW■■.■-■■M■q N■■.gWMW.■-Mr..--■-W Wn■■■W .MnM..-qME ■.-ptlW'I-- �..' 'U3'U3 qq■M........... ■MM./■W■.■-.-■■MMq■.■.■.. ■ .qM■i^' `• � � ■.q■M■MM--..M .1■1.■.■..W1r1MW Wq/r■W nrlrrgnrrlrr■. ■ y :. qMM■■1 :N:::-am::-q-N........ :q•■•H-•■■-1.aN-:::NN:ma--::mam mamq--tl■ O r3 A 1 MEN a!IMPAIR tl.. ::ee-a:am.s ii..a.— __ . Nmm 1 , =. UU::a aaam U.;....... :maa:a.....ammaa�mammm::::U•U.° ul I. .. o- .., ..■■11117111 ■ Mq■■.M■■...--WM■NW-- _ I-■■n■-■MNM/ggMgq.MH•tl y J911:11111111 _ •..W....U..M........-..Y::�N�-�•• :I I:::Y::an M:m::a0m:uUB:::p-Wf. 0 ■rl..ln /qM\//na-\.■1■■■MW■MHW■. �.8..�1■W■-ngq...NM\■NM■■-qW • i_3 I ■■■■11r..MM ■ i..._- _,-t-M�im....r. .MHn...maam ummaa //MW• -. • -}. . . : + /...W■.■nM m■-mmm..aMU-a■Wtl (it ■ap■t •UUU M./W �U1U1p� U.p//■tlM 1_ m,_ a$ - $$I M0HtlrMSMU-$aia$-W.MCCWM.HW$$ :. :H■t $■W.M:pgpMgM/BN$$N■■$$WW . .: .} $ :::..$ iW$}rY $.■aMW.-�Op �$ 9911 q.UUUU•U $$.N U$ N $UU :M 1 rrgaN.tl $ • .■/M■M■.--■.1..■1.-MMgU■i■-WtlUNin..q-WILT r.l■1.MM■p■-MH■■■rM.l■U■UW_' o 1 mmmms $ __ ■.Mn- . .r■ . . . Mr IMISOWNIS r.qr.- ■.B ■M limn r■ Mr .'a ..1 I -__- --_,. +{ --_ '1••MM�./1U$l/Mumma/11111/■/Wgmmm-q.■■tlgq$::Wn. ��■.mmpppgm Wl■.W.�mggmml■/11 :.-:j:::mnW o 7'O •- m - I 7"U.■B■ -■■.....■-W■-.M\M$$ r■-M■.■ :--HN■--qH o m a m : c K r N ■ ;-�N-■1•qM■.■ -W...O■..a ntlM-■11111-.1HM■-■..tl..H.■-MM.-uu 2 m N I. ° UUU$$ 'U $ • ggiBe n mmmaa$mmm$amammam :mma:a:::$a$ag::m:a:mms m::mm:gam m:a amm:emgmmmii$g:m:a:a:mmmasl o 1 441 O.6��'N UU::s $ !i i$ $.r111�!$$$1$--111$$$$$!$$1$111-1$$$1111 -11$-$1110 5$ $$$E . >LLLL.- Y Y N N o t'ii_ w 1 r'..,,, ,� as::mamma M:a-\-IIa ::Mr--m um ■./tlHMM■M-MOamaap MMM-M.-MM■■M MMMMImmmm:ap •■HH■. ■.'J d N 3 a nI l ^, •W--M■■■■•■■1■1B•:rM--Wtl■:au ua.-$:H.m:m-M.u:::u.Wtlm:�aaau �:mm:u-■1�- ■a:UUNM--■:m■■U:::U UWl o •O _m I . ti. .. W -MrG4NM.-■OM.rnn■..M---MHW-.WM■M 1\111171 -MMM..MW/..W M1lJ.a. o L 1 ---mow-- .■W W I : M.■ 4•_ W■\■M-.\M M.•MN USE m9.$mm11 .Mr .ri.T mn■r/MUM/r RUM a T ■... N•Cl • 1 {.. :pm::$m$aam$:�:` _._i.{""{ m:°$m:va::: ,!1= mt ■rrq$■.m$ NNEU� .�• C. N U UU$$$ $9 $U U$��:$$$RB$i1U EE g n� UU_UU U$ d•U• 1 -r.-■q■-H-M.. --11111111.--MM.r--W---Mnr..W ■M.■W H.MM--- ■NM\MNM--INJEMMWI o �_ ■■■■■.■■■■■■■■- .//■■■ -Wn■.//■: /l /imm M.-■tl.-■-.N. MUMMEME N. tl ■ $U■H ..HW r/r■rrr. U: : - :m $ uaa - -$$ a:::Wmp$ a= :mm : U- : p:°. Uau: ■■ a: a: .= 111.■■-Hrtllrl...- m a ■ M . ..... . ■■■ M■ A■ am . -M :m-M-- ■ma � qM■ma Y:ma:B:a-W:l a::Ua1 -Ugmmm r% aaaUU: a:■Wtl-a m:Bmq `i m m mmm-W qOmm U: :UO Bmm:m ••Mr -MM■..■■/-qW: = .- .MUUUMU■■ /-n.r.rr:■W1 mN ■ : : 1 WN / ' :m :tlMqMm:mMtl1.W.. i.M■ • m ■ aI EL t I 11111111/44—'• mmq 1 amm mmansmomm . ■ a r .- H 111 ' -■aamr■.. •■ Ts . ' _ : 4. _ 7 $ aW . U - .W _ q■ : $ . )il .MWqp■ :■■MM■U ■ MM■■■■qM■-■/.... WMGAI GM■■-gUrN.. M:.rl/■■■Mrm 0mWa /8. /tlM/■.■■■/■■.rM.r Mlr■■■..tl■I.W.M. .�. _ r■ B n . W::W m:mM, ::- � aW : �1Baa :Lim '. . mlpm■- m■ tl- M-. --/ ■:: -mBa■■■q m-- o N.--W• •••■MaN1-■NW.--.■---■MH-■-aW--W■-■dWMMI-■-■WN••••• ®®- aM- MWNPl 4 O O O g O O O O O O O O O O O . .m 0(U��O� +� � Ilj/(�43noS LL V 6V.IA L. TRANSMITTAL LETTER CHECKLIST WELL NAME K R(,t,. .2F-/gL -o ( 04. -_1.5s(AL PTD# 02 /30S3 /Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: X upon( R;Ad- POOL: I4tJ..'c,4 L.JC �i V&I� //c ,✓k X kW,/W/ O, Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /<R(,� (If last two digits in Permit No. /9 Co/ �' ,API No. 50-0,77 - a a 20-OO- O . API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 co Tcs p m ° a Y Q f0/) U 2 T 2 0 0 ui o L m O) a) 0) - 7 c 0 a) To c m c co E Q ° m a) Q co L a) Q > n a) O c c O 3 m o C N a C a) p CO v c m = cn cn E -o a) > L O N Q o m O L.LI U)p o O W O O m c a) m ` 7 c a Q o E O a>`. L° 0 rn Q U C a) of M o o c co 3 O O 0 0 7 o) 3 a • T c 3 c ~ H -C = c •-o • a) as co a aa) -`o = _ CD m O- m O T CO a ui 3 .= T .E U - Q1 6 m L O a) O O Q ,- E a) c oc ° a 9 c D o O L U E °U. '. @ > J a O .5 O U p U > Q > -0 CO 0) m 7 a V - a) U ' o E al 22 LL 0 ' C a) L a U W 1°n cn co E- c F O o a aa) a o c > o = 0- a) z co co > ` O c 2 C. o co co Q D N N '� O a) N 0 M a m a Y o E o c °m O .@ rn JO Q CO N �„ ° - m O N 0 CC U U a) a) N a) U _ To D Q Q n m m w a' w m E o m E ca 12 0 � co w N Y a = `C M - N 2 co a � Q Y c m ° c m .3 Q o v c > D t CC U .- E Y a) a) m U - asi m 'o D a) Y m 7 w c O c U U 'N N Q a > 2 N o > m c m rn a) 'n T o m m E C v7 C c c c m 2 m a v°) O J o m = U 'fn 'fn N c d o 7 LL a) O- E CO U L a) co n -O m C) i° p 0 0 a)) o cm) cm) o m T o N m c -o o) Z (N ll �' N N 0 U a) a) .0 co .- - a) o a) co - O N CO CO 7 0 0 7 CO E m a E o a) a of p d `7 `r a CD -o L x E (n a o) a a' CD O O Q) 0 7 7 2 0) 2 0 a N 0 X 'y 0 w < Y Y 0 0 0 cn 0) a CC a` LL 2 I 5 w 7 CL > w 0 < < a) a) a) a) a) a) aa)) a) a) a) a) a) < < < < < < < o a) a) < a) < a a)) a`n) a`n) a`n) a`n) o CO < 0 a) < < < Q z z >- >- >- >- � >- >- >- >- >- >- >- z z z Z Z Z Z Z } >- z >- z >- r r r >- >- Z z r Z z z T I- co U LL T p J m U a o C To a) m E E 3 - E a) o U 0 5 c a) U • o 0 8 .o 7 co n C L O a E ` It 0 o a ) c U O -a 3 E N 3 0 M U _ O U C Z 0 c .5 m - E a) m Y p 0 a) L rn o E U O D co U to o O a N a m a) 0 a) 0 n m 00 LV a) N c > LL C n 7 N Q �' 7 E T c 7 U m Q C a N U m Q 9 o Q o o w m 2 c m rn v N m N p o O ° m '� U m -o 'N co w m e o Y `o m m = 7 t c E a c° Q > c a) E o ix 0 7 a) c > .3 0 '� ao N o N o Q c c co o 3 a) N w Mo co 3 E o m a s 0 o N m a °- n ° -° aa') In a) 7 a.) m T .L-. N a s o E a) a '5 O co 'O O •7 U N Cr- (.) O = L O U ` N m 7 (n c O) L c co j or Lo 7 < co U a) N o) .. Z "o o C -0 0 a) C -7 m 0 Q D O C a) CO 0 0 0) O L 2 C D co E E = -°o c c E �° 2 0 c c w '' a o m 06 a�a)) x c o r m °- °N r a c c c Q U O o -0 7 - o P m c 3 0 " m n U c o m N a' T o., Q Y Q a U m 92 m o 0 0 0) 7 0 .Q _ m o '0 d 3 > Y x a Q o .0 o a) m .c > o ° a m - m o 0 0 m o E .E '� m Q .@ - w a o a) t4.o a) c a E - r o o m c - a o w 3 3 a) o Y a E m c a �° �° m a n . L L m m '7o aa) m i E c 1) N co m 'cn _ a) o cn o n 3 0 c o T 3 5 E. o m o a) w U m 3 3 a) a o .. a N .7 1) 3 0 2 ° ° a) N a '2 m m o 3 r a) ° w U o c -a o m m a a m o Q) 0 a) 5 o m E `o 'o aa) o o °c s o 0 N a E a°) m E o o) o 0 Q O 7 c a 7.1C1- O n a`) a) = a ° 7 7 Q C r o Y m rn O - 0 -C = U U a) a a) m v Q - a m a E CO c L U U N E m O O 0) N Q y 0) N L , 'C o) O- m m (a m m o N o) T .- ° 3 2. a fa)/-) N o Q ° a m m m S Q Q m 3 m m a) .3 c c 7 7 Y u) ._o '- O a) a -o o a N '- il O 7 -co C a -0 -0 0 N C f(6 L L -0 -o L U)) N 'N a) 0 o-) „S L 0 0 Q " U O U ° U C m E 0 c o E a) m m m m p o L c c m U m m m aai = 3 ° ° O m 0 0 c o c o rn O aa)) 7 3 m m m m m m m 3 7 o U - m ._ ' a m = c C m co m U c y z c . c a) o 0 o m m ° ° .°.. m o = O 0 U 00 .3 C) m $ m r C ui Q E a) 3 a) ( U., a U a 6 J 00 c m a) a) a) a) a) m E E ° m 3 ac 't H F H 'uc- a6i `) 'c a a o Y`o n D. N m c m >, o a) m e 7 a 0- 0- a`) a`) m - 0 7 2 22 m a m a = 0 0 L 0 a) m a) a) o p 0 c Z a _i D c n B O O a a O Q a 0 0) 0 0 0 0 < < 0 CO CO 0 Ln M a o <n <n O W Q r O N M V l0 (0 00 0) O N M V lf) CO r CO O) O N M LC) (O r 0o Q) EO N M '7 l0 CO r W C)) N N N N N N N N N N M M M M C71:3 M M M M M U O F- M co M CD 2 O C ON N C. - (NN_ U O_ M o I _o En U Cl O W M R � C C') � O E 0 a N To a) T O E O Q c a o a uj 1.- C a c Q ; or T4 s. THE STATE Alaska Oil 0 nil Gas �"' °fALAS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFALAS�� Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Lamar Gantt CT Drilling Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F-18L1-01 ConocoPhillips Alaska, Inc. Permit No: 213-053 Surface Location: 275' FNL, 1713' FEL, SEC. 33, T11N, R9E, UM Bottomhole Location: 261' FNL, 828' FEL, SEC. 9, T1ON, R9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 2F-18L1, Permit No 196-178, API 50-029-22720-00-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. Foerster Chair t/ DATED this /7 y of April, 2013. RECEIVED ED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 7 2013 PERMIT TO DRILL ,1?) tia�� 20 AAC 25.005 , la.Type of Work: lb.Proposed Well Class: Development-Oil •Q Service-Winj ❑ Single Zone U 1c.Specify if well is proposed for: Drill ❑ •Lateral 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59-52-180• 2F-18L1-01+ 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13850', TVDSS: 6073'• Kuparuk River Field, 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:275 FNL, 1713'FEL,Sec.33,T11 N,R9E,UM ADL 25657,25666 Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1300'FNL,617'FEL,Sec.4,T1ON, R9E,UM 2583,2587 4/24/2013 • Total Depth: 9.Acres in Property: 045 14.Distance to 261'FNL,828'FEL,Sec.9,T1ON,R9E,UM 256.0-5/ o y}lglla Nearest Property: 2530 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 138 feet 15.Distance to Nearest Well Open Surface:x- 517519 y- 5948608 Zone- 4 , GL Elevation above MSL: , 92.5 feet to Same Pool: 2F-17,2975 16.Deviated wells: Kickoff depth: •9550 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25035) Maximum Hole Angle: ,,100° deg Downhole:4582 psig • Surface:3979 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade _ Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 SLT 4902' 8948' 5797' 13850' 6211' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9715 6385 9350 9588 6270 none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 280 sx AS I 121' 121' Surface 5573' 9.625 330 sx ASLW, 1220 sx 5614' 3161' Intermediate Class G,60 sx AS I Production 9103' 7 130 sx Class G 9142' 5923' Liner 780' 5 137 sx Class G 9715' 6436' Perforation Depth MD(ft): Perforation Depth TVD(ft): 9325'-9335', 9359'-9383' 6086'-6095', 6117'-6138' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Progran- Q• Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 ' 20 AAC 25.055000rre9 'ements IS 21.Verbal Approval: Commission Representative: Date: /1-/1 /v 22. I hereby certify that the foregoing is true and correct. Contact Kai Starck -M1 Email Kai.Starckaconocoghillios.com Printed Nam Lamar G Title CT Drilling Supervisor j Signature VNS)- Phone: 265-4021 Date A- `1(\3 Commission Use Only Permit to Drill PI Number: Permit Appro I ^f� See cover letter Number:0213 0 53 50-0°.9 — aa?.�D _GI_ 0 0 Date: \��\J for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: VI- Other: 0 op trS7` fip #5-60 5-6 5 L Samples req'd: Yes ❑ No ►� Mud log req'd: Yes El No H2S measures: Yes Z No ❑ Directional svy req'd: Yes d No❑ Spacing exception req'd: Yes ❑ No Q Inclination-only svy req'd: Yes❑ No[✓' t APPROVED BY THE _Approved by: OMMISSIONER COMMISSION Date: 4- . . Form 0 11 (Relied 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) x�; o�� V1- 4118113 '/2- #, 6 Kuparuk CTD Laterals NABORS ALASKA Drilling &Wells 2F-18L1 and 2F-18L1-01 Application for Permit to Drill Document 2nc 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 2 (Requirements of 20 AAC 25.005(c)(6)) 2 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 5 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 Attachment 1: Directional Plans for 2F-18L1 and 2F-18L1-01 6 Attachment 2: Current Well Schematic for 2F-18 6 Attachment 3: Proposed Well Schematic for 2F-18 CTD Laterals 6 Page 1 of 6 4 April 4,2013 PTD Application for KRU 2F-18L1 & 2F-18L1-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) There are two proposed laterals described in this document: KRU 2F-18L1 and 2F-18L1-01. The L1 lateral will be drilled off the motherbore and the L1-01 lateral will be drilled off the L1 lateral. Both will be classified as "Development-Oil"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The 2F-18L1 lateral is planned to target the Kuparuk A4 sand to south of the existing well. The 2F-18L1-01 lateral is planned to target the Kuparuk A5 sand to the south of the existing well. See the attached 10-401 forms for surface and subsurface coordinates of each of the 2F-18 laterals. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4500 psi. Using a maximum potential formation pressure of 4582 psi, the maximum potential surface pressure is 3979 psi assuming a gas gradient of 0.1 psi/ft. See the"Drilling Hazards Information and Reservoir Pressure"section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The latest 2F-18 SBHP taken 3/30/13 was 4136 psi for a 13.1 EMW from the A4/A5 sands. The pressure has been on a steady decline since shutting in the nearby injectors and we anticipate the 2F-18 formation pressure to be a 12.9 EMW by the time drilling commences in May 2013. Injector 2F-17 to the west, shut in since June 2012, has a current BHP of 4041, 12.8 EMW. The closest well is 2F-12 to the north, believed to be isolated from 2F-18 by a fault, with a BHP of 2679, 8.6 EMW. To the west is producer 2F-19, also isolated from 2F-18 by faults, with a BHP of 3824, 12.2 EMW. Injection wells in the area have had higher formation pressures. 2G-12 to the west was as high as 4700 (6155' TVD, 14.6 EMW) in the past. Because we will be drilling to the south into an undeveloped area we will assume this to be maximum potential formation pressure. For 2F-18 this equates to a maximum formation pressure of 4582 psi(9268' MD, 6035' TVD). The maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft would be 3979 psi. Potential Gas Zones (Requirements of 20 AA C 25.005(c)(4)(b)) No specific gas zones will be drilled and there has been no gas or MI injection in the area Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 2F-18 laterals is hole stability due to interbedded shales and silts in the A-sand. We will mitigate hole instability by maintaining a minimum ECD target of 12.9 ppg EMW at the window while drilling the CTD laterals, as well as using mud additives that minimize chemical instability. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) Both of the 2F-18 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Page 2 of 6 April 5, 2013 PTD Application for KRU 2F-18L1 & 2F-18L1-01 New Completion Details Liner Liner Liner Liner Lateral Name Top MD Btm Top Btm Liner Details MD SSTVD SSTVD 2F-18L1 9550' 13,550' 6137' 6185' 2%", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2F-18L1-01 8948' 13,850' 5797' 6211' 2%", 4.7#, L-80, ST-L slotted liner; Liner Deployment Sleeve on top Existing Casing/Liner Information Weight Top Btm Top Btm Burst Collapse Category OD (PM MD Connection MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 41' 121' 0' 121' Surface 9-5/8 40 L-80 BTC 41' 5614' 0' 3161' 5750 3090 Casing 7" 26 L-80 BTC-MOD 38.5' 9141' 0' 5923' 5410 7240 Liner 5" 18 L-80 LTC-MOD 8935' 9715' 5744' 6298' 9910 10,490 Tubing 3W 9.3 L-80 EUE8rdMOD 36.8' 8979' 0' 5778' 10,160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine or used drilling mud (-9.9 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.9 ppg). This mud weight alone will not hydrostatically overbalance formation pressure in the 2F-18 motherbore. MPD practices described below will used to maintain overbalance conditions while drilling. — Completion operations: The well will be loaded with 13.1 ppg Potassium Formate completion fluid in order to maintain pressure over-balance while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-200 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive of the rig during drilling operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD)techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing pressure over- balance to the formation. In the 2F-18 laterals we will target a constant BHP of 12.9 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. t 'tA Page 3 of 6 April 5,2013 PTD Application for KRU 2F-18L1 & 2F-18L1-01 Pressure at the 2F-18L1 Window(9268' MD, 6035' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure (12.9 ppg) 4082 psi 4082 psi Mud Hydrostatic(9.9 ppg) 3107 psi 3107 psi Annular friction (i.e. ECD, 0.095 psi/ft) 880 psi 0 psi Mud + ECD Combined 3987 psi 3107 psi (no choke pressure) (underbalanced (underbalanced 95 psi) 975 psi) Target BHP at Window(12.9 ppg) 4048 psi 4048 psi Choke Pressure Required to Maintain 61 psi 941 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AA C 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AA C 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AA C 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 2F-18 was originally completed in 1997 as a A4/A5-sand producer. It remained on production until it began producing sand through casing damage in the A4 interval. Remedial cementing through a cement retainer has plugged off the A4 perforations. The well is currently shut in for the CTD laterals. A mechanical whipstock will be placed in the 5" liner at the planned kickoff point. The 2F-18L1 lateral will exit the 5" liner at 9268' MD and target the A4 sand to the south of the existing well with a 4282' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,550' MD with an aluminum billet at 9550' MD. The 2F-18L1-01 lateral will kick off from the aluminum billet at 9550' MD and will target the AS sand south of the existing well with a 4300' lateral. The hole will be completed with a 2%' slotted liner to the TD of 13,850' MD with a liner top deployment sleeve at 8970' MD, inside the 3%" tubing. Pre-CTD Work 1. MIRU E-line. Set Whipstock @ 9268'oriented 10 ROHS 2. MIRU Coiled tubing unit. Mill 2.75" nipple at 8942' to 2.80" Page 4 of 6 April 5, 2013 PTD Application for KRU 2F-18L1 & 2F-18L1-01 3. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16" BOPE, test. 2. 2F-18L1 Sidetrack (A4 sand, South) a. Mill 2.80"window through 5" liner b. Drill 2.70"x 3" bi-center lateral to TD of 13,550' MD c. Run 2%" slotted liner with an aluminum billet from TD up to9550" 3. 2F-18L1-01 Lateral (A5 sand, south) a. Kick off of the aluminum billet at 9550' MD b. Drill 2.70"x 3" bi-center lateral to TD of 13,850' MD c. Run 2%"slotted liner with a liner deployment sleeve from TD to above the 3W mule shoe at 8972' ELMD 4. Freeze protect. Set BPV, ND BOPE. 5. RDMO Nabors CRD2-AC. Post-Rig Work 1. PuII BPV 2. Obtain static BHP, Install gas lift valves 3. Put well on production Pressure Deployment of BHA The planned bottomhole assemblies (BHAs)are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Liner Running — Fluid of sufficient density to over-balance the formation will be used to provide well control. See the "Drilling Fluids" section for more details. — While running 2%"slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" pipe rams provide secondary well control while running 2%" liner. h _ _ Page 5 of 6 April 5,2013 PTD Application for KRU 2F-18L1 & 2F-18L1-01 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AA C 25.050(b)) — There are no other affected owners — Please see attached directional plans for each lateral. — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to nearest property line and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 2F-18L1 02 2850' 2630' 2F-12 2F-18L1-01 01 2530' 2975' 2F-17 Attachment 1: Directional Plans for 2F-18L1 and 2F-18L1-01 Attachment 2: Current Well Schematic for 2F-18 Attachment 3: Proposed Well Schematic for 2F-18L1 and L1-01 CTD Laterals r ;- Page 6 of 6 s April 5,2013 c 2 O p N rn 'o2 4�O r.go) c cc) m <2 N c-, Y °b� vb G DC 2Q III ¢�c; O J s wO. N 4 I I CCO F- Co ✓ 0 0 c co II co E m ccoo m m Y N Y Y CC CC N a Em N o CO © OOp O) CO co m V Off j, ') v a) Y o -o L) Y a) a © E sZ ecl co E U) o � I In = E iz o� n. H @ c a) m m � a) C CO _ � Y I Q w 0) a N co O 8 O O O o J CV 0-C co co co CO CO O of U 0 O COa., cV I CV (V N N OJ a) a) a) N C Y O Y Y Y r c- co C CU CO ca N , a) M M ch (h c6 m _I m m m C O) CO La- -0 C) x o �� N Q .� O_ �• � , 0 < �C aa)) V E . a)= Al. 1 . -7- oLt m : ,I. t c I- Ill __ _ CI r r !_ U t ) O (o co a) N o g 0) o m 0 u) a. ' N o -- 0 2 o°o 0 mm IX a`)Q3 --I Y o_co o_co It 2 00 0 C MM`` a in COI I (71 CON 1cNv) V N� cf) 6) r I rt - N V < O a) <O) 1 N CNO� FE O C° N •d) g CC i 1. a M . x vin.., i KUP 2F-18 . ConocoPhillips 0 Well Attributes Max Angle&MD TD Alaska III` Wellbore API/UWI Field Name Well Status Incl(°) MD(RKB) Act Btm(MB) Corftx gyps 500292272000 KUPARUK RIVER UNIT PROD 70.96 3,950.00 9,715.0 "" Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date wen coo,' -2F-18 45rz01310415 PM SSSV:NIPPLE 130 10/12/2007 Last WO: 1/19/1997 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,334.0 2/9/2013 Rev Reason:TAG TOC haggea 4/4/2013 �t Casing Strings .pie HANGER.37 -n4 Casing Description String 0... String ID...Top(ROB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 41.0 5,614.4 3,161.4 40.00 L-80 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt.,String...String Top Thrd PRODUCTION 7 6.276 38.5 9,141.7 5,922.8 26.00 L-80 BTC-MOD �` Casing Description String 0.., String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd I LINER 5 _ 4.276 8,935.4 9,715.0 18.00 L-80 LTC-MOD Liner Details CONDUCTOR, Top Depth 41-121 (ND) Top Inot Semi... IP Top(RKB) ( B) (°) Rem Description Comment ID(in) NIPPLE,523 8,935.4 5,738.5 26.79 PACKER BAKER TIEBACK SLEEVE w/LINER TOP PACKER 4.408 8,949.3 5,750.9 26.80 HANGER BAKER LINER HANGER 4.408 8,955.8 5,756.7 26.86 SBE BAKER SEAL BORE EXTENSTION 4.000 Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(NO)...String Wt...String...String Top Thrd TUBING I 31/2 I 2.992 I 36.8 I 8,979.4 J 5,777.8 I 9.30 I L-80 I EUE8RDMOD GAS LIFT, Completion Details Top Depth (ND) Top Incl Noml... Top(RKB) (RKB) (°) item Description Comment ID(in) 36.8 36.8 -0.16 HANGER FMC GEN IV TUBING HANGER 3.500 523.0 522.6 5.82 NIPPLE CAMCO DS LANDING NIPPLE 2.812 d 8,942.0 5,744.4 26.80 NIPPLE CAMCO D LANDING NIPPLE NO GO 2.750 8,949.1 5,750.7 26.80 LOCATOR BAKER GBH-22 LOCATOR 3.000 8,951.2 5,752.6 26.87 SEAL ASSY BAKER SEAL ASSEMBLY w/1.62 OF SEALS&MULE SHOE,(Mule 3.000 SURFACE, I Shoe)TTL ELMD @ 8972 SWS LDL 2/7/1997 • 41-5.614 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I. Top Depth (ND) Top net GAS LIFT, Top(MB) MB) (°) Description Comment Run Date ID(in) 6,784 11= 9,350.0 6,108.6 27.08 CMT Retainer INFLATABLE CEMENT RETAINER SET,PUMPED JUST 1 1/10/2013 0.000 - BBL CEMENT le Perforations&Slots Shot GAS LIFT, Top(ND) Btm(TVD) Dens 7,759 Top(RKB)Btm(ftKB) (RKB) (RKB) Zone Dote (sh... TYPe Comment • 9,325.0 9,335.0 6,086.2 6,095.2 A-5,2F-18 6/14/2010 6.0 APERF 2.5"HSD Gun,60 deg phase 9,359.0 9,383.0 6,116.6 6,137.9 A-4,2F-18 2/11/1997 4.0 IPERF 2.5"HSD;180 deg phasing Stimulations&Treatments Bottom GAS LIFT oa a,5 in{ M Top Max Btm Top Depth Depth• Depth Depth (TVD) (TVD) (RKB) (RKB) (RKB) (RKB) Type Date Comment 1. 9,325.0 9,335.0 6,086.2 6,095.2 FRAC 6/15/2010 A-SAND FRAC-placed 95,972 lbs.of 16/20 Carbolite behind Perfs @ 9325'-9335' Notes:General&Safety GAS LIFT, End Date Annotation 8,896 10/142010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE.8,942 Io /1 LOCATOR, 8.949 SEAL ASSY. 8,951 It PRODUCTION. 395,142 APERF, 9,3255,335 FRAC,9,325 'IIII ®t Mandrel Details ■ Top Depth Top Port CMT Retainer, ® 5... (ND) Inc! OD Voice Latch Size TRO Run 9' N...Top(RKB) (RKB) (°) Make Model (in) Sery Type Type (in) (Psi) Run Date Com... CMT PLUG, 1 4,242.6 2,669.7 69.85 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 12/6/2012 6:00 9,361 2 6,783.6 3,855.2 36.58 CAMCO KBMM 1 GAS LIFT DMY INT 0.000 0.0 12/6/2012 11:30 1PERF, ■ 3 7,768.7 4,709.1 28.59 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 12/6/2012 7:00 9,359-9,383 4 8,504.3 5,356.8 28.60 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 12/112012 8:00 5 8,896.2 5,703.6 26.66 CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 12/72012 3:00 'O 9,715 y 'emu F `a 4 arcs.• /u A t 6 I. • ConocoPhifli s p Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2F Pad 2F-18 2F-18L1-01 Plan: 2F-18L1-01_wp01 Standard Planning Report 16 April, 2013 BAKER HUGHES ' Baker Hughes INTEQ Conoco Phillips Planning Report BAKER UGH ES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2F-18 L 1-01_wp01 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2F Pad Site Position: Northing: 5,949,341.82ft Latitude: 70°16'21.978 N From: Map Easting: 517,392.55ft Longitude: 149°51'33.576 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.13° Well 2F-18 Well Position +NI-S 0.00 ft Northing: 5,948,607.88 ft Latitude: 70°16'14.756 N +E1-W 0.00 ft Easting: 517,519.05 ft Longitude: 149°51'29.942 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 92 50f Wellbore 2F-18L1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 6/30/2013 15.49 79.87 57,348 Design 2F-18L1-01 wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,550.00 Vertical Section: Depth From(TVD) +N/-S ,. +E/-W Direction (ft) (ft) (ft) (°) -96.80 0.00 0.00 175.07 4/16/2013 5:02:18PM Page 2 COMPASS 2003.16 Build 69 1 bv Baker Hughes INTEQ Ilrfai ConocoPhill.lips Planning Report BAKER Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2F-18L1-01_wp01 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°I100ft) (°i100ft) (°I100ft) (°) Target 9,550.00 89.87 181.80 5,999.27 -6,304.69 1,111.58 0.00 0.00 0.00 0.00 9,635.00 100.07 181.80 5,991.91 -6,389.21 1,108.92 12.00 12.00 0.00 0.00 9,713.00 99.94 191.31 5,978.32 -6,465.43 1,100.16 12.00 -0.17 12.18 90.00 9,793.00 90.96 194.73 5,970.73 -6,542.93 1,082.23 12.00 -11.22 4.28 159.00 10,093.00 89.91 182.78 5,968.44 -6,838.88 1,036.65 4.00 -0.35 -3.98 265.00 10,243.00 81.75 186.61 5,979.34 -6,987.83 1,024.44 6.00 -5.43 2.55 155.00 10,343.00 86.02 182.36 5,990.00 -7,086.91 1,016.69 6.00 4.26 -4.25 315.00 10,443.00 89.88 181.33 5,993.58 -7,186.78 1,013.48 4.00 3.86 -1.03 345.00 10,593.00 90.09 175.33 5,993.62 -7,336.65 1,017.85 4.00 0.14 -4.00 272.00 10,793.00 94.67 168.76 5,985.31 -7,534.39 1,045.47 4.00 2.29 -3.28 305.00 10,918.00 94.65 173.78 5,975.15 -7,657.50 1,064.37 4.00 -0.01 4.01 90.00 11,043.00 89.95 175.49 5,970.13 -7,781.81 1,076.05 4.00 -3.76 1.37 160.00 11,393.00 87.07 189.19 5,979.28 -8,130.53 1,061.83 4.00 -0.82 3.92 102.00 11,743.00 87.76 203.19 5,995.15 -8,465.46 964.57 4.00 0.20 4.00 87.50 12,043.00 85.94 191.31 6,011.68 -8,751.00 875.88 4.00 -0.61 -3.96 261.00 12,443.00 86.10 175.27 6,039.60 -9,148.07 853.06 4.00 0.04 -4.01 270.00 12,643.00 88.47 167.62 6,049.09 -9,345.46 882.77 4.00 1.18 -3.83 287.00 13,043.00 88.53 183.63 6,059.64 -9,742.86 913.19 4.00 0.01 4.00 90.00 13,343.00 88.56 171.62 6,067.30 -10,041.95 925.60 4.00 0.01 -4.00 270.00 13,543.00 89.55 179.56 6,070.61 -10,241.17 940.95 4.00 0.49 3.97 83.00 13,850.00 89.56 191.84 6,073.02 -10,546.06 910.51 4.00 0.00 4.00 90.00 4/16/2013 5:02:18PM Page 3 COMPASS 2003.16 Build 69 n _ y \ i 'k,:.' . c i G c La, ";r-, Baker Hughes INTEQ INS ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2F-18L1-01_wp01 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (1 (o) (ft) (ft) (ft) (ft) (°1100ft) (0) (ft) (ft) 9,550.00 89.87 181.80 5,999.27 -6,304.69 1,111.58 6,376.94 0.00 0.00 5,942,306.42 518,645.19 TIP/KOP 9,600.00 95.87 181.80 5,996.76 -6,354.58 1,110.01 6,426.51 12.00 0.00 5,942,256.54 518,643.74 9,635.00 100.07 181.80 5,991.91 -6,389.21 1,108.92 6,460.92 12.00 0.00 5,942,221.90 518,642.73 Start 12 dls 9,700.00 99.98 189.72 5,980.57 -6,452.84 1,102.50 6,523.76 12.00 90.00 5,942,158.26 518,636.46 9,713.00 99.94 191.31 5,978.32 -6,465.43 1,100.16 6,536.10 12.00 91.38 5,942,145.67 518,634.15 3 9,793.00 90.96 194.73 5,970.73 -6,542.93 1,082.23 6,611.77 12.00 159.00 5,942,068.14 518,616.40 4 9,800.00 90.94 194.45 5,970.61 -6,549.70 1,080.46 6,618.36 4.00 -95.00 5,942,061.36 518,614.65 9,900.00 90.59 190.47 5,969.28 -6,647.32 1,058.89 6,713.76 4.00 -95.00 5,941,963.71 518,593.31 10,000.00 90.24 186.48 5,968.56 -6,746.20 1,044.16 6,811.01 4.00 -95.06 5,941,864.80 518,578.80 10,093.00 89.91 182.78 5,968.44 -6,838.88 1,036.65 6,902.71 4.00 -95.09 5,941,772.11 518,571.51 Start 4 dls 10,100.00 89.52 182.96 5,968.48 -6,845.87 1,036.30 6,909.64 6.00 155.00 5,941,765.12 518,571.18 10,200.00 84.09 185.50 5,974.04 -6,945.40 1,028.94 7,008.17 6.00 155.00 5,941,665.58 518,564.05 10,243.00 81.75 186.61 5,979.34 -6,987.83 1,024.44 7,050.05 6.00 154.86 5,941,623.15 518,559.65 Start 6 dls 10,300.00 84.18 184.18 5,986.32 -7,044.15 1,019.13 7,105.70 6.00 -45.00 5,941,566.83 518,554.47 10,343.00 86.02 182.36 5,990.00 -7,086.91 1,016.69 7,148.10 6.00 -44.70 5,941,524.06 518,552.13 7 10,400.00 88.22 181.77 5,992.86 -7,143.80 1,014.64 7,204.60 4.00 -15.00 5,941,467.17 518,550.21 10,443.00 89.88 181.33 5,993.58 -7,186.78 1,013.48 7,247.32 4.00 -14.97 5,941,424.20 518,549.15 Start 4 dls 10,500.00 89.96 179.05 5,993.66 -7,243.77 1,013.29 7,304.09 4.00 -88.00 5,941,367.21 518,549.10 10,593.00 90.09 175.33 5,993.62 -7,336.65 1,017.85 7,397.01 4.00 -88.00 5,941,274.35 518,553.87 9 10,600.00 90.25 175.10 5,993.60 -7,343.62 1,018.44 7,404.01 4.00 -55.00 5,941,267.38 518,554.47 10,700.00 92.54 171.82 5,991.16 -7,442.92 1,029.82 7,503.92 4.00 -55.00 5,941,168.12 518,566.09 10,793.00 94.67 168.76 5,985.31 -7,534.39 1,045.47 7,596.39 4.00 -55.08 5,941,076.69 518,581.95 10 10,800.00 94.67 169.04 5,984.74 -7,541.24 1,046.81 7,603.33 4.00 90.00 5,941,069.85 518,583.30 10,900.00 94.65 173.06 5,976.61 -7,639.67 1,062.31 7,702.74 4.00 90.02 5,940,971.46 518,599.04 10,918.00 94.65 173.78 5,975.15 -7,657.50 1,064.37 7,720.67 4.00 90.35 5,940,953.65 518,601.13 11 11,000.00 91.57 174.90 5,970.70 -7,738.96 1,072.45 7,802.53 4.00 160.00 5,940,872.20 518,609.40 11,043.00 89.95 175.49 5,970.13 -7,781.81 1,076.05 7,845.52 4.00 160.06 5,940,829.37 518,613.10 12 11,100.00 89.48 177.72 5,970.42 -7,838.70 1,079.43 7,902.50 4.00 102.00 5,940,772.49 518,616.61 11,200.00 88.65 181.63 5,972.05 -7,938.67 1,080.00 8,002.14 4.00 101.99 5,940,672.54 518,617.42 11,300.00 87.82 185.55 5,975.13 -8,038.40 1,073.75 8,100.97 4.00 101.92 5,940,572.80 518,611.40 11,393.00 87.07 189.19 5,979.28 -8,130.53 1,061.83 8,191.73 4.00 101.80 5,940,480.65 518,599.70 13 11,400.00 87.08 189.47 5,979.64 -8,137.43 1,060.70 8,198.50 4.00 87.50 5,940,473.75 518,598.58 11,500.00 87.26 193.47 5,984.57 -8,235.29 1,040.84 8,294.30 4.00 87.49 5,940,375.86 518,578.95 11,600.00 87.46 197.47 5,989.18 -8,331.54 1,014.19 8,387.90 4.00 87.29 5,940,279.55 518,552.53 11,700.00 87.67 201.47 5,993.43 -8,425.72 980.89 8,478.86 4.00 87.10 5,940,185.31 518,519.45 11,743.00 87.76 203.19 5,995.15 -8,465.46 964.57 8,517.06 4.00 86.93 5,940,145.53 518,503.23 14 11,800.00 87.41 200.94 5,997.55 -8,518.24 943.18 8,567.80 4.00 -99.00 5,940,092.71 518,481.96 11,900.00 86.79 196.98 6,002.61 -8,612.67 910.74 8,659.09 4.00 -98.90 5,939,998.21 518,449.75 4/16/2013 5:02:18PM Page 4 COMPASS 2003.16 Build 69 , Baker Hughes INTEQ 1Tr� ConocoPhillipss Planning Report NUGNES Alaska Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2F-18L1-01_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 12,000.00 86.20 193.01 6,008.73 -8,709.07 884.92 8,752.91 4.00 -98.70 5,939,901.76 518,424.15 12,043.00 85.94 191.31 6,011.68 -8,751.00 875.88 8,793.91 4.00 -98.46 5,939,859.81 518,415.21 15 12,100.00 85.95 189.02 6,015.71 -8,806.96 865.85 8,848.80 4.00 -90.00 5,939,803.83 518,405.31 12,200.00 85.97 185.01 6,022.76 -8,905.95 853.66 8,946.37 4.00 -89.84 5,939,704.83 518,393.35 12,300.00 86.01 181.00 6,029.76 -9,005.54 848.43 9,045.14 4.00 -89.56 5,939,605.23 518,388.35 12,400.00 86.07 176.99 6,036.67 -9,105.27 850.17 9,144.65 4.00 -89.28 5,939,505.52 518,390.32 12,443.00 86.10 175.27 6,039.60 -9,148.07 853.06 9,187.54 4.00 -89.00 5,939,462.73 518,393.32 16 12,500.00 86.77 173.09 6,043.15 -9,204.66 858.83 9,244.42 4.00 -73.00 5,939,406.16 518,399.22 12,600.00 87.96 169.26 6,047.75 -9,303.35 874.16 9,344.06 4.00 -72.86 5,939,307.51 518,414.77 12,643.00 88.47 167.62 6,049.09 -9,345.46 882.77 9,386.75 4.00 -72.69 5,939,265.43 518,423.48 17 12,700.00 88.47 169.90 6,050.61 -9,401.34 893.87 9,443.38 4.00 90.00 5,939,209.58 518,434.71 12,800.00 88.48 173.90 6,053.28 -9,500.29 907.95 9,543.18 4.00 89.94 5,939,110.68 518,449.02 12,900.00 88.49 177.90 6,055.92 -9,599.98 915.09 9,643.11 4.00 89.83 5,939,011.01 518,456.39 13,000.00 88.52 181.90 6,058.53 -9,699.92 915.26 9,742.70 4.00 89.73 5,938,911.08 518,456.79 13,043.00 88.53 183.63 6,059.64 -9,742.86 913.19 9,785.30 4.00 89.62 5,938,868.15 518,454.82 18 13,100.00 88.53 181.34 6,061.11 -9,799.78 910.71 9,841.80 4.00 -90.00 5,938,811.22 518,452.48 13,200.00 88.54 177.34 6,063.67 -9,899.72 911.86 9,941.46 4.00 -89.94 5,938,711.29 518,453.86 13,300.00 88.55 173.34 6,066.21 -9,999.34 919.97 10,041.41 4.00 -89.84 5,938,611.71 518,462.20 13,343.00 88.56 171.62 6,067.30 -10,041.95 925.60 10,084.35 4.00 -89.74 5,938,569.11 518,467.93 19 13,400.00 88.84 173.89 6,068.59 -10,098.48 932.79 10,141.29 4.00 83.00 5,938,512.60 518,475.24 13,500.00 89.33 177.86 6,070.19 -10,198,19 939.98 10,241.24 4.00 82.95 5,938,412.92 518,482.67 13,543.00 89.55 179.56 6,070.61 -10,241.17 940.95 10,284.15 4.00 82.89 5,938,369.95 518,483.74 20 13,600.00 89.55 181.84 6,071.06 -10,298.16 940.26 10,340.87 4.00 90.00 5,938,312.96 518,483.18 13,700.00 89.55 185.84 6,071.85 -10,397.92 933.56 10,439.68 4.00 89.98 5,938,213.20 518,476.71 13,800.00 89.55 189.84 6,072.64 -10,496.96 919.92 10,537.18 4.00 89.95 5,938,114.14 518,463.30 13,850.00 89.56 191.84 6,073.02 -10,546.06 910.51 10,585.29 4.00 89.92 5,938,065.02 518,454.01 Planned TD at 13850 4/16/2013 5::02:18PM Page 5 COMPASS 2003.16 Build 69 1 j yy p c F `L... t.. 6 t F. L.a. • Baker Hughes INTEQ Ft al ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2F-18L1-01_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2F-18L1-01_T08(copy) 0.00 0.00 5,995.00 -8,448.36 962.16 5,940,162.63 518,500.78 70°14'51.666 N 149°51'1.964 W -plan misses target center by 8.89ft at 11728.10ft MD(5994.56 TVD,-8451.74 N,970.36 E) -Point 2F-18L1_Fault02(copy) 0.00 0.00 0.00 -7,124.41 1,027.25 5,941,486.59 518,562.78 70°15'4.687 N 149°51'0.065 W -plan misses target center by 5974.98ft at 10100.00ft MD(5968.48 TVD,-6845.87 N,1036.30 E) -Rectangle(sides W370.00 H1.00 D0.00) 2F-18L1-01_T09(copy) 0.00 0.00 6,039.00 -9,130.45 980.57 5,939,480.65 518,520.77 70°14'44.958 N 149°51'1.431 W -plan misses target center by 128.52ft at 12434.00ft MD(6038.99 TVD,-9139.12 N,852.35 E) -Point 2F-18L1-01_T03(copy) 0.00 0.00 5,980.00 -7,086.41 1,031.34 5,941,524.59 518,566.78 70°15'5.061 N 149°50'59.946 W -plan misses target center by 17.66ft at 10340.81ft MD(5989.84 TVD,-7084.73 N,1016.78 E) -Point 2F-18L1_Fault01(copy) 0.00 0.00 0.00 -7,054.42 1,035.42 5,941,556.59 518,570.78 70°15'5.375 N 149°50'59.828 W -plan misses target center by 5972.12ft at 10100.00ft MD(5968.48 TVD,-6845.87 N,1036.30 E) -Rectangle(sides W370.00 H1.00 D0.00) 2F-18L1-01_T01(copy) 0.00 0.00 5,973.00 -6,541.49 1,083.62 5,942,069.58 518,617.79 70°15'10.420 N 149°50'58.424 W -plan misses target center by 2.45ft at 9791.07ft MD(5970.76 TVD,-6541.07 N,1082.72 E) -Point 2F-18L1-01_T06(copy) 0.00 0.00 5,970.00 -7,794.24 933.68 5,940,816.61 518,470.78 70°14'58.099 N 149°51'2.789 W -plan misses target center by 142.93ft at 11046.97ft MD(5970.14 TVD,-7785.76 N,1076.36 E) -Point 2F-18L1-01_T11(copy) 0.00 0.00 6,073.00 -10,549.19 826.25 5,938,061.69 518,369.77 70°14'31.004 N 149°51'5.922 W -plan misses target center by 84.32ft at 13851 00ft MD(6073.02 TVD,-10546.06 N,910.51 E) -Point 2F-18L1-01_T02(copy) 0.00 0.00 5,968.00 -6,844.43 1,047.91 5,941,766.59 518,582.78 70°15'7.440 N 149°50'59.464 W -plan misses target center by 11.53ft at 10097.98ft MD(5968.46 TVD,-6843.85 N,1036.40 E) -Point 2F-18L1_Fault04(copy) 0.00 0.00 0.00 -8,449.36 963.16 5,940,161.63 518,501.78 70°14'51.656 N 149°51'1.935 W -plan misses target center by 5988.52ft at 11429.52ft MD(5981.13 TVD,-8166.45 N,1055.55 E) -Rectangle(sides W385.00 H1.00 D0.00) 2F-18L1-01_T10(copy) 0.00 0.00 6,067.00 -10,008.19 843.51 5,938,602.67 518,385.77 70°14'36.325 N 149°51'5.419 W -plan misses target center by 76.98ft at 13300.00ft MD(6066.21 TVD,-9999.34 N,919.97 E) -Point 2F-18L1-01_T05(copy) 0.00 0.00 5,985.00 -7,544.33 981.27 5,941,066.60 518,517.78 70°15'0.557 N 149°51'1.404 W -plan misses target center by 64.93ft at 10791.99ft MD(5985.39 TVD,-7533.41 N,1045.27 E) -Point 2F-18L1-01_T04(copy) 0.00 0.00 5,993.00 -7,274.39 1,016.90 5,941,336.60 518,552.78 70°15'3.212 N 149°51'0.367 W -plan misses target center by 2.85ft at 10530.76ft MD(5993.67 TVD,-7274.53 N,1014.13 E) -Point 2F-18L1_Fault03(copy) 0.00 0.00 0.00 -7,543.33 981.27 5,941,067.60 518,517.78 70°15'0.567 N 149°51'1.404 W -plan misses target center by 5974.60ft at 11000.00ft MD(5970.70 TVD,-7738.96 N,1072.45 E) -Rectangle(sides W380.00 H1.00 D0.00) 2F-18 CTD Polygon(cor 0.00 0.00 0.00 -6,061.01 893.72 5,942,549.57 518,426.78 70°15'15.146 N 149°51'3.946 W -plan misses target center by 5993.11ft at 9793.00ft MD(5970.73 TVD,-6542.93 N,1082.23 E) -Polygon Point 1 0.00 -6,061.01 893.72 5,942,549.57 518,426.78 Point 2 0.00 -6,061.81 1,243.75 5,942,549.59 518,776.78 Point 3 0.00 -8,010.92 1,205.31 5,940,600.59 518,742.88 Point 4 0.00 -10,846.73 993.84 5,937,764.58 518,538.03 Points 0.00 -10,796.85 611.91 5,937,813.56 518,156.02 Point 6 0.00 -8,010.04 820.28 5,940,600.57 518,357.89 4/16/2013 5:02:18PM Page 6 COMPASS 2003.16 Build 69 Baker Hughes INTEQ rf.I- I ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2F-18 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site: Kuparuk 2F Pad North Reference: True Well: 2F-18 Survey Calculation Method: Minimum Curvature Wellbore: 2F-18L1-01 Design: 2F-18L1-01_wp01 Point 7 0.00 -6,061.01 893.72 5,942,549.57 518,426.78 2F-18L1-01_T07(copy) 0.00 0.00 5,979.00 -8,116.21 911.93 5,940,494.62 518,449.77 70°14'54.933 N 149°51'3.423 W -plan misses target center by 150.30ft at 11408.76ft MD(5980.08 TVD,-8146.05 N,1059.23 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") 1"1 9,140.00 5,783.31 7" 7 8-1/2 13,850.00 6,073.02 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +Nl-S +E/-W (ft) (ft) (ft) (ft) Comment ' 9,550.00 5,999.27 -6,304.69 1,111.58 TIP/KOP 9,635.00 5,991.91 -6,389.21 1,108.92 Start 12 dls 9,713.00 5,978.32 -6,465.43 1,100.16 3 9,793.00 5,970.73 -6,542.93 1,082.23 4 10,093.00 5,968.44 -6,838.88 1,036.65 Start 4 dls 10,243.00 5,979.34 -6,987.83 1,024.44 Start 6 dls 10,343.00 5,990.00 -7,086.91 1,016.69 7 10,443.00 5,993.58 -7,186.78 1,013.48 Start 4 dls 10,593.00 5,993.62 -7,336.65 1,017.85 9 10,793.00 5,985.31 -7,534.39 1,045.47 10 10,918.00 5,975.15 -7,657.50 1,064.37 11 11,043.00 5,970.13 -7,781.81 1,076.05 12 11,393.00 5,979.28 -8,130.53 1,061.83 13 11,743.00 5,995.15 -8,465.46 964.57 14 12,043.00 6,011.68 -8,751.00 875.88 15 12,443.00 6,039.60 -9,148.07 853.06 16 12,643.00 6,049.09 -9,345.46 882.77 17 13,043.00 6,059.64 -9,742.86 913.19 18 13,343.00 6,067.30 -10,041.95 925.60 19 13,543.00 6,070.61 -10,241.17 940.95 20 13,850.00 6,073.02 -10,546.06 910.51 Planned TD at 13850 4/16/2013 5:02:18PM Page 7 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 2F Pad 2F-18 2F-18L1-01 2F-18L1-01_wp01 Travelling Cylinder Report 16 April, 2013 BAKER HUGHES 1 Baker Hughes INTEQ r//iii conocOP inipS Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit TVD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp01 Offset TVD Reference: Offset Datum Reference 2F-18L1-01_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,550.00 to 13,850.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,580.88ft Error Surface: Elliptical Conic Survey Tool Program Date 4/16/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 50.00 5,525.00 2F-18 GyroData(2F-18PB1) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 5,550.00 9,250.00 2F-18 GyroData(2F-18) Copy of GYD-CT-CMS Gyrodata cont.casing m/s 9,250.00 9,550.00 2F-18L1_wp02(2F-18L1) MWD MWD-Standard 9,550.00 13,850.00 2F-18L1-01_wp01(2F-18L1-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 9,140.00 5,921.31 7" 7 8-1/2 13,850.00 6,211.02 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2F Pad 2F-18-2F-18L1-2F-18L1_wp02 9,550.00 9,550.00 0.00 0.36 -0.22 FAIL-Minor 1/10 2F-19-2F-19-2F-19 Out of range 2F-19-2F-19A-2F-19A Out of range 2F-19-2F-19AL1-2F-19AL1 Out of range 2F-19-2F-19AL2-2F-19AL2 Out of range 2F-19-2F-19AL3-2F-19AL3 Out of range 2F-19-2F-19PB1-2F-19PB1 Out of range 2F-19-2F-19PB2-2F-19PB2 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/16/2013 4:18:58PM Page 2 of 7 COMPASS 2003.16 Build 69 QP ! ., I t ! p... , Baker Hughes INTEQ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit TVD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp01 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2F Pad- 2F-18-2F-18L1-2F-18L1_wp02 Offset Site Error: 0.00 fl Survey Program: 50-Copy of GYD-CT-CMS,5550-Copy of GYD-CT-CMS,9250-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth 0N/-S +EI-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) P1 (ft) (ft) (ft) (ft) (ft( (ft) 9,550.00 6,137.27 9550.00 6,137.27 0.00 0.00 -178.20 -8,304.69 1,111.58 0.22 0.00 0.36 -0.22 FAIL-Minor 1/10,CC,ES,SF 9,574.98 6,136.67 9,575.00 6,137.33 0.32 0.04 -16.44 -6,329.67 1,110.58 0.22 0.70 0.61 0.14 Pass-Minor 1/10 9,599.81 6,134.78 9,600.00 6,137.41 0.32 0.08 -16.48 -6,354.63 1,109.14 0.22 2.78 0.69 2.14 Pass-Minor 1/10 9,624.35 6,131.65 9,625.00 6,137.50 0.33 0.13 -16.54 -6,379.56 1,107.28 0.22 6.23 0.74 5.55 Pass-Minor 1/10 9,648.86 6,127.48 9,650.00 8,137.61 0.33 0.19 -13.97 -6,404.45 1,104.95 0.22 10.78 0.77 10.10 Pass-Minor l/10 9,673.64 6,123.15 9,675.00 6,137.73 0.33 0.25 -7.47 -6,429.30 1,102.21 0.22 15.25 0.84 14.59 Pass-Minor l/10 9,698.43 6,118.84 9,700.00 6,137.87 0.33 0.30 0.09 -6,454.09 1,099.04 0.22 19.58 0.93 18.92 Pass-Minor l/10 9,723.62 6,114.80 9,725.00 6,138.02 0.33 0.38 7.07 -6,478.83 1,095.43 0.22 23.78 1.03 23.13 Pass-Minor l/10 9,749.68 6,111.29 9,750.00 8,138.19 0.34 0.45 11.70 -6,503.50 1,091.39 0.22 27.04 1.12 26.47 Pass-Minor 1/10 9,776.00 6,109.30 9,775.00 8,138.37 0.40 0.52 15.69 -6,528.10 1,086.92 0.22 29.12 1.20 28.63 Pass-Minor l/10 9,801.94 6,108.58 9,800.00 6,138.57 0.46 0.80 18.64 -6,552.61 1,082.02 0.22 30.08 1.27 29.45 Pass-Minor 1/10 9,827.01 8,108.19 9,825.00 6,138.78 0.52 0.67 19.10 -8,577.07 1,076.85 0.22 30.75 1.32 30.06 Pass-Minor 1/10 9,852.10 8,107.84 9,850.00 6,138.99 0.59 0.74 19.38 -6,801.80 1,072.03 0.22 31.39 1.36 30.64 Pass-Minor 1/10 9,877.21 8,107.53 9,875.00 6,139.20 0.65 0.82 19.61 -6,626.21 1,067.63 0.22 32.01 1.39 31.19 Pass-Minor 1/10 9,902.33 8,107.25 9,900.00 6,139.41 0.71 0.89 19.81 -6,650.89 1,063.67 0.22 32.60 1.41 31.73 Pass-Minor 1/10 9,927.46 8,107.02 9,925.00 6,139.62 0.79 0.96 19.98 5,875.84 1,060.14 0.22 33.17 1.42 32.23 Pass-Minor 1/10 9,952.61 6,106.82 9,950.00 8,139.83 0.87 1.03 20.12 -6,700.45 1,057.04 0.22 33.72 1.43 32.71 Pass-Minor 1/10 9,977.78 6,106.66 9,975.00 6,140.04 0.96 1.11 20.24 -6,725.30 1,054.38 0.22 34.24 1.43 33.16 Pass-Minor 1/10 10,002.96 6,106.54 10,000.00 6,140.25 1.04 1.18 20.34 -6,750.20 1,052.14 0.22 34.74 1.44 33.60 Pass-Minor l/10 10,028.15 6,106.48 10,025.00 6,140.46 1.14 1.27 20.42 -6,775.14 1,050.35 0.22 35.20 1.44 34.00 Pass-Minor l/10 10,053.36 8,108.42 10,050.00 6,140.67 1.24 1.36 20.49 -6,800.10 1,048.99 0.22 35.65 1.43 34.38 Pass-Minor l/10 10,078.58 8,108.42 10,075.00 6,140.88 1.34 1.45 20.55 -6,825.08 1,048.06 0.22 36.06 1.44 34.75 Pass-Minor 1/10 10,104.01 8,108.52 10,100.00 6,141.08 1.44 1.54 21.43 -6,850.07 1,047.57 0.22 36.43 1.44 35.06 Pass-Minor 1/10 10,129.67 6,107.14 10,125.00 6,141.33 1.55 1.65 24.16 5,875.07 1,047.38 0.22 36.52 1.43 35.10 Pass-Minor 1/10 10,155.30 6,108.39 10,150.00 8,141.81 1.65 1.78 27.08 -6,900.06 1,046.91 0.22 36.30 1.43 34.86 Pass-Minor l/10 10,180.88 8,110.25 10,175.00 8,142.54 1.76 1.88 30.14 -6,925.04 1,046.07 0.22 35.80 1.44 34.36 Pass-Minor 1/10 10,208.40 8,112.72 10,200.00 6,143.52 1.88 1.99 33.41 -8,949.99 1,044.88 0.22 35.01 1.45 33.65 Pass-Minor l/10 10,231.85 6,115.80 10,225.00 6,144.75 2.00 2.12 36.99 -6,974.91 1,043.33 0.22 33.95 1.44 32.83 Pass-Minor l/10 10,256.87 6,119.26 10,250.00 6,146.22 2.11 2.25 39.81 -6,999.79 1,041.42 0.22 32.73 1.42 32.36 Pass-Minor 1/10 10,281.68 8,122.34 10,275.00 6,147.95 224 2.38 40.46 -7,024.63 1,039.16 0.22 31.67 1.42 31.29 Pass-Minor l/10 10,306.53 8,124.97 10,300.00 6,149.92 2.36 2.51 39.19 -7,049.41 1,038.54 0.22 30.72 1.43 30.33 Pass-Minor 1/10 10,331.33 6,127.14 10,325.00 6,152.15 2.50 2.85 35.83 -7,074.14 1,033.57 0.22 29.90 1.44 29.53 Pass-Minor 1/10 10,355.96 6,128.84 10,350.00 6,154.48 2.63 2.79 31.26 -7,098.83 1,030.48 0.22 29.38 1.44 29.01 Pass-Minor 1/10 10,380.51 6,130.13 10,375.00 6,158.84 2.77 2.93 27.11 -7,123.59 1,027.76 0.22 29.31 1.44 28.95 Pass-Minor l/10 10,405.04 6,131.01 10,400.00 6,158.82 2.91 3.07 23.30 -7,148.40 1,025.43 0.22 29.70 1.43 29.18 Pass-Minor l/10 10,429.56 6,131.49 10,425.00 6,160.41 3.05 3.20 19.98 -7,173.26 1,023.49 0.22 30.50 1.42 29.56 Pass-Minor 1/10 10,454.31 6,131.80 10,450.00 6,181.94 3.19 3.35 16.71 -7,198.16 1,021.87 022 31.54 1.42 30.44 Pass-Minor 1/10 10,479.37 8,131.64 10,475.00 8,163.07 3.35 3.50 12.93 -7,223.09 1,020.38 022 32.28 1.42 31.05 Pass-Minor 1/10 10,504.40 6,131.66 10,500.00 6,163.78 3.50 3.66 8.87 -7248.05 1,019.03 022 32.61 1.42 31.30 Pass-Minor 1/10 10,529.39 8,131.67 10,525.00 6,164.07 3.68 3.82 4.45 -7,273.02 1,017.81 0.22 32.62 1.41 31.25 Pass-Minor l/10 10,554.30 8,131.88 10,550.00 8,184.04 3.83 3.98 -0.75 -7,297.98 1,016.58 0.22 32.41 1.40 31.01 Pass-Minor 1/10 10,579.07 8,131.64 10,575.00 6,163.85 3.99 4.14 -7.46 -7,322.93 1,014.91 022 32.27 1.38 30.91 Pass-Minor 1/10 10,603.53 6,131.58 10,600.00 6,183.53 4.16 4.30 -15.54 -7,347.84 1,012.85 022 32.50 1.36 31.64 Pass-Minor l/10 10,627.64 6,131.32 10,625.00 6,163.06 4.34 4.47 -24.51 -7,372.71 1,010.37 022 33.51 1.32 33.17 Pass-Minor 1/10 10,651.53 6,130.84 10,650.00 8,182.45 4.52 4.63 -33.87 -7,397.54 1,007.49 022 35.58 1.28 35.22 Pass-Minor 1/10 10,675.16 6,130.14 10,675.00 6,161.70 4.70 4.80 -42.95 -7,422.31 1,004.19 0.22 38.83 1.22 38.46 Pass-Minor l/10 10,698.52 6,129.22 10,700.00 6,180.81 4.87 4.98 -51.25 -7,447.02 1,000.49 0.22 43.32 1.16 42.92 Pass-Minor l/10 10,721.57 8,128.11 10,725.00 8,159.77 5.06 5.14 -58.55 -7,471.65 996.38 0.22 48.99 1.07 48.57 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/16/2013 4:18:58PM Page 3 of 7 COMPASS 2003.16 Build 69 1 -' Baker Hughes INTEQ IF/Iii Conoco Phillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit TVD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18P61 @ 138.00ft(2F-18PB1) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp01 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2F Pad- 2F-18-2F-18L1-2F-18L1_wp02 Offset Site Error. 0.00 ft Survey Program: 50-Copy of GYD-CT-CMS,5550-Copy of GYD-CT-CMS,9250-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface 4. Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/S 4-El-IN Hole Size Centre Distance Deviation Ift) (ft) Off) (ft) (ff) (ft) Cl (ft) (ft) (ft) (ft) (ft) (ft) 10,744.28 6,126.80 10,750.00 6,158.60 524 5.32 -64.79 -7,49622 991.87 0.22 55.77 0.95 55.31 Pass-Minor 1/10 10,768.64 6,125.31 10,775.00 6,15729 5.42 5.49 -70.09 -7,520.69 986.95 0.22 63.57 0.78 63.08 Pass-Minor 1/10 10,788.61 6,123.66 10,800.00 6,155.83 5.60 5.67 -74.58 -7,545.07 981.63 0.22 72.30 0.52 71.78 Pass-Minor 1/10 10,812.15 6,121.75 10,825.00 6,154.24 5.76 5.85 -76.95 -7,569.36 975.91 0.22 81.67 0.56 81.11 Pass-Minor l/10 10,836.43 6,119.77 10,850.00 6,152.51 5.92 6.02 -78.33 -7,593.60 970.04 022 90.96 0.60 90.36 Pass-Minor l/10 10,881.22 8,117.78 10,875.00 6,150.65 6.08 6.20 -79.15 -7,617.92 964.55 0.22 99.62 0.64 98.98 Pass-Minor l/10 10,886.49 6,115.70 10,900.00 6,148.67 6.24 6.37 -79.58 -7,642.32 959.48 0.22 107.57 0.68 106.89 Pass-Minor 1/10 10,912.22 6,113.62 10,925.00 6,146.56 6.41 6.55 -79.72 -7,686.79 954.82 0.22 114.77 0.72 114.05 Pass-Minor l/10 10,937.87 8,111.68 10,950.00 6,144.33 6.60 8.72 -80.29 -7,691.32 950.58 0.22 121.23 0.75 120.49 Pass-Minor l/10 10,963.07 6,110.16 10,975.00 6,142.24 6.78 6.89 -80.99 -7,715.91 946.54 0.22 127.33 0.78 126.55 Pass-Minor l/10 ' 10,988.54 6,109.06 11,000.00 6,140.59 6.97 7.07 -81.57 -7,740.52 942.50 0.22 133.35 0.81 132.54 Pass-Minor l/10 11,014.08 6,108.38 11,025.00 6,139.38 7.16 7.25 -82.05 -7,765.16 938.45 0.22 139.26 0.84 138.43 Pass-Minor 1/10 11,039.69 6,108.13 11,050.00 6,138.60 7.37 7.42 -82.44 -7,789.82 934.40 0.22 145.07 0.87 144.21 Pass-Minor l/10 11,088.82 8,108.19 11,075.00 6,138.25 7.58 7.60 -82.08 -7,814.49 930.36 0.22 150.67 0.89 149.78 Pass-Minor 1/10 11,094.03 6,108.36 11,100.00 6,138.15 7.80 7.78 -81.48 -7,839.20 926.58 0.22 155.61 0.92 154.69 Pass-Minor l/10 11,121.72 6,108.65 11,125.00 6,138.19 8.02 7.97 -80.77 -7,863.97 923.22 0.22 159.71 0.93 158.78 Pass-Minor l/10 11,149.63 8,109.05 11,150.00 6,138.39 824 8.15 -79.97 -7,888.79 920.26 0.22 162.97 0.94 162.03 Pass-Minor l/10 11,177.73 6,109.56 11,175.00 6,138.73 8.46 8.34 -79.08 -7,913.66 917.70 0.22 165.38 0.98 164.42 Pass-Minor l/10 11,205.95 6,11020 11,200.00 6,139.23 8.69 8.52 -78.12 -7,938.56 915.56 022 166.91 0.97 165.95 Pass-Minor l/10 11,234.25 6,110.95 11,225.00 6,139.87 8.92 8.72 -77.09 -7,963.50 913.82 0.22 167.58 0.96 166.62 Pass-Minor l/10 11,262.55 8,111.81 11,250.00 6,140.66 9.15 8.92 -75.99 -7,988.45 912.50 0.22 167.38 0.96 166.42 Pass-Minor l/10 11,290.82 6,112.79 11,275.00 8,141.60 9.39 9.12 -74.83 -8,013.41 911.58 0.22 166.31 0.95 165.35 Pass-Minor l/10 11,318.99 6,113.88 11,300.00 6,142.69 9.62 9.32 -73.81 -8,038.38 911.08 0.22 164.36 0.94 183.42 Pass-Minor 1/10 11,347.01 6,115.08 11,325.00 6,143.92 9.86 9.53 -72.31 -8,083.35 910.98 0.22 161.56 0.92 160.64 Pass-Minor 1/10 11,374.83 6,116.37 11,350.00 6,145.31 10.09 9.74 -70.95 -8,088.31 911.30 0.22 157.91 0.90 157.01 Pass-Minor 1/10 11,402.36 6,117.76 11,375.00 6,146.83 10.33 9.95 -69.49 -8,113.25 912.02 0.22 153.41 0.87 152.54 Pass-Minor 1/10 11,429.52 6,119.12 11,400.00 6,148.39 10.55 10.17 -67.93 -8,138.18 913.18 0.22 148.07 0.84 147.23 Pass-Minor l/10 11,458.31 8,120.45 11,425.00 6,149.91 10.77 10.39 -66.28 -8,163.08 914.77 0.22 141.88 0.80 141.08 Pass-Minor l/10 11,482.69 8,121.74 11,450.00 6,151.41 10.98 10.61 -64.50 -8,187.95 916.79 0.22 134.88 0.76 134.10 Pass-Minor l/10 11,508.62 6,122.98 11,475.00 6,152.87 11.19 10.84 -62.58 -8,212.79 919.24 0.22 127.05 0.72 126.32 Pass-Minor l/10 11,534.05 6,124.18 11,500.00 6,154.30 11.40 11.06 -60.42 -8,237.58 922.13 0.22 118.46 0.68 117.79 Pass-Minor l/10 11,558.95 6,125.33 11,525.00 8,155.69 11.81 11.30 -58.00 -8,262.32 925.45 0.22 109.18 0.63 108.53 Pass-Minor l/10 11,583.29 6,126.43 11,550.00 6,157.05 11.81 11.53 -55.19 -8,287.00 929.21 0.22 99.19 0.58 98.61 Pass-Minor l/10 11,607.03 8,127.49 11,575.00 6,158.38 12.01 11.77 -51.82 -8,311.61 933.39 0.22 88.62 0.53 88.09 Pass-Minor l/10 ' 11,830.14 8,128.50 11,800.00 6,159.68 12.20 12.00 -47.60 -8,338.15 938.00 022 77.58 0.48 77.10 Pass-Minor l/10 11,652.62 6,129.46 11,625.00 6,160.94 12.38 12.24 -42.02 -8,360.60 943.03 0.22 66.25 0.43 65.82 Pass-Minor l/10 11,674.44 6,130.38 11,650.00 6,162.17 12.56 12.48 -34.18 -8,384.97 948.50 0.22 54.97 0.38 54.58 Pass-Minor l/10 11,695.59 6,131.25 11,675.00 6,163.36 12.74 12.72 -22.40 -8,409.24 954.37 0.22 44.45 0.35 44.10 Pass-Minor 1/10 11,716.40 6,132.09 11,700.00 6,164.57 12.91 12.96 -4.66 -8,433.54 960.10 0.22 36.42 0.33 36.10 Pass-Minor l/10 11,737.04 6,132.91 11,725.00 6,165.84 13.08 13.20 19.17 -8,457.94 965.40 0.22 33.03 0.34 32.70 Pass-Minor l/10 11,757.84 6,133.74 11,750.00 6,167.18 13.25 13.43 42.14 -8,482.42 970.28 0.22 35.50 0.38 35.14 Pass-Minor l/10 11,779.29 6,134.64 11,775.00 6,168.54 13.42 13.67 58.45 -8,506.98 974.74 0.22 42.32 0.42 41.91 Pass-Minor1/10 11,801.38 6,135.61 11,800.00 6,169.96 13.60 13.91 68.75 -8,531.62 978.77 0.22 51.26 0.46 50.80 Pass-Minor l/10 11,824.08 6,136.67 11,825.00 6,171.44 13.78 14.15 75.16 -8,556.31 982.37 0.22 80.95 0.50 60.45 Pass-Minor l/10 11,847.38 6,137.82 11,850.00 6,172.96 13.96 14.39 79.21 -8,581.06 985.53 0.22 70.70 0.55 70.16 Pass-Minor 1/10 11,871.25 6,139.05 11,875.00 6,174.54 14.15 14.64 81.80 -8,605.88 98827 0.22 80.16 0.59 79.58 Pass-Minor l/10 11,895.87 6,140.37 11,900.00 6,176.17 14.34 14.88 83.43 -8,630.70 990.58 0.22 89.14 0.63 88.50 Pass-Minor 1/10 11,920.59 6,141.79 11,925.00 6,177.84 14.55 15.13 84.42 -8,655.57 992.45 022 97.50 0.67 96.84 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/16/2013 4:18:58PM Page 4 of 7 COMPASS 2003.16 Build 69 Oi ! (' '?;S Baker Hughes INTEQ FS it ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit TVD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp01 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2F Pad- 2F-18-2F-18L1-2F-18L1_wp02 Offset Site Error: 0.00 ft Survey Program: 50-Copy of GYD-CT-CMS,5550-Copy of GYD-CT-CMS,9250-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth ON/-S +E/-W Hole Size Centre Distance Deviation lft) (ft) (ft) (ft) (ft) (ft) (') (ft) (ff) (ft) (ft) (ft) (n) 11,946.00 6,143.30 11,950.00 6,179.56 14.77 15.38 84.95 -8,680.47 993.90 0.22 105.19 0.70 104.49 Pass-Minor 1/10 11,971.84 6,144.90 11,975.00 6,181.34 15.00 15.62 85.13 -8,705.39 994.90 0.22 112.14 0.73 111.41 Pass-Minorl/10 11,998.07 6,146.60 12,000.00 6,183.16 15.22 15.87 85.05 -8,730.32 995.48 0.22 118.31 0.77 117.55 Pass-Minor 1/10 12,024.66 6,148.40 12,025.00 6,185.02 15.46 16.13 84.77 -8,755.24 995.62 0.22 123.68 0.79 122.89 Pass-Minor l/10 12,051.53 6,150.28 12,050.00 6,186.94 15.71 16.38 84.31 -8,780.17 995.33 0.22 128.21 0.81 127.41 Pass-Minor l/10 12,078.60 6,152.20 12,075.00 6,188.89 15.97 16.63 83.69 -8,805.08 994.60 0.22 131.91 0.82 131.09 Pass-Minor 1/10 12,105.87 6,154.12 12,100.00 8,190.90 16.23 16.88 82.91 -8,829.97 993.44 0.22 134.76 0.84 133.93 Pass-Minor 1/10 12,133.28 6,156.06 12,125.00 8,192.95 16.51 17.13 82.00 -8,854.84 991.85 0.22 136.75 0.84 135.92 Pass-Minor 1/10 12,160.80 6,158.00 12,150.00 6,195.04 16.78 17.39 80.96 -8,879.67 989.82 0.22 137.88 0.84 137.04 Pass-Minor 1/10 12,188.34 6,159.94 12,175.00 6,197.17 17.06 17.64 79.81 -8,904.46 987.38 0.22 138.15 0.84 137.31 Pass-Minor 1/10 12,215.89 6,161.88 12,200.00 6,199.27 17.34 17.89 78.62 -8,929.26 985.08 0.22 138.09 0.84 137.25 Pass-Minor l/10 12,243.44 6,163.81 12,225.00 6,201.29 17.63 18.14 77.47 -8,954.11 983.21 0.22 137.96 0.63 137.13 Pass-Minor 1/10 12,270.98 6,165.73 12,250.00 6,203.24 17.91 18.39 76.33 -8,978.99 981.76 0.22 137.76 0.83 136.93 Pass-Minor 1/10 12,298.51 6,167.65 12,275.00 8,205.10 18.20 18.64 75.22 -9,003.90 980.75 0.22 137.49 0.82 136.87 Pass-Minor 1/10 12,326.04 6,169.57 12,300.00 6,206.89 18.49 18.89 74.13 -9,028.83 980.18 0.22 137.16 0.81 136.35 Pass-Minor 1/10 12,353.56 6,171.47 12,325.00 6,208.60 18.78 19.15 73.06 -9,053.77 980.01 0.22 136.75 0.80 135.95 Pass-Minor 1/10 12,381.06 6,173.37 12,350.00 6,210.23 19.06 19.41 72.02 -9,078.71 980.28 0.22 138.28 0.79 135.49 Pass-Minor l/10 12,408.58 8,175.25 12,375.00 6,211.79 19.35 19.67 71.00 -9,103.66 980.96 0.22 135.72 0.78 134.94 Pass-Minor l/10 12,436.01 6,177.13 12,400.00 6,213.25 19.64 19.93 69.94 -9,128.61 981.50 0.22 134.55 0.77 133.78 Pass-Minor l/10 12,463.13 8,178.93 12,425.00 6,214.62 19.93 20.19 68.84 -9,153.57 981.62 0.22 132.49 0.75 131.74 Pass-Minor l/10 12,490.02 6,180.57 12,450.00 8,215.90 20.21 20.46 67.62 -9,178.53 981.31 0.22 129.61 0.73 128.88 Pass-Minor 1/10 12,518.73 6,182.06 12,475.00 6,217.09 20.50 20.72 66.27 -9,203.49 980.57 0.22 125.92 0.71 125.21 Pass-Minor l/10 12,543.19 6,183.39 12,500.00 6,218.19 20.78 20.99 64.78 -9,228.44 979.41 0.22 121.42 0.68 120.74 Pass-Minor l/10 12,569.37 6,184.56 12,525.00 6,219.20 21.06 21.25 83.06 -9,253.37 977.82 0.22 116.13 0.64 115.49 Pass-Minor l/10 12,595.23 6,185.58 12,550.00 6,220.11 21.34 21.52 61.15 -9,278.27 975.80 0.22 110.09 0.61 109.48 Pass-Minor l/10 12,620.71 6,188.44 12,575.00 8,220.93 21.62 21.78 58.96 -9,303.14 973.36 0.22 103.32 0.58 102.74 Pass-Minor l/10 12,645.49 6,187.16 12,600.00 6,221.85 21.89 22.05 56.62 -9,327.96 970.49 0.22 95.87 0.54 95.32 Pass-Minor l/10 12,667.75 6,187.75 12,625.00 6,22229 22.13 22.31 55.54 -9,352.74 967.21 0.22 88.17 0.52 87.86 Pass-Minor l/10 12,690.11 6,188.35 12,650.00 6,222.82 22.38 22.58 54.15 -9,377.46 963.50 0.22 80.53 0.49 80.04 Pass-Minor l/10 12,712.59 6,188.95 12,675.00 8,223.27 22.60 22.85 52.34 -9,402.11 959.37 0.22 72.97 0.47 72.51 Pass-Minor 1/10 12,735.19 6,189.55 12,700.00 6,223.85 22.83 23.11 49.95 -9,426.89 954.81 0.22 65.55 0.44 65.11 Pass-Minor 1/10 12,757.90 6,190.16 12,725.00 8,223.99 23.06 23.37 46.76 -9,451.18 949.83 0.22 58.34 0.41 57.93 Pass-Minor 1/10 12,780.72 6,190.77 12,750.00 6,224.28 23.29 23.64 42.47 -9,475.59 944.42 0.22 51.45 0.39 51.07 Pass-Minor 1/10 12,803.67 6,191.38 12,775.00 6,224.53 23.53 23.90 36.66 -9,499.90 938.59 0.22 45.08 0.36 44.70 Pass-Minor 1/10 12,828.74 6,191.99 12,800.00 6,224.73 23.77 24.17 28.81 -9,524.10 932.34 0.22 39.43 0.35 39.08 Pass-Minor l/10 12,849.93 6,192.60 12,825,00 6,224.88 24.01 24.43 18.40 -9,548.19 925.67 0.22 34.95 0.34 34.62 Pass-Minor l/10 12,873.25 6,193.22 12,850.00 6,224.99 24.26 24.70 5.37 -9,572.17 918.58 0.22 32.14 0.33 31.81 Pass-Minor 1/10 12,896.71 6,193.84 12,875.00 6,225.05 24.50 24.96 -9.25 -9,596.02 911.09 022 31.46 0.34 31.12 Pass-Minor 1/10 12,920.49 6,194.46 12,900.00 8,225.10 24.75 25.22 -22.55 -9,619.92 903.75 0.22 32.89 0.35 32.54 Pass-Minor 1/10 12,944.67 6,195.09 12,925.00 8,225.14 25.01 25.47 -32.88 -9,643.94 896.82 0.22 35.67 0.37 35.31 Pass-Minor 1/10 12,989.20 6,195.73 12,950.00 6,225.19 25.27 25.73 -40.36 -9,688.08 890.31 0.22 39.06 0.38 38.68 Pass-Minor 1/10 12,994.05 6,196.38 12,975.00 6,225.24 25.53 25.99 -45.60 -9,692.32 884.23 0.22 42.54 0.40 42.14 Pass-Minor 1/10 13,019.18 8,197.03 13,000.00 8,225.28 25.80 26.26 -49.19 -9,716.67 878.57 0.22 45.77 0.42 45.35 Pass-Minor l/10 13,044.48 6,197.68 13,025.00 8,225.33 26.07 26.61 -51.69 -9,741.12 873.34 0.22 48.53 0.43 48.10 Pass-Minor l/10 13,068.51 6,198.30 13,050.00 6,225.38 26.33 27.01 -55.39 -9,765.65 868.53 022 51.12 0.45 50.67 Pass-Minor 1/10 13,092.50 6,198.92 13,075.00 6,225.42 26.60 27.45 -58.82 -9,790.27 864.15 0.22 53.79 0.47 53.32 Pass-Minor 1/10 13,116.45 6,199.53 13,100.00 6,225.47 26.86 27.94 -61.99 -9,814.95 860.20 0.22 56.54 0.49 56.05 Pass-Minor l/10 13,140.34 6,200.14 13,125.00 6,225.52 27.13 28.28 -64.95 -9,839.70 856.69 0.22 59.35 0.51 58.84 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/16/2013 4:18:58PM Page 5 of 7 COMPASS 2003.16 Build 69 `- Baker Hughes INTEQ Elk, ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit TVD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp01 Offset TVD Reference: Offset Datum Offset Design Kuparuk 2F Pad- 2F-18-2F-18L1-2F-18L1_wp02 Offset site Error: 0.00 ft Survey Program: 50-Copy of GYD-CT-CMS,5550-Copy of GYD•CT•CMS,9250-MWD Rule Assigned:Minor 1/10 Offset Well Error. 0.00 fl Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation lft) Iffl Iffl OH ON lffl Ii (ft) Iff) Iffl Iffl lffl Iff) 13,164.17 6,200.75 13,150.00 6,225.56 27.40 28.62 -67.71 -9,884.51 853.60 0.22 62.21 0.52 61.69 Pass-Minor l/10 13,187.96 8,201.36 13,175.00 6,225.61 27.67 28.96 -70.30 -9,889.37 850.95 0.22 65.11 0.54 64.57 Pass-Minor 1/10 13,211.70 6,201.97 13,200.00 8,225.66 27.94 29.31 -72.74 -9,914.27 848.73 0.22 68.04 0.56 67.47 Pass-Minor 1/10 13,235.38 6,202.57 13,225.00 8,225.70 28.21 29.61 -75.05 -9,939.21 848.95 0.22 70.99 0.58 70.40 Pass-Minor 1/10 13,259.02 6,203.17 13,250.00 6,225.75 28.48 29.91 -77.24 -9,984.17 845.61 0.22 73.95 0.60 73.35 Pass-Minor 1/10 13,282.60 6,203.77 13,275.00 6,225.78 28.76 30.21 -79.33 -9,989.15 844.69 0.22 76.93 0.62 76.32 Pass-Minor 1/10 13,30629 6,204.37 13,300.00 6,225.38 29.03 30.50 -8129 -10,014.14 843.91 0.22 80.08 0.63 79.45 Pass-Minor l/10 13,329.42 6,204.95 13,325.00 6,224.32 29.30 30.79 -84.42 -10,039.10 843.14 0.22 83.51 0.85 82.88 Pass-Minor 1/10 13,353.77 8,205.58 13,350.00 8,222.60 29.58 31.09 -86.68 -10,064.03 842.37 022 87.21 027 86.53 Pass-Minor l/10 13,379.82 8,206.18 13,375.00 8,220.24 29.87 31.39 -87.98 -10,088.91 841.60 022 9021 029 89.93 Pass-Minor l/10 13,40524 6,206.71 13,400.00 6,21722 30.17 31.68 -89.43 -10,113.71 84023 0.22 93.64 0.70 92.94 Pass-Minor l/10 13,432.10 6,20720 13,425.00 6,213,56 30.45 31.97 -91.05 -10,138.43 840.08 0.22 96.33 0.71 95.63 Pass-Minor l/10 13,45827 6,20722 13,450.00 6,20925 30.74 32.27 -92.86 -10,163.04 839.30 0.22 98.75 0.72 98.04 Pass-Minor l/10 13,484.42 8,207.99 13,475.00 8,204.30 31.03 32.56 -94.88 -10,187.53 838.54 022 100.96 0.73 10026 Pass-Minor l/10 13,510.51 6,208.30 13,500.00 6,198.70 31.31 32.85 -97.07 -10,211.89 837.79 022 103.05 0.73 102.35 Pass-Minor 1/10 13,536.52 6,208.55 13,525.00 6,192.47 31.60 33.13 -99.50 -10,236.09 837.04 0.22 105.10 0.74 104.41 Pass-Minor 1/10 13,56227 6,208.76 13,550.00 6,18521 31.89 33.42 -102.13 -10,260.11 836.30 0.22 107.20 0.74 106.53 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/16/2013 4:18:58PM Page 6 of 7 COMPASS 2003.16 Build 69 Baker Hughes INTEQ Ira" ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2F-18 Project: Kuparuk River Unit TVD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Reference Site: Kuparuk 2F Pad MD Reference: 2F-18PB1 @ 138.00ft(2F-18PB1) Site Error: 0.00ft North Reference: True Reference Well: 2F-18 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2F-18L1-01 Database: EDM Alaska Prod v16 Reference Design: 2F-18L1-01_wp01 Offset TVD Reference: Offset Datum Reference Depths are relative to 2F-18PB1 @ 138.00ft(2F-18PB1) Coordinates are relative to:2F-18 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is 0.13° Ladder Plot 180 - . 1 I 135— C 0 2 I (B J Il] 1 cu m co N w 90 U 0 2 J cu U LLLl11JJJ 45— 11 I r4 Pm LI- III 0 I I I 0 2500 5000 7500 10000 12500 15000 Measured Depth LEGEND -a- 2F-18,2F-18L1,2F 18L1_wp02V0 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 4/16/2013 4:18•58PM Page 7 of 7 COMPASS 2003.16 Build 69 ORIGIP0A1 s` f � L II h s ►V '" e g `W g w h A °° - 7.1 w o M ry $ N ',al m $ M e� 4 N 1, 8 �I i tzt- - ." — - o I� a , I N s III I ' 1 1 0 enV nl 4 8 i2 C III I, 0. , ' I �. I _ °,E Irl F 8 O VIII /� -_-_ vOi w �'b6L . m ' I I. F. TO_ioi N I .$v g I I w - U 2 N e c. ` I S'• h Fr 1 rI �+I . �I • 4 4 q q 4 I Q FI FI o 0 g m O d.W G O N O. O N IL Le a H N N A `/ J D a O O▪ 82 i vdi 8 d 8 v°, 8 8 .°n 2 8 8 --- - 8 O Ill m . (pjn o5�)(+)INOI1/(-)mnoS ffiI g iC II a 4 Q ZI 2 CID I WI ul rmi ~_I .2 ° $ Z a� 4Fo o g a5MaNE 5 ° d Na' Z.' — 8 4l p __ fI g O >m8.,•-cc F-F- �Fr Pa o ,w„ 4 ZN '.° 88888888888888$888888S , g S P L. riLL o� ± oos0rRm� � BS��i`°R�NB�°°5 �:� - n } 4 2 2 --- CI.n°ro� x'888888888888888888888 €I U.U. oo v,ri CO vvvv vva evvc -- e N ^' Y Y N �- __i m __ _ Z '52=e Qr {�..361°�"'iM4f24mv�380;488 °�S IT, — a. - 9 a`NTO o-"P -' �°OOOOOOOg So82%mw8rnrn3» I_�I m r y N b N J p _ E ti Wo? '4' 'qtr��`� cq oq o o0 c o � o Q Y° ■AA" /' . o z� / ... 56-g gg-7 2SliITA SSg°vM PMER morn Sim mom 8.g m°'mmE`o o"'ogffio°iom h CL 8 0888888888888888888888 :IA r 2 °g 8 2G Pwri ees eeen 11 (UY1J OS 0 trICIOCI U3 110A Dm! ti i TRANSMITTAL LETTER CHECKLIST WELL NAME K R 2F- I$L j - 0 PTD# 30S3 V Development Service Exploratory Stratigraphic Test Non-Conventional r Well I/ ;� FIELD: l<u1/41304b„.)( 1�i JET POOL: XL. . J lRi J��T 14 J A . I-�;��t � 1 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well i()), - (If last two digits in permit No. API number are 1 / 7-6 ,API No. 50-029 - ab. between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 111 To u) 0 — a) 0 a a 0 u, T 2 0 N 0 a) 3 c .° @ rn a) rn N C @ C a). Q 0 To a) Q -e 0, L a) n u > n a) O C C U @ _ O C M -c° a) O v @ 'co- a) a.) E a CD > O .� 0- g = o 0 w c c`6 N w 3 o a a) O m o c a Q 0 E O aa)a) -00 3 0) ° a) c 'c °_ M 3 a U m L 3 0 3 o T C 3 F ° = a) -0 0 0 ° aa) 40 c = c co c o T Q co E ai, Ut n° c 3 O.O _n — O C @ 2 L u) E a > .N N j '-• CI_ 0) C 0 O co > n N > 0 00 n v 3 ° X w : o E Lu a). N F -) O Cr @ 3 j 2 0 V. N Q u) H CO O U N N a 2 7 > O. 2 n N. 0 N N m „ W E N @ O M - a Y n c ° O ° > O O) @ O LI- 0 E O m (0 N O) ° a' C N l0 M N >, 0 a) aa) 'y N 0 N C ai a< d Q N .0 lL ,= @ co N y E N X 0 D 0 N Y a = '°t M E. 2 2 a) -0 .@ d 0' Y c m o Et = m 3 Q. n `* .� 2 n m. m c 2 co a, co 3 LL C 0 E C v) N Z w '(n N d a .° O �, c u c c m a) cry) a) a a)co ai o ,) -, -- o @ = u, 'gin N - a) c n rn 0 ti a a) as E N LU . D 0 0 a) o co U O in T o N N a 0)j CO O N U w N N `O a) a) O co @ � a) ° m — a E U a) 0 Jo D d = -c `C 0 L 'x E u) � w n rn z o tY D O O a) o = C 2 o) 2 o a N a) x 'N a) w < . 00 0 u) u) d C d LL 2 I 5 w = 3 a w 0 Q Q a) co a) a) a) a) aa)) a0) aa)) a0) aa)) aa)) Q Q Q Q Q Q Q O a) a) Q a) Q a) au)) a) a) a) a) Q 0 a) Q Q Q a z z >- >- >- >- >- >- >- >- >- >- >- >- z z z z z z z z >- >- z >- z >- >- >- >- >- >- Z z >- Z z z T r o a) N v @ w _ T 0 @ C U u) 0 C ° a) a) F. 2 3 - 2 a) O 0 0 j 0 N N C I$ V o_ O O o 0y O w T Z u, C E O ' Q C L O a E # ° c >, o a`) m 3 E 3 0 O a M .N U O o > _ 0 c Z o Et C '` @ a E a) Lp' Y 0 O a) m o E ° (C�,, 0.' N "C O '� O a) 0 0. (6 O LL 0 X a) v♦ Y c N Ihuti Hit @ i T o E o Vs N _(0 @ C > a) N LL cr) o a ° n 0 a) F Ca °) o m T d) 0 a o 06 E a) m '5 o M O 7 co w 2 ct o O ._ L O U > N @ c 3 u) c co L c N 7 7 Q co N a) a) O) .. Z _ -o o E a o a) c -o @ a) 0 D o c a) m o a o a) N a N c a) c O 0 M E E _ °o c c E @ m o c c u) > ac o C' a) c N r rn n o -!°: a c u Q 6 c a 0 c o a) 0 a o w, Q Q o o `° a ° @ m o o p m 7 �j 'n n o a� d a 3 > Y CL Q O °O a) a) .5 >, 0 c 7 ° a co Y c6 2 O o > CO 0 2 (6 '@ f6 Q (6 - co "T o O) O. N, C y.,`!.: Y Q E C 'c a as co @ o. n C L L -_0a cc6 m -0 m f6 ` •c c a) a co 0 'cn 0 L o aa.) o n 3 0 c E. >, 3 C o -- o w o a) ° N — c 3 .3 > a a) .. -a u, '0 a o m '- O n o 0 a ._ u, 0 3 Cl) m a) o LL a 0 a c > a > > o v a) o n n = @ o r Z U ° c o c ° ° > o o n a Q o o o 0 0 0 o c CT o u) a a) @ 0 m c a n co a) ° a @ a) CO O a) o 0 _ a) o E a) E L 0 o a) > C c.o J O Cl) d 0 -° O. Q () — a) n u) u) n E V a) n OL o a) a a) ,- .2 a @ 2 g O N :.. N c O C O -O 2 u) O @ E @ O O @ a) @ n cn N @ L C g n 7 co @ V) @ .Q •N O T a 3 2 -C .co 0 N O O. @ N d a) c .S a s N > N a) a) 0 3 E C m cr 0. a) c c m — Q a w L.C. , 7 0 0 a) a.) T _::-= a) w O @ .0 - a a a 0 C @ L -0 L a L a) N - a a > co c L a) N a u) • 0 a) C @ C E U a°i a) 2 a) @ o L c c .3 c @ @@ o a�i = 3 0 c o o@ c a C o LI c O > a) C 3@@ ca c @@ E@ 0 0 = a) a @ = c o co Z c C a) 0 0 0 a) @ 0 0 0 0 0 0 u) 0 0 a) o o - m@ o@ t C N n E '3 a) 'C .0 `) 0 a C�a)(n 0 0 E a) O o O O -- -� @ c6 n O N n -0 N > > 3 C 7r 41 Q a) C w w 1 Y a) L n E Q w6 ai tO >, 0 Cl)` ai 'C ° ° ° m o a) a) a) a`) co c 0 3 2 0 = 2 2 ca -o @ -o a c 0 0 t 0 ° aai Cl) co as Cl) a) 0 0 V @zw _1 D � � � 0) • OOaaU ¢ a U <nUUUUQttQ4- ommU ,2 2 aocncn0 W n r Co N M V Ln O Co O) Co N Co V LO (D r CO O) Co N Co V LU (0 r Co 0) I EO .- N CO V CO N- CO 0) �- ,- N N N N N N N N N N Co Co Co Co Co Co Co Co Co Co M co co C� a, G Co C '-' Co w N "' N (? 0 Ce CO 0 CO CI co a. OM r@~-. V C V V N E ,�, N N >+ J N -- C c O o r 3 o f a s •c 0 ; 0 a s U CL s a w a 0 a