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219-012
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KER � I Date: 1 HUGHES August 12, 2019 1 aGEcompany BE Abby Bell AOGCC 333 West 7`h Ave, Suite 100 Anchorage, Alaska 99501 219012 3109 1 Letter of Transmittal Harvey Finch Baker Hughes, a GE Company 795 East 94`h Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1J-10UP62 1C -19L1 1R-101 RECEIVED AUG 13 2019 AOGCC (3) Total print 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 return mail. 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Well Status: oil El Gas❑ SPLUG❑ Other ❑ Abandoned El Suspended [21 20AAC 25.105 20AAC25.110 GINJ❑ WINJ❑ WAG❑ WDSPL❑ No. of Completions: 1b. Well Class: Development ❑O Exploratory ❑ Service E] Stratigraphic Test E] 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp.onp--Ior Abend.: 6/20/2019 14. Permit to Drill Number / Sundry: 219-012 3. Address: P.O. Box 100360 Anchorage, AK 99510.0360 7. Date Spudded: 2/16/2019 15. API Number: 50-029.23010.60-00 4a. Location of Well (Governmental Section): Surface: 1996' FSL, 2536' FEL, Sec 35, Tll N, R10E, UM ' Top of Productive Interval: NIA Total Depth: 4914' FNL, 4103' FEL, Sec 27, T11N, R10E, UM 8. Date TD Reached: 2/15/2019 16. Well Name and Number: KRU 1J-101-1/1.110-L1P81 9. Ref Elevations: KB:114 GL:79 - BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: N/A 18, Property D nation: A 25661 - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558673 • y- 5945808 • Zone- 4 TPI: x- N/A y- N/A Zone- 4 Total Depth: x- 551795 y- 5949407 Zone- 4 11. Total Depth MD/TVD: . 1036216021 • 19, DNR Approval Number: , ,/y LONS 83-137 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1566/1520 5. Directional or Inclination Survey: Yes 2 (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: • 10283/5975 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, 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 if necessary NIA 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVDAMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 91.5 H40 35 120 35 120 24 460 sx ASI 9.625 40 L-80 34 6945 34 3995 12.25 741sx AS Lite & 488sx UteCrete 7 16 L-80 32 10231 32 5944 8.5 178sx Class G 4.5 12.6 L-80 9967 10843 6325 6.125 127sx Class G 24. Open to production or injection? Yes ❑ No ❑v . If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): TE R26(1 U „ IFI D 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD1TVD) 4.5 9979 9985/5798 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No ❑r Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: NIA Method of Operation (Flowing, gas lift, etc.): UNABLE TO COMPLETE DRILL Date of Test: - Hours Tested: - Production for Test Period Oil -Bbl: - Gas -MCF: - Water -Bbl: - Choke Size: - Gas -Oil Ratio: Flow Tubing Press. Casino Press: Calculated 24 -Hour Rate Oil-Bbl:Gas-MCF: Water -Bbl: - Oil Gravity - API(cord: - Form 10-407 Revised 5/2017 VTL 1013119 CONT /N ED ON PAGE 2 RBDMS2`4JUL 3 1 10bmit ORI I IIAA_L or 28. CORE DATA Conventional Core(s): Yes ❑ No 21 . Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, Fromlro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A information, including reports, per 20 AAC 25.071. Formation @ TPI - Kalubik Shale 10283 • 5975 Formation at total depth: Kalubik Shale 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolog cal report. production or well test results. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: R an McLaughlin Authorized Title: St Engineer Contact Email: R an.McLau hlin co .com Authorized Contact Phone: 265-6218 a9�s Signature: Date: INSTRUCTIONS General: This forth and the required attachments provide a complete and concise record for each well drilled 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Ahernating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Winston, Hugh E (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Wednesday, July 31, 2019 2:13 PM To: Winston, Hugh E (CED) Subject: RE: [EXTERNAL]KRU 1J-101-1 Well Completion Report PTD# 219-012 Huey, No logging was done during drilling. We utilized a liner drilling BHA for this project which did not have a -line capabilities. Ryan From: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Sent: Wednesday, July 31, 2019 10:53 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1J-101-1 Well Completion Report PTD# 219-012 Hi Ryan, I've received the revised 10-407 for this well. Thank you for making the changes, although the logs are still absent. Was there any logging done during the drilling that occurred? Huey From: Winston, Hugh E (CED) Sent: Friday, July 26, 2019 11:44 AM To: McLaughlin, Ryan <Rvan.McLaughlin@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1J-101.1 Well Completion Report PTD# 219-012 Hi Ryan, Please change the status on the 30-407 to suspended since this is not an open to production oil well. Additionally could you please provide a list of the logs that were run during drilling and any formations that were encountered. These would go in boxes 22 and 29 respectively. Also just one more minor error. The Township for the total depth in box 4a should be 11 rather than 11 believe. If you could make these changes and re -submit a signed copy I would really appreciate it. Thanks HueV Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907-793-1241 Winston, Hugh E (CED) From: Winston, Hugh E (CED) Sent: Friday, July 26, 2019 11:44 AM To: McLaughlin, Ryan Subject: RE: [EXTERNAL]KRU 1J-101-1 Well Completion Report PTD# 219-012 Hi Ryan, Please change the status on the 10-407 to suspended since this is not an open to production oil well. Additionally could you please provide a list of the logs that were run during drilling and any formations that were encountered. These would go in boxes 22 and 29 respectively. Also just one more minor error. The Township for the total depth in box 4a should be 11 rather than 1 I believe. If you could make these changes and re -submit a signed copy I would really appreciate it. Thanks Huev Winston Statistical Technician Alaska Oil and Gas Conservation Commission hugh.winston@alaska.gov 907-793-1241 From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Thursday, July 25, 2019 9:03 AM To: Winston, Hugh E (CED) <hugh.winston@alaska.gov> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Ohlinger, James J <James.J.Ohlinger@conocophiliips.com>; Starck, Kai <Kai.Starck@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1J -10L1 Well Completion Report PTD# 219-012 Huey, The CTD project on this well was not able to be completed to scope due to a stuck BHA and the L1-01,-02,-03 laterals were unable to be attempted. There are plans in the future to do diagnostic work on this well and that is why we did not mark suspended in box la. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Winston, Hugh E (CED) <hugh.winston(aalaska.eov> Sent: Tuesday, July 23, 2019 2:32 PM To: McLaughlin, Ryan <Ryan McLaughlin@conocophillips.com> Cc: Loepp, Victoria T (CED) <victoria.loeppC@alaska.aov> Subject: [EXTERNAL]KRU 11-101-1 Well Completion Report PTD# 219-012 Hi Ryan, I've just received the 10-407 for this well but it appears from the notes on the form and some missing information that the well was not completed. If that's the case I believe the current status marked in box la should either be P&A or Suspended. Is there a plan to complete this well in the future? Huey Winston Statistical Technician Alaska Oil and Gas Conservation Commission hueh.winston@alaska.¢ov 907-793-1241 STATE OF ALASKA ALASKA & AND GAS CONSERVATION COMMISSI "�I WELL COMPLETIOIORyRECOMPLETION RE' RT AND LOG 1a. Well Status: oil Gas❑ SPLUG ❑ Other ElAbandoned Ll Suspended &a 20MC 25.105 20MC 25110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp.us , or Aband.: /20/2019 14. Permit to Drill Number / Sundry: 219-012 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 2115/2019 15. API Number: 60-029-23010-60-00 4a. Location of Well (Governmental Section): Surface: 1996' FSL, 2536' FEL, Sec 36, T11N, R10E, UM Top of Productive Interval: N/A He„-, Total Depth: Tit* 4914' FNL, 4103' FEL, Sec 27, Tod, R10E, UM 8. Date TO Reached: 2/15/2019 16. Well Name and Number: IT/O-L/P KRU A44964/1J10-L1P61 9. Ref Elevations: K13:1114 GL:79 BF: 17. Field / Pool(s): Kuparuk River FieldlKuparuk Oil Pool 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 2660, ADL 25661 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558673 y- 5945808 Zone- 4 TPI: x- N/A y- NIA Zone- 4 Total Depth: x- 551795 y- 5949407 Zone- 4 11. Total Depth MD/TVD: 10362/6021 19. DNR Approval Number: LONS 83-137 12. SSSV Depth MD1TVD: N/A 20. Thickness of Permafrost MD/TVD: 1586/1520 5. Directional or Inclination Survey: Yes ❑D (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 1028315975 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, 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 if necessary 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20 91.5 H-40 35 120 35 120 24 460 sx ASI 9.625 40 L-80 34 6945 34 3995 12.25 741sx AS L8e & 488$x LkeCrets 7 16 L-80 32 10231 32 5944 8.5 178sx Class G 4.5 12.6 L-80 9967 10843 6325 6.125 127sx Class G 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SVS' D TE & 7,0 Z09 VE IFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4.5 9979 1 9985/5798 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑r Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): UNABLE TO COMPLETE DRILL Date of Test: - Hours Tested: - Production for Test Period Oil -Bbl: - Gas -MCF: - Water -Bbl: - Choke Size: I - Gas -Oil Ratio: I - Flow Tubing Press. Casino Press: lCalculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: - Oil Gravity- API (corr): I - 2 V1'_ Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 R MS / JUL 2 6 2019 Submit ORIGINAL only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, Fromrro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A information, including reports, per 20 AAC 25.071. Formation @ TPI - Formation at total depth: Kalubik Shale 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, oaleontolooical report, oroduction or well test results, per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: k&' S%eq?Ir' lL Contact Name: Ryan McLaughlin Authorized Title: Staff CTD Engineer Contact Email: Ryan.McLaughlinifiloop.com Authorized Contact Phone: 265-6218 +7 Signature: Date: T -'ZZ - ` INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: 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. Item 30: 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. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1J-10 Proposed CTD Schematic 0" 91.56 H40 shoe @ 120 -MD 9.518" 400 L40 (shoe @ 6945' MD T" 266 L40 shoe ®10231' MD KOP® 10,203 MD FG send pads 10446' • 10 SS' MD 4-U2" 12.66 L -BO shoe ®10,843' MD 3-112" Crocco DM nipple @ 508' MD (3.8]5" min ID) 4-1R" 12.60 IDT EUE BM Tubing to surface 4-112" ce. gas lift mandels @ 4-1R" Camoo DB binding nipple ® 9933' MD (milled 3.87" min ID) Baker4-42"GBH-22 Locator Baker Seal assembly ® 9980' MO (3.958" IDI Baker Packer& Tie -Back Sleeve Baker ZXP Liner Top Pecker ® 9985' MD (4.438" ID) Baker Liner Hanger Comm DNlpple @ 10,325' MD milled 3 SP" ID) FISH ® -10,400' MD: Ped Gun Otis XN-Nipple @ 10,521' MD pi 3]25" ID) ConocoPPhillips KUP PROD WELLNAME IJ -10 RIVER UNIT NIPPLE WELLBORE U-10 1I-10.Trmmlem'.mm7ry Last Tag vedwaemnmbgainui Annotation DryMMBI End Data sessions, lase W,4 By Last Tag:RKB 1 UI 0 IYZ/201] 1J-10 Ipprosen I XNIOFx:me Last Rev Reason Annotation I End Data weulnre Lost mW By Rev Reason Set Whipstock 2 "P,n 1J-10 ITS., ................................... ..... Casing Strings Casing oeacdpliun Do IOM) ropRKB) sea Oe pmlrcRB1 set ospin(TVOI...sNLan( I Top Tnreao J.rade CONDUCTOR 20 19.12 350 1200 120.0 91.50 Hd0 WELDED Case, asserting- 0lin) 10(i-) Top(RKB) east Depth 0I 4et Depth LIVD...NARG" ft Top TM1reae loads SURFACE 95/8 883 345 16.9l 139954 40.00 1 BTC Casing Chiseling.. go (aft 10 Dn) Top ryMB) gel wgng0(ta Bat -,on I, vi W�Len II...Omde lop TM1reatl coFo'ucioli'. zoixi0 PRODUCTION 7 828 317 10.2308 5944.4 26.0 LA0 BTC -MOD Casing Description ODied Io In) TOptou" sn Dawn lttl(91 sM ceptn lrvol...ani 1115,ede rop Tnrme LINER 41/2 3.96 9,967.2 10,843.0 6,324) 12.60 LHM NSCT I NIPPLE: SR.O Liner Details Nammal ID Top MBI TORVDNMER Topind(°) Item Das Co. (in) 9.9672 5]8].0 53.74 TIEBACK BAKER PACKER & TIE -BACK SLEEVE 4,438 CAS DPT. SM 8- 99852 5,7976 53.67 PACKER BAKER ZXP LINER TOP PACKER 4,438 9,9892 5800.0 53.66 HANGER BAKER LINER HANGER 4.5(K 10.3277 60017 SIM NIPPLE CAM D'NIPPLE - DRILL U 3,830 DURING ATTEMPT TO PULL FISH 2&2008 Oas LIFT: 6,311,7 WESTOVER 10,5207 6.118.5 5181 NIPPLE OTIS 'XN'NIPPLE wI No Go. 3 81r PI RE, 3725 3 725profile Tubing Strings mane Description s1,me ma_. ID lml Top -KS) set Leads (A.. sea wpm (rvD) (-. w101N9 .meas rop Coaneenon SVRFACE:3eee,9av`B- TUBING 41/2 396 296 9,991] 5,801.5 1260 L-80 IBT Completion Details DASUST:Raga.a rop END) rep mel anal to Premiss meed CI IRm Des Core ID gn) 29.6 29.6 001 HANGER FMC GEN V TUBING HANGER 4,500 508.0 508.0 197 NIPPLE CAMCO DBA NIPPLE wl3875 TOP NO GO PROFILE 3.875 9,9334 5.7670 53.86 NIPPLE CAMCO DB NIPPLE w/ 3.812 PROFILE - DTO 3 87 3,830 Las LFT: LIST s DURING ATTEMPT TO PULL FISH 2/812008 WORKOVER 9,9787 5.7938 5370 LOCATOR BAKER GBH -22 LOCATOR 3.958 FW oAL=z4zz; e,tmo 9,979.9 5,]94.5 5369 SEAL ASSY BAKER SEAL ASSEMBLY w/MULESHOE 3.958 Other In Hole Wireline retrievable plugs, valves, pumps, flab, etc.) rop(Al TOp(IM nMa) IpInd I'1 Des Dam Run Dab loin) ons uFr: 9,eazz 9.126.0 5.276.9 5135 fish- A= N K nII ON Unhartool l j% 1 19 3.363 2422 bbing (218.847. Triple Conn. Bushing (1,12').24/13' X- Treme Motor (10.62% VO 2-318" REG x 2-3/8' PAC, NIPPLE; Qay.4 PDC Bit Durabrce XD (0.821 TOE TVD 5164.T, BOF TVD 53165', OPAL of Fish = 2422 10,3010 5.986.0 5388 WINDOW-PBt indow Cut from 10, Ot-1 t ria wRich we drilled a ]21 ODDD 1JH0IUPB1 and left a moor, bit, ado 112joint of liner On bottom LOCATOR."Qual 10,326.0 ILWO7 5388 FISH E F UNPERFGUNDR ED7/ 1, 10,532, LENGTH 34.4', MAX OD 363'; WORKED TO 3n) RETRIEVE THIRD 81291 1. WELL SHUT IN B FREEZE SEALAssy;9.g>'t, PROTECTED. 36' BAT SUB LEFT ON TOP OF E11NE TOOL 1W25204 Fish Pulled up to10,312'CTMD 61//205: Tagged Fish @ 10339' IRKS 1/19/208 Tagged Fish @ 10301' SLM 2/&230 WORKOVER TO PULL FISH -,ONLY PUSHED IT DOWNHOLE FROM 10312 TO Iftst spot CTION; av-do.zm.9- perforations & Slots wMDLW-Par, Ma]I o shod Len ioMKS) alMKS) I. MKS) Top446. atm466,0 Llnyvd IDne Dale ) Tyree Com t0p46.0 10,466.0 50]2] 6,084.9 5,07 CJ, 1J-10 ]/192001 6.0 APERF 3 318" PSD PJ Ng%, fi0° on 10,6580 10,678.0 6205. 6,217A A -5,1J-10 6I1212J01 6.0 IPERF 12.5 HSDBH&DP FISH. 143S.0 Frac Summary Stan Dab P,oppand Cesipnm 0qReps"m FMTaum pea 6/162001 stg♦ Bbdwb Tep wpM lN(BI BM InKB) Llnkb FluM 3yshm VOICWn(na9 Va131urry(nbp 1 W1612001 10,858.0 10,8780 Mandrel Inserts sl asN LI DNER', 10,METHO,WIL0 Tap ITVDI Top gued me) Velve Latin Poe3ne TRO Run age. gassed Won, Ser, Type Tyw (In) bass Run Data COT 1 3,723.8 2,558.4 CAMCO KBD -2 1 GAS LIFT LV BK 0.188 1,246.0 1/2112019 4:30 2 031167 3.7230 CAMCO KBG-2 1 GAS LIFT OV BK 0250 0.0 1/2012019 7:30 APERF', 10,N6DID..- 3 8,0682 4,677.0 CAMCO KBG-2 1 GAB LIFT DMY BK 0.000 00 3/29/2017 5:00 4 9132.6 5,263.0 CAMCO KBG-2 1 GAS LIFT DMV SK 0.000 00 5/23/2001 4.15 5 9,882.2 5,736.8 CAMCO KBG-2 1 GAS LIFT JUNY JUN I 0.000 00 2/912014 7:00 Notes: General & Safety End DabAnnolalwn 2812008 N '.W RK V DONE OP LL FISH, MILLED NIPPLES. UNU E UL, PUSHEOFISH DOWNHOLE IPERF: nra-S.o-1Qa)a0 FRAC: Town 312012019 NOTE'. Letta molar, bit and half d jurist liner On botbm In 1J-10L1PB1 LINER: 8.9613-10,8s90� Uperations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation rtKB) End Depth(ftKB) 2/10/2019 2/10/2019 2.00 MIRU MOVE DMOB P Continue RDMO from 3S-06, load out 0.0 0.0 17:00 19:00 DTH trucks, secure rig landings and stairs, secure cellar, Peak arrives on site at 19:00 hrs 2/10/2019 2/10/2019 4.00 MIRU MOVE DMOB P Load up shop & 1/2 -Way house, hold 0.0 0.0 19:00 23:00 PJSM with rig / Peak team. Pull off well. Install Jeeps. Rig down cellar area 2/10/2019 2/11/2019 1.00 MIRU MOVE MOB P Move from 3S -Pad to 1J -Pad (25.4 0.0 0.0 23:00 00:00 miles) 2/11/2019 2/11/2019 4.35 MIRU MOVE MOB P Continue moving rig to 1J -Pad 0.0 0.0 0000 04:21 2/11/2019 2/11/2019 5.40 MIRU MOVE MOB T Field went to phase 3 driving 0.0 0.0 0421 0945 conditions. park rig at KCS Y (15.4 mile), standby for weather, Phase conditions lifted, send grader and blower to 1J -pad to confirm clear of snow. 2/11/2019 2/11/2019 4.25 MIRU MOVE MOB P Continue moving rig to 1J -Pad 0.0 0.0 0945 1400 (stopped at KOC for fuel) 2/11/2019 2/11/2019 2.50 MIRU MOVE MOB P Arrive on 1J -Pad 14:00 hrs, drop off 0.0 0.5- 1400 1630 jeeps, sub & pits spotted, mats laid (-50 min to lay mats for sub & pits) 2/11/2019 2/11/2019 4.00 MIRU MOVE MOB P DTH on location rig up tiger tank and 0.0 0.0 1630 2030 hardline (air-test/good-test), Continue RU checklist, hook up PUTZ, hook up steam, drop stairs & landings, spot shop & half -way house 2/11/2019 2/11/2019 1.00 MIRU MOVE MOB P Complete RU checklist, energize 0.0 0.0 20:30 21:30 Koomey, unlock injector & reel, begin MU tiger -tank hard-line, grease tree & tangos, grease Romeo & Bravo valves 2/11/2019 2/12/2019 2.50 MIRU WHDBOP NUND P Nipple up BOP, grease crew on 0.0 0.0 21:30 00:00 location, service tree valves. *** Note: Rig Accept 2/11/19 @ 21:30 pm 2/12/2019 2/12/2019 0.60 MIRU WHDBOP NUND P Complete prep for BOP test 0.0 0.0 00:00 00:36 2/12/2019 2/12/2019 0.90 MIRU WHDBOP PRTS P PJSM, fluid pack, & shell test, good 0.0 0.0 0036 01:30 2/12/2019 2/12/2019 1.50 MIRU WHDBOP ROPE T Begin BOP test, good test on test 1, 0.0 0.0 01:30 03:00 though continue to see pressure when bleeding off, observe gas through night cap, trouble shoot master & SSV, function SSV open and closed, re -fluid pack stack, taking to tiger tank, close swab to check for pressure build at tangos, good, carry on w/ test -' 250 psi low / 3500 psi high (witness waived by Bob Noble of AOGCC) 2/12/2019 2/12/2019 6.10 MIRU WHDBOP ROPE P Continue w/ BOP test, fail/pass on 0.0 0.0 03:00 0906 test #13, draw -down test 2/12/2019 2/12/2019 1.00 MIRU WHDBOP BORE P Flud pack coil, reverse circulate, test 0.0 0.0 09:06 10:06 inner reel valve 2/12/2019 2/12/2019 1.10 MIRU WHDBOP PRTS P Pop off injector, PT PDL's & tiger -tank 0.0 0.0 10:06 11:12 line 2/12/2019 2/12/2019 0.40 SLOT WELLPR OTHR P clear floor 0.0 0.0 11:12 11:36 2/12/2019 2/12/2019 1.40 PROD? RPEQPT PULD P PJSM, PD BHA#1 Coil -Trak w/ 0.0 43.0 11:36 1300 nozzle, slide in cart, install checks, MU to coil, tag up, set counters Page 1/18 Report Printed: 7118/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Actively Code Time P -T -X Operation (Me) End Depth (WB) 2/12/2019 2/12/2019 2.00 FROM RPEQPT TRIP P RIH w/BHA #1 43.0 10,160.0 13:00 15:00 2/12/2019 2/12/2019 0.20 FROM RPEQPT DLOG P Log formation for -5' correction 10,160.0 10,186.0 15:00 15:12 2/12/2019 2/12/2019 0.30 PROD1 RPEQPT TRIP P Close EDC, PUW = 37K, continue 10,186.0 10,307.0 15:12 15:30 RIH, log K1 for -1' correction, tag TOWS at 10,307', PUW = 42K 2/12/2019 2/12/2019 0.70 PRODt RPEQPT DISP P Continue flushing w/ seawater 10,307.0 10,280.0 15:30 16:12 2/12/2019 2/12/2019 1.20 PROD1 RPEQPT DISP P Obtain SBHP 10,295.0 10,295.0 16:12 17:24 MID bit = 10,295', TVD sensor = 5974.7', annular = 2882 psi, EMW = 9.29 ppg Decision made to reduce KWF to 10.8 ppg for BHA swap (no formation open at this point) 2112/2019 2/12/2019 2.60 PROD1 RPEQPT DISP P Squeeze 150K LSRV pill followed by 10,295.0 2,000.0 17:24 20:00 10.8 ppg KWF to surface Losses started @ 0.5 bpm increased to 1.5 bpm, and lost returns @ - 2000 feet. **Phase 1 @ 20:23 2/12/2019 2/12/2019 3.60 PRODt RPEQPT DISP T Additional KW fluid called out earlier, 2,000.0 2,000.0 20:00 23:36 water truck needs for dilution of KW stuck on pad, Still Phase one. Roads & pads, extracted water truck, off loaded same. Built 9.5 ppg KW fluid. 2/12/2019 2/13/2019 0.40 PRODi RPEQPT DISP P Online with 9.5 ppg NaBr to the coil, 2,000.0 2,000.0 23:36 00:00 filling hole, note 39 bbl coil volume all 10.8 ppg, 49 bbls away started seeing returns, waited until 9.5 ppg returns at surface. 2/13/2019 2/13/2019 0.80 PRODi RPEQPT DISP P Waited until 9.5 ppg at surface, 2,000.0 2,000.0 00:00 00:48 brought fluid back inside. 10.45 ppg and heavier EMW yealds zero returns. Density out staarting to drop, 9.5 ppg comming back. 2/13/2019 2/13/2019 0.40 PROM RPEQPT TRIP P Waited until 9.5 ppg at surface, 2,000.0 55.0 00:48 01:12 brought fluid back inside. 10.45 ppg and heavier EMW yields zero returns. POOH 2/13/2019 2113/2019 0.70 PROD1 RPEQPT PULD P LD BHA#1 over a dead well, on 55.0 0.0 01:12 01:54 1 vacuum, 2/13/2019 2/13/2019 1.00 FROM RPEQPT PULD P PU 4 joints of PH6, caped w nozzle 55.0 0.0 01:54 02:54 and Mrs, Nozzle -0.66', XO's-0.69/0.73', joints 1,2,3,&4 - 31.38', 31.36', 31.53', and 32.81'. 2/13/2019 2/13/2019 0.70 FROM RPEQPT CTOP P Pull UQC, cut and boot E -line, stab 55.0 0.0 02:54 03:36 onto PH6, Pump up to 2.5 bpm, listen for wine moving and stop. Repeated ramp to 2.5 bpm 3 more limes no noise associated with wire movement. 2/13/2019 2/13/2019 1.00 FROM RPEQPT CTOP P Fill well to stump, flow check good, 55.0 0.0 03:36 04:36 unstab, pull wire, 132' retained, theoretical was 151'. Cut 8.5' of coil, cut a -line and reboot. BHA hand noticed flat spot on pipe, recut pipe and reboot a -line. 2/13/2019 2/13/2019 2.50 PROM RPEQPT CTOP P Instal BH coil connector, pull test, 55.0 0.0 04:36 07:06 1 pressure test Page 2118 Report Printed: 711812019 Operations Summary (with Timelog Depths) 1.1-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth Ms) End Depth(ftKB) 2/13/2019 2/13/2019 0.50 FROM RPEQPT CTOP P Pull 4 jnts PH -6, run nozzle & 1 jnt PH 0.0 0.0 0706 0736 -6 in hole, stab on injector, prep to pump ball 2/13/2019 2/13/2019 0.70 PROD1 RPEQPT CTOP P Drop ball, Gose & pressure up on IRV 0.0 0.0 07:36 08:18 to 3000 psi, open IRV, bring on pumps to 2.5 bpm, pump 1.5 coil volumes Order 50 sacks Poly Swell to rig 2/13/2019 2/13/2019 0.80 PROD1 RPEQPT CTOP P Pop off, LD PH -6 jnts, additional 32' of 0.0 0.0 08:18 09:06 slack pumped forward, retireved ball from nozzle, good test on a -line, cut a- line, epoxy & protect tag end 2/13/2019 2/13/2019 1.40 PROD? WHPST PULD P PJSM, PU BHA #2 Window Assembly 0.0 245.0 09:06 10:30 2/13/2019 2/13/2019 0.90 PROD1 WHPST DISP T Displace coil to milling fluid 245.0 245.0 10:30 11:24 2/13/2019 2/13/2019 1.50 FROM WHPST WAIT T Wait on Poly Swell to rig 245.0 245.0 11:24 12:54 Establish pressures at various rate: 1 bpm: circ = 196 psi, WHIP = 182 psi 1.5 bpm: circ = 282psi WHIP = 305 psi 2 bpm: circ = 415 psi, WHIP = 396 psi 2.5 bpm: circ = 534 psi, WHIP = 521 psi 2/13/2019 2/1312019 1.10 PROD1 WHPST CIRC T Fresh water arrives at rig, PolySwell 245.0 245.0 12:54 14:00 arrives at rig, add sacks of KCI, add sacks of PolySwell, mix 2/13/2019 2/13/2019 1.50 FROM WHPST CIRC T Begin pumping pill, low efficiency on 245.0 245.0 14:00 15:30 pump #2, unable to get pill pumping, pull screen on pump $#1, pumping pill @ 2.3 bpm, pill at top of perfs (circ = 699, WHIP = 731) 2/13/2019 2/13/2019 0.90 PROM WHPST CIRC T Squeeze away 10 bbl at .75 bpm, 245.0 245.0 15:30 16:24 shutdown pumps allow to swell for 45 min " 192 total pumped leaves 2 bbl above TOWS 2/13/2019 2/13/2019 0.60 PROD1 WHPST CIRC T Squeeze 5 more bbl's @ .5 bpm, wait 245.0 245.0 16:24 17:00 2/13/2019 2/13/2019 1.70 PROD? WHPST CIRC T Squeeze away remaing poly swell, 245.0 245.0 17:00 18:42 leaving 2 bbl above TOWS, wait 2113/2019 2/13/2019 1.80 FROM WHPST TRIP P RIH, min rate down the coil, targeting 245.0 10,247.4 18:42 20:30 1 for 1 returns. Some poly swell back at the shaker causing choke issues, had to lake -2 bbls outside, gas back 2/1312019 2/13/2019 0.30 PROD1 WHPST DLOG P Tie into flag for +6.7'correction. PU Wt 10,247.4 10,312.0 20:30 20:48 42 k lbs, RIH, dry tag TOW @ 10312.39' 2113/2019 2/13/2019 1.10 PROM WHPST CIRC P Increase rate to 10,312.0 10,147.0 20:48 21:54 1 bpm down coil, full returns, WH 19 psi, CT 1819, 2 bpm down coil, 1.9 bpm out - WH 23 psi, CT 3091' 2.6 bpm in, 2.48 bpm out - WH 37 psi, CT 4150 psi, - Circulate bottoms up, large amount of poly swell returned to the shaker, over flowed, lost +1-60 bbls to the cuttings pit. Returns cleared up post bottoms up. 2/13/2019 2113/2019 0.30 PROD1 WHPST TRIP P IH RB, 10,147.0 10,311.3 21:54 2212 Page 3118 Report Printed: 7/1 812 01 9 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start TIM End Time our (hr) Phase Op Code AMAY Code rime P -T -X Operston (VS) Fsd Depth (ftKa) 2/13/2019 2/14/2019 1.80 PROD1 WHPST WPST P Tag up w/ top of whipstock @ 10,311.3 10,313.5 22:12 00:00 10,311.3', Free spin CT 3750 psi, WH 178 psi, CT Wt 15 k lbs. Flag pipe at the horses head, start feeding tenths, - 1' /hr , with average 240 psi motor work. 2.61 bpm in 2.50 bpm out. 2/1412019 2/14/2019 2.50 PROD1 WHPST WPST P Continue to mill exit window. 2.6 bpm 10,313.5 10,315.5 00:00 02:30 in 2.5 bpm out, CT free spin 3750 psi, allowed CT wt to drop to 11 k lbs and CT pressure to climb to 4100 psi - 350 psi motor work. Parked for - 13 min, CT pressure fell off rapidly to 4000 psi and CT weight climbed to 12.6 k lbs. reengaged the stick, mill ahead, WH 168 psi. 2/14/2019 2/14/2019 2.00 PROD1 WHPST WPST P Increase ROP to 1.2 ft/hr. 2.6 bpm in, 10,315.5 10,318.0 02:30 04:30 2.54 bpm out, WH 170 psi, Ct 3800 psi, CT Wt 13.5 k lbs. 2/14/2019 2/14/2019 2.00 PRODt WHPST WPST P Continue milling window, CWT= 10,318.0 10,320.2 04:30 06:30 12.51K, circ = 3811 2.6 bpm in, 2.53 bpm out 2/14/2019 2/14/2019 3.00 PROD1 WHPST WPST P Milling window, CWT = 12.71K, circ = 10,320.2 10,323.5 06:30 09:30 3828 psi, WHIR = 172 psi, approx 10.07 ppg assuming 25 psi/1000' frictional pressure loss, mill exits bit - 10323.4' 2/14/2019 2/14/2019 1.30 PROD1 WHPST WPST P Milling window, CWT = 13.1 K, circ = 10,323.5 10,325.0 09:30 10:46 3932 psi, WHIP = 172 psi TOW = 10,311.3', BOW = 10,323.4' 2/14/2019 2/14/2019 2.40 PROD1 WHPST WPST P Begin pushing on it, milling rat -hole, 10,325.0 10,336.3 10:48 13:12 CWT = 10.7K, circ = 4115 psi, WHP = 172 psi, pump 5x5 sweeps 2/1412019 2114/2019 0.60 PROD1 WHPST REAM P Begin reaming, up -hole, PUW=37K 10,336.3 10,305.0 13:12 13:48 2/14/2019 2114/2019 1.10 PROD1 WHPST DLOG P PUH to 10,305', trap 580 psi WHIP 10,305.0 10,305.0 13:48 14:54 (EMW of -10.3 ppg), shut down pumps, allow WHIP to drop, confer w/ town, decision made to kill well w/ 9.9 ppg KWF SBHP: WHIP = 252, EMW = 9.6 ppg, still dropping 2114/2019 2114/2019 2.00 PRODi WHPST REAM P Continue reaming passes (3 up & 3 10,305.0 10,305.0 14:54 16:54 down total), dry drift window up & down dean, PUW = 40K 2/14/2019 2/14/2019 3.00 PROD1 WHPST CTOP P Transfer and build 9.9 ppg KW fluid. 10,305.0 10,264.0 16:54 19:54 2/1412019 2/1412019 0.70 PROD1 WHPST DISP P Start pumping KW to the coil 10,264.0 10,282.0 19:54 20:36 2/14/2019 2/14/2019 1.60 PRODi WHPST DISP P POOH laying in 9.87 ppg KW and 10,282.0 256.0 20:36 22:12 painting flags Park @ 10142.43 and paint a red flag and again @ 10047.39' red and white candy cane. Continue to POOH. 2114/2019 2/14/2019 1.20 PRODt WHPST PULD P Park, flow check - good, slight vac. 256.0 256.0 22:12 23:24 LD BHA#2 over a dead well, Retrieved and cut off an additional 60' of a -line. Meg wire - greater than 2000 ohms, good test. Skid cart. 2/14/2019 2/15/2019 0.60 PROD1 WHPST PULD P Fluid still in the stack. Lay down BHA 256.0 0.0 23:24 00:00 #2 Speed mill and string reemer 3.80" go 3.79" No go Page 4118 ReportPrinted: 7/18/2019 Operations Summary (with Timelog Depths) ii -10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth nt DS sled rims EMTima our (hr) Phase op Coda Ac" Time me P -T -X C Aeration End Depth (ftXa) 2/15/2019 2/15/2019 1.90 PROD1 DRILL CIRC P Boot wire, install side jet nozzle, stab 0.0 0.0 00:00 01:54 on, turn coil over to milling fluid, shelter time to chink bomb bay doors, jetting the stack. 2/15/2019 2/15/2019 3.40 PROD? DRILL PULD P Pop off, PU BHA #3, drilling liner, 0.0 0.0 01:54 05:18 2/15/2019 2/15/2019 2.50 PROD1 DRILL TRIP P RIH w/ BHA#3, correct+4.3'to pipe 0.0 10,230.0 05:18 07:48 1 1 1 flag, PUW = 39K 2/15/2019 2/15/2019 1.50 PROD1 DRILL DISP P Displace well to drilling fluid @ 1.5 10,230.0 10,230.0 07:48 09:18 bpm, bring rate up to 2.0 bpm, circ = 4144 psi, WHP = 19 psi (choke wide open), 2/15/2019 2/15/2019 0.20 PROD1 DRILL TRIP P Shut down pumps, RIH 20 fpm 10,230.0 10,336.0 09:18 09:30 through window, at 10,330' bring rate up to 2 bpm, FS = 4105 psi, begin drilling at 10,336' 2/15/2019 2/15/2019 1.50 PROD1 DRILL DRLG P Drilling, FS = 4105 psi, circ = 4277 psi, 10,336.0 10,356.0 09:30 11:00 CWT = 12.7K, 1.98 bpm in, 1.94 bpm out, choke open, stall at 10,343', PUW = 41 K, continue drilling ahead 2/15/2019 2/15/2019 1.80 PROD1 DRILL DRLG P Drilling, CWT = 9.85K, circ = 4207, 10,356.0 10,356.0 11:00 12:48 -100% returns, begin stacking weight, though no increase in motor -work, stacking pipe in hole, PU to breakover, PUW = 43K, zero dp counter, again stacking weight @ 10,356', atempt again, PUW = 43K, again slack weight at 10,356', PUW = 47K Confer w/ town, decision made to PU 10' (full rate), PUW = 50K, no success, make multiple attempts. Appear to be hitting bottoms though no motor -work 2/15/2019 2/15/2019 1.70 PRODi DRILL CIRC T Thaw product, build 50 bbl Drilzone 10,356.0 10,356.0 12:48 14:30 pill for potential bit balling 2/15/2019 2/15/2019 0.60 PROD1 DRILL CIRC T Begin pumping 25 bbl Drilzone pill, 5 10,356.0 10,356.0 14:30 15:06 bbl mud spacer, follow by 25 bbl Drilzone, bit just off bottom, PU & go to drilling 2/15/2019 2/15/2019 1.90 PROM DRILL DRLG T Drill ahead to 10,361'& stall, PUW = 10,356.0 10,380.0 15:06 17:00 43K, continue drilling ahead. Circ = 3941 psi, open choke, 99% returns, 15 -20 fph, -100 psi motor -work, again begin to stack weight, building 30 bbl Drilzone, PUW = 42K 2/15/2019 2/15/2019 0.60 PROM DRILL DRLG T Stacking coil weight and not making 10,380.0 10,377.0 17:00 17:36 hole. PU to 10,369', Ct Wt 40.6 k lbs, 4 more pick ups to get restarted with decreasing PU weight. Restarted, drilling ahead slowly with pickups to 10,377' where the motor stalled. 2/15/2019 2/15/2019 1.20 PROM DRILL DRLG T Unable to Pick up after stall, Pull up to 10,377.0 10,377.0 17:36 18:48 70 k lbs, bleed coil back to 0. work pie, work CT pressure up to 2000 psi, work pipe to 70 k. No movement, no indication of circulation. 2/15/2019 2/15/2019 0.70 PROD1 DRILL DRLG T Dog house discussion, manually pump 10,377.0 10,377.0 18:48 19:30 up injector circuits. Cycle pipe up to 80k squatting up to -10 k, pulling speeds up to 100 ft/min, no movement. Consult w engineering. Work pipe to 90% - 90,000 lbs. squatting,varying running speed. no movement. Consult town again. Page 5/18 Report Printed: 7 /1 812 0 1 9 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth rt De Start Tmre Entl Time Dw(hr) Phase Op Code AcUvi Code ry Time P-T-X Operatlon End Depth (fll(a) 2/15/2019 2/15/2019 1.50 PROD? DRILL DRLG T Online with the pump in attempt to 10,377.0 10,377.0 19:30 21:00 shear the 2500 psi circ port above the motor. Well started taking fluid @ 0.4 bpm and 2800 psi. Worked pipe to 80k while pumping, no movement or indication burst disc burst. Increase rale to 2.5 bpm and 7000 psi. No indication of shear circ sub opening, no indication of the flow disconnect in the liner disconnecting. Start additional generator. 2/15/2019 2/15/2019 0.60 PROD1 DRILL DRLG T Cycle rate to 3 bpm and 7000 psi 13 10,377.0 10,377.0 21:00 21:36 times with no indication of shear/ shift in liner running assembly. 2/15/2019 2/15/2019 1.30 PROM DRILL DRLG T PJSM, drop 5/8" ball, launch with 3100 10,377.0 10,288.0 21:36 22:54 psi, hear indication of launch, chase @ 1.8 bpm, Ct 5500 psi, WH 200 psi. Cut rate with 26 bbls away to 0.45 bpm. @ 41 bbls away, surge rate from 0.25 bpm to 2.5 bpm. At 4340 bbls away, CT to 5800 psi, Walk pressure up to 7300 psi. after - 2 minutes saw pressure fall to 1300 psi. PUH to 10288 (technically 10086'), established circulation @ 2 bpm, CT 2763 psi, WH 246 psi. 7300 ****Top of fish - 10159' CTMD. 2/15/2019 2/16/2019 1.10 PROD1 DRILL CIRC T Park and reset counters after dropping 10,288.0 10,050.0 22:54 00:00 off drilling liner. Circulate bottoms up X2 while creeping up hole slowly. CT 2736 psi, WH 228 psi, 2.01 bpm in / 1.95 bpm out. 2/16/2019 2/16/2019 0.90 PROD1 DRILL CIRC T Continue to circulate botooms up 10,050.0 10,720.0 00:00 00:54 2/16/2019 2/16/2019 0.30 PROD1 DRILL DISP T Pump 9.9 KW fluid to the n=le 10,096.0 10,086.0 00:54 01:12 2/16/2019 2/16/2019 1.50 PRODi DRILL DISP T POOH displacing well to 9.9 ppg KW 10,086.0 237.0 01:12 02:42 fluid. full returns. 2/16/2019 2/16/2019 1.40 PROM DRILL PULD T LD BHA 3, less drilling liner left in 237.0 0.0 02:42 04:06 hole. Hole fill <1 bbl/hr 2/16/2019 2/16/2019 7.70 PROM DRILL WAIT T Wait on a-line, 0.0 0.0 04:06 11:48 Confer w/ town, decision made to cut fish w/ chemical cutter at 10,325' 2/16/2019 2/1612019 1.90 PROM DRILL ELNE T SLB a-line arrives at rig, PJSM, RU e- 0.0 0.0 11:48 13:42 1 1 line, get tools to rig floor 2/16/2019 2/16/2019 1.30 PRODi DRILL ELNE T PJSM,PU a-line tools 0.0 0.0 13:42 1500 2/16/2019 2/16/2019 1.00 PROD1 DRILL ELNE T RIH w/ chemical cutter, PUH to log K1, 0.0 10,330.0 15:00 16:00 arrive at cutting depth, make cut in 3.5" FlushMax pipe at 10,330' (CCL depth of 10,319', a-line tension drops from 1170 Ibf to 878 Ibf, wiat 5 minutes, RIH to release dogs 2/16/2019 2/16/2019 1.00 PROD1 DRILL ELNE T POOH w/e-line 10,330.0 0.0 16:00 17:00 2116/2019 2116/2019 1.70 PROM DRILL ELNE T Lay town E-line tools and clear the dg 0.0 0.0 17:00 18:42 floor 2/16/2019 2/16/2019 1.70 PROD1 DRILL PULD T PJSM, PU BHA #41, fishing assembly. 0.0 236.0 18:42 20:24 2/16/2019 2/16/2019 1.50 PROD1 DRILL TRIP T RIH, Ct PU Wt@ 10,099' CTMD 42 k 236.0 10,155.0 20:24 21:54 lbs, PUH 37.5 k lbs. Page 6118 Report Printed: 7/1812019 Operations Summary (with Timelog Depths) ii -10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log staM1 Depth Start Time End Time our (h0 Phase Op Cade AMAY Code Time P4 -X Operation (WB) EM Depm (WB) 2/16/2019 2/16/2019 0.10 PROD1 DRILL TRIP T Run into fish @ - 30 it/min. Set down 10,155.0 10,155.0 2154 2200 on fish at 101 55'CTMD. SID - 3k lbs, PU to 50 k lbs, Fish on! Pull into 60k, Jar fired, pulled free, 2/16/2019 2/17/2019 2.00 PRODt DRILL TRIP T POOH with fish. CT wt 38k lbs and 10,155.0 396.0 2200 0000 slowly dropping. 2/17/2019 2/17/2019 2.00 PROD1 DRILL PULD T LD BHA #4, fishing BHA. 396.0 165.0 00:00 02:00 2/17/2019 2/17/2019 1.00 PROD1 DRILL PULD T LD flish, hanger assembly, and 6 full 165.0 0.0 02:00 03:00 joints plus 1 partial cut jpint of 3.5: Flow Max. "' Left 61.00' of fish in hole, partial 7.74' joint #2 3.5 Flush max, full 27.64' joint Flush Max, XO burst disc, motor and bit. 2/17/2019 2/17/2019 1.40 PRODi DRILL CTOP T Clean floor, skid cart, no wire in site, 0.0 0.0 03:00 04:24 Stab on and pump slack back. 2/17/2019 2/17/2019 2.10 PROD1 DRILL CTOP T Unstab, skid cart, pick up hydraulic 0.0 0.0 04:24 06:30 cutter, cut 296' of pipe to find a -line, cut additional 4' for a total of 300' cut 2/1712019 2/17/2019 1.70 PROD1 DRILL CTOP T Bevel & ream pipe, install CTC, pull 0.0 0.0 06:30 0812 test 2117/2019 2/17/2019 1.30 PROD1 DRILL CTOP T Install UQC & re -head a -line, pressure 0.0 0.0 08:12 09:30 test CTC test wire, greater than 1800 mega ohms and 69.5 ohms. 2/17/2019 2/17/2019 0.50 PROD1 DRILL CIRC T Pump coil volume forward @ 2.5 bpm 0.0 0.0 09:30 1000 2/1712019 2/17/2019 0.90 PROD1 DRILL PULD T PU BHA#5 Nozzle, slide in cart, MU 0.0 53.0 10:00 10:54 to Coil, tag up, set counters 2/17/2019 2/17/2019 1.90 PROD? DRILL TRIP T RIH w/ BHA #5, begin sending drilling 53.0 10,280.0 10:54 12:48 fluid 2/17/2019 2/17/2019 0.20 PROD1 DRILL DLOG T Log K1 for -8' correction 10,280.0 10,299.0 12:48 13:00 2/17/2019 2/17/2019 1.30 PROD1 DRILL TRIP T Continue RIH &jog WS tray multiple 10,299.0 10,312.0 13:00 1418 times, pumping 2 bpm (TOWS to 10,312'), pump two 5x5 sweeps 2/17/2019 2/17/2019 1.70 PRODi DRILL TRIP T POOH, displacing to 9.9 ppg KWF, 10,312.0 53.0 14:18 1600 flow check, good 2/17/2019 2/17/2019 0.50 PROD1 DRILL PULD T PJSM, LD BHA #5 (break off nozzle) 53.0 0.0 16:00 16:30 2/17/2019 2117/2019 0.40 PROD1 DRILL PULD T PU BHA#6 WS Fishing Assembly 0.0 66.0 16:30 16:54 (BOT hook), slide in Cart, MU to Co!I, tag up, set counters 2/17/2019 2/17/2019 1.70 PRODi DRILL TRIP T RIH w/ BHA #6 66.0 9,845.0 16:54 18:36 2/17/2019 2/17/2019 0.20 PROD1 DRILL DLOG T Tie into the K1 for a -2.5' correction 9,845.0 9,879.0 18:36 18:48 PU W140 k Ibs 2/17/2019 2/17/2019 0.70 PROD1 DRILL PULL T Continue to RIH, Wt check above WS 9,879.0 10,315.0 18:48 19:30 @ 10239'40 k lbs. RIH from 10300 to 10315'@ 5 ft/min cycle pipe across tray jetting with hook oriented neutrally 194, 190, 200, and 180 " ROHS wile pumping 2 bpm, 1.8 bpm returns, 10.1 ppg EMW @ the window. PU above WS, orient hook to 14° ROHS. RIH, stack 2.5 k WOB @ 10309.9' PU, up to -3.0 k lbs WOB, broke back, suspect fish on, 2/17/2019 2/17/2019 2.20 PRODi DRILL TRIP orienter turned off, 90 ft/min 10,315.0 70.0 19:30 21:42 1 1 ::=POOH, 2/17/2019 2/17/2019 0.90 PROD1 DRILL PULD T Stand back upper BHA, LD fishing 70.0 0.0 21:42 22:36 1 I I BHA and fish -(whipstock) Page 7118 Report Printed: 7/18/2019 . Uperations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Ir m End Time our (hr) Phase Op Code ACNO Code Time P -T -X Operation (WS) End Depth (1tK6) 2/17/2019 2/17/2019 0.70 PROD1 DRILL PULD T PU BHA #7 clean out assembly, 0 ° 0.0 62.5 22:36 23:18 motor with D331 bit, 2.7" no go. inspect pack offs, good. 2117/2019 2/18/2019 0.70 PROD1 DRILL PULD T RIH 62.0 3,267.0 23:18 00:00 2118/2019 2/18/2019 1.10 PROD1 DRILL TRIP T Continue to RIH. 3,267.0 9,842.0 00:00 01:06 2/18/2019 2/18/2019 0.20 PRODt DRILL DLOG T Tie into K1 for +6' correction 9,842.0 9,864.0 01:06 01:18 2/18/2019 2/18/2019 0.20 PROD1 DRILL CIRC T Contine to RIH, milling fluid at the bit 9,842.0 10,329.0 01:18 01:30 @ 10302'. SID @ 10,329, stall, PU 42 k Itis 2/18/2019 2/18/2019 1.00 PRODi DRILL CIRC T RBIH, 1.84 bpm in, 1.80 bpm out, free 9,842.0 10,326.0 01:30 02:30 spin 421 psi, 10.04 ppg EMW a@ the window. SID 10,326', stall, PU 42 k lbs. RBIH, start taking weight @ 10,325.96'. Motor work, no ROP, hard lag. 2/18/2019 2/1812019 1.00 PROD? DRILL CIRC T Perform jetting passes from 10320 to 10,326.0 10,317.0 02:30 03:30 1 1 10300. Tum coil over to seawater 2/18/2019 2/18/2019 1.20 PROD1 DRILL DISP P Seawater at the bit, wash from 10300 10,317.0 4,436.0 03:30 04:42 to 10320 x2. POOH chasing seawater uphole. Park w 25 bbis of seawater above the bit, open EDC. POOH 2/18/2019 2/18/2019 1.30 PROD1 DRILL DISP P LRS, rigged up and PT'd to 4500 psi, 4,436.0 70.0 04:42 06:00 start pumping 40 bbis diesel to the coil @ 2 bpm, 4400 psi. 2/18/2019 2/18/2019 0.70 PROD1 DRILL PULD P PJSM, PUD BHA#7 70.0 0.0 06:00 06:42 " 395 psi SITP 2/18/2019 2/18/2019 1.50 DEMOB WHDBOP RURD P Jet stack, & sucked out, freeze protect 0.0 0.0 06:42 08:12 -tree, dear floor 2/18/2019 2/16/2019 1.50 DEMOB WHDBOP RURD P Work RD checklist, freeze -protect tree, 0.0 0.0 08:12 09:42 blow -down PUTZ, break off TT line (hard-line still MU) 2/18/2019 2/18/2019 1.30 DEMOB WHDBOP NUND P Break -off MP line, lock -out injector, NO 0.0 0.0 09:42 11:00 BOPE Rig Released: 2/18/19 @ 11:OOAM 6/12/2019 6112/2019 1.50 MIRU MOVE P Complete RD, pull off well, hook up 0.0 0.0 00:00 01:30 1 1 1jeeps and sows. 6/12/2019 6/12/2019 3.00 MIRU MOVE MOB P Roll off pad to 1J-10 0.0 0.0 01:30 04:30 6/12/2019 6/1212019 1.50 MIRU MOVE WAIT P Park inbetween 2C access pads to 0.0 0.0 04:30 06:00 allow for crew/field change out 6/12/2019 6/12/2019 5.00 MIRU MOVE MOB P Move rig from 2C access road to I 0.0 0.0 06:00 11:00 pad - meet with pad op. permission to spot up/dg up. Inspect wellhead close OA and IA, 6/12/2019 6/12/2019 2.20 MIRU MOVE RURD P Move in and spot modules 0.0 0.0 11:00 13:12 6/12/2019 6/12/2019 4.50 MIRU WHDBOP RURD P Begin RU check list, drop stairs, 0.0 13:12 17:42 secure landings, scaffold crew on location to build deck, MU hard-line, begin moving shop & 1/2 -Way House 6/12/2019 6/12/2019 0.75 MIRU WHDBOP NUND P Begin NU BOP, continue RU checklist 0.0 0.0 17:42 18:27 `•' Rig Accept @ 19:00hrs Page 8118 Report Printed: 7/1 812 01 9 Operations Summary (with Timelog Depths) 1.1-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start rime End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operahon (ftm) End Depth (11KS) 6/12/2019 6/12/2019 4.00 MIRU WHDBOP RURD P Crew Change, lockout Koomey Unit 0.0 0.0 18:27 22:27 and attempt to function (locked out) Preform Lockout audit (good), Change out 2-3/8" Deployment rams, check tree bolts. Grease crew on location, service tree valves, rig crew service choke manifold and rig valves. 6/12/2019 6/12/2019 0.55 MIRU WHDBOP RURD P Fluid pack test pump and surface 0.0 0.0 22:27 2300 lines, Perform shell test on door seal and containment (good) 6/12/2019 6/13/2019 1.00 MIRU WHDBOP BOPE P Stan Initial BOPE test, 3,500 psi 0.0 0.0 23:00 00:00 High/250 psi Low/2,500 psi Annular, witness waived by AOGCC (Austin McLeod) 6/13/2019 6/13/2019 3.50 MIRU WHDBOP BOPE P Continue initial BOP test, 3.500 psi 0.0 0.0 00:00 03:30 High/250 psi Low/2,500 psi Annular, witness waived per AOGCC (Austin McLeod) 6/13/2019 6/13/2019 0.30 MIRU WHDBOP CTOP P RD testing equipment, blow down & 0.0 0.0 03:30 03:48 1 1 1 freeze protect test pump 6/13/2019 6/13/2019 0.75 MIRU WHDBOP PRTS P Slide INJH can forward, install nozzle, 0.0 0.0 03:48 04:33 stab onto stump, test inner reel valve and pac-off. 6/13/2019 6/13/2019 1.50 MIRU WHDBOP PRTS P Fliud pack and test PDUs and tiger 0.0 0.0 04:33 06:03 tank line 6/13/2019 6/13/2019 1.50 SLOT WELLPR CTOP Blow down test equipment, work valve 0.0 0.0 06:03 07:33 check list, mud test -found sticks, plastic ad other debris packing off screens while laking on mud from Peak Vac truck. Circulated over the top to shaker screens, fluid overran the shaker with 200 mesh - research partial size of black product in mud, Peed 100 mesh or larger. 6/13/2019 6/13/2019 1.50 SLOT WELLPR PULD P PJSM, PU BHA # 8 - Clean out BHA, 0.0 54.0 07:33 09:03 3.80 parabolic (D331) mill W BOT 2- 7/8" straight motor below 2-3/8" coilTrak, Stab injector, bump up, set counters 6/13/2019 6/13/2019 2.00 SLOT WELLPR DISP P RIH turning well over to Seawater. 54.0 10,045.0 09:03 11:03 Initial tubing pressure 886 psi 6/13/2019 6/13/2019 0.30 SLOT WELLPR DLOG P Tie into the upper Kalubik -10' 10,045.0 10,106.9 11:03 11:21 correction 6/13/2019 6/13/2019 0.60 SLOT WELLPR CIRC P PU Weight 41 k lbs, RIH, hard tag and 10,106.9 10,301.9 11:21 11:57 stall @ 10301.9' with 1 k WOB, PU 41 k lbs, RBIH, and S/D two more times at the same depth, hard stall stacked WOB to 7 k and 4.7 k WOB, pickups clean @ 41-44 k lbs CT Wt. Attempted to hold 11.8 ppg EMW, loosing 0.5 bpm, targeting 10.5 ppg until well swapped over to mud. Call and consult with town engineering ' on depth with K1 6/13/2019 6/13/2019 1.10 SLOT WELLPR DISP P Pump sweeps followed by mud - 8.65 10,300.8 10,000.0 11:57 13:03 ppg Power Pro with Kla-Shield (3% KCI, 1.5% Kla-Stop, 1 % Lube 776, 1 % Drilzone, 8 ppb Asphasol Supreme, 4 ppb Resinex). Chase to bit while cycling pipe. Targeting 11.8 ppg EMW. Pull above seal bore assembly 6/13/2019 6/13/2019 0.40 SLOT WELLPR DLOG P Park, swap to CCL, RIH logging from 10,000.0 10,300.0 13:03 13:27 9970' to 10,300' bit depth. Park , open EDC. Page 9/18 ReportPrinted: 7/1812019 Uperations Summary (with Timelog Depths) ii -10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time EMTme Our (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth Y") EM Depth(WS) 6/13/2019 6/13/2019 3.00 SLOT WELLPR TRIP P POOH targeting 11.8 ppg EMW at the 10,300.0 46.0 13:27 16:27 shoe. minor loses, tag up space out 6/13/2019 6/13/2019 1.20 SLOT WELLPR PULD P PUD BHA #8, clean out BHA. 46.0 46.0 16:27 17:39 Struggle to equalize PDL, pump not moving Fluid. 6/13/2019 6/13/2019 0.85 PROD1 RPEQPT PULD P Re-config BHI tools, clean RF, crew 46.0 0.0 17:39 18:30 change, PU 4.5" XL Mono -bore WS 6/13/2019 6/1312019 1.10 PROD1 RPEQPT PULD P PD WS Setting BHA #9 0.0 76.7 18:30 19:36 6/13/2019 6/13/2019 0.20 PROD1 RPEQPT PULD P Function open 2-3/8" Deployment 76.7 76.7 19:36 19:48 rams, tag up, reset counters 6/13/2019 6/13/2019 1.80 PROD1 RPEQPT TRIP P RIH 76.7 10,065.0 19:48 21:36 6/13/2019 6/13/2019 0.20 PRODt RPEQPT DLOG P Log formation for depth control (Upper 10,065.0 10,138.0 21:36 21:48 Kalubik) @ 5 fph, correction of minus 10.5', PUW 37 k 6/13/2019 6/13/2019 0.20 PROD? RPEQPT TRIP P Continue IH to setting depth 10,138.0 10,298.7 21:48 22:00 6113/2019 6/13/2019 0.50 PROD1 RPEQPT WPST P Confirm TOWS selling depth 10,283' 10,298.7 10,283.0 22:00 22:30 as per plan, 330 ROHS, shut down pump, close EDC, obtain static differentual pressure 543 psi 6/13/2019 6/13/2019 0.20 PROD1 RPEQPT WPST P Bring pump up to shear 5,083 psi, set 10,283.0 10,244.0 22:30 22:42 down 6 k DHWOB, PUW 36 k 6/13/2019 6/1412019 1.30 PRODt RPEQPT TRIP P Obtain static pressure @ 5,946.32' 10,244.0 10,244.0 22:42 00:00 TVD 6/14/2019 6/14/2019 0.70 PRODt RPEQPT DISP P Continue building KWF, PUH slowly @ 10,283.0 10,244.0 00:00 00:42 1 1 11 fpm 6/14/2019 6/14/2019 0.75 PROD1 RPEQPT DISP P Start displacing well to 11.5 ppg KWF, 10,244.0 10,244.0 00:42 01:27 Note: bleed IA pressure from 1,458 psi down to 1000 6114/2019 6/14/2019 1.90 PROD? RPEQPT TRIP P POOH 10,244.0 76.7 01:27 03:21 6/14/2019 6/14/2019 0.50 PROW RPEQPT OWFF P check well for Flow (Initial Loss Rate 6 76.7 76.7 03:21 03:51 bph), PJSM for LD BHA 6/14/2019 6/14/2019 0.60 PROD1 RPEQPT PULD P LD setting tools on a dead well 76.7 0.0 03:51 04:27 6/14/2019 6/14/2019 0.80 PROD1 RPEQPT CTOP Move Cart forward, remove BHI UQC, 0.0 0.0 04:27 05:15 cul and boot a -line 6/14/2019 6/14/2019 1.00 PROD1 RPEQPT CTOP PU/MU 4 joints of 2-3/8" PH6 with 0.0 05:15 06:15 ported nozzle for catching ball 6/14/2019 6/14/2019 0.80 PROD1 RPEOPT CTOP Sab injector pump 1 coil volume 0.0 06:15 07:03 forward 6 surges up to 2.5 bpm to pump wire forward. 6/14/2019 6114/2019 0.60 PROD1 RPEQPT CTOP Unstab injector, cul and pull wire, 0.0 07:03 07:39 recoverd 136' of a -line. Cut pipe back 13', reboot Elms. 6/14/2019 6/14/2019 0.50 PROD1 RPEQPT CTOP Install BOT external coil connector, 0.0 07:39 08:09 Pull test to 37 k Ibs, PT to 4000 psi - good. 6/14/2019 6/14/2019 0.80 PROD1 RPEQPT CTOP P Drop ball, pumps to 2.5 bpm, hear 0.0 0.0 08:09 08:57 ball launch, some more wire move, hear ball leave the coil to the goose neck, SID 40 bbls away. 6/14/2019 6/14/2019 0.50 PROD1 RPEQPT CTOP P Pop off, LD PH-6jnts, additional 134' 0.0 0.0 08:57 09:27 of slack pumped forward, retireved ball from nozzle, good test on a -line 65.6 Ohms/2000 M ohms, cut a -line, epoxy & protect tag end. "Total wire recovered 270' Page 10118 Report Printed: 711812019 . Uperations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan oepm a Ti Stanme Eml Time Our ae) Phase Op Cotl Acwlty Cafe Time P -T -X Operabon (flK Erq Cepm (flKa) 6/14/2019 6/14/2019 2.40 PRODi RPEQPT CTOP P Discuss amounts of wire relieved, 0.0 0.0 09:27 11:51 Stabbed on and pumped one last time. No additional wire returned, left 2'stump. LD PH -6. 6/14/2019 6/14/2019 1.40 PROD1 WHPST PULD P PJSM, PU BHA#2 Window Assembly, 0.0 248.7 11:51 13:15 bump up and set counters 6/14/2019 6/14/2019 1.60 PROD1 WHPST TRIP P RIH pumping 15 bbl spacer between 248.7 10,283.0 13:15 14:51 KW and Mud W black product. PU Wt @ 10200'39 k lbs, Dry tag TOB 10,283 6/14/2019 6/14/2019 0.70 PROD1 WHPST DISP P Turn well over to milling fluid. Took 10,283.0 10,226.0 14:51 15:33 gas back to surface, exported returns to the tiger tank. IA pressure built rapidly was 1108 psi @ 14:00. to 1400 psi. Suspect T x IA, deep leak, possibly the OV, 6/14/2019 6/14/2019 2.00 PROD1 WHPST DISP T Export119 bbls. IA tracking wellhead. 10,226.0 10,283.0 15:33 17:33 Bring mud back inside. Bleed IA from 1,400 to ll55 psi. Observe fluid entering the IA. Set rates and RIH to mill window. 6/14/2019 6/14/2019 1.00 PROD? WHPST TRIP P Set parameters, CT 4340 psi, WH 351 10,283.0 10,293.0 17:33 18:33 psi, @ 2.5 bpm in and 2.5 bpm out, RIH wt 11.1 k lbs, IA 1219 psi, OA 58 psi., chase weight down to 10,293', PUH and dry tag x 2 TOWS @ 10293' 6/14/2019 6/14/2019 2.00 PROD1 WHPST MILL P Set parameters, CT 4340 psi, WH 351 10,293.0 10,294.7 18:33 20:33 psi, @ 2.5 bpm in and 2.5 bpm out, RIH wt 11.1 k lbs, IA 1219 psi, OA 58 psi 6/14/2019 6/14/2019 2.00 PROD1 WHPST MILL P Milling ahead , 4,574 psi, WH 558 psi, 10,294.7 10,295.7 20:33 22:33 @ 2.5 bpm in and 2,48 bpm out, IA 1,306 psi, OA 75 psi 6/14/2019 6/15/2019 1.45 PROD1 WHPST MILL P Milling ahead, 4,654 psi, WH 558 psi, 10,295.7 10,296.5 22:33 00:00 @ 2.5 bpm in and 2,48 bpm out, IA 1,307 psi, OA 82 psi 6/15/2019 6/15/2019 0.50 PROD1 WHPST MILL P Milling ahead , 4,654 psi, WH 558 psi, 10,296.5 10,296.7 00:00 00:30 @ 2.5 bpm in and 2,48 bpm out, IA 1,307 psi, OA 82 psi 6/15/2019 6/15/2019 0.20 PROD1 WHPST MILL P Stall motor, PUH PUW 36 k 10,296.7 10,296.7 00:30 00:42 6/15/2019 6/15/2019 2.00 PROD? WHPST MILL P Restart 2.49 bpm @ 4,325 psi, 10,296.7 10,298.9 00:42 02:42 Diff -130 psi, WHP=550, IA=1,301, OA=82 6/15/2019 6/15/2019 2.30 PRODt WHPST MILL P Milling ahead, 4,274 psi, WH 541 psi, 10,298.9 10,301.5 02:42 05:00 @ 2.50 bpm in and 2,53 bpm out, IA 1,301 psi, OA 86 psi 6/15/2019 6/15/2019 1.50 PRODi WHPST MILL P Milling ahead , 4,228 psi, WH 576 psi, 10,301.5 10,303.3 05:00 06:30 @ 2.5 bpm in and 2.5 bpm out - CT Wt 7.5 k lbs, 6/15/2019 6/15/2019 1.30 PROD1 WHPST MILL P "Mill exits the rasing - 11.8' window- 10,303.3 10,304.9 06:30 07:48 10,303.3' Milling ahead , 4,180 psi, WH 582 psi, @ 2.50 bpm in and 2.45 bpm out, 6/15/2019 6/15/2019 1.70 PROD1 WHPST MILL P •* Both mill and reamer out - start 10,304.9 10,318.0 07:48 09:30 pushing on it - 10,304.9' Milling ahead , 4,180 psi, WH 582 psi, @ 2.50 bpm in and 2.45 bpm out, 10,312.1' Stall, PU Wt 40 k lbs TD rat hole - Geo confirms shale in sample 6/15/2019 6/15/2019 0.80 PROD1 WHPST MILL P Perform reaming passes to 10,288' 10,318.0 10,289.0 09:30 10:18 second up pass clean. Page 11/18 ReportPrinted: 7/18/2019 Operations Summary (with Timelog Depths) 1.1-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time Dur (hr) Phase Op Code Activity Cade Tim P-T-X Operaiwn Start Depth (KKa) End Depth (WB) 6/15/2019 6/15/2019 1.00 PROD1 WHPST MILL P PUH, cut pumps, Dry drift, good, turn 10,289.0 10,258.0 10:18 11:18 coil over to kill weight fluid - 11.5 ppg NaBr 6/15/2019 6/15/2019 3.30 PROD1 WHPST TRIP P PUH turning well over to KW fluid. 10,258.0 270.0 11:18 14:36 Pulled heavy@ 10113', 9937', 9742', and 9389' Unexplainable, tripped injector set points. Seems to happen at pulling speeds above 80-85 ft/min. Reduced POOH speed to 70 ft(min. 6/15/2019 6/15/2019 2.00 PROD1 WHPST PULD P At surface, 90 psi well head as soon 270.0 0.0 14:36 16:36 as the pumps were cut. Bleed IA, WH dropping with IA. Zero WH with 880 psi on the IA, Shut in IA, climbed slowly to 958 and stabilized, Zero flow, PJSM, LD BHA#10. DSM and string reamer gauged out at 3.79" / 3.80" respectfully. 6/15/2019 6/15/2019 2.00 PROM DRILL PULD P PU Drilling liner 0.0 218.6 16:36 18:36 6/15/2019 6115/2019 0.30 PROM DRILL PULD P PU TJ Hydraulic Disconnect, XO 2- 218.6 248.6 18:36 18:54 3/8" Reg x 2-3/8" Pac, and dual back pressure valve 6/15/2019 6/15/2019 0.30 PROM DRILL PULD P PU 6 2-3/8" PH6 CS Hydrill joints 248.6 436.0 18:54 19:12 6/15/2019 6/15/2019 0.30 PROM DRILL PULD P PU/MU BHI CoilTrak tools with 436.0 458.1 19:12 19:30 lockable swivel. 6/15/2019 6/15/2019 1.80 PROM DRILL TRIP P Stab INJH, tag up, reset counters, RIH 458.1 8,059.0 19:30 21:18 pumping 0.46 bpm at 595 psi, @ Limited tripping speed per NS Rep - 80 fpm 6/15/2019 6/15/2019 0.20 PRODt DRILL TRIP P Check depth at EOP flag 7,605.6', 8,059.0 10,308.0 21:18 21:30 looks like minus 10', continue IH thru window with no pumps, @ 10,313' bring pump up to 0.36 bpm tag bottom @ 10,318', correct minus 10.0', PUH PUW 41 k 6/15/2019 6/15/2019 1.80 PRODt DRILL DISP P Displace well to 9.0 ppg drilling fluid 10,308.0 10,308.0 21:30 23:18 6/15/2019 6/15/2019 0.20 PROD1 DRILL DRLG P Bring pump up to 2.52 bpm at 5,643 10,308.0 10,309.0 23:18 23:30 1 1 psi, WHP=229, IA=926, OA=74 6/15/2019 6/16/2019 0.50 PROD1 DRILL DRLG P Drill ahead to 103092', seems to be 10,309.0 10,309.0 23:30 00:00 stalled, PUH 55 k, broke back to 43k, bring pump back online, 2.5 bpm @ 5.738 psi, WHP=225, IA=943, OA=75 6/16/2019 6/16/2019 0.20 PROD1 DRILL DRLG P PUH PUW 41 k 10,309.0 10,263.0 00:00 00:12 6/16/2019 6/16/2019 0.30 PROD1 DRILL DRLG P RBIH, dry tag bottom @ 10,308' 10,263.0 10,308.0 00:12 00:30 6/16/2019 6/16/2019 0.20 PR0D1 DRILL WPRT P PUH, bring pump up to 2.54 bpm @ 10,308.0 10,306.0 00:30 00:42 5,087 psi, seemed to be in a stall @ 6,400 psi, PUW70 k, RBIH @ 1.5 bpm @ 3,600 psi, attempt to RIH from 10,300', stackoul at 10,306' 6/16/2019 6/16/2019 0.20 PROD1 DRILL WPRT P PUH above window 10,177', continue 10,306.0 10,177.0 00:42 00:54 building tubed pill 3 Dols to 5% lubes 2.5% lo-torque, and 2.5% 776, while receping pipe 6/16/2019 6/1612019 0.80 PROD1 DRILL WPRT P 5 bbls of lube pill out bit, RIH, stackout 10,177.0 10,283.0 00:54 01:42 10,283', PUH PUW 43 k x 6, uinable to pass through TOWS, PUH slowly phone town team on plan forward, Page 12118 Report Printed: 7/18/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log stat Time End Time our (hr) Please op Cade Acbvity Code Time P -TA operation Stan Depm (WB) EM Depen (ftKB) 6/16/2019 6/16/2019 1.50 PROD1 DRILL DISP T Recieved call back, decision was 10,283.0 10,283.0 01:42 03:12 made to kill well with 11.5 ppg KWF, confirm KWF is 11.5 ppg, configure pits for displacement. 6/16/2019 6/16/2019 0.25 FROM DRILL TRIP T POOH 40 k, while displacing well to 10,283.0 9,355.6 03:12 03:27 11.5 ppg KWF, pulled tight at 9,355'50 k, top of tools @ 9,097', work pipe up/down -10 k/+70 k 6/16/2019 6/16/2019 1.50 PROD1 DRILL TRIP T Phone town team on plan forward, 9,355.6 9,355.6 03:27 04:57 tools limitations, plan forward finish killing well, work pipe up to 80 k, pump 5/8" steel ball to attempt release of the NS liner running tool. 6/16/2019 6116/2019 3.30 FROM DRILL DISP T Continue killing the well, KW strung 9,355.6 9,355.6 04:57 08:15 out. 1.45 bpm in and 1 bpm out, reduce pump rate, 1 bpm in and .9 bpm out. Out MM density slowly rising, Out MM reading -.1 ppg higher than pressurized mud balance in pits. 6/16/2019 6/16/2019 1.00 FROM DRILL DISP T Kill weight all the way around. 1.02 9,355.6 9,355.6 08:15 09:15 bpm in and 0.9 bpm out, CT 2702 psi, WH 0, IA 1348 psi, OA 81 psi. CT Wt 10.81 k lbs S/I pump for flow test, WH climbed to 579 psi, Bleed IA for 15 minutes, WH fell to Zero, IA @ 600 psi, S/I bleed, IA climbed to 677 and slowly climbed. Flow test well, Well is dead. Work coil from 80 K Ibis to -20 K lbs 5 times, still stuck. 6/162019 6/1612019 0.80 PROD1 DRILL DISP T Launch 5/8" ball to activate liner 9,355.6 9,355.6 09:15 10:03 hanger release tool Pump KW @ 2 bpm. Ball left the reel at 31 bbls away. Reduce rale to - 0.5 bpm. 6116/2019 6/16/2019 0.30 PRODi DRILL DISP T Ball on seat. Pressure up CT to 4 k, 9,355.6 9,211.0 10:03 10:21 wait, pick up to 50k lbs Ct. Slack of to 9 k CT Wt, pump CT to 5 k psi, wait, slack off to 0 k CT PU 50ft/min, to 55 k Ibis CT wt. slack off to 9 k ct wt, pump on CT again, observe shear at 5350 psi, WH 456 psi. Well unloaded as we PUH, had been packed off above. POOH pumping 2 bpm, full returns, screening down at shaker to 120 mesh. Balls ofAsphasol Supreme / Resinex coming off the shaker, not much if any metal. 6/16/2019 6/16/2019 4.20 FROM DRILL TRIP T PUH, CT 5645 psi, 2.28 bpm in and 9,211.0 2,000.0 10:21 14:33 2.11 bpm out WH 296psi, IA 955 psi, OA 105 psi. Did not correct bit depth for dropped off liner and setting tools. Estimate top of fish @ 9113.37 - Should tag ten feet deeper @ 9123' because of correction. "242.23' of fish left in hole, liner hanger, 8 joints of 3.5" 511 tubing, triple connection bushing W 2.5 k SI disk, sleeve over motor, 2-7/8" straight motor, XO and 4.125" bi center bit. 6/16/2019 6/16/2019 0.90 PRODt DRILL TRIP T Large amount of pea gravel sized 2,000.0 240.0 14:33 15:27 cuttings returned to the shaker @ 2000'. Heavy flow for - 10 minutes, increased pump rate to 2.4 bpm. Gravel returns diminished by 1,550'. Page 13118 ReportPrinted: 7/1 812 01 9 e Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time ad Tune Our (hr) Phase Op Code ANvity Code Time P -T -x OperaBon Start Depth (flKB) Ertl Depth (flKB) 6/16/2019 6/16/2019 1.20 PROD1 DRILL PULD T Bump up, IA 858 psi, S/I pumps, WH 240.0 0.0 15:27 16:39 climbed to 280 psi, bleed IA for 5 min WH fell to 0 psi. S/I bleed. Flow check good. Lay down BHA#11 over a dead well. ***Retrieved 5/8" ball from liner setting tool. 6/16/2019 6/16/2019 1.20 PROD1 DRILL PULD T PU BHA #13, Clean out assmbly 0.0 213.7 16:39 17:51 6/16/2019 6/16/2019 1.90 PROD1 DRILL TRIP T Stab INJH, tag up reset counters, RIH 213.7 9,126.0 17:51 19:45 6/16/2019 6/16/2019 1.50 PROD1 DRILL TRIP T Dry tag TOF @ 9,126', PUH continue 9,126.0 9,126.0 19:45 21:15 loading new mud system into pits 6/16/2019 6/1612019 0.50 PRODt DRILL DISP T Displace well to drilling fluid, line up 9,126.0 9,123.0 21:15 21:45 returns to tiger (15 bbls), bring back in, blow dawn the tiger tank line. 6/16/2019 6/16/2019 1.25 PROD1 DRILL WPRT T Perform recips x 3 from 9,123' up hole 9,123.0 8,040.0 21:45 23:00 8,050' w/sweeps, pumping 2.8 bpm at 4,915 psi, WHP=301, IA=379, OA=74, not seeing pea gravel (shale), black sand and glass beads. 6/16/2019 6117/2019 1.00 PROD1 DRILL WPRT T POOH, performing jogs from 8,100' x 8,040.0 6,464.0 23:00 00:00 3 w/5x5 sweep 6/17/2019 6/17/2019 1.70 PROD1 DRILL WPRT T Continue swab wiper, performing jogs 6,464.0 214.0 00:00 01:42 from 6,350' and 3,750'x 3 w/5x5 sweeps 6117/2019 6/17/2019 1.80 PROD1 DRILL TRIP T Tag up, reset counters, RBIH 214.0 9,100.0 01:42 03:30 6/17/2019 6/17/2019 0.50 PRODt DRILL DISP T Displace well to 11.5 ppg KWF 9,100.0 9,100.0 03:30 04:00 6/17/2019 6/17/2019 1.80 PROD1 DRILL TRIP T POOH, while displacing well to KWF, 9,100.0 243.0 04:00 05:48 interface 10 bbls sent out to tiger tank. 6/17/2019 6/17/2019 1.40 PROD1 DRILL PULD T Bleed IA, till WH zero, S/I bleed, flow 243.0 0.0 05:48 07:12 check good. LD BHA#12 over a dead well. 6/17/2019 6/17/2019 1.00 PROD1 DRILL PULD T PU BHA#13, fishing assembly. Stab 0.0 226.6 07:12 08:12 on, Bump up and set counters. 6117/2019 6/17/2019 1.80 PRODi DRILL TRIP T RIH w fishing assembly pumping min 226.8 9,130.0 08:12 10:00 rale 11.5 ppg KW fluid. Lightweight fluid coming back according to micro motion, Verified good kill weight returning via pressurized mud balance. Pinch in choke to hold a small amount f back pressure micro motion signal cleaned up, 11.5 ppg KW returning. Continue in hole. PU Wt 33 k lbs 8918' Set down 9130 6/17/2019 6/17/2019 0.70 PROD1 DRILL FISH T Make multiple fishing attempts with 9,130.0 9,134.7 10:00 10:42 GS spear. Run into fish washing down from 1 tol.9 bpm. Stacking up to -10 k CT Wt, PU Wt, 30-34 k lbs, No indication of engaging fish, Pick up weights clean. Deepest CT depth recorded 9134.7 with -10 k CT Wt. Page 14118 Report Printed: 711812019 uperations Summary (with Timelog Liepths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Siert Depth Start Torre End Time our (hr) Poase Op Code Activity Code Time ?-T-X Operabon (flKa) End Deplh (Id(9) 6/17/2019 6/17/2019 3.60 PROD1 DRILL FISH T PUH 300 feet, RBIH, S/D in same 9,134.7 9,119.0 10:42 14:18 spot, 9134.6' and -5 k CT Wt. Wash over fish @ 1.9 bpm, while building kill weight viscosified sweep. Pump 10 bbls high vis 11.5 ppg sweep. Wash down over fish as sweep exits, chase sweep out of hole. Nothing notable in the returns as the sweep landed at the shaker. 6/17/2019 6/17/2019 0.80 PROM DRILL FISH T Hit 5 jar licks down trying to latch 9,119.0 9,091.0 14:18 15:06 every time. No movement in fish and no definitive indication that fish is on. 6/17/2019 6/17/2019 1.40 PROD1 DRILL TRIP T POOH pumping over the top 9,091.0 262.0 15:06 16:30 6/17/2019 6/17/2019 1.40 PRODi DRILL PULD T LD BHA#13 over a dead well, did not 262.0 0.0 16:30 17:54 have to bleed IA. (IA 495 psi, OA 73 psi) 6/17/2019 6/17/2019 1.10 PROM DRILL PULD T PU BHA#14 ,No Go, 2-3/8" intact AKO 0.0 237.6 17:54 19:00 (03 0", w 2.77" slick D331. 6/17/2019 6/17/2019 1.50 PROD1 DRILL TRIP T RIH with motor and mill - cleanout 237.6 9,118.0 19:00 20:30 assembly. 6/17/2019 6/17/2019 0.60 PROD1 DRILL CIRC T Dry tag @ 9137.5' PU 33 k lbs. RBIH 9,118.0 9,136.0 20:30 21:06 pumping 1.89 bpm. Set 10k Ibs CT Wt down, no fluctuation in pump pressure, not making hole. Chase 10 bbl 11.5 ppg Hi Ys sweep to bit and jet inside fishing neck while puling slowly up hole. 6/17/2019 611712019 2.65 PRODt DRILL TRIP T POOH chasing sweep pumping 1.87 9,136.0 238.0 21:06 23:45 bpm and pulling 50 ft/min. 6/17/2019 6/18/2019 0.25 PROD1 DRILL OWFF T Check well for flow 238.0 238.0 23:45 00:00 6/18/2019 6/18/2019 0.50 PROM DRILL PULD T Continue monitoring well for flow, LD 238.0 0.0 00:00 00:30 cleanout BHA#14 6/18/2019 6/18/2019 0.85 PROD1 DRILL PULD T PU/MU fishing assembly 0.0 226.8 00:30 01:21 6/18/2019 6/18/2019 1.60 PRODt DRILL TRIP T RIH w/ fishing BHA#15 to fish NS 226.8 9,080.0 01:21 02:57 Liner Drilling Assembly, w/4' GS and jars. 6/18/2019 6/18/2019 0.15 PROD? DRILL TRIP T Perform PUW 33 k 9,080.0 9,080.0 02:57 03:06 6/18/2019 6/18/2019 1.50 PROD1 DRILL FISH T Continue IH, dry tag TOF @ 9,080.0 9,121.0 03:06 04:36 9,121'CTMD uncorrected, PUW 33 k, no fish, bring pump up to 1.5 bpm, RBIH, set down minus 10 k CTSW, PUH, RBIH, attempt to latch fish, increase pump rate 1.75 bpm, set down 8.0 k 6/18/2019 6/18/2019 1.90 PROM DRILL TRIP T POOH unable to engage fish, hole 9,121.0 0.0 04:36 06:30 appears to be clean, pump pipe displacement 6/18/2019 6/18/2019 0.50 PROD1 DRILL OWFF T OWFF for 30 min. 0.0 0.0 06:30 07:00 6/18/2019 6/18/2019 2.10 PROD1 DRILL PULD T LD BHA# 15 and inspect 4" GS, the 0.0 0.0 07:00 09:06 4" GS, had a shiny mark, a full 360° around the dog retainer skirt, with a slight lip. It appear the GS is fully NOGO'd to leave this mark but is not engaging the deployment sleeve. Trimmed 3/8" of the dog retainer sleeve to give the GS a deeper reach. MU BHA#16 with modified 4" GS Page 15118 Report Printed: 7/18/2019 Uperations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start TMs End Tim Our mr) Phase Do Cade Activity Code Time P -T -x Operation Start Depth (RKB) End Depth (RKa) 6/18/2019 6/18/2019 1.60 FROM DRILL TRIP T RIH w/ fishing BHA#16, 4" GS, 0.0 9,126.0 09:06 10:42 modified skirt, PUW 33K 6/18/2019 6/18/2019 0.70 FROM DRILL FISH T Tag at 9126, SD 10K, PU clean, make 9,126.0 9,126.0 10:42 11:24 9 attempts to engage and latch, no overpulls, try pumping, surging 6/18/2019 6/18/2019 1.50 FROM DRILL TRIP T POOH, unable to engage fish, tag up 9,126.0 0.0 11:24 12:54 6/18/2019 6/18/2019 0.50 FROM DRILL OWFF T OWFF for 30 min 0.0 0.0 12:54 13:24 6/18/2019 6/18/2019 1.40 FROM DRILL PULD T LD BHA#16 and inspect 4" GS, no 0.0 0.0 13:24 14:48 discernible marks on GS. MU BHA #17, 3.77" OD LIB 6/1812019 6/18/2019 1.60 PROM DRILL TRIP T RIH w/ LIB to take picture of fish, at 0.0 9,126.0 14:48 16:24 9000' CTMD, PUW 33K, pump jars open and let pressure stabilize 5 min, down on pump, run into fish at 50 FPM, 13K, tag at 9126' CTMD, w/ IOK down, 1 jar lick. 6/18/2019 6/18/2019 1.50 PROD1 DRILL TRIP T POOH to develop picture. 9,126.0 226.7 16:24 17:54 6/18/2019 6/18/2019 0.50 FROM DRILL OWFF T At surface, check well for flow, PJSM 226.7 226.7 17:54 18:24 6/18/2019 6/18/2019 0.50 FROM DRILL PULD T LD LIB BHA#17 226.7 0.0 18:24 18:54 6/18/2019 611812019 0.75 FROM DRILL CTOP T Discuss plan forward with town team 0.0 18:54 19:39 6/18/2019 6/18/2019 1.00 PROD1 DRILL PULD T PU fishing BHA#18 w/stinger and 0.0 235.3 19:39 20:39 D331 (2.77od) 6/18/2019 6/18/2019 1.50 FROM DRILL TRIP T RIH 235.3 9,119.0 20:39 22:09 6/18/2019 6118/2019 0.80 FROM DRILL FISH T PUW 33 k,Tag TOP of fish @ 9,119.0 9,119.0 22:09 22:57 9,119' (8.0' higher), PUW 33 k, PUH to 9,100', RBIH bring pump up to 1.83 bpm w/5,360 psi, slowdown to 5 fpm, observe 200 psi increase in pump pressure, stack out at 9,116', PUH, PUW 33 k, PUH further RBIH increasing speed up to 45 fpm, set down -10 k, PUW 33 k, repeat process while pumping washing down slowly, not seeing any indication of latching up. x 13, with no success. 6/18/2019 6/18/2019 0.20 FROM DRILL TRIP T Discuss plan forward with town team, 9,119.0 9,119.0 22:57 23:09 decision was made to POOH for po- go, motor and mill. Paint EOP flag 8,903 EOP (Yellow) 6/18/2019 6/1912019 0.85 FROM DRILL TRIP T POOH 9,119.0 3,789.0 23:09 00:00 6/19/2019 6/19/2019 0.75 FROM DRILL TRIP T Continue POOH with GS BHA #18 3,789.0 235.3 00:00 00:45 6/19/2019 6/19/2019 0.50 FROM DRILL OWFF T Tag up, observe well for flow (no -flow) 235.3 235.3 00:45 01:15 6/19/2019 6/19/2019 0.50 FROM DRILL PULD T LD BHA #18 on a dead well 235.3 0.0 01:15 01:45 6/19/2019 6/19/2019 0.50 PROD1 DRILL PULD T PU/MU Cleanout BHA#19 0.0 237.6 01:45 02:15 6/19/2019 6/19/2019 1.50 FROM DRILL TRIP T Tag up, reset counters, RIH, PUW 33 237.6 9,100.0 02:15 03:45 k 6/19/2019 6/19/2019 0.20 FROM DRILL TRIP T Continue RIH, set down 2-3k CTSW 9,100.0 9,133.8 03:45 03:57 @ 9,133', 8,904' EOP same as pervious BHA#17 Page 16118 ReportPrinted: 7118/2019 ` Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tim our (hr) Phase Op Cade Activity Code Time P -T-% Operation (flKS) End Depth(W) 6/19/2019 6/19/2019 2.80 PROD1 DRILL TRIP T Work numbers, discuss recorded tag 9,133.8 9,133.0 03:57 06:45 up and depths. Wait to discuss with Town team. 6/19/2019 6/1912019 1.40 PROD1 DRILL TRIP T POOH, w/ motor & D331 mill 9,133.0 237.6 06:45 08:09 6/19/2019 6/19/2019 0.50 PROD1 DRILL OWFF T Tag up, observe well for flow (no -flow) 237.6 237.6 08:09 08:39 6/19/2019 6/19/2019 1.70 PROD1 DRILL PULD T LD BHA *19, MU BHA#20, GS w/ 0.0 238.3 08:39 1021 motor and 2.77" D331 mill, Tag up, reset counters, 6/19/2019 6/19/2019 1.60 PROD1 DRILL TRIP T RIH wl 4" GS above motor and 2.77" 238.3 9,139.0 10:21 1157 D331 mill. 6/19/2019 6/19/2019 0.50 PROD1 DRILL FISH T Tag @ 9139', pumping 0.3 bpm, CP= 9,139.0 9,139.0 11:57 1227 4200 psi, down on pump, let pressure bleed off, no jar lick, PU clean. Make 4 more attempts to latch, saw over 1000 psi pressure drop after 2nd attempt, unsure why, CP now at 4600 psi at 1.9 bpm, CP was 5900 psi at same rale, not able to latch fish 6/19/2019 6/19/2019 1.56 PRODt DRILL TRIP T POOH 9,139.0 0.0 12:27 14:00 6/19/2019 6/19/2019 0.50 PROD1 DRILL OWFF T Tag up, observe well for flow 0.0 0.0 14:00 14:30 6/19/2019 611912019 1.75 PROD1 DRILL PULD T LD BHA #20, no indication of latching, 0.0 0.0 14:30 16:15 no marks 6/19/2019 6/19/2019 1.50 PROW DRILL CTOP P Pump wire slack back, cut off BOT 0.0 0.0 16:15 17:45 connector, cut coil, found wire @ 290' Note: 290' of coiled tubing trimmed. 6/19/2019 6/19/2019 1.75 PROD1 DRILL CTOP P Crew change, test e -line (64.81>2000), 0.0 0.0 17:45 19:30 Install CTC, pull test 35 k, head up BHI upper quick 6/19/2019 6/19/2019 0.50 PROD1 DRILL CTOP P PT CTC 4,500 psi 0.0 0.0 19:30 20:00 6/19/2019 6/19/2019 0.20 PROD? DRILL CTOP P Install 2-118" nozzle with 0.75 ID port 0.0 0.0 20:00 20:12 on bottom, 6.125" length. 6/19/2019 6/19/2019 0.30 PROD1 DRILL CTOP P Stab INJH, pump 1 coil volume 0.0 0.0 20:12 20:30 forward 6/19/2019 6/19/2019 0.45 PROD1 DRILL PULD P PJSM, PU CoilTrak tools 0.0 42.8 20:30 20:57 6/19/2019 6/19/2019 1.80 PROD1 DRILL TRIP P Tag up, reset counters, RIH 42.8 8,640.0 20:57 22:45 6/19/2019 6/19/2019 0.30 PRODt DRILL DLOG P Log formation correction of minus 5.0', 8,640.0 8,668.0 22:45 23:03 6/19/2019 6/19/2019 0.20 PROD1 DRILL TRIP P Continue IH, while circulating SW 8,668.0 9,113.0 23:03 23:15 down coil 6/19/2019 6/19/2019 0.25 DEMOB WHDBOP DISP P Displace well to SW 9,113.0 9,113.0 23:15 23:30 6/19/2019 6/20/2019 0.75 DEMOB WHDBOP DISP P POOH, while displacing well 9,113.0 6,344.0 23:30 00:15 6/20/2019 6/20/2019 0.70 DEMOB WHDBOP TRIP P Continue POOH, LRS on location, 6,344.0 2,500.0 00:00 00:42 PJSM move unit in and rig up to rig, PIT hose to 4,500 psi 6120/2019 6/20/2019 0.75 DEMOB WHDBOP FRZP P Load CT w/45 bblFreeze protect well 2,500.0 2,500.0 00:42 01:27 6/20/2019 6/20/2019 0.50 DEMOB WHDBOP FRZP P POOH, while displacing well to deisel 2,500.0 2,500.0 01:27 01:57 6/20/2019 6/20/2019 1.05 DEMOB WHDBOP PULD P PUD, BHA#21 2,500.0 42.8 01:57 03:00 Page 17118 Report Printed: 7/18/2019 Operations Summary (with Timelog Depths) U-10 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time I End Time our(hr) Phase Op Code Activity Code Time P -T-% Operation Start Depth (ftKB) End Depth ttKB) 6/20/2019 6/20/2019 1.00 DEMOB WHDBOP PULD P LD, Displace and freeze protect BHA 42.8 0.0 03:00 04:00 #21 "' Note: June 13th Static w/8.84 ppg fluid IH, ECD=11.139 ppg, RKB to Sea Lvl = 114.25', AP=3,441 psi, Pres Sensor=5,946.32' TVD "' Note: Final tubing pressure 1,057 psi / no BPV installed 6/20/2019 6/20/2019 0.50 DEMOB WHDBOP RURD P MU Nozzle, stab onto well, recep coil 0.0 0.0 04:00 04:30 while flushing all surface lines and stack. 6/20/2019 6/20/2019 0.25 DEMOB WHDBOP RURD P UnstabINJH, RU to bore -o -scope 0.0 0.0 04:30 04:45 BOPE, while off loading and cleaning pits 6/20/2019 6/20/2019 5.25 DEMOB WHDBOP RURD P RDMO, Work thru Demob checklist, 0.0 0.0 04:45 1000 Rig off High Line, *** Rig Release @ 10:00 AM .`", NES Trucks on location at 11:45 AM, Hold Pre Move safety meeting Page 18/18 Report Printed: 7/18/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1.1 Pad 1J-10L1PB1 50-029-23010-70 Baker Hughes INTEQ Definitive Survey Report 12 April, 2019 BA ER hUGHES Pant' Dealgn 1J-10L1P81 Aoea Nat, Version: LO Phase. ACTUAL Tie On Depth: 10,166.00 Vertical Seelon: Depth From (WD) +Nb +EIY9 Donations (usftl (such) (oeh) (1) 11425 000 000 120.Dp ER a 1 WRFS J 70° 15 45,169 N 149-31 32.426W 0 00 usft FWd Mmngm (nT) 57.424 Survey Program ConoeoPhillips v , , COf1000�lll�ip5 Survey Report From To Definitive company: Comcomullips Areas lne Kupamk Local Corortlinam Reference: Well 1J-10 Praia.: Ku(xmk River Unil_1 TVD Reference: 1J-10:114.25 ®114.25uaf (1J 1(1:114.25) Site: 1(upamk iJ Pad MD Reference: 1J-10:114.25 ®114,25usft (1J-10:114.25) Well: 1J10 North Reference: True Wellbore: 1J-1oL1PB1 Survey Calculation Method Minimum Curvature Design: 1J-1UL1PB1 Database: EDT 14 Alaska Pmducdon Protect Kupamk River Urn, Nunn Slope matte, Unded Sleks Panel Map Sysnm: US State Plane 1927 (Evac) solution) System Datum: Mean Sea Level Gee Datum: NAD 1927 (NADCON CONUS) Using Well Reference Paint Map Zorn: Moak. Zone 04 Using geedelic scale factor Well 1J-00 Wall Foodon +NIS 0.00 Usti Northing: 5,945,800.06us8 Laetude: +EI -W 0.00 Ulm Easting: 558,673.32ueft Longitude: Posluer Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: Walloon, 1J-1011 PB1 Ma9nctics Model Name Sample Date Declination Dip Angle M r) BGGM2018 21112019 1677 80.84 Dealgn 1J-10L1P81 Aoea Nat, Version: LO Phase. ACTUAL Tie On Depth: 10,166.00 Vertical Seelon: Depth From (WD) +Nb +EIY9 Donations (usftl (such) (oeh) (1) 11425 000 000 120.Dp ER a 1 WRFS J 70° 15 45,169 N 149-31 32.426W 0 00 usft FWd Mmngm (nT) 57.424 Survey Program Data From To Burvey Survey (.111 (Intl) BMrvey(W.IIbmm Tool Name DeseApdon Start DM End Data ! I 205.18 10,166.0 1J-10(iJ-10) MWDtlFR-AKL -$C MWD+IFR AS CAZ SCC 69nool 10,307.00 10,30Z00 1J-1011 PBI (IJ -101.1 PB1) BLIND Blind drilling 211512019 211512019 WfZffi19 7,51:31AM Panel COMPASS 5)00.14 Budd 850 �ER 1 W11E6 4/128019 7,57,J1AM Pe9e J COMPASS 5000.149uJC 850 ConocoPhillips ConocoPhlllips Definitive Survey Report CmmWOY Cono.Philips Alaska Inc Kupamk Local Corortllnme Reference: We111J-10 Pmjeat Kupamk River Unhl TVD Reference: 1J-10:11425®114.25usfl(1J-10:11425) Sao: Kupamk IJ Pad MD Reference: 1J-10:114.250114.25usfl(1J-10:11425) Well: 1J-10 N.Mi Reference: True Wellbore: 1J-101-1 PB1 Survey Calculation Mema0: Minimum Curvature Deal9n: it -10L1 PBI Deab... EDT 14 Alaska Protluction Survey Map Map Vertical MD Inc M TVD TVOSS aN14 ae.w No EaDLS Section Survey Too] Name Annotation (usrc) (°) 19 (0aln (pan) luau) (wrc) (ft) l P100.1 (M Int 10.166M 52.95 295,14 5,945.76 5,]9:1.97 3.587.77 .7.455949]43.13 55193876 075 -]6060 1.04 BLIND (2) TIP f0307D3 53.92 293.02 5.969.18 5,8]481 3,63467 -,0..53 5,949.389.22 551835.34 1.01 -0.714% BLIND (2) KOP 10,382. 53.92 293.02 6,021.55 5,90].30 3,65..63 -B %19 5.949.406&5 551]85.54 0.00 -7.25075 PRQIECTEDWTD �ER 1 W11E6 4/128019 7,57,J1AM Pe9e J COMPASS 5000.149uJC 850 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1J-IOLI ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-012 Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Surface Location: 1996' FSL, 2536' FEL, SEC. 35, TI 1N, R10E, UM Bottomhole Location: 4871' FNL, 4211' FEL, SEC. 27, TI 1N, R10E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 201-071, API No. 50-029- 23010-00-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this5 day of February, 2019. STATE OF ALASKA AL ,<A OIL AND GAS CONSERVATION COMM1 ,,ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED JAN 2 5 2019 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑ Lateral El Stratigraphic Test ❑ Development -Oil 0 Service - Winj ❑ Single Zone ❑� CoalbA( a( ) EG)I�drates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ @ Geothermal Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑� Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 • KRU 1J -10L1 ' 3. Address: 6. Proposed Depth: -T V 6t 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10500' n TVDflSi5982' ,p * ,� Kuparuk River Field / 4a. Location of Well (Governmental Section): 7. Property Designation: • rN L ZSS61 p llp Kupamk River Oil Pool Surface: 1996' FSL, 2536' FEL, Sec 35, Tl l N, R10E, UM ADL 25660 11rt•f14 Top of Produ a zo r 1 11 µ•06V• / S¢c2�, 11 N 10 & Cn..a 8. DNR Approval Number: 13. Approximate Spud Date: 't;I *I 24"' . 14 / 4 LONS 83-137 2/13/2019 otal Dept : µ"�'ai/ ` NL 4•z r r'FE� S�.et� TIr R�aIE 9. Acres in Property: 14. Distance to Nearest Property: (ie6� ry 2560 11,020' 4b. Location ZN Well (Slate Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 114' 15. Distance to Nearest Well Open Surface: x- 558673 ' y- 5945808 ' Zone- 4 GL / BF Elevation above MSL (ft): 79' to Same Pool: 2502', KUP 34-11-10 1 16. Deviated wells: Kickoff depth: 10,310' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 57 • degrees Downhole: 2914 Surface: 2315 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 4-1/4" 3-1/2" 9.3# L-80 HYD511 300' 10,200' 5811' 10,500' 5982' Solid 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 10,845' 6326' N/A 10,843' 6324' 10,400' Casing Length Size Cement Volume MD TVD Conductor/Structural 85' 16" 460 sx AS 1 115' 115' Surface 6911' 9-5/8" 700 sx AS Lite & 450 sx LiteCrete 6938' 3991' Production 10,199' 7" 170 sx G 10,231' 5944' Liner 876' 4-1/2" 150 sx GasBlok 10,843' 6325' Perforation Depth MD (ft): 10,446'- 10,4661,10,6581-10,6781 Perforation Depth TVD (ft): 6073'- 6085', 6205'- 6218' Hydraulic Fracture planned? Yes ❑ No ❑1 20. Attachments: Property Plat ❑ P Sketch B Drilling e e✓ Diveoer Sketch Seabed Report Drilling ng Fluid Program 20 AAC 25 050 requi ementsB 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ryan McLaughlin AXID Authorized Name: James Ohlinger Contact Email: Ryan. McLauqh1inCEDcop.com Authorized Title: S ff CTD Engineer Contact Phone: 907-265-6218 Authorized Signature: Date:/i'V1'F Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: —0 150- 01"In 01 D — 60 I Date: 1, 5 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: IV Other: 8 pP fr,5 f -/ p 3500® 5 /� . Samples req'd: Yes ❑ Noy Mud log req'd: Yes ❑ No Y %tYLn !/ i R ✓ �Jr< ✓<N j-`<�- tD Z S!>O P 5.4 9 H,S measures: Yes & No ❑ Directional svy req'd: Yes Y No ❑ Spacing exception req'd: Yes ❑ No Q" Inclination -only svy req'd: Yes ❑ No T Post initial injection MIT req'd: Yes ❑ No Er APPROVED BY Z /s-//' Approved by: COMMISSIONER THE COMMISSION Date: 1 r�orm 10-401 Revised 5/2017 Vhi.�errgit j5 valid for 24 mgWlyfpry �L. G� �,9 Submit Form and t�dat�oftap�rp�al per 20 C25 0$( ) A>t c mems in Duplicate' /Ht /" I &.KOttSl It,7 UKI IN L I ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 23, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill four laterals out of the KRU 1 J-10 (PTD# 201-071) using the coiled tubing drilling rig, Nabors CDR3-AC. ' CTD operations are scheduled to begin on February 6, 2019. The objective will be to drill four laterals KRU 1 J- 101-1, 1J-101-1-01, 1J-101-1-02 and 1J-101-1-03 targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 1J-101-1, 1J-101-1-01, 1J-101-1-02 and 1J-101-1-03 - Detailed Summary of Operations - Directional Plans for 1J-101-1, 1J-101-1-01, 1J-101-1-02 and 1J-101-1-03 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1J-101-1, 1J-101-1-01, 1J-101-1-02, & 1J-101-1-03 Application for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4 ........................................................................................................ (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))...................................................................................................................2 Seismic Analysis............................................................................................................................. 4 2. Location Summary .......................................................................................................................... 2 11. (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.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3 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)(6))..................................................................................................................................................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 ............................................. (Requirements of 20 AAC 25.005(c)(12)) ........................................... 13. Proposed Drilling Program .............................. (Requirements of 20 AAC 25.005(c)(13)) ................................... Summary of Operations ................................................ LinerRunning................................................................ 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) ................... ................................................................ 4 ......................................................................................... 4 ...................................................................... 4 ................................................................................................. 4 ........................................................................................4 ...................................................................................6 .................................................................. 6 ........................................................................................... 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments....................................................................................................................................6 Attachment 1: Directional Plans for 1J-101-1, 1J-101-1-01, 1J-101-1-02, & 1J-101-1-03 laterals.......................................6 Attachment 2: Current Well Schematic for 1 J-10............................................................................................................6 Attachment 3: Proposed Well Schematic for 1J-101-1, 1J-101-1-01, 1J-101-1-02, & 1J -10L1-03 laterals .........................6 Page 1 of 6 January 15, 2019 PTD Application: 1J -10L1, 1J-101_1-01, 1J -10L1-02, & 1J-101_1-03 Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1J-101-1, 1J -10L1-01, 1J -10L1-02, and 1J -10L1-03. The laterals will be classified as "Development -Oil' wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C4 sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1J -10L1, 1J -10L1-01, 1J-101-1-02, and 1J-101-1-03 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 CDR3-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 to 3500 psi. Using the maximum formation pressure in the area of 2914 psi in 1 L-29 (i.e. 9.2 ppg EMW), the maximum potential surface pressure in 1 J-10, assuming a gas gradient of 0.1 psi/ft, would be 2315 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 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 formation pressure in KRU 1J-10 was measured to be 2880 psi (9.2 ppg EMW) on 1/20/2019. The maximum downhole pressure in the 1J-10 vicinity is the 1 L-29 at 2914 psi (9.2 ppq EMWI measured on 2/19/2017. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 1J-10 have injected gas, so there is a possibility of encountering free gas while drilling the 1J-10 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1J-10 laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1J-10 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 6 January 15, 2019 PTD Application: 1J-101_1, 1J-101_1-01, 1J-101_1-02, & 1J -10L1-03 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 1J-101_1 10,200' 10,500' 5811' 5,982' ORCA Liner Drilling BHA 0' 120' 1530 520 Surface 2-3/8", 4.7#, L-80, ST -L slotted liner; 1J-101_1-01 12,300' 15,200' 6045' 6120' aluminum billet on to 3995' 5750 3090 Production 7" 2-3/8", 4.7#, L-80, ST -L slotted liner; 1J -10L1-02 12,150' 14,775' 6041' 6028' aluminum billet on to 1J-101_1-03 10,400' 14,100' 5,927' 6088' 8", 4.7#, L-80, ST -L slotted liner; NSCT 9967' 10,843' 5787' 6325' w2-3/ith shortdeployment sleeve on to Existing Casing/Liner Information Category OD Weight ippf Grade Connection Top MD Btm MD Top TVD Btm TVD Burst si Collapse psi Conductor 20" 91.5 H-40 Welded 0' 120' 0' 120' 1530 520 Surface 9-5/8" 40.0 L-80 BTC 0' 6945' 0' 3995' 5750 3090 Production 7" 26.0 L-80 BTC -MOD 0' 10,321' 0' 5944' 7240 5410 Liner 4-1/2" 12.6 L-80 NSCT 9967' 10,843' 5787' 6325' 8430 7500 Tubing 4-1/2" 12.6 L-80 IBT 0' 9992' 0' 5802' 8430 7500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride -based PowerVis mud (8.6 ppg) — Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and shale stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1J-10 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be Page 3 of 6 January 15, 2019 PTD Application: U-101-1, 1J-101-1-01, 1J-101-1-02, & 1J-101-1-03 employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1J-10 Window (10,310' MD, 5991' TVD) Using MPD 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 AAC 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 for a land based 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 100 ri1 Background KRU Well 1J-10 is a Kuparuk producer equipped with 4-1/2" tubing and 4-1/2" production liner. The project targets stranded C -Sand resource to the south and east of 1J-10 into an area along the C -Sand margin south of existing production and injection. This project will involve drilling four CTD laterals from the IJ -10 parent wellbore. The first lateral will kickoff from a whipstock set at 10,310' and will drill out 200' from the motherbore to straddle the Kalubik shale with Northern Solution's Liner Drilling BHA. The subsequent three laterals will target the Kuparuk C4 sand package with access gained from the U -10L I lateral. Page 4 of 6 January 15, 2019 Pumps On 1.8 bpm) Pumps Off C -sand Formation Pressure 9.2 2866 psi 2866 psi Mud Hydrostatic 8.6 2679 psi 2679 psi Annular friction i.e. ECD, 0.08psi/ft) 825 psi 0 psi Mud + ECD Combined no chokepressure) 3504 psi Overbalanced -638psi) 2679 psi Underblanced -187psi) Target BHP at Window 11.8 3676 psi 3676 psi Choke Pressure Required to Maintain Target BHP 172 psi 997 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 AAC 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 for a land based 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 100 ri1 Background KRU Well 1J-10 is a Kuparuk producer equipped with 4-1/2" tubing and 4-1/2" production liner. The project targets stranded C -Sand resource to the south and east of 1J-10 into an area along the C -Sand margin south of existing production and injection. This project will involve drilling four CTD laterals from the IJ -10 parent wellbore. The first lateral will kickoff from a whipstock set at 10,310' and will drill out 200' from the motherbore to straddle the Kalubik shale with Northern Solution's Liner Drilling BHA. The subsequent three laterals will target the Kuparuk C4 sand package with access gained from the U -10L I lateral. Page 4 of 6 January 15, 2019 PTD Application: U-101-1, 1J-101-1-01, 1J-101-1-02, & 1J-101-1-03 Pre -CTD Work 1. RU Slickline: Drift tubing with dummy whipstock, obtain SBHP, C/O gas lift design 2. RU E -line: Caliper, set whipstock 3. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. U-1 OLI Lateral (Straddle the Kalubik w/Liner Drilling BHA) a. Mill 3.80" window at 10,310' MD. b. Drill 3-3/4" lateral with ORCA liner drilling BHA to TD of 10,500' MD. c. Hydraulically release off 3-1/2" liner drilling BHA leaving TOL at 10,200' MD 3. 1J-IOLI-01 Lateral (C4 sand - southeast) a. Set top of whipstock in 3-1/2" drilled in liner at 10,420' MD b. Mill 2.80" window at 10,420' MD c. Drill 3" bi-center lateral to TD of 15,200' MD. d. Run 2-3/8" slotted liner with aluminum billet from TD up to 12,300' MD. 4. 1J-IOLI-02 Lateral (C4 sand -south) a. Kickoff of the aluminum billet at 12,300' MD. b. Drill 3" bi-center lateral to TD of 14,775' MD. c. Run 2-3/8" slotted liner with aluminum billet from TD up to 12,150' MD. 5. 1J-IOLI-03 Lateral (C4 sand -east) a. Kickoff of the aluminum billet at 12,150' MD. b. Drill 3" bi-center lateral to TD of 14,100' MD. c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 10,400' MD. 6. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 7. Obtain SBHP. 8. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. 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 slick -line lubricator can be used. This pressure control equipment listed 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 Page 5 of 6 January 15, 2019 PTD Application: U-101-1, 1J-101-1-01, 1J-101-1-02, & 1J-101-1-03 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 un -deployment, the steps listed above are observed, only in reverse. Liner Running — The 1 J-10 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids' section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will provide secondary well control while running 2-3/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans — 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 open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance U-101-11 11,020' 1J-10LI-01 16,913' 1J -10L1-02 7620' 1J -10L1-03 17,081' Distance to Nearest Well within Pool Lateral Name, Distance Well 1J -10L1 2502' KUP 34-11-10 1 1J -10L1-01 1845' 1L-29 1J -10L1-02 2706' 1E-117 1J -10L1-03 2694' 1J-168 16. Attachments Attachment 1: Directional Plans for 1J -10L1, 1J-101-1-01, 1J-101-1-02, & 1J -10L1-03 laterals Attachment 2: Current Well Schematic for IJ -10 Attachment 3: Proposed Well Schematic forlJ-10L1, 1J -10L1-01, 1J -10L1-02, & 1J -10L1-03 laterals Page 6 of 6 January 15, 2019 ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1J Pad IJ -1O 1J -10L1 Plan: 1J-10L1_wp01 Standard Planning Report 17 December, 2018 BT�a GHES GE company �, ConocoPhillips BA (ER ConocoPhillips Planning Report I�UGHES a GE company Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J-10 Wellbore: 1J-101-1 Design: 1J-10L1_wp01 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1J-10 Mean Sea Level 1J-10:114.25 @ 114.25usft(iJ-10:114.25) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States 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 1J Pad Site Position: Northing: 5,945,919.64 usft Latitude: 70° 15'46.258 N From: Map Easting: 558,789.95 usft Longitude: 149° 31'29.007 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.45 ' Well 1J-10 Well Position +NIS 0.00 usft Northing: 5,945,808.06 usft Latitude: 70° 15'45.169 N +E/ -W 0.00 usft Basting: 558,673.32 usft Longitude: 149° 31'32.426 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1J-101.1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) Cl (nT) BGGM2018 211/2019 16.77 80.84 57424 Design 1J-101-1_wp01 Audit Notes: Version: Phase: PLAN Te On Depth: 10,16600 Vertical Section: Depth From (TVD) +N/S +EAW Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 120,00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NIS +EAW Rate Rate Rate TFO (usft) (°) (I (usft) (usft) (usft) (°1100usft) (°/100usft) (°/100usft) (°) Target 10,166.00 52.95 295.12 5,790.91 3,587.77 -6,706.45 0.00 0.00 0.00 0.00 . 10,310.00 53.94 293.80 5,876.68 3,635.66 -6,811.74 1.01 0.69 -0.92 -47.36 10,335.00 56.55 292.00 5,890.93 3,643.65 -6,830.66 12.00 10.45 -7.19 330.00 10,500.00 56.55 292.00 5,981.87 3,695.23 -6,958.31 0.00 0.00 0.00 0.00 12/172018 10:37:55AM Page 2 COMPASS 5000.14 Build 850 `, ConocoPhillips BAI(ER ConocoPhillips Planning Report HUGHES a GEcanlrany Database: EDT 14 Alaska Production Vertical Company: _ConocoPhillips Export Company Project: Kuparuk River Unit -NIS Site: Kupamk 1J Pad Rate Well: 1J-10 Easting Wellbore: iJ-101-1 (usft) Design: 1,1401.1 wp01 (usft) Planned Survey 3,587.77 -6706.45 Measured TVD Below r Depth Inclination Azimuth System (usft) V) (I (usft) 10,166.00 52.95 295.12 5,790.91 TIP 3,632.39 -6,804.35 10,200.00 53.18 294.81 5,811.34 10,300.00 53.87 293.89 5,870.79 10,310.00 53.94 293.80 5,876.68 KOP 5,949,390.19 551,834.11 10,335.00 56.55 292.00 5,890.93 End 12 dls, Start tangent Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well ii -10 Mean Sea Level 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature 3,643.65 -6,830.66 -7,737.35 12.00 -30.00 5,949,398.03 551,815.13 10,400.00 56.55 292.00 5,926.75 3,663.97 -6,880.95 -7,791.06 0.00 10,500.00 56.55 292.00 5,981.87 3,695.23 -6,958.31 -7,873.68 0.00 Planned TD at 10500.00 0.00 5,949,417.95 551,764.70 0.00 5,949,448.60 551,687.10 Casing Points Vertical Dogleg Toolface Map Map -NIS -E/-W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°1100usft) f) (usft) (usft) 3,587.77 -6706.45 -7,601.84 0.00 0.00 5,949,343.13 551,939.76 3,599.24 -6,731.09 -7,628.92 1.01 -47.36 5,949,354.40 551,915.04 3,632.39 -6,804.35 -7,708.94 1.01 -47.17 5,949,386.98 551,841.53 3,635.66 5,811.74 -7,716.97 1.01 -46.63 5,949,390.19 551,834.11 3,643.65 -6,830.66 -7,737.35 12.00 -30.00 5,949,398.03 551,815.13 10,400.00 56.55 292.00 5,926.75 3,663.97 -6,880.95 -7,791.06 0.00 10,500.00 56.55 292.00 5,981.87 3,695.23 -6,958.31 -7,873.68 0.00 Planned TD at 10500.00 0.00 5,949,417.95 551,764.70 0.00 5,949,448.60 551,687.10 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,500.00 5,981.87 2 3/e" 2.375 3.000 5,790.91 3,587.77 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NIS -E/-W (usft) (usft) (usft) (usft) Comment 10,166.00 5,790.91 3,587.77 -6,706.45 TIP 10,310.00 5,876.68 3,635.66 5,811.74 KOP 10,335.00 5,690.93 3,643.65 -6,830.66 End 12 dls, Start tangent 10,500.00 5,981.87 3,695.23 -6,958.31 Planned TD at 10500.00 12/172018 10:37:55AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1J Pad ii -10 1J -10L1 1J-10L1_wp01 Travelling Cylinder Report 07 December, 2018 BT�a GHES GE company �, ConocoPhillips BA ER Con000�l1��IpS Travelling Cylinder Report t UGHES a GE company Company: ConocoPhillips(Alaska) Inc.-Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Wellbore 1J-101-1 Reference Design: 1J-10L1_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1J-10 IJ -1 0:114.25 @ 114.25usft(I J-10:114.25) 1J-10:114.25 @ 114.25usft (1 J-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Onset Datum Reference 1J-10L1_wp01 Casing Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+100/1000 of reference To Interpolation Method: MD Interval 100.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,238.58 usft Emor Surface: Pedal Curve Survey Tool Program Date 12/7/2018 Casing Hole From To Diameter Diameter (usft) (usft) Survey (Wellbore) Tool Name Description 205.18 10,166.00 1J -10 (1J-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,166.00 10,500.001J-10L7_wp01(1J-10L1) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 6,936.54 3,991.30 9 5/8" 9 625 12,250 10,142.96 5,891.30 7" 7.000 8.500 10,500.00 6,096.12 23/8" 2.375 3.000 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1J Pad 1J -03 -1J -03-1J-03 114.25 116.12 161.44 0.74 160.70 Pass - Major Risk 1J-03-iJ-03L1-1J-031_1 114.25 116.00 161.44 1.02 160.41 Pass -Major Risk 1J-03-1J-03L2-iJ-031_2 114.25 116.00 161.44 1.02 160.41 Pass -Major Risk IJ-03-1J-03L2PB1-1J-03L2PB1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J -09 -1J -09-1J-09 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J -09 -1J -09A -1J -09A 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09-1J-09AL7-iJ-09AL7 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-10-1J-10-iJ-10 10,499.33 10,500.00 14.99 13.99 5.31 Pass - Major Risk iJ-10 - 1J-101.1-01 - 1J-101-7-01_wp02 Out of range 1J-10 - 1J-1 OLl-02 - 1J-10L1-02_wp01 Out of range IJ -10 - 1J-10Li-03 - 1 J-10L1-03_wp01 Out of range 1J-105 - 1J-105 - IJ -1 05 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-1051-1-1JA 05LI 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J -105 -1J -105L2 -7J-1051_2 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-105P81-1J-105PB1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J -107 -1J -107-1J-107 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-107-iJ-1071-7-1J-1071_1 305.01 300.00 190.36 4.92 165.44 Pass - Major Risk 1J-109 - 1J-109 - 1 J-109 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-109-1J-109PB1-1J-109PB7 192.21 200.00 159.58 2.72 156.86 Pass -Major Risk 11-115 - 1J-115 - 1J-115 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -115 -1J -11517 -1J -115L1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk IJ -115 -1J -115L7 Pet -1J-11511 P81 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -115 -1J -115L1 PB2 - 1 J-11 51.11 PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk IJ -115 -1J -11512-1J-1151_2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-lJ-115L2PB7-1J-115L2PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115L2PB2-iJ-115L2PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk CC - Min centre to center distance or covergsnt point, SF - min separation factor, ES - min ellipse separation 12/72018 9:56,40AM Page 2 COMPASS 5000.14 Build 85D Summary ConocoPhillips B ER ConocoPhillips Travelling Cylinder Report I UGHES aGEcompany Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well IJ -10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-101_1 Database: EDT 14 Alaska Production Reference Design: 1J-101_1_wp01 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1J Pad 1J-115-1J-115PB1-1J-115PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1 J-11 5 - 1 J-11 5PB2 - 1 J-11 5PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB3-1J-115PB3 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-1 15 - 1 J-11 5PB4 - 1 J-11 5PB4 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -118 -1J -118-1J-118 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118LI-1J-11811 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -118 -1J -1181_2-1J-1181_2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118PB1-1J-118PBI 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118PB2-1J-118P82 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -120 -1J -120-1J-120 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120LI-1J-120LI 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 Pal -1J -120L1 Pat 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 PB2-1J-120LI P132 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 PB3 - 1 J-1 201-1 PB3 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 PB4 - 1J-1 201-1 PB4 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120 - IJ -12012 - 1J-12012 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-1201_2PB1-1J-1201_2PB1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-152 - 1J-152 - 1J-152 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152LI-1J-152LI 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1 J-152 - 1J-1521-2 - 1J -152L2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-1521_2PB1-1J-1521_2PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk IJ-152-1J-152PB1-1J-152PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152PB2-1J-152P82 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-154 - 1J-154 - 1J-154 605.44 600.00 146.13 10,47 135.67 Pass - Major Risk 1J-154-1J-154LI-1J-1541-1 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J-154 - 1J-15412 - 1J-1541-2 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -156 -1J -156-1J-156 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156 -1J -1561 -1 -1J -156L1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156-1J-1561-1 PB1-1J-156L1 Pat 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156 -1J -1561-2-1J-15612 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J-158 - 1 J-158 - 1 J-158 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1J-158-1J-1581-1-1J-158LI 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 11-159 - 1 J-159 - 1 J-159 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159 -1J -159L1 -1J -159L1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159 -1J -159L1 PBI -1J-159LI Pat 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159 -1J -159L1 PB2-1J-159LI PB2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159 -1J -15912-1J-15912 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-159PB1-1J-159PB1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -160 -1J -160-1J-160 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160-1J-160L1-1J-160Ll 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-1 60 - 1 J-160Ll Pat -1J-160LI Pal 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J -160 -1J -1601_2-1J-1601_2 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J -162 -1J -162-1J-162 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -162 -1J -1621_1-1J-1621-1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -162-1J-1621.1 PBI -1J-1621-1 Pal 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162PB1-1J-162PB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162PB2-1J-162PB2 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -164 -1J -164 -IJ -164 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J -164 -1J -1641_1-1J-1641_1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J -164 -1J -1641-2-1J-1641_2 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-164-lJ-1641_2PB1-1J-1641_2PB1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J -166 -1J -166-1J-166 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk IJ -166 -1J -166L1 -1J -166L1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12//!1018 9:56..40AM Page 3 COMPASS 5000.14 Build 85D "iConocoPhillips Kuparuk B ER CQnOcoPhiilips Travelling Cylinder Report F 11GHES Reference Offset aGEcomPany Company: ConowPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 Q 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 Q 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-1011 Database: EDT 14 Alaska Production Reference Design: 1 J-101_1_wp01 Offset TVD Reference: Offset Datum Summary Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03 Reference Offset Centre to NO -Go Allowable Survey Program: 201-MW0 Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan me. Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1J Pad Measured Vertical 1J -166-1J-16611 P61 -1J -166L1 Pal 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -166 -1J -16612-1J-16612 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1 J-1 66 - 1 J-1 66L2PB1 - 1J-1 66L2PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -168 -1J -168-1J-168 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J -168 -1J -168L1 -1J -168L1 404.72 400.00 161.98 6.61 155.38 Pass -Major Risk 1J -168 -1J -168L2 -1J -168L2 404.72 400.00 161.98 6.61 155.38 Pass -Major Risk 1J-168-1J-168L2PB1-1J-168L2PB1 404.72 400.00 161.98 6.61 155.38 Pass -Major Risk 1J -170 -1J -170-1J-170 5,690.17 8,300.00 247.69 159.88 140.49 Pass -Major Risk 1J-170-1J-170L1-1J-170Ll 5,566.22 8,300.00 182.48 156.25 55.71 Pass - Major Risk 1J -170 -1J -17012 -1J -170L2 5,394.81 6,200.00 166.39 152.00 53.52 Pass - Major Risk 1J-170-1J-170PB1-1J-170PB1 5,676.40 8,300.00 273.16 159.57 164.32 Pass - Major Risk 1J-170-1J-170PB2-1J-170PB2 5,690.17 8,300.00 247.69 160.14 140.23 Pass - Major Risk Plan 1J-104(empty)-Prelim: 1J -104 -Prelim: IJ- 406.82 400.00 232.09 5.53 226.57 Pass - Major Risk Plan 1J-104 (empty)- Prelim: 1J-104 L7 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1 J-1 04 (empty) - Prelim: IJ -1 04 L2 -Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1 J-1 09a - 1 J-1 09PB1 x-1J-109PB1x 114.25 33.25 177.64 1.02 176.62 Pass - Major Risk W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15 487.50 500.00 209.67 9.95 199.72 Pass - Major Risk W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2 396.03 400.00 184.70 5.72 178.98 Pass - Major Risk W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20 610.09 800.00 83.61 17.14 66.47 Pass - Major Risk W BAK PLT 3 - W SAK PLT 3 - W SAK PLT 3 503.17 500.00 184.73 11.21 173.52 Pass - Major Risk W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4 491.49 500.00 196.71 7.54 189.18 Pass - Major Risk W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5 486.33 500.00 231.04 10.16 220.89 Pass - Major Risk Offset Design Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03 oeeet she Error: a.00 mn Survey Program: 201-MW0 IFR-MSCC Rule Assigned: Major Risk Offset well Error: 0.00 usft Reverence me. Semi Major Axis Measured Vertical Measured Vertical Reference Ones, Toonace+ Offset Maps. Centre Casing- Co.. to No Go AllawaMe warm, Depth Depth Depth Caput Azimuth aN/45 +EI -W Hole Size Centre Distance Deviation (uan) (uSRI (usft) loan) (ien) (usft) r) hour loan) (in) rust) (usf) (usft) 11425 114.25 11612 116,12 0.00 0.00 4671 11069 11751 8.875 161.44 074 16070 Pass- Major Risk, CC. ES. SF 197.92 197.92 200AU 199.95 0.05 0.05 46,87 111.45 11889 0.875 163.01 1.83 161.18 Pass -Major Risk 297.75 297.75 300.00 29990 0.15 0.17 47,31 113.30 122.46 8.075 167.03 3A1 163.63 Pass - Major Risk 397.01 397.00 400,00 399,80 0.27 0.28 47.93 115.05 126.60 0.875 171.49 4.97 166.52 Pass - Major Risk 493.34 493.32 500.00 499.54 0.38 SAO 49.14 117.62 133.26 8.875 179.64 6.53 173.12 Pass -Major Risk 587.98 587.87 600,00 590.98 0.49 0.53 51,31 120.27 143.56 0.875 192.72 8,10 184.64 Pass - Major Risk 6.4.68 677.31 MOSS 697.93 0.60 0.67 53.92 123.90 157.38 8.875 212.30 9.64 202.72 Pass -Major Risk 752.37 751.30 000.00 796.49 0.69 hall 57.67 124.33 174.25 8.875 238.69 10.99 227.80 Pass - Major Risk MAO 833.59 KOSS 894.78 0.02 0.95 61,01 127.00 192.55 0.875 273.85 12,51 261.59 Pass -Major Risk 921.90 916.44 1,000,00 99243 0.95 1.12 63]8 132.0 213.20 0.075 316.43 14.15 602.78 Pass - Major Risk 1,002.62 994.25 1,100.00 1,088.93 1.08 1.34 68.04 141.43 23288 8,875 365.16 15.84 350.18 Pass -Major Risk 1,072,17 1.060,68 1.200,00 1,183.97 1.21 1.59 67,68 153.99 266.27 0.075 420.60 17.51 404.45 Pass -Major Risk 1.128.96 1,114.17 1,300.00 1276.57 1,32 1.90 68]0 171.29 299.72 0.875 484.87 19.14 467.71 Pass - Major Risk 1,180.86 1,168.03 1,400.00 1,365.40 1.45 2.28 69,33 193.03 340.12 8,875 557.89 21.02 539.71 Pass - Major Risk 1,236.53 1,213.77 11500.00 1,45111 1.57 2.72 69.75 219.16 385.04 8.875 636.46 22,91 617.42 Pass - Major Risk 1.280.95 1,254.20 1.6OOAO 1,533.47 1.68 3.22 70.28 245.70 434.57 8.075 719.64 24.83 699.94 Pass - Maj, Risk 1,316]5 1,286.41 1,700.00 1,611.71 1.76 3.77 70.68 275.94 488.99 8.875 007.16 26.73 786.71 Pass - Major Risk 1,350]4 1,316.67 1,800,00 1,60635 1.06 4.37 70.91 308.71 546.89 0.875 WAS 28.75 876.61 Pass - Major Risk 1,377.15 1,339.96 1,900.00 1,756.55 1.93 5.02 71.00 343.98 608.70 0.875 990% 3034 889.42 Pass -Major Risk 141OA1 1,389,01 2000SO 1,822.44 2.02 5.72 71.04 381.24 674.06 8,875 1,086,49 32.93 1,064.35 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/72018 9.56: 40AM Page 4 COMPASS 5000.14 Build 85D ✓ ConocoPhillips gp 1=R ConocoPhillips Travelling Cylinder Report F�UGHES aOEcompany Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Reference Site: Kupamk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Wellbore 1J-101-1 Reference Design: 1J-10L1_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1J-10 1J-10:114.25 @ 114.25usft (1J-10:114.25) 1J-10:114.25 @ 114.25usft (1 J-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Offset Design KuparuklJPad- 1J -03 -1J -03-1J-03 oem, site Emx. Dw usft Surveyprzram: 201 -MW FFR -AH -SCC Rule Auamtd: Maley Rik Offset Well Emor: 0.00 uan Referee. meet Semi Malo, AxN Measured Porti.) Msu id Vertical Relemnce Offset Tema... Onset Wellbereeemre Ca9fiy- CeMrze. N.Ge Allowable Waming Depth Depth Depth Depth Azimuth ♦Nl aVl Hole Six. Duere Distance Devufion (usft) (use) Nita) (usft) lu.ftl (usft) (9 lueftl (use) (in) IueRl (use) Jaen) 1,417.06 1,374.]] 2,100.00 1.883.19 2.03 6.45 70.93 42025 74321 8.875 1,183.65 30.82 1.181.34 Pass-MajerRisk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/12018 9:56:40AM Page 5 COMPASS 5000.14 Build 85D l"YUP" (JUL) 1+J44'vN/194+""J CN M m " o ao `'9 0 O HF Cap9 w ¢HYWa v �'w�imMm -2400 >o. -Mn > �o m -22]00 -0 2 O ao o A. o A. S. -3000 V 4 c OIO x-00 c ......_ - -3300 _ c n -2]00 3600 39N -2850 4200 I, I�bNM 4500 W in r �o ao ry -480C 3000 -51« -540C � 5]0C p o;c o� rno FN��h to O m z� o -3150 -63« „ o V N < N V7 C OOINN -3300 -6600 �Q O - } s - -6900 - - - � M M VO2 0 0 0 0 -7200 u3 0 -3450 -]500 -3600 -]800 -3900 l"YUP" (JUL) 1+J44'vN/194+""J G� 3 CN M m " o ao `'9 0 O HF Cap9 w ¢HYWa v �'w�imMm >o. -Mn > �o m -0 2 O ao o A. o A. S. r o o V N OIO x-00 U10000 0000^0 n -2]00 -2850 jR�U3 I�bNM W in r �o ao ry 3000 WNm�cmm � p o;c o� rno FN��h to O m z� _ N.0 O O 000 -3150 'V NNNN V N < N V7 C OOINN -3300 NV)NN �Q O } p o 0 0 0 S O o 0 � M M VO2 0 0 0 0 u3 0 -3450 G� 3 I -24M 2550 -2]00 -2850 3000 -3150 -3300 -3450 -3600 -3]50 -3900 4050 4200 -4350 -4500 -4650 -4800 e a -4950 - -5100 a -5250 -5400 -5550 -5]00 -5850 .6000 .6150 6300 6450 -6600 -6]50 6900 - 4 -]050 4200 ]350 -]500 -]650 Y G % 800 o, -]950 °o ... -.. -8250 A -8400 I ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1J Pad ii -10 IJ -101-1-011 Plan: 1 J-101-1-01 _wp02 Standard Planning Report 17 December, 2018 BA UGHES a GE company ConocoPhillips BA ER ConoCoPhiiiips Planning Report BAT aGEmmpeny Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kupamk River Unit Site: Kupamk 1J Pad Well: 1J-10 Wellbore: iJ-101-1-01 Design: iJ-10L1-01_wp02 Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Well 1J-10 Mean Sea Level 1J-10:114.25® 114.25usft(iJ-10:114.25) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States 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 1J Pad Site Position: From: Position Uncertainty: Northing: Map Easting: 0.00 usft Slot Radius: 5 945,919.64 usft Latitude: 558,789.95 usft Longitude: 0.000in Grid Convergence: 70° 15'46.258 N 149° 31'29.007 W 0.45' Weil 1J-10 Well Position +NIS 0.00 usft Northing: 5,945,808.06 usft Latitude: 70° 15' 45.169 N +E/.W 0.00 usft Easting: 558,673.32 usft Longitude: 149' 31'32.426 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1J-101-1-01 Magnetics Model Name Sample Date Declination Dip Angie (°I (°) Field Strength (nT) BGGM2018 2/1/2019 16.77 80.84 57,424 Design 1J-10L1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,420.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I „,,,, nnn 19n nn 12/172018 10:42.18AM Page 2 COMPASS 5000.14 Build 85D `ConocoPhillips BA ER ConOC4, Mips Planning Report BAT a GE company Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site: Kuparuk 1J Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellbore: 1J-101.1-01 Depth Inclination Design: 1J-101-1-01_wp02 -N/-S •E/ -W Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System -N/-S •E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°1100usft) (°1100usft) (°) Target 10,420.00 56.55 292.00 5,937.78 3,670.22 -6,896.42 0.00 0.00 0.00 0.00 10,441.00 59.11 290.29 5,948.96 3,676.63 -6,913.00 14.00 12.18 -8.15 330.00 10,517.97 90.00 273.78 5,969.34 3,691.06 -6,984.57 45.00 40.13 -21.45 330.00 10,800.00 90.00 146.87 5,969.34 3,494.42 -7,099.58 45.00 0.00 -45.00 270.00 11,125.00 90.00 124.12 5,969.34 3,264.16 -6,873.25 7.00 0.00 -7.00 270.00 11,330.00 77.61 116.83 5,991.46 3,160.95 -6,698.13 7.00 -6.05 -3.56 210.00 11,530.00 77.98 102.51 6,033.96 3,095.37 -6,514.58 7.00 0.19 -7.16 270.00 11,735.00 90.47 109.63 6,054.58 3,038.94 -6,319.14 7.00 6.09 3.47 30.00 12,035.00 91.15 130.62 6,050.29 2,889.25 -6,061.12 7.00 0.23 7.00 88.00 12,300.00 91.09 112.06 6,045.04 2,752.05 -5,835.82 7.00 -0.02 -7.00 270.00 12,700.00 83.54 139.07 6,064.11 2,522.19 -5,513.88 7.00 -1.89 6.75 106.00 13,050.00 89.04 115.14 6,087.08 2,313.28 -5,237.34 7.00 1.57 -6.84 282.00 13,300.00 89.69 132.63 6,089.88 2,174.45 -5,030.82 7.00 0.26 7.00 88.00 13,700.00 90.19 104.63 6,090.30 1,984.68 4,683.02 7.00 0.13 -7.00 271.00 14,050.00 85.23 128.65 6,104.48 1,829.16 -4,372.76 7.00 -1.42 6.86 102.00 14,450.00 90.45 101.11 6,119.85 1,662.80 -4,013.70 7.00 1.30 -6.88 280.00 14,850.00 89.69 129.10 6,119.35 1,494.75 -3,655.09 7.00 -0.19 7.00 91.50 15,200.00 90.13 104.61 6,119.89 1,337.84 -3,345.21 7.00 0.13 -7.00 271.00 12/172018 10:42:15AM Page 3 COMPASS 5000.14 Build 85D COf1OCO�lillips ConocoPhillipsER Planning Report I UGHES aGEmmparry Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site: Kuparuk 1J Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellbore: 1J-101-1-01 Design: 1J-101.1-01_wp02 Planned Survey Measured T/D Below Vertical Dogleg Toclface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 10,420.00 56.55 292.00 5,937.78 3,670.22 -6,896.42 -7,807.58 0.00 0.00 5,949,424.08 551,749.18 TIP/KOP 10,441.00 59.11 290.29 5,948.96 3,676.63 -6,913.00 -7,825.14 14.00 -30.00 5,949,430.36 551,732.55 End 14 dls, Start 45 dls 10,500.00 82.70 277.27 5,968.20 3,689.34 -6,966.73 -7,878.03 45.00 30.00 5,949,442.65 551,678.72 10,517.97 90.00 273.78 5,969.34 3,691.06 -6,984.57 -7,894.34 45.00 -25.63 5,949,444.23 551,660.88 3 10,600.00 90.00 236.87 5,969.34 3,670.63 -7,062.56 -7,951.67 45.00 -90.00 5,949,423.20 551,583.06 10,700.00 90.00 191.87 5,969.34 3,590.20 -7,117.56 -7,959.09 45.00 -90.00 5,949,342.34 551,528.68 10,800.00 90.00 146.87 5,969.34 3,494.42 -7,099.58 -7,895.63 45.00 -90.00 5,949,246.72 551,547.41 End 46 dls, Start 7 dls 10,900.00 90.00 139.67 5,969.34 3,414.22 -7,039.95 -7,803.89 7.00 -90.00 5,949,167.00 551,607.66 11,000.00 90.00 132.87 5,969.34 3,341.89 -6,970.99 -7,708.00 7.00 -90.00 5,949,095.21 551,677.17 11,100.00 90.00 125.87 5,969.34 3,278.50 -6,893.73 -7,609.39 7.00 -90.00 5,949,032.43 551,754.92 11,125.00 90.00 124.12 5,969.34 3,264.16 -6,873.25 -7,584.49 7.00 -90.00 5,949,018.26 551,775.51 5 11,200.00 85.46 121.49 5,972.32 3,223.58 -6,810.28 -7,509.66 7.00 -150.00 5,948,978.17 551,838.78 11,300.00 79.41 117.92 5,985.48 3,174.47 -6,724.24 -7,410.60 7.00 -149.90 5,948,929.74 551,925.20 11,330.00 77.61 116.83 5,991.46 3,160.95 -6,698.13 -7,381.23 7.00 -149.43 5,948,916.43 551,951.40 6 11,400.00 77.65 111.81 6,006.46 3,132.81 -6,635-85 -7,313.22 7.00 -90.00 5,948,888.77 552,013.90 11,500.00 77.88 104.65 6,027.69 3,102.26 -6,543.09 -7,217.61 7.00 -86.92 5,948,858.94 552,106.88 11,530.00 77.98 102.51 6,033.96 3,095.37 -6,514.58 -7,169.47 7.00 -87.41 5,948,852.28 552,135.45 7 11,600.00 82.23 104.98 6,045.99 3,078.98 -6,447.62 -7,123.29 7.00 30.00 5,948,836.42 552,202.53 11,700.00 88.33 108.43 6,054.21 3,050.35 -6,352.22 -7,026.36 7.00 29.58 5,948,808.53 552,298.13 11,735.00 90.47 109.63 6,054.58 3,038.94 -6,319.14 -6,992.00 7.00 29.29 5,948,797.38 552,331.30 8 11,800.00 90.63 114.17 6,053.96 3,014.70 -6,258.85 3,927.67 7.00 88.00 5,948,773.62 552,391.77 11,900.00 90.86 121.17 6,052.66 2,968.30 3,170.35 6,827.83 7.00 88.04 5,948,727.91 552,480.62 12,000.00 91.08 128.17 6,050.97 2,911.48 6,088.16 6,728.23 7.00 88.13 5,948,671.71 552,563.24 12,035.00 91.15 130.62 6,050.29 2,889.25 6,061.12 6,693.71 7.00 88.25 5,948,649.72 552,590.45 9 12,100.00 91.15 126.07 6,048.98 2,848.95 -6,010.16 6,629.43 7.00 -90.00 5,948,609.82 552,641.72 12,200.00 91.13 119.06 6,046.99 2,795.17 -5,925.96 -6,529.61 7.00 -90.09 5,948,556.70 552,726.33 12,300.00 91.09 112.06 6,045.04 2,752.05 -5,835.82 6,429.99 7.00 -90.23 5,948,514.29 552,816.80 10 12,400.00 89.16 118.79 6,044.82 2,709.14 -5,745.56 -6,330.37 7.00 106.00 5,948,472.09 552,907.38 12,500.00 87.24 125.53 6,047.96 2,655.98 -5,661.00 -6,230.56 7.00 106.01 5,948,419.59 552,992.34 12,600.00 85.36 132.28 6,054.43 2,593.35 -5,583.38 -6,132.03 7.00 105.80 5,948,357.58 553,070.44 12,700.00 83.54 139.07 6,064.11 2,522.19 -5,513.88 -6,036.26 7.00 105.37 5,948,286.97 553,140.48 11 12,800.00 85.04 132.20 6,074.08 2,451.11 -5,444.35 -5,940.50 7.00 -78.00 5,948,216.44 553,210.56 12,900.00 86.61 125.36 6,081.37 2,388.68 -5,366.65 -5,841.99 7.00 -77.32 5,948,154.62 553,288.74 13,000.00 88.22 118.54 6,085.89 2,335.85 -5,281.94 -5,742.22 7.00 -76.82 5,948,102.46 553,373.85 13,050.00 89.04 115.14 6,087.08 2,313.28 -5,237.34 -5,692.31 7.00 -76.51 5,948,080.24 553,418.61 12 13,100.00 89.17 118.64 6,087.87 2,290.68 -5,192.76 -5,642.40 7.00 88.00 5,948,057.99 553,463.37 13,200.00 89.42 125.63 6,089.10 2,237.52 -5,108.14 -5,542.54 7.00 87.95 5,948,005.50 553,548.39 13,300.00 89.69 132.63 6,089.88 2,174.45 -5,030.62 -5,443.87 7.00 87.86 5,947,943.04 553,626.39 13 13,400.00 89.81 125.63 6,090.32 2,111.38 -4,953.10 -5,345.20 7.00 -89.00 5,947,880.58 553,704.39 12/172018 10:42:18AM Page 4 COMPASS 5000.14 Build 85D Conoco�'IIl�IpS Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Survey Calculation Method: Site: Kupamk 1J Pad Azimuth Well: 1J-10 Easting (usft) Wellbore: 1J -10L1-01 ('1100usft) (I Design: 1J -101-1-01_w1302 (usft) 2,058.23 Planned Survey -5,245.33 7.00 -88.97 Measured 5,947828.09 553,789.43 TVD Below Depth Inclination Azimuth System (usft) (_) (_) (usft) 13,50000 8994 118.63 6,090.54 13,600.00 90.07 111.63 6,090.53 13,700.00 90.19 104.63 6,090.30 14 5,947,725.77 554,070.67 1,911.64 13,800.00 88.74 111.48 6,091.24 13,900.00 87.30 118.34 6,094.69 14,000.00 85.91 125.21 6,100.62 14,050.00 85.23 128.65 6,104.48 16 4,701.51 7.00 101.29 14,100.00 85.85 125.20 6,108.37 14,200.00 87.12 118.30 6,114.51 14,300.00 88.44 111.42 6,118.39 14,400.00 89.78 104.55 6,119.95 14,450.00 90.45 101.11 6,119.85 16 4,452.87 7.00 -79.31 14,500.00 90.36 104.61 6,119.50 14,600.00 90.17 111.61 6,119.04 14,700.00 89.98 118.61 6,118.92 14,800.00 89.79 125.61 6,119.13 14,850.00 89.69 129.10 6,119.35 17 4,259.59 7.00 91.50 14,900.00 89.75 125.60 6,119.60 15,000.00 89.88 118.61 6,119.92 15,100.00 90.01 111.61 6,120.02 15,200.00 90.13 104.61 6,119.89 Planned TD at 15200.00 5,947,356.61 ConocoPhillips BA ER Planning Report BAT aGEcompeny Local Co-ordinate Reference: Well 1J-10 TVD Reference: Mean Sea Level MD Reference: 1J-10:114.25 @ 114.25usft(1J-10:114.25) North Reference: True Survey Calculation Method: Minimum Curvature 12/17/2018 10:42:18AM Page 5 COMPASS 5000.14 Build 85D Vertical Dogleg Toolface Measured Map Map •N1 -S +EPW Section Rate Azimuth (usft) Northing Easting (usft) (usft) (usft) ('1100usft) (I (usft) (usft) 2,058.23 -4,868.47 -5,245.33 7.00 -88.97 5,947828.09 553,789.43 2,015.78 -4,778.00 -5,145.76 7.00 -88.95 5,947,786.36 553,880.22 1,984.68 -4,683.02 5,047.95 7.00 -88.95 5,947,756.00 553,975.43 1,953.70 4,588.01 -4,950.18 7.00 102.00 5,947,725.77 554,070.67 1,911.64 -4,497.42 -4,850.70 7.00 101.94 5,947,684.41 554,161.57 1,859.11 -4,412.61 4,750.99 7.00 101.70 5,947,632.56 554,246.78 1,829.16 4,372.76 4,701.51 7.00 101.29 5,947,602.92 554,286.86 1,799.22 -4,332.92 4,652.03 7.00 -80.00 5,947,573.29 554,326.93 1,746.74 4,248.10 4,552.33 7.00 -79.73 5,947,521.48 554,412.15 1,704.75 4,157.49 4,452.87 7.00 -79.31 5,947,480.21 554,503.08 1,673.90 -4,062.44 4,355.13 7.00 -79.04 5,947,450.10 554,598.35 1,662.80 4,013.70 4,307.36 7.00 -78.93 5,947,439.38 554,647.17 1,651.67 -3,964.96 4,259.59 7.00 91.50 5,947,428.63 554,695.99 1,620.60 -3,869.98 4,161.80 7.00 91.52 5,947,398.31 554,791.20 1,578.20 -3,779.48 4,062.23 7.00 91.56 5,947,356.61 554,882.02 1,525.08 -3,694.83 -3,962.36 7.00 91.57 5,947,304.16 554,967.07 1,494.75 -3,655.09 -3,912.78 7.00 91.55 5,947,274.14 555,007.04 1,464.42 -3,615.35 -3,863.20 7.00 -89.00 5,947,244.12 555,047.01 1,411.30 -3,530.70 -3,763.33 7.00 -88.98 5,947,191.67 555,132.07 1,368.90 -3,440.20 -3,663.75 7.00 -88.96 5,947,149.98 555,222.88 1,337.84 -3,345.21 -3,565.96 7.00 -88.95 5,947,119.66 555,318.10 12/17/2018 10:42:18AM Page 5 COMPASS 5000.14 Build 85D Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 15,200.00 6,119.69 23/8" 2.375 3.000 - 12/17/2018 10:42:18AM Page 5 COMPASS 5000.14 Build 85D �ConocoPhillips BA ER ConoCoF, ihil ips Planning Report F�UGHES aGEmmpany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J-10 Wellbore: 1J -10L1-01 Design: 1J-1OL1-01_wp02 Plan Annotations Measured Vertical +E/ -W Depth Depth 3,670.22 (usft) (usft) -6,913.00 10,420.00 5,937.78 3,494.42 10,441.00 5,948.96 -6,673.25 10,517.97 5,969.34 3,095.37 10,800.00 5,969.34 -6,319.14 11,125.00 5,969.34 2,752.05 11,330.00 5,991.46 5,513.88 11,530.00 6,033.96 2,174.45 11,735.00 6,054.58 4,683.02 12,035.00 6,050.29 1,662.80 12,300.00 6,045.04 -3,655.09 12,700.00 6,064.11 13,050.00 6,087.08 13,300.00 6,089.88 13,700.00 6,090.30 14,050.00 6,104.48 14,450.00 6,119.85 14,850.00 6,119.35 15,200.00 6,119.89 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Local Coordinates -NI-S +E/ -W (usft) (usft) 3,670.22 -6,896.42 3 67fi 63 -6,913.00 3,691.06 -6,984.57 3,494.42 -7,099.58 3,264.16 -6,673.25 3,160.95 -6,698.13 3,095.37 -6,514.58 3,038.94 -6,319.14 2,889.25 -6,061.12 2,752.05 -5,835.82 2,522.19 5,513.88 2,313.28 -5,237.34 2,174.45 -5,030.62 1,984.68 4,683.02 1,829.16 4,372.76 1,662.80 4,013.70 1,494.75 -3,655.09 1,337.84 -3,345.21 Comment TIP/KOP End 14 dls, Start 45 dls 3 End 45 dls, Start 7 dls 5 6 7 8 9 10 11 12 13 14 15 16 17 Planned TO at 15200.00 Well 1 J-10 Mean Sea Level 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature 12/172018 10:42:18AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1J Pad ii -10 iifF IIIcE111 1 J-10L1-01_wp02 Travelling Cylinder Report 10 December, 2018 BT�a GHES GE company ConocoPhillips RVER ConocoPhillips Travelling Cylinder Report UGHES a GEc mpany Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1.1 Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Wellbore 1J-101-1-01 Reference Design: 1J-IGL1-01_wp02 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1J-10 1J-10:114.25 @ 114.25usft(1J-10:114.25) 1J-10:114.25 a 114.25usft (1J-10:114,25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 1J-101-1-01 wp02 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 201100/1000 of reference Measured Interpolation Method: MD Interval 100.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,708.58 usft Error Surface: Pedal Curve Survey Tool Program Date 12/10/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 205.18 10,166.00 1J -10(1J-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,166.00 10,420.001J-10L1_wp01(1J-101-1) MWD MWD - Standard 10,420.00 15,200.00 1J-101-1-01_wp02(1J-101-1-01) MWD MWD - Standard I Casing Points Measured Vertical Casing Hole Depth Depth Allowable Diameter Diameter (usft) (usft) Name (in) (In) 6,936.54 3,991.30 9 5/8" 9.625 12.250 10,142.96 5,891.30 7" 7.000 8.500 15,200.00 6,234.14 2 3/8" 2.375 3.000 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1 E Pad 1E -35 -Plan 1 E -35A - 1 E -35A (wp02) 14,800.00 14,900.00 980.15 524.29 458.57 Pass - Major Risk Kuparuk 1J Pad 1J -03 -1J -03-1J-03 114.25 116.12 161.44 0.74 160.70 Pass - Major Risk 1J -03 -1J -031-1-1J-031-1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J -03 -1J -03L2 -1J-031-2 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1 J-03 - 1J-03L2PBl - 1 J-03L2PB1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1 J-09 - 11-09 - 1J-09 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J -09 -1J -09A -1J -09A 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09-1J-09AL1-1J-09AL1 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J -10 -1J -10-1J-10 10,488.86 10,500.00 29.34 13.37 20.96 Pass - Major Risk 1J-10 - 1J-101-1 - 1 J-101-1_wp01 Out of range 1J -10-1J-1 OLl-02-1J-1011-02 wp01 11,100.00 11,100.00 0.00 2.43 -0.42 FAIL - Minor 1/10 1J -10-1J-1 OLl-03-1J-10L1-03_wp01 11,100.00 11,100.00 0.00 2.43 -0.42 FAIL - Minor 1/10 1J-105 - 1 J-105 - 1 J-105 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-1051-1-1J-tO5L1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J -105 -1J -10512-1J-1051-2 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-105PBI-1J-105PB1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J -107 -1J -107-1J-107 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-1 07 - 1 J-107LI - 1 J-10711 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J -109 -1J -109-1J-109 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-109-1J-109PBI-1J-109PB1 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J -115 -1J -115-1J-115 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -115 -1J -1151-1-1J-11511 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -115-1J-11511 Pat -1J-11511 PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -115 -1J -115L1 PB2-13-115LI PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/102018 4:21:10PM Page 2 COMPASS 5000.14 Build 85D `- ConocoPhillips R ER ConocoPhillips Travelling Cylinder Report UGHES Reference Offset Centre to a GE.pany Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well 1J-10 Project: Kupawk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuporuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: Two Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-1011-01 Database: EDT 14 Alaska Production Reference Design: 1J-10L1-01_wp02 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1J Pad 1J -115 -1J -115L2 -1J -115L2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115L2PB1-1J-115L2PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-1I5L2PB2-1J-1151-2PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115P131-1J-115PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB2-1J-115PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB3-1J-115PB3 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB4-1J-115PB4 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1 J-118 - 1 J-118 - 11-118 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -118 -1J -11811-1J-11811 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -118 -1J -11812-1J-11812 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -118-1J-11 Spat -1J-118PB1 304.63 300.00 189.29 4.81 184.48 Pass -Major Risk 1J-118-1J-118PB2-1J-118PB2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -120 -1J -120-1J-120 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120LI-1J-120LI 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1 J-1 20 - 1 J-1 20LI Pat -1J-12011 PBI 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 PB2-1J-120L1 PB2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120-1J-1201-1 PB3-1J-120LI PB3 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120-1J-12011 PB4-1J-12011 PB4 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -1201-2-1J-12012 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120L2PB1-1J-120L2PB1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -152 -1J -152-1J-152 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1 J-152 - 1 J-1521-1 - 1J-152LI 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J -152 -1J -1521-2-1J-1521-2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152L2PB1-1J-152L2PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-1 52 - 1J-1 52PB1 - 1 J-1 52PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152PI32-1J-152PB2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J -154 -1J -154-1J-154 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -154 -1J -15411-1J-15411 605.44 600.00 146.13 10.47 135.67 Pass -Major Risk 1J -154 -1J -15412-1J-15412 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -156 -1J -156-1J-156 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156 -1J -15611 -1J -156L1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1 J-1 56 - 1 J-1 56LI Pet -1J-15611 Pat 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156 -IJ -15612-1J-15612 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1 J-158 - 1 J-158 - 1 J-158 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1 J-1 58 - 1 J-1 58LI - 1 J-1 581-1 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1J -159 -1J -159-1J-159 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159 -1J -1591-1-1J-1591-1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159-1J-1591-1 Pat -1J-159LI Pet 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159-1J-1591-1 PB2-1J-159L1 PB2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159 -1J -159L2 -1J-1591-2 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J-159-1J-159PB1-1J-159PB1 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J -160 -1J -160-1J-160 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160-1J-160LI-1J-160L1 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J -160-1J-16011 Pat -1J-16011 Pat 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1 J-160 -1 J-16012 - 1J-16012 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J -162 -1J -162-1J-162 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -162 -1J -1621-1-1J-16211 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -162-1J-1621-1 Pat -1J-162LI PBt 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162 - 1J-162PB1 - 1J-162PB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162PB2-1J-162PB2 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -164 -1J -164-1J-164 796.36 800.00 77.47 13.02 64.51 Pass -Major Risk 1J-164-1J-16411-1J-164LI 796.36 800.00 77.47 13.02 64.51 Pass -Major Risk 1J -164 -1J -16412-1J-1641-2 796.36 800.00 77.47 13.02 64.51 Pass -Maior Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/102018 4:21:10PM Page 3 COMPASS 5000.14 Build 85D .- Kuparuk 1 Pad- 1E -35 -Plan tE-35A-1E-35A(wp02) ConocoPhillips ConocoPhillips Montaguerror: ew van Travelling Cylinder Report JUGHES Offset Centre to No -Go Allowable a GEcompan, Company: ConocoPhillips (Alaska) Inc. -Kupi Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: iJ-10:114.25 @ 114.25usft (iJ-10:114.25) Reference Site: Kuparuk IJ Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error. 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-1011-01 Database: EDT 14 Alaska Production Reference Design: 1J-10L1-Gl_wp02 Offset TVD Reference: Offset Datum Summary Kuparuk 1 Pad- 1E -35 -Plan tE-35A-1E-35A(wp02) Montaguerror: ew van survey Program: Reference Offset Centre to No -Go Allowable Rule Assigned: Major Risk g ustwell Ener: 0.00 usft Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Measured Offset Well - Wellbore - Design (usft) (usft) (usft) wee, (usft) Oftael WeBmreCentre Kuparuk IJ Pad Centre to No Go Allowfbb warning Depth DoPM Depth 1J-164-1J-1641-2PB1-1J-16412PB1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J -166 -1J -166-1J-166 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -166 -1J -166L7 -1J-16611 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -166 -1J -166L7 Pat -1J-1661-1 PB1 703.30 700.00 122.72 12.34 110.38 Pass -Major Risk 1J -166 -1J -1661-2-1J-16612 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166-1J-1661-2PB1-1J-16612PB1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-168-IJ-168-iJ-168 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J -168 -1J -168L7 -1J -168L1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J -168 -1J -1681-2-1J-16812 404.72 400.00 161.98 6.61 155.38 Pass -Major Risk 1J-168-1J-16812PB1-1J-1681-2PB1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J -170 -IJ -170-1J-170 5,690.17 8,300.00 247.69 159.88 140.49 Pass - Major Risk 1J-170-1J-170Ll-1J-17011 5,566.22 6,300.00 182.48 156.25 55.71 Pass - Major Risk 1J -170 -1J -1701-2-1J-17012 5,394.81 8,200.00 166.39 152.00 53.52 Pass -Major Risk 1J-170-1J-170PB7-1J-170PBi 5,676.40 8,300.00 273.16 159.57 164.32 Pass -Major Risk 1J-170-1J-170PB2-1J-170PB2 5,690.17 8,300.00 247.69 160.14 140.23 Pass - Major Risk Plan 1J-104(empty)-Prelim: l J -104 -Prelim: iJ- 406.82 400.00 232.09 5.53 226.57 Pass - Major Risk Plan 1J-104 (empty) - Prelim: 1J-104 L1 - Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-104(empty)-Prelim: 1J-104 L2 -Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-109a-1J-109PB7 x-1J-109PB1x 114.25 33.25 177.64 1.02 176.62 Pass - Major Risk W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15 487.50 500.00 209.67 9.95 199.72 Pass - Major Risk W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2 396.03 400.00 184.70 5.72 178.98 Pass - Major Risk W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20 810.09 800.00 83.61 17.14 66.47 Pass - Major Risk W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3 503.17 500.00 184.73 11.21 173.52 Pass - Major Risk W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4 491.49 500.00 196.71 7.54 189.18 Pass - Major Risk W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5 486.33 500.00 231.04 10.16 220.89 Pass - Major Risk Offset Design Kuparuk 1 Pad- 1E -35 -Plan tE-35A-1E-35A(wp02) Montaguerror: ew van survey Program: 199-GYD-CT-CMS.69fi1MW0 Rule Assigned: Major Risk g ustwell Ener: 0.00 usft Reference lMset Semi Major Axia Measured Vertical Measured vertical Reference wee, rocket, Oftael WeBmreCentre Casing- Centre to No Go Allowfbb warning Depth DoPM Depth Depth Aunnuvi ena -E/-W Hole Sim Centre Distance linn.n luaftl (deft) WaNI luaftl luahl Ideal CI (uef0 (usft) lin) used fuift) Itself) 13,900.00 6,208.94 13.700,00 5,798.68 5502 11045 42.28 3,33825 -3,668.78 5.000 1699.37 438.66 1,266.27 Pass -Major Risk 13,950.00 6,211.60 13.800.00 5,92546 5552 111.94 45.20 3,253.12 -3,623.67 5.000 1,644.38 452.80 1,203.10 Pau -Major Risk 13,950.00 6,211.60 13,900,00 5.852.24 55.52 113.44 44.84 3,167.98 -3,57056 5.000 1,592.39 456.38 1,139.51 Paid -Maki -Risk 14.520.69 8,233.63 14,000.00 5,879.02 61.71 114.94 29.31 3,082.85 -3,533.45 3.000 1,535.28 417.35 1,127.32 Pass - Major Risk 14,550.00 6,233.48 14,100.00 5,905.80 62.05 116.44 30.95 2,997.71 -3,488,33 3.000 1.462.60 430,15 1.043.86 Pass-Muoraisk 14,57031 0233.39 14,200.00 5.932.58 62.29 117.95 31.92 2,912.58 -3."3.22 3.000 1,392.03 440.00 960.62 Pass - Major Risk 14,600.00 6.233.29 14.300.00 5,959.36 62.84 119.45 33.43 2,827,45 -3.390.11 3,000 1,323.66 452.37 Na.39 Pass - Major Risk 14,627.13 6.233.23 14,400.00 5,988.14 62.7 120.% U.7a 2,742.31 -3,353.00 3.000 1,253.30 463.82 801,98 Paas -Major Risk 14,650.00 6,233,19 14,500.00 6.012.92 63.24 122.46 35.59 2,657.18 -3,307.69 3.000 1,195.70 473.62 725.15 Pau - Major Rkk 14,700.00 8,233.17 14,60000 0039.71 63.85 123.97 38.27 2,572.04 -3862.78 3.000 1,136.24 490.68 655.04 Pass - Major Risk 14.M5.15 6,233.19 14,700.00 0066.49 Ws 125.48 39.09 2,486.91 -3,217.67 3.000 1.080.17 500.53 504.43 Pass - Major Risk 14,750.00 0233.23 14,800.00 6,093.27 64.46 127.00 39.78 2,401.77 -3,172.56 3000 1,028.20 510.04 517.95 Pass -Major Risk 14.800.00 023336 14.900.00 6,120.05 65.06 128.51 42.08 2,316.64 -3,127.45 3.000 980.15 524.29 458.57 Pass- Major Risk, CC, ES, SF CC - Min centre to Center distance or covergem point, SF- min separation factor, ES -min ellipse separation 12110/2018 4:21:10PM Page 4 COMPASS 5000.14 Build 85D (u1/ysn 00£) (+)g13oN k-)g111°S � ry p,Q �`� w a � S a r 1= Y vi a 0 ado a caa v � ym�MmQNQOAmNMmOI Y]Mrm lnANe,O� O]N MO��N„51��ANh >��r1�rn�m�aOm�OOMthM a z =<o c°iopO0000 o 00000000mo O ��1y000O00000mO,pN Q M M N N N N N D N N N OOOOOOC>00000 CR C 0 S 0 0 0 0 0 0 0 0 0 0 0 o p o °�po<��r���r•rrnrrrr`r•� r .- ? ,100 {GM AMm'Rm�hMrOM(V NI Y]N WN mACfOmmmMOmNN O,OMOmM J `M (Or (gNMmN,ONAQNNmmmmmONQ Wm � N,GOQ�O)MmNO�Nem�ml�m O,O�OeO�m�N(V a7QQOfNQA W � �mm{Q+JMMMI+INNNNNm���� J W (/)mmQe maDm OfQ�mmOmm,tf Of yrTM(?�QmmNO�-O�Mm�Mm � o, cco pAmoimoi '-eio cvia limo<moi of >MQmmmmMmm ,ommmo�.-� 3000 L� ~NUOIJNN,Ahm[OOb�(00 [00 (OO tpOmmaOm 00 Z W O T m r m mMOOQmA� 0gy—mm mMMmmm mNOM,�rnnmN�mom - c4 .1i m.�vc-'iNoomoornNoorn2] OMQ�mneom rN!rrr-----MOm.m- —.Ow- —NmNMN� vcNmnvmi �WIo!) + pppppmM�pm o o mo o o o 0oop00000 pp 1�6'd6 m000000000 NQ�ONMMMMOO�[]OONNmo � o -3150 + ry -3300 3450 ONE ■■■■■■� .3600 , ■■M■ ■■■■�■� 3]50 ■■■No ■■ J�h!!!V■_�■_w71 ; 3900 -4050 -4200 - B -4350 ME 10-1 01-f1 ......... __.. ..... iiQi��■■■■■■■®i -4500 - 4650 ��■i■■■■■■■■■ fl Y -4800 ..,, 50110-19 P11 ._... ......_....._a -a9s0 a - - -sloo a 5250 (u1/ysn 00£) (+)g13oN k-)g111°S C � ry p,Q �`� w a � S a r 1= Y vi a 0 ado a caa v � ym�MmQNQOAmNMmOI Y]Mrm lnANe,O� O]N MO��N„51��ANh >��r1�rn�m�aOm�OOMthM a z =<o c°iopO0000 o 00000000mo O ��1y000O00000mO,pN Q M M N N N N N D N N N OOOOOOC>00000 CR C 0 S 0 0 0 0 0 0 0 0 0 0 0 o p o °�po<��r���r•rrnrrrr`r•� r .- ? ,100 {GM AMm'Rm�hMrOM(V NI Y]N WN mACfOmmmMOmNN O,OMOmM J `M (Or (gNMmN,ONAQNNmmmmmONQ Wm � N,GOQ�O)MmNO�Nem�ml�m O,O�OeO�m�N(V a7QQOfNQA W � �mm{Q+JMMMI+INNNNNm���� J W (/)mmQe maDm OfQ�mmOmm,tf Of yrTM(?�QmmNO�-O�Mm�Mm � o, cco pAmoimoi '-eio cvia limo<moi of >MQmmmmMmm ,ommmo�.-� 3000 L� ~NUOIJNN,Ahm[OOb�(00 [00 (OO tpOmmaOm 00 Z W O T m r m mMOOQmA� 0gy—mm mMMmmm mNOM,�rnnmN�mom - c4 .1i m.�vc-'iNoomoornNoorn2] OMQ�mneom rN!rrr-----MOm.m- —.Ow- —NmNMN� vcNmnvmi �WIo!) + pppppmM�pm o o mo o o o 0oop00000 pp 1�6'd6 m000000000 NQ�ONMMMMOO�[]OONNmo � o -3150 + C I 1 2400 2550 ,100 2850 3000 8 -3150 ry -3300 3450 .3600 3]50 3900 -4050 -4200 - B -4350 10-1 01-f1 ......... __.. ..... -4500 4650 fl Y -4800 50110-19 P11 ._... ......_....._a -a9s0 a - - -sloo a 5250 -5400 5550 5]00 00610991-11 ......... __. 5850 -6000 6150 ma -mal..:__ ....... _.._ _6300 6450 6600 .6)50 ILLS -6900 ... - o -7050 Z -10.190111.__. ._ o -]200 -]350 -]500 6 r -]650 -]800 � O - -]950 - w` P -8100 a v 3 -8250 N W � -84M I ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1J Pad IJ -IO 1.1-101-1-02 Plan: 1 J-10L1-02_wp01 Standard Planning Report 17 December, 2018 BT�a GHES GE company ConocoPhillips BA ER cm0cailillips Planning Report F�IGHES aGEcompany Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J-10 Wellbore: 1J-101-1-02 Design: 1J -101-1-02_w1001 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1J-10 Mean Sea Level 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States 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 Kupawk 1J Pad Site Position: From: Map Northing: Easting: 5,945,919.84 usft 558,789.95 usft Latitude: Longitude: 70° 15'46.258 N 149° 31'29,007 W Position Uncertainty: 0.00 usft Slot Radius: 0.00Oin Grid Convergence: 0.45° Well 1J-10 Well Position -NIS 0.00 usft Northing: 5,945,808.06 usft Latitude: 70° 15'45.169 N +E/ -W 0.00 usft Easting: 558,673.32 usft Longitude: 149" 31'32.426 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1J-101-1-02 Magnetics Model Name Semple Date Declination Dip Angle Field Strength (nT) BGGM2018 2/1/2019 16.77 80.84 57,424 Design 1J-101-1-02 wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 12,300.00 Vertical Section: Depth From (TVD) -NIS +EI -W Direction (usft) (usft) (usft) PI 0.00 0.00 0.00 180.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NIS +E1 -W Rate Rate Rate TFO (usft) (1) (°) (usft) (usft) (usft) (°1100usft) (°HOOusft) (°/100usft) V) Target 12,300.00 88.48 142.97 6,045.13 2,762.32 -5,844.45 0.00 0.00 0.00 0.00 12,425.00 80.92 147.39 6,058.67 2,660.26 -5,773.42 7.00 -6.05 3.53 150.00 12,575.00 90.03 152.61 6,068.50 2,530.92 -5,698.80 7.00 6.08 3.49 30.00 12,900.00 91.96 175.29 6,062.76 2,220.69 -5,609.53 7.00 0.59 6.98 85.00 13,225.00 91.81 198.05 6,051.92 1,900.18 -5,647.00 7.00 -0.05 7.00 90.00 13,500.00 91.71 178.79 6,043.39 1,629.56 -5,687.06 7.00 -0.04 -7.00 270.00 13,775.00 90.63 198.01 6,037.73 1,358.84 -5,727.05 7.00 -0.39 6.99 93.00 14,175.00 90.55 170.01 6,033.54 963.80 -5,754.76 7.00 -0.02 -7.00 270.00 14,375.00 90.54 184.01 6,031.63 764.58 -5,744.36 7.00 -0.01 7.00 90.00 14,775.00 90.47 156.01 6,028.04 374.57 -5,675.68 7.00 -0.02 -7.00 270.00 12/17201810:44:13AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillipsBA ERGHES F�U ConocoPhillips Planning Report aGE.inpany Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usit (1J-10:114.25) Site: Kuparuk 1J Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellbore: iJ-10L1-02 Design: IJ -100-02 wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NIS +E/.W Section Rate Azimuth Northing Easting (usft) (o) (_) (usft) (usft) (usft) (usft) (`I100usft) (°I (usft) (usft) 12,300.00 88.48 142.97 6,045.13 2,762.32 -5,844.45 -2,762.32 0.00 0.00 5,948,524.49 552,808.08 TIPIKOP 12,400.00 82.43 146.49 6,053.05 2,680.99 -5,786.92 -2,680.99 7.00 150.00 5,948,443.62 552,866.25 12,425.00 80.92 147.39 6,056.67 2,660.26 -5,773.42 -2,650.26 7.00 149.72 5,948,423.00 552,879.90 Start 7 We 12,500.00 85.47 150.02 6,065.56 2,596.64 -5,734.76 -2,596.64 7.00 30.00 5,948,359.69 552,919.06 12,575.00 90.03 152.61 6,068.50 2,530.92 -5,698.80 -2,530.92 7.00 29.69 5,948,294.26 552,955.52 3 12,600.00 90.19 154.36 6,068.45 2,508.55 -5,687.64 -2,508.55 7.00 85.00 5,948,271.98 552,966.85 12,700.00 90.79 161.33 6,067.60 2,415.99 -5,649.95 -2,415.99 7.00 85.00 5,948,179.73 553,005.26 12,800.00 91.39 168.31 6,065.69 2,319.56 -5,623.78 -2,319.56 7.00 85.06 5,948,083.51 553,032.17 12,900.00 91.96 175.29 6,062.76 2,220.69 -5,609.53 -2,220.69 7.00 85.20 5,947,984.76 553,047.20 4 13,000.00 91.95 182.29 6,059.34 2,120.83 -5,607.42 -2,120.83 7.00 90.00 5,947,884.93 553,050.08 13,100.00 91.91 189.29 6,055.98 2,021.46 -5,617.50 -2,021.46 7.00 90.24 5,947,785.49 553,040.78 13,200.00 91.83 196.30 6,052.71 1,924.05 -5,639.62 -1,924.05 7.00 90.48 5,947,687.93 553,019.42 13,225.00 91.81 198.05 6,051.92 1,900.18 -5,647.00 -1,900.18 7.00 90.70 5,947,664.00 553,012.23 6 13,300.00 91.80 192.80 6,049.55 1,827.94 -5,666.93 -1,827.94 7.00 -90.00 5,947,591.62 552,992.86 13,400.00 91.77 185.79 6,046.43 1,729.37 -5,683.06 -1,729.37 7.00 -90.17 5,947,492.93 552,977.50 13,500.00 91.71 178.79 6,043.39 1,629.56 -5,687.06 -1,629.56 7.00 -90.38 5,947,393.10 552,974.29 6 13,600.00 91.33 185.78 6,040.73 1,529.73 -5,691.04 -1,529.73 7.00 93.00 5,947,293.26 552,971.08 13,700.00 90.93 192.77 6,038.75 1,431.12 -5,707.15 -1,431.12 7.00 93.19 5,947,194.53 552,955.74 13,775.00 90.63 198.01 6,037.73 1,358.84 -5,727.05 -1,358.84 7.00 93.32 5,947,122.11 552,936.41 7 13,800.00 90.63 196.26 6,037.46 1,334.96 -5,734.41 -1,334.96 7.00 -90.00 5,947,098.17 552,929.23 13,900.00 90.62 189.26 6,036.37 1,237.49 -5,756.49 -1,237.49 7,00 -90.02 5,947,000.54 552,907.91 14,000.00 90.60 182.26 6,035.31 1,138.07 -5,766.53 -1,138.07 7.00 -90.10 5,946,901.05 552,898.66 14,100.00 90.58 175.26 6,034.28 1,038.16 -5,764.37 -1,038.16 7.00 -90.17 5,946,801.17 552,901.59 14,175.00 90.55 170.01 6,033.54 963.80 -5,754.76 -963.80 7.00 -90.24 5,946,726.90 552,911.78 S 14,200.00 90.55 171.76 6,033.30 939.12 -5,750.80 -939.12 7.00 90.00 5,946,702.26 552,915.93 14,300.00 90.55 178.76 6,032.34 839.53 -5,742.55 -839.53 7.00 90.02 5,946,602.74 552,924.96 14,375.00 90.54 184.01 6,031.63 764.58 -5,744.36 -764.58 7.00 90.08 5,946,527.79 552,923.73 9 14,400.00 90.54 182.26 6,031.40 739.62 -5,745.73 -739.62 7.00 -90.00 5,946,502.82 552,922.55 14,500.00 90.53 175.26 6,030.47 639.71 -5,743.57 -639.71 7.00 -90.02 5,946,402.94 552,925.49 14,600.00 90.52 168.26 6,029.55 540.81 -5,729.25 -540.81 7.00 -90.08 5,946,304.16 552,940.58 14,700.00 90.49 161.26 6,028.67 444.39 -5,702.99 -444.39 7.00 -90.15 5,946,207.96 552,967.59 14,775.00 90.47 156.01 6,028.04 374.57 -5,675.68 -374.57 7.00 -90.21 5,946,138.36 552,995.44 TD at 14775.00 �Planned Casing Points _ Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,775.00 6,028.04 2 3ie" 2.375 3.000 12/172018 10:44:13AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillipsBAKER ConoCofullip5 Planning Report I-'UGHES a GE.,n, y Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kupawk River Unit Site: Kupamk U Pad Well: 1J-10 Wellbore: 1J -10L1-02 Design: 1J-101-1-02_Wp01 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 12,300.00 6,045.13 12,425.00 6,056.67 12,575.00 6,068.50 12,900.00 6,062.76 13,225.00 6,051.92 13,500.00 6,043.39 13,775.00 6,037.73 14,175.00 6,033.54 14,375.00 6,031.63 14,775.00 6,028.04 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Local Coordinates *NIS +EI -W (usft) (usft) 2,762.32 -5,844.45 2,660.26 -5,773.42 2,530.92 -5,698.80 2,220.69 -5,609.53 1,900.18 5,647.00 1,629.56 5,687.06 1,358.84 5,727.05 963.80 -5,754.76 764.58 -5,744.36 374.57 -5,675.68 Comment TIPIKOP Start 7 dls 3 4 5 6 7 8 9 Planned TO at 14775.00 Well U-10 Mean Sea Level 1J-10:114.25 @ 114.25usft (1J-10:114.25) True Minimum Curvature 1271712018 10:44:13AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1J Pad 1J-10 1J -10L1-02 1 J-10L1-02_wp01 Travelling Cylinder Report 10 December, 2018 BT�aGEcornpany GHES ConocoPhillipsER COnOCOP%liiiips Travelling Cylinder Report JUGHES aGE ompary Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Reference Site: Kupawk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Wellbore 1J-1011-02 Reference Design: 1J-101-1-02_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well ii -lo 1J-10:114.25 @ 114.25usft (iJ-10:114.25) IJ -1 0:114,25 @ 114.25usft (iJ-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 1J-101-1-02_wp01 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 100.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,666.08 usft Error Surface: Pedal Curve Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1.1 Pad 1J -03 -1J -03-1J-03 114.25 116.12 161.44 0.74 160.70 Pass - Major Risk 1J -03 -1J -031-1-1J-031-1 114.25 116.00 161.44 1.02 160.41 Pass -Major Risk 1J-03-iJ-031-2-1J-031-2 114.25 116.00 161.44 1.02 160.41 Pass -Major Risk 1J-03-1J-03L2PB1-1J-03L2PB1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J-09 - 11-09 -1J-09 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J -09 -1J -09A -1J -09A 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J-09-1J-09AL7-1J-09AL1 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J -10 -1J -10-1J-10 10,488.86 10,500.00 29.34 13.60 20.73 Pass - Major Risk IJ -10 - lJ-101-1 - 1 J-10L7_Wp01 Out of range 1J-10-1J-10L1-01-1J-101-1-07_wp02 12,313.37 12,300.00 0.93 2.64 -1.78 FAIL - Minor 1110 IJ-10-iJ-10LI-03-1J-10L1-03_wp01 12,469.66 12,500.00 106.86 2.03 104.92 Pass -Minor 1/10 1J -105 -1J -105-1J-105 305.08 300.00 218.10 4.82 213.29 Pass -Major Risk 1J-105-iJ-1051-1-1J-105LI 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J -105 -1J -10512 -1J -105L2 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J-105-1J-105PB7-1J-105PBi 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J -107 -1J -107-1J-107 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-107-1J-107LI-1J-10711 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J -109 -1J -109-1J-109 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk IJ-109-1J-109PB1-1J-109PB1 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk IJ-115-1J-115-iJ-115 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -115 -1J -1151-1-1J-11511 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -115-1J-1151-1 Pat -1J-1151-1 Pat 403.76 400.00 159.15 6.67 152.48 Pass -Major Risk 1J -115-1J-11511 P82 -1J-1151-1 P82 403.76 400.00 159.15 6.67 152.48 Pass -Major Risk 1J -115 -1J -11512-1J-1151-2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1 J-11 5 - 1J-11 5L2PB1 - 1 J-11 5L2PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/10/2018 4:32:27PM Page 2 COMPASS 5000.14 Build 85D „- ConocoPhillips Conoco �ll��lp5 Travelling Cylinder Report IUGHFS a GE company Company: ConocoPhillips (Alaska) Inc. -Kupt Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparllk 1J Pad MD Reference: 1J-10:114.25 Q 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-1011-02 Database: EDT 14 Alaska Production Reference Design: 1 J-10L7-02_wp01 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1J Pad 1J-115-1J-115L2PB2-1J-115L2PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB1-1J-115PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB2-1J-115PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115 - 1 J-11 5PB3 - 1 J-1 1 5PB3 403.76 400.00 159.15 6.67 152.48 Pass -Major Risk 1J-115-1J-115PB4-1J-115PB4 403.76 400.00 159.15 6.67 152.48 Pass -Major Risk 1J -118 -1J -118-1J-118 304.63 300.00 189.29 4.81 184.48 Pass -Major Risk 1J -118 -1J -11811-1J-11811 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -118 -1J -11812 -1J -118L2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118PB1-1J-118PB1 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118PB2-1J-118PB2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -120 -1J -120-1J-120 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 -1J -120L1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 Pat -1J -120L1 Pat 304.57 300.00 216.86 4.81 212.05 Pass -Major Risk 1J-1 20 - 1 J-1 20LI PB2-1J-120L1 PB2 304.57 300.00 216.86 4.81 212.05 Pass -Major Risk 1J -120 -1J -120L1 PB3. 1J-120LI PB3 304.57 300.00 216.86 4.81 212.05 Pass -Major Risk 1J -120 -1J -120L1 PB4-1J-120L1 PB4 304.57 300.00 216.86 4.81 212.05 Pass -Major Risk 1J -120 -1J -1201.2 -1J -120L2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-12012PB1-1J-120L2PB1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -152 -1J -152-1J-152 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J -152 -1J -1521.1-1J-1521-1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J -152 -1J -1521-2-1J-1521-2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-1521-21`131-1J-152L2PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1 J-1 52 - 1 J-152PB1 - 1 J-1 52PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152PB2-1J-152PB2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J -154 -1J -154-1J-154 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -154 -1J -1541-1-1J-1541.1 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -154 -1J -15412-1J-15412 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -156 -1J -156-1J-156 2,226.75 2,100.00 117.13 48.45 79,06 Pass - Major Risk 1J -156 -1J -15617 -1J -156L1 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156 -1J -156L1 Pat -1J-156LI PBt 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156 -1J -156L2 -1J-15612 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -158 -1J -158-1J-158 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1J-158-1J-158LI-1J-158L1 392.81 400.00 60.36 6.31 54.05 Pass - Major Risk 1J -159 -1J -159-1J-159 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J-159-1J-159L1-1J-159LI 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J-159-1--1591-1 P81 -1J -159L1 P81 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J -159-1J-1591-1 PB2-1J-159L1 PB2 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J -159 -1J -1591 -2 -1J -159L2 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J-159-1J-159PBI-lJ-159PB1 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J -160 -1J -160-1J-160 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J-160-1J-16OLl-1J-16011 291.93 300.00 21.20 L57 16.63 Pass -Major Risk 1J -160 -1J -160L1 Pat -1J -160L1 Pat 291.93 300.00 2120 4.57 16.63 Pass -Major Risk 1J -160 -1J -180L2 -1J -160L2 291.93 300.00 2120 4.57 16.63 Pass - Major Risk 1J -162 -1J -162-1J-162 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -162 -1J -162L1 -1J -162L1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -162 -1J -162L1 Pat -1J-16211 Pat 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162PB1-1J-162PB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 7J-162-1J-162PB2-1J-162PB2 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -164-1J-164. 1J-164 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J -164 -1J -164L1 -1J-1641-1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J -164 -1J -164L2 -1J-1641-2 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J-1 64 - 1 J-1641.21`131 - 1 J-164L2PB1 796.36 800.00 77.47 13.02 64.51 Pass - Major Risk 1J -166 -1J -166-1J-166 703.30 700.00 122.72 12.34 110.38 Pass - Maor Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12FI02018 4.32:27PM Page 3 COMPASS 5000.14 Build 85D I. ConocoPhillips B' 1 J-03 - 1 J-03 ConocoPhillips Travelling Cylinder Report UGHES Reference Offset a GEcompery Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Coordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: iJ-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-101-1-02 Database: EDT 14 Alaska Production Reference Design: 1J-101-1-02_Wp01 Offset TVD Reference: Offset Datum Summary Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03 Reference Offset Centre to No -Go Allowable Survey Program: 201-MW3+IFR-AK-SCC Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore- Design (usft) (usft) (usft) (usft) Kupamk 1J Pad Measured Vertical Measuretl 1J -166 -1J -166L1 -1J -166L1 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -166 -1J -166L7 Pat -1J -166L1 Pet 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -166 -1J -16612-1J-1661_2 703.30 700.00 122.72 12.34 110.38 Pass -Major Risk 1J-166-1J-166L2PB1-1J-166L2PB1 703.30 700.00 122.72 12.34 110.38 Pass -Major Risk 1J-168 -1 J-168 - 1 J-168 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J -168 -1J -168L1 -1J-1681_1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168 -1 J-1681_2 - 1 J-16812 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168-1J-168L2PB1-1J-168L2PB1 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J -170 -1J -170-1J-170 5,690.17 8,300.00 247.69 159.88 140.49 Pass - Major Risk 1J -170 -1J -17011-1J-17011 5,566.22 8,300.00 182.48 156.25 55.71 Pass - Major Risk 1J -170 -1J -170L2 -1J-17012 5,394.81 8,200.00 166.39 152.00 53.52 Pass - Major Risk 1J-170-1J-170PB1-1J-170PB7 5,676.40 8,300.00 273.16 159.57 164.32 Pass - Major Risk 1J-170-1J-170PB2-1J-170PB2 5,690.17 8,300.00 247.69 160.14 140.23 Pass - Major Risk Plan 1J-104(empty)-Prelim: IJ -104 -Prelim: IJ- 406.82 400.00 232.09 5.53 226.57 Pass - Major Risk Plan 1J-104(empty)-Prelim: 1J-104 L1 -Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-104(empty)-Prelim: 1J-104 L2 -Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-109a-1J-109PB1 x-1J-109PBix 114.25 33.25 177.64 1.02 176.62 Pass - Major Risk W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15 487.50 500.00 209.67 9.95 199.72 Pass - Major Risk W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2 396.03 400.00 184.70 5.72 178.98 Pass - Major Risk W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20 810.09 800.00 83.61 17.14 66.47 Pass - Major Risk W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3 503.17 500.00 184.73 11.21 173.52 Pass - Major Risk W SAK PLT 4-W SAK PLT 4-W SAK PLT4 491.49 500.00 196.71 7.54 189.18 Pass -Major Risk W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5 486.33 500.00 231.04 10.16 220.89 Pass - Major Risk Offset Design Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03 offset site Error. 0 00 on Survey Program: 201-MW3+IFR-AK-SCC Rule assigned: Major Risk Offset well Enpr: 0.00 u59 Referenm Offset Semi Major Axis Measured Vertical Measuretl Vertical Reference Offset Toolfacee Offset Well6orecemre casing- centre to N.G. Alluwabla Waming pepth Depth Depth Depth Aximutb rN/S +EFW Role Sim Centre Distance Deviation (usft) (.sft) (um) Juan (usft) (usn) r) (usft) fusel finj lusfll (usm (usft) 114.25 144.25 116.12 116.12 0.00 0.00 46.71 11 OAS 11751 8,875 16164 074 166.70 Pass- Major Risk. CC. ES, SF 19].92 197.92 200.00 199.98 0.05 0.05 46.07 111.45 118.89 8.875 163.01 1.83 161.18 Pass -Major Risk 297.75 297.75 300.00 299.90 0.15 0.17 47.31 113.30 122.46 8875 167.03 3.41 163.63 Pass Major Risk 397.01 197.00 400.00 399.80 0.27 0.28 47.91 115.05 126.60 8.875 171.49 4.97 166.52 Pau - Major Risk 493.34 493.32 500.00 499.54 0.38 0.40 49.14 117.62 131.26 8.875 178.64 6.53 173.12 Pass -Major Risk 587.98 587.87 600.00 5101.06 0.49 0.53 51.31 120.27 143.55 9.875 192.72 8.10 181.64 Pass Major Risk 677.68 s7].11 700.00 697.93 Dec 0.67 53.92 123.90 157.38 8.875 212.30 9.64 202.72 Pau - Major Risk 752.37 751.30 800.00 706.49 0.69 0.81 57.67 124.33 174.25 9.875 238.69 10.99 227.80 Pau - Major Risk 836.40 833.59 900.00 094.76 0.02 0.95 61.01 127.00 192.55 0.075 273.85 12.51 261.59 Pau Major Risk 92190 916.44 1,000.00 992.43 0.95 1.12 63.78 132.65 213.20 8.875 316.43 14.15 302.78 Pass -Major Risk 1.002.62 994.25 1,100.00 1,0643.93 1.0 1.34 66.01 141.43 237.88 8.875 365.16 15.84 350.18 Pau - Major Risk 1.072.17 1.06168 1.200.00 1,103.97 1.21 1.59 67.60 153.99 266.27 8.975 420.60 17.51 404.45 Pau Major Risk 1,128.96 1,114.17 1,300.00 1.276.57 1.32 1.90 6070 171.29 299+72 8.875 484.87 19.14 467.71 Pass Major Risk 1186.86 1.168.03 1,400.00 1,355.40 1.45 2.28 69.33 193.00 340.12 8.875 557.89 21.02 539.71 Pus - Major Risk 1.236.53 1,213.77 1,500.00 1,451.11 1.57 2.72 69.75 218.16 385.04 8.975 636.46 22.91 617.42 Pau Major Risk 1,280.95 1,251.20 1,600.00 1.533.47 1.68 332 70.20 245.70 431.57 0.875 719.64 24.83 699.84 Pass -Major Risk 1,316.75 1.2%.41 1,700.00 1,611.71 1.76 3.T/ 70.66 275.94 488.99 8.875 007.16 26.73 785,71 Pass Major Risk 1.350.74 1,316.67 1,800.00 1,665.35 1.86 4.37 70.91 306.71 546.89 8.975 897.66 2875 876.61 Pass Major Risk 1.3A.15 1,339.% 1.900.00 11755311 1.93 5.02 71.00 MISS 608.70 8.87$ 990.96 30.74 969.42 Pau - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/102018 4:32:27PM Page 4 COMPASS 5000.14 Build 85D a 4 m (uij(lsu 000 (+)9)JaN/(-)43u0S a � mvy JM - in O r E4 6ryMe�nmrmrns m V r SEE �mm A m.n.mmMrni; of 9 Z N N N N � � „ MENEM �� UIOOOOOOOOOO U o o O o 0 o O o 0 OMNI j�LL 616 OOGNOOO {7000 p�000000000 M O O O O O0O O O O O O p O A A A r r r r A r OMNI � VeW1n000AM[O �MlMMM0 d.7 ac oirnn<�vi CM u1.1n u]V���fTvNhM� J M 1OA (nNNNOfmmeOmA WO M rnm�mmmu�v2 a NZN00000]WMee W N }tpmMNONmmtOA AmNNOmM O1rM e: o J .255 (/JMAOmNNMCMe MI+ m0 W Ol _(p IMINIMIN r O� L o� ..MMM. m m m m m m. m m m zmra�rn�nm���� ��CIMmNOA0000 m < m m c<mommrmvmi ueia O3. zc � o o oma.=�ococ m m m m o m m w rn m 1} p o 00 0 0 0 0 0 0 0 M o 0 ..... 0 ri.. c vi vi ovio vi �Zvi O N A O N O A r r A e mONlnr�Mr -425 � o y,�NMe�nmrmmo Zo tS ♦ -510 -595 go -680 m®■MmmMme 1... so IN .850 935 MM WWII&A .... 020 Sol -1105 - -1190 (uij(lsu 000 (+)9)JaN/(-)43u0S E vi a � mvy JM - in O r E4 6ryMe�nmrmrns m V r £j mNOfmN fOeOmA OJ YJN yt�NA�m InNOO E 00AmMee �mtOMNONbmfOr A m.n.mmMrni; of 9 Z N N N N � � �� UIOOOOOOOOOO U o o O o 0 o O o 0 O j�LL 616 OOGNOOO {7000 p�000000000 M O O O O O0O O O O O O p O A A A r r r r A r � VeW1n000AM[O d.7 ac oirnn<�vi CM u1.1n u]V���fTvNhM� J M 1OA (nNNNOfmmeOmA WO M rnm�mmmu�v2 a NZN00000]WMee W N }tpmMNONmmtOA AmNNOmM O1rM e: o J .255 (/JMAOmNNMCMe MI+ m0 W Ol _(p y�mNAOf pNtG�N�Cl I�a7�m ern r O� L o� ..MMM. m m m m m m. m m m zmra�rn�nm���� ��CIMmNOA0000 m < m m c<mommrmvmi ueia O3. zc � o o oma.=�ococ m m m m o m m w rn m 1} p o 00 0 0 0 0 0 0 0 M o 0 ..... 0 ri.. c vi vi ovio vi �Zvi O N A O N O A r r A e mONlnr�Mr -425 � o y,�NMe�nmrmmo Zo tS ♦ E vi E -85 c 4 - v -170 e: o .255 m- -340 O3. zc 1101. 1 ........ -425 -510 -595 -680 -065 .850 935 020 -1105 - -1190 ;a -Ins -1360 445 ZOl Z 'f]OI [I ---1530 -1615 1]00 1]85 -1810 -1955 -2040 2125 -221C -229: -2380 -246! -255( a 263' P 2( - o -280' a F - -289( -291' -306( J -314' -3231 -331: a -3401 N -348: 9 .3571 E ConocoPhillips _ConocoPhillips Export Company Kuparuk River Unit Kuparuk 1J Pad ii -10 1J-101-1-03 Plan: 1 J-10L1-03_wp01 Standard Planning Report 17 December, 2018 BT�a GHES GE company �, ConocoPhillips BAKER ConocoPhillips Planning Report Ups OAT GE company Database: EDT 14 Alaska Production Company: _ConocoPhillips Export Company Project: Kupawk River Unit Site: Kupawk lJ Pad Well: 1J-10 Wellbore: 1J-101-1-03 Design: 1J-10L1-03_wp01 Local Co-ordinate Reference. TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1J-10 Mean Sea Level 1J-10:114.25 ® 114.25usft(1J-10:114.25) True Minimum Curvature Project Kupawk River Unit, North Slope Alaska, United States 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 1J Pad 1J-1011-03_wp01 Site Position: Northing: 5,945,919.64 usft Latitude: 70° 15'46.258 N From: Map Easting: 558,789.95 usft Longitude: 149° 31'29.007 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.45 ° Well 1J-10 1J-1011-03_wp01 Audit Notes: Well Position -NIS 0.00 usft Northing: 5,945,808.06 usft Latitude: 70° 15'45.169 N +E/ -W 0.00 usft Easting: 558,673.32 usft Longitude: 149° 31'32.426 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: O.00usft Wellbore 1,1401-1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) M (nT) BGGM2018 2/1/2019 16.77 80.84 57,424 Design 1J-1011-03_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 12,150.00 Vertical Section: Depth From (TVD) +NIS +EI -W Dtrection (usft) (usft) (usft) (°I System 0.00 0.00 0.00 90.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°I (usft) (usft) (usft) (°I100usft) (°/lo0usft) ('MOOUsft) (°) Target 12,150.00 88.46 132.46 6,041.11 2,873.09 -5,945.19 0.00 0.00 0.00 0.00 12,250.00 94.52 128.96 6,038.51 2,807.93 -5,869.47 7.00 6.06 -3.50 330.00 12,500.00 83.25 115.55 6,043.40 2,675.00 -5,658.94 7.00 -4.51 -5.37 230.00 12,800.00 84.41 94.46 6,076.01 2,598.30 -5,372.49 7.00 0.39 -7.03 272.00 13,200.00 89.72 66.92 6,096.86 2,662.53 -4,982.26 7.00 1.33 -6.88 280.00 13,600.00 89.76 94.92 6,098.71 2,725.05 -4,591.20 7.00 0.01 7.00 90.00 13,850.00 91.27 77.48 6,096.45 2,741.54 -4,342.73 7.00 0.61 -6.97 275.00 14,100.00 92.71 94.93 6,087.70 2,758.02 4,094.40 7.00 0.58 6.98 85.00 12/17/201810:45:29AM - Page 2, COMPASS 5000.14 Build 85D �, ConocoPhillips BATHER ConocoPhillips Planning Report F�UGIiES a GE compm Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1J-10 Company: _ConocoPhillips Export Company TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114,25) Site: Kuparuk 1J Pad North Reference: True Well: 1J-10 Survey Calculation Method: Minimum Curvature Wellbore: 1J -10L1-03 Map Depth Inclination Design: 1J -10L1-03 wP01 +N/.S +E/ -W Planned Survey Measured Vertical Local Coordinates Depth Depth Measured +E1 -W TVD Below (usft) (usft) Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/.S +E/ -W Section Rate Azimuth Northing Easting (usft) (I (I (usft) (waft) (usft) (usft) ('1100usft) (I (usft) (usft) 12,150.00 4 88.46 132.46 6,041.11 2,873.09 -5,945.19 -5,945.19 0.00 0.00 5,948,634.47 552,70649 -4,591.20 TIP/KOP 13,850.00 6,096.45 2,741.54 -4,342.73 7 14,100.00 6,087.70 2,758.02 12,200.00 Planned TD at 14100.00 91.49 130.71 6,041.13 2,839.91 -5,907.80 -5,907.80 7.00 -30.00 5,948,601.58 552,744.14 12,250.00 94.52 128.96 6,038.51 2,807.93 -5,869.47 -5,869.47 7.00 -30.00 5,948,569.90 552,782.71 Start 7 dis 12,300.00 92.26 126.28 6,035.56 2,777.47 -5,829.94 -5,829.94 7.00 -130.00 5,948,539.75 552,822.48 12,400.00 87.75 120.93 6,035.55 2,722.16 -5,746.70 -5,746.70 7.00 -130.16 5,948,485.10 552,906.13 12,500.00 83.25 115.55 6,043.40 2,675.00 -5,658.94 -5,658.94 7.00 -130.16 5,948,438.64 552,994.25 3 12,600.00 83.54 108.51 6,054.92 2,637.77 -5,566.91 -5,566.91 7.00 -88.00 5,948,402.13 553,086.56 12,700.00 83.93 101.48 6,065.84 2,612.08 -5,470.95 -5,470.95 7.00 -87.19 5,948,377.18 553,182.71 12,800.00 84.41 94.46 6,076.01 2,598.30 -5,372.49 -5,372.49 7.00 -86.42 5,948,364.18 553,281.26 4 12,900.00 85.67 87.54 6,084.66 2,596.57 -5,272.95 -5,272.95 7.00 -80.00 5,948,363.22 553,380.81 13,000.00 86.98 80.65 6,091.08 2,606.83 -5,173.74 -5,173.74 7.00 -79.40 5,948,374.25 553,478.92 13,100.00 88.34 73.78 6,095.17 2,628.93 -5,076.36 -5,076.36 7.00 -78.96 5,948,397.10 553,577.11 13,200.00 89.72 66.92 6,096.86 2,662.53 -4,982.26 -4,982.26 7.00 -78.68 5,948,431.44 553,670.94 6 13,300.00 89.73 73.92 6,097.34 2,696.03 -4,888.10 -4,888.10 7.00 90.00 5,948,465.66 553,764.83 13,400.00 89.73 80.92 6,097.81 2,717.80 -4,790.57 -4,790.57 7.00 89.97 5,948,488.19 553,862.18 13,500.00 89.74 87.92 6,098.27 2,727.52 -4,691.11 -4,691.11 7.00 89.93 5,948,498.68 553,961.56 13,600.00 89.76 94.92 6,098.71 2,725.05 -4,591.20 -4,591.20 7.00 89.90 5,948,496.99 554,061.47 6 13,700.00 90.37 87.94 6,098.60 2,722.55 -4,491.29 -4,491.29 7.00 -85.00 5,948,495.27 554,161.38 13,800.00 90.97 80.97 6,097.43 2,732.20 -4,391.83 -4,391.83 7.00 -85.01 5,948,505.70 554,260.76 13,850.00 91.27 77.48 6,096.45 2,741.54 -4,342.73 -4,342.73 7.00 -85.09 5,948,515.42 554,309.78 7 13,900.00 91.57 80.97 6,095.21 2,750.89 -4,293.63 -4,293.63 7.00 85.00 5,948,525.15 554,358.80 14,000.00 92.16 87.95 6,091.95 2,760.53 -4,194.21 -4,194.21 7.00 85.09 5,948,535.56 554,458.13 14,100.00 92.71 94.93 6,087.70 2,758.02 -4,094.40 -4,094.40 7.00 85.31 5,948,533.83 554,557.95 Planned TO at 14100.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 14,100.00 6,087.70 23/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth -NIS +E1 -W (usft) (usft) (usft) (usft) Comment 12,150.00 6,041.11 2,873.09 -5,945.19 TIP/KOP 12,250.00 6,038.51 2,807.93 -5,869.47 Start 7 dls 12,500.00 6,043.40 2,675.00 -5,658.94 3 12,800.00 6,076.01 2,598.30 -5,372.49 4 13,200.00 6,096.86 2,662.53 -4,982.26 5 13,600.00 6,098.71 2,725.05 -4,591.20 6 13,850.00 6,096.45 2,741.54 -4,342.73 7 14,100.00 6,087.70 2,758.02 -4,094.40 Planned TD at 14100.00 12/172018 10.45.29AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1J Pad 1J-10 1 J -10L1-03 1 J-10L1-03_wp01 Travelling Cylinder Report 10 December, 2018 BT�a GHES GE company ✓ ConocoPhiliipsER Conoco�{lill1ps Travelling Cylinder Report UGHES aGEcompany Company: ConocoPhillips(Alaska) Inc.-Kupi Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: 0.00 usft Reference Well: 1J-10 Well Error: 0.00 usft Reference Wellbore 1J -10L1-03 Reference Design: lJ-10L1-03_wp01 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1 J-10 1J-10:114.25 @ 114.25usft(1J-10:114.25) 1J-10:114.25 @ 114.25usft(1J-10:114.25) True Minimum Curvature 1.00 sigma EDT 14 Alaska Production Offset Datum Reference 1J-101_1-03_wp01 Casing Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference TO Interpolation Method: MD Interval 100.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tram. Cylinder North Results Limited by: Maximum center -center distance of 1,598.58 usft Error Surface: Pedal Curve Survey Tool Program Date 12/10/2018 Casing Note From TO Diameter Diameter (usft) (usft) Survey (Wellbore) Tool Name Description 205.18 10,166.00 1J-10(11-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10,166.00 10,420.00 1J-10L1_wp01 (1J-101-1) MWD MWD -Standard 10,420.00 12,150.001J-10L1-0l_wp0l(1J-1011-01) MWD MWD - Standard 12,150.00 14,100.001J-101_1-03_wp01(1J-101_1-03) MWD MWD - Standard Casing Points Measured Vertical Casing Note Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 6,936.54 3,991.30 9518" 9.625 12.250 10,142.96 5,891.30 7" 7.000 8.500 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1E Pad tE-35-Plan 1 E -35A - 1 E -35A (wp02) 14,100.00 12,900.00 1,404.59 311.20 1,124.72 Pass - Major Risk Kuparuk 1J Pad 1J -03 -1J -03-1J-03 114.25 116.12 161.44 0.74 160.70 Pass -Major Risk 1J -03 -1J -03L1 -IJ -031_1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J -03 -1J -031.2 -IJ -0312 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J-03-1J-03L2PB1-1J-03L2PB1 114.25 116.00 161.44 1.02 160.41 Pass - Major Risk 1J -09 -1J -09 -IJ -09 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J -09 -1J -09A -1J -09A 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk IJ-09-1J-09AL1-1J-09ALI 299.44 300.00 160.28 3.57 156.71 Pass - Major Risk 1J -10-11-10-1J-10 10,488.86 10,500.00 29.34 13.60 20.73 Pass - Major Risk 1 J-10 - 1J-1011 -1 J-101.1_wp01 Out of range 1J-10- 1J-10Ll-01 -1J-1 OL1-01_wp02 11,100.00 11,100.00 0.00 2.65 -0.45 FAIL - Minor 1110 1J-10-1J-101_1-02-1J-101_1-02_wp01 12,470.52 12,500.00 106.97 2.12 104.89 Pass -Minor 1/10 1J -105 -1J -105-1J-105 305.08 300.00 218.10 4.82 213.29 Pass -Major Risk 1J -105 -1J -1051_1 -1J -105L1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J -105 -1J -1051.2-1J-1051_2 305.08 300.00 218.10 4.62 213.29 Pass - Major Risk 1J-105. 1J-105PB1-1J-105PB1 305.08 300.00 218.10 4.82 213.29 Pass - Major Risk 1J -107 -1J -107-1J-107 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J-107-1J-107LI-1J-107L1 305.01 300.00 190.36 4.92 185.44 Pass - Major Risk 1J -109 -1J -109-1J-109 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J-109-1J-109PB1-1J-109PB1 192.21 200.00 159.58 2.72 156.86 Pass - Major Risk 1J -115 -1J -115-1J-115 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -115 -1J -1151_1-1J-1151_1 403.76 400.00 159.15 6.67 152.48 Pass -Major Risk 1J-115-1J-115LI PB1-1J-115L1 PBI 403.76 400.00 159.15 6.67 152.48 Pass -Major Risk 1J -115-1J-1151_1 PB2 - 1 J-11 51_1 PB2 403.76 400.00 159.15 6.67 152.48 Pass -Moor Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/102018 4:38:56PM Page 2 COMPASS 5000.14 Build 85D Summary ConocoPhillipsER ConocoPhillips Travelling Cylinder Report UGHES Reference a GEcompany Company: ConocoPhillips (Alaska) Inc. -Kup1 Local Co-ordinate Reference: Well 1J-10 Project: Kupamk River Unit TVD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-1011-03 Database: EDT 14 Alaska Production Reference Design: 1 J-10L1-03_Wp01 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kuparuk 1J Pad 1J -115 -1J -1151.2-1J-1151-2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115L2PB1-1J-115L2PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115L2PB2-1J-115L2PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB1-1J-115PB1 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB2-1J-115PB2 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-115-1J-115PB3-1J-115PB3 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J-1 15 - 1 J-11 5PB4 - 1 J-11 5PB4 403.76 400.00 159.15 6.67 152.48 Pass - Major Risk 1J -118 -1J -118-1J-118 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -118 -1J -1181-7-1J-11811 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -118 -1J -1181-2-1J-11812 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-11Spat -1J-118PB1 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J-118-1J-118PB2-1J-118PB2 304.63 300.00 189.29 4.81 184.48 Pass - Major Risk 1J -120 -1J -120-1J-120 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-1 20 - 1 J-1 201-1 - 1 J-120Ll 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L7 Pat -1J-120Ll Pat 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 PB2-1J-1201-1 PB2 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 PB3-1J-12011 PB3 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -120L1 PB4 - 1 J-1 201-1 PB4 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -120 -1J -1201-2-1J-12012 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J-120-1J-120L2PB1-1J-1201-2PB1 304.57 300.00 216.86 4.81 212.05 Pass - Major Risk 1J -152 -1J -152-1J-152 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152LI.1J-1521-1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J -152 -1J -15212-1J-1521-2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152L2PB1-1J-152L2PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152PB7-1J-152PB1 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J-152-1J-152PB2-1J-152PB2 405.78 400.00 200.32 6.58 193.74 Pass - Major Risk 1J -154 -1J -154-1J-154 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -154 -1J -1541 -1 -1J -154L1 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -154 -1J -1541-2-1J-15412 605.44 600.00 146.13 10.47 135.67 Pass - Major Risk 1J -156 -1J -156-1J-156 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156 -1J -1561-1-1J-15611 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156-1J-1561-1 Pat -1J-15611 Pal 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -156-1J-1561-2-1,-15612 2,226.75 2,100.00 117.13 48.45 79.06 Pass - Major Risk 1J -158 -1J -158-1J-158 392.81 400.00 60.36 6.31 54.05 Pass -Major Risk 1J -158 -1J -158L1 -1J-15811 392.81 400.00 60.36 6.31 54.05 Pass -Major Risk 1J -159 -1J -159-1J-159 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159 -1J -15911-1J-1591-1 405.33 400.00 38.11 6.69 31.42 Pass -Major Risk 1J -159 -1J -159L7 Pat -1J-1591-1 PB7 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159-1J-1591-1 PB2-1J-1591-1 PB2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J -159 -7J -15912 -1J -159L2 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-159-1J-159PBt-1J-159PB1 405.33 400.00 38.11 6.69 31.42 Pass - Major Risk 1J-160 -1 J-160 - 1 J-160 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J -160 -1J -160L7 -1J -160L1 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J -160 -1J -160L7 Pat -1J-160L1 PB7 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J -160 -1J -1601-2-1J-16012 291.93 300.00 21.20 4.57 16.63 Pass - Major Risk 1J -162 -1J -162-1J-162 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -162 -1J -1621 -7 -1J -162L7 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J -162 -1J -162L1 Pal -1J -162L7 Pat 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162P131-1J-162PB1 491.49 500.00 40.65 8.37 32.28 Pass - Major Risk 1J-162-1J-162PB2-1J-162PB2 491.49 500.00 40.65 8.37 32.28 Pass -Major Risk 1J -164 -1J -164-1J-164 796.36 800.00 77.47 13.02 64.51 Pass -Major Risk 1J -164 -1J -16411-1J-1641-1 796.36 800.00 77.47 13.02 64.51 Pass -Major Risk 1J-164 -1 J-1641-2 - 1J-1641-2 796.36 800.00 77.47 13.02 64.51 Pass - Moor Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 12/102018 4:38:58PM Page 3 COMPASS 5000.14 Build 85D - ConocoPhillips BAKER Conoc(3Phillips Travelling Cylinder Report offal site Endo 000 daft UGHES Reference Offset a GEcompery Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1J-10 Project: Kuparuk River Unit TVD Reference: 1J-10:114.25 @ 114,25usft(1J-10:114.25) Reference Site: Kuparuk 1J Pad MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25) Site Error: 0.00 usft North Reference: True Reference Well: 1J-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1J-IOL1-03 Database: EDT 14 Alaska Production Reference Design: 1J-10L1-03_wp01 Offset TVD Reference: Offset Datum Summary Kuparuk 1 Pad- 1E -35 -Plan 1E-35A-tE-35A(wpO2) offal site Endo 000 daft Survey Program: 199GVD-CT-CMS.6963-M= Reference Offset Centre to No -Go Allowable Reference meet Semi Major Avis Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Centre to Offset Well - Wellbore . Design (usft) (usft) (usft) Azlmdlh (usft) +EI -W Kuparuk 1J Pad Centre Daunce Deviation (deft) wsn) (usft) (urn) (ana) (usftl r) 1J-164-1J-164L2PB1-1J-164L2PB1 796.36 800.00 7747 13.02 64.51 Pass -Major Risk 1J -166 -1J -166-1J-166 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -166 -1J -166L7 -1J-1661_7 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -166 -1J -166L7 Pat -1J-16611 Pal 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -166 -1J -16612-1J-1661_2 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J-166-1J-166L2PB1-1J-166L2PB7 703.30 700.00 122.72 12.34 110.38 Pass - Major Risk 1J -168 -1J -168-1J-166 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J -168 -1J -16811-1J-16811 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J -168 -1J -1681_2-1J-16812 404.72 400.00 161.98 6.61 155.38 Pass - Major Risk 1J-168-1J-168L2PB1-1J-168L2PB1 404.72 400.00 161.98 6.61 155.38 Pass -Major Risk 1J-170- 1J-170- 1J-170 5,690.17 8,300.00 247.69 159.88 140.49 Pass- Major Risk 1J-170. 1J-17OL1-1J-17011 5,566.22 8,300.00 182.48 156.25 55.71 Pass - Major Risk 1J -170 -1J -17012-1J-17012 5,394.81 8,200.00 166.39 152.00 53.52 Pass - Major Risk 1J-170-1J-170PB7-1J-170PB1 5,676.40 8,300.00 273.16 159.57 164.32 Pass - Major Risk 1J-170-1J-170PB2-1J-170PB2 5,690.17 8,300.00 247.69 160.14 140.23 Pass - Major Risk Plan 1J-104(empty)-Prelim: 1J -104 -Prelim: IJ- 406.82 400.00 232.09 5.53 226.57 Pass - Major Risk Plan 1J-104(empty)-Prelim: 1J-104 L7 -Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-104(empty)-Prelim: 1J-104 L2 -Prelim: 406.82 400.00 232.07 5.53 226.54 Pass - Major Risk Plan 1J-109a-1J-109PB1x-1J-109PB1x 114.25 33.25 177.64 1.02 176.62 Pass - Major Risk W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15 487.50 500.00 209.67 9.95 199.72 Pass - Major Risk W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2 396.03 400.00 184.70 5.72 178.98 Pass - Major Risk W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20 810.09 800.00 83.61 17.14 66.47 Pass - Major Risk W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3 503.17 500.00 184.73 11.21 173.52 Pass - Major Risk W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4 491.49 500.00 196.71 7.54 189.18 Pass - Major Risk W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5 486.33 500.00 231.04 10.16 220.89 Pass - Major Risk Offset Design Kuparuk 1 Pad- 1E -35 -Plan 1E-35A-tE-35A(wpO2) offal site Endo 000 daft Survey Program: 199GVD-CT-CMS.6963-M= Rule Assigned: Malar Risk Was, Well Errar: 000 waft Reference meet Semi Major Avis Measured vertical Measured Vertical Reference Offset Tongues♦ OHut Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth DeWh Depth Azlmdlh ♦N1.8 +EI -W Hole Size Centre Daunce Deviation (deft) wsn) (usft) (urn) (ana) (usftl r) rdrn) leen) gn) ruslo (suaft) ruam 14,050.00 6204.19 12,700.00 5.530.87 4735 9562 26.57 418959 -4.119.88 7.750 1,578.47 290.32 1,310.12 Pass - Major Risk 14074.47 4203.12 12,800.00 5,557.65 47.51 97.09 28.71 4104.46 4.074.77 7.750 1.490.99 300.56 1,217.02 Paas -Major Risk 14,100.00 6,201.95 12.900.00 5.584+43 47.68 98.57 30.95 4,019.32 4,029.66 7.750 1.404.59 311.20 1.124.72 Pass- Major Risk, CC, ES, SF CC - Min centre to center distance or covergent point, SP - min separation factor, ES - min ellipse separation 12/10,2018 4:38:58PM Page 4 COMPASS 5000.14 Build 65D lul/8sn 00£) l+)97iom/l-)43nos OQ JM �¢FinMQmmM1 M 0 0 v SOM1 C1Y � m d N OfM1QmmOmO y�-b OfQNI�e >vminmwvrn ■SEEM `m?"?mS"MS'Y�YY 170 ■ommm.IS ._�. �p &00000000 wi JLjLLOOOONOONVf M■■■■■■■■11ml 3300 N NEI r, Opoi�M1M1M1I�M1M1 -3400 3m QM1emmomo OaNNM1Q r.r O -'? h rVN N 0 pIN m m Q O) m Flow NMI On vi �■�01- ■ml tOM1 ■- WO � FAI MA®mill H -3600 ,r ?i 00 p.-ao r+imamrd n: ■■■%i/M■®■I c_o QMQM1omo+m ��m.ocmmm�m t o MEMO ow Z N o�Q,amemrnern m m N m N N m m N Naohamery ..r MORE a�mNm.-NmM1.- cQ.nNeM1M1Nr tl<NIQ OrO�N -3800 _,I/II/I�■r■I r. ■■EN// 0 0 0 0 0 0 0 0 . %■t■■■I , r MEMO ■I �FFAMI Zo I:r ■■mm®! ����ENNISno �rAMEN ��I �� r ■■N■■1 -4000 0 Of r n ....... ..... . ...... ....::::::. 111110 RmLon 0 �■■o■■moll. ■■r��,r�i✓ 4200 ONE //i �moommo®MESPAMEN � -4300 ...r -4400 4500 N®AF410- ■■■m■■■moi -4600 r. 111�-09RAI■■■ -0700 ONE ■■■■I omoommommomm -4800 IN r mmmmmommm -4900 1:r. .... _................. 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N -5000 -5100 -5200 -5300 4 4 -5400 -5500 5600 .5700 -5800 3 900 d -6000 fi100 6200 -6300 -64W -65W -66W -67W J -6800 a -6900 ]000 _ -7100 J .7200 N -73W in 9 9 C_ I ( i r � aA' ��m o� = a;.d± 4 !� J O O T O ` q R.UE z i a� 2 2 von - S a- Ym,,pp O� a. 6W o � _ o mnv a CL a (ui gsn oSb) (+)41aoN/(-)43nos s p KUP PROD 1J-10 CanaoPhillip$ Wall Attributes Max Angle 8 MD 7D Alaska, lnC Wellbore,lplNWl FIe1G Nnme Wellborn SoAua 500292301000 KUPARUO RIVER UNIT PROD -I,,, MD(.N.f Ac19on I,KB) 6].58 3.10186 10.845.0 Comment H25(ppm)paR Ease NIPPLE 40 9/1012016 Annotation EnE DMe N6�Grd (firMEReluu Dale Last WU: 218/2008 35.]6 512412001 11tp.3G1/10n 1046'.16414 ne acMmem actin ennnw- Deplb (mn, EM Dab Mnd,n Lael MW ey End Dab _.. _ Last Tag'. RKB 10,3400 3/2]201] Rev Reason: TAG, GLV CI0. WS ppoven 3/31/201] HANGER: 29.6 as ng rang. azlnq peaeapnon OD In) mpn) Top lnHe) .cep. force) sn cepIM1 ITVO)... WULen p... Gnne, TOP TnreaY CONDUCTOR 20 19.124 35.0 1200 120.0 91.50 H40 WELDED Lazin93esninion oD lin) IDhn) Topffi Set Ease, (WE) Bet DaPIM1 ITVp1-WVten h._,ride Top Tlllmf V. _... - ...- SURFACE 9518 8.835 34.5 6,945.3 3,995.4 NO BTC Casing Description OD (ln) ID lln) Top nKD) fief Oapin lRKa) Bet Dep. lNp)... WULen p... ,rade Top 71110.6 PRODUCTION ] 62]6 31 ] 10.2306 5946.4 26.00 L80 BTGMOD Casing Description On (in) ID (in) Top,.nN) EC IOP.I1KBl Set Depin 1TVO).. WULen II... Gmtle Top ihraN LINER 4112 3958 996]2 10,843.0 6,326] 1260 L80 NSCT Liner Details Nomi el lD I'd.. 15b TOIr.A 6,]oo Tnp (.N.) In ITVOt(rX.J Top In=I r) Item pes Co. LIN 9,967.2 5,]8]0 53.]4 TIEBACK BAKER PACKER& TIE -BACK SLEEVE 4.438 9,985.2 5,707.6 53.67 PACKER BAKER ZXP LINER TOP PACKER 4430 NIPPLE, Ws 0- 9,989.2 5,8000 5365 HANGER BAKER LINER HANGER 4.500 10,327,7 8,001] 53.86 NIPPLE CAMCO'D'NIPPLE- DRILLED CUT TO 3.87" 3.830 DURING ATTEMPT TO PULL FISH 0812008 WORKOVER -BORE 10,520.] 6.1185 5181 NIPPLE OTIS'XH NIPPLE w/ No Go, 3.812"PKG, 3725 GAS LIFT: aM3.6 3 725" profile Tubing Strings Tubing oeuapeon Sang Ma... mon Top NtKe) sm Depm (n.. sn oep.11w)(... wtpbttq Grade Top connection TUBING 41/2 3.958 296 8991 i 5,801.5 1260 LSD IBT Completion Details GAs LIFT: 6.311.] Nw(in) ID Top I1Ka) Top (IVD)(29.6 TopIM01 in.DosCo. (in) 208 29.6 OOt HANGER FMC GEN VTUBING HANGER 6.500 W80 508.0 197 NIPPLE CAMC0 DBA NIPPLE el 3.875 T0P N0 G0 PROFILE 3.875 8,9334 5]6]0 53.86 NIPPLE CAM00 Be NIPPLE wl 3.012 PROFILE - DRILLED OUT 3.830 TO 3.87 DURING ATTEMPT TO PULL FISH M2008 WORKOVER sUNFACE34.661.6 - 9,9]8] 5,701.8 53.70 LOCATOR BAKER GBH -22 LOCATOR 3.956 9.8]9.9 5,]94.5 5369 SEAL ASSY BAKER SEALAMSS -EM BLV wI ULESHOE 3958 . UFT. uxx z Other In Hole ryyireline retde4atiie plugs, valves, pumps, firth, III Trap Irv) IDp.d Top INK.) INK.) I°1 Des Com Nun D. IEHiH 10,400.0 6,0468 5294 FISH PERF GUN PERF GUN DROPPED 7124/01, T0P 3/17/2008 10,532, LENGTH 34.4'. MAX OD 36T'; WORKED T0RETRIEVETHRU829O1. I ELLSHUTIN& GAs LIF: e132a FREEZE PROTECTED. 36" SAT SUB LEFTON TOP OF E -LINE TOOL 102512004: Fish Pulled up to10,312 CTMD 61]2005: Tagged Fish @ 10339 WE 1119!2008 Tagged Fish G 10301' SUM 2/8/2005 WORKOVER TO PULL FISH -ONLY PUSHED IT DOWMHOLE FROM 10312' TO 10400' GA6 LIFT', 9 B6? 2 Perforations & Slots snot Dene xIwLE: 9.Yii< TOP(We) BIm stim, Top (WEN 0X08) em(rvD) M.M Zone Dale (show 11 TVps Cam 10,446.0 10,466.0 6,072.7 6,0849 C-3.1110 711912001 6.0 APERF3310"PSDPJ dgs,60 tleg ph l 10,558.0 106]80 6,205.0 I 5T,N A-5,13-10 6/12/2001 6.p /PERF 25"HSDBH&DP Stimulations & Treatments Prop'nin noon. lln) ProP"U11 FOrmanon (m) Olt,LCLPTG R: e9]B.i 6/1612001 Stimulations & Treatments 3EAL PS6V:99ip.p Vol cl(sa Pump ME! Top I-Kp) 6M(1KB) OMe BtimRron Find (bbl) V.Blurryl,.,, 1 10°658.0 10,678.0 6"612001 Mandrel Inserts M aN on rop(rvD1 valve IAlcn Pnnsbe Tao ann N Top I1Ke) ante) Mase Model GD finsSw Type Type (In) und, Run pale Co. t 3,]23.8 2,558.4 CAMCO KBG-2 1 GAS LIFT GLV BK 0.188 1149.0 31291201] 4:30 2 6,3117 33230 CAMCO KBG-2 1 GAS LIFT OV BK 0.207 00 3/29221] 7:30 PRopumgx;JtTn023]9- 3 0,068.2 4,62]0 AMC.CKBG-2 1 GAS LIFT OMY BK DODO 00 3/291201] 500 4 9,1326 5,2(430 CAMCO KBG-2 1 GASLTI DMY OK 0000 0.0 51232001 415 5 9.82.2 5,]368 CAMCO KBG-2 I 1 GASLIFT JU., IS, I ErE01 00 1 2/9/2014 ]:00 Notes: General & Safety End Dote Amousion 2812008 NOTE: WORKOVER DONE TO PULL FISH, MILLED NIPPLES; UNSUCCESSFUL, PUSHED FISH DOMHOLE FlSH m.lapo 9/29/2010 NOTE: Vrew Serenade al Abse Scllemelic9.0 APENR 10.148 LL1p.IB6G- IPERR10.614.1NlOGRO FRAC;10850p LINEP;996]2106430- n v m v v v mmmmm i � III III p N m p] LO O ❑ iy!� MN w0 JCI O � t0 a) G� 100 N m Q � Y v� i�@I my p N y U O ao p N � Of b0 From: McLaughlin, Ryan To: Boyer, David L (DOA) Cc: Loeoo. Victoria T (DOA) Subject: RE: [EXTERNAL]Digital Survey Files for Four 13-10 Laterals Date: Thursday, January 31, 2019 4:48:46 PM Hello Dave, Here is the corrected government section data: KRU 1J-101-1: Top of Productive Interval: 4931' FNL, 4064' FEL, Sec 27, T11N, R10E, UM Total Depth: 4871' FNL, 4211' FEL, Sec 27, T11N, R10E, UM KRU 1J-101-1-01: Top of Productive Interval: 4896' FNL, 4149' FEL, Sec 27, T11N, R10E, UM Total Depth: 1946' FNL, 600' FEL, Sec 34, T11N, R10E, UM KRU 1J-101-1-02: Top of Productive Interval: 523' FNL, 3098' FEL, Sec 34, T11N, R10E, UM Total Depth: 2911' FNL, 2931' FEL, Sec 34, T11N, R10E, UM KRU 1J -10L1-03: Top of Productive Interval: 412' FNL, 3198' FEL, Sec 34, T11N, R10E, UM Total Depth: 526' FNL, 1348' FEL, Sec 34, T11N, R10E, UM Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Thursday, January 31, 2019 4:08 PM To: McLaughlin, Ryan <Ryan.McLaughlin @conocophillIps.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL] Digital Survey Files for Four 1J-10 Laterals Ryan, In looking through the PTD's, I noticed that all four have the same Top of Productive Horizon and Total Depth in the legal description in Part 4A on Form 10-401. Please send over the corrected government section data, and I will make the adjustments on the forms. I assume that the legal description is correct for the first lateral: KRU 1J -10L1 but not for the -01, -02, and -03 laterals? Thank you, Dave Boyer AOGCC From: McLaughlin, Ryan <Ryan McLaughlin(@conocophillisn com> Sent: Thursday, January 31, 2019 11:53 AM To: Boyer, David L (DOA) <dav)d boyer2@alaska gov> Subject: RE: [EXTERNAL] Digital Survey Files for Four 1J-10 Laterals Hello Dave, I've attached .txt files for the 1J-10 laterals. Your assumption about our drill order is correct, we are currently planning on drilling 1J-10 before 3M-26. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Boyer, David L (DOA) <david boyer2galaska Eov> Sent: Thursday, January 31, 2019 10:13 AM To: McLaughlin, Ryan <Rvar McLaughlingconocophillips.com> Subject: [EXTERNAL] Digital Survey Files for Four 11-10 Laterals Hi Ryan, I just began reviewing the 4 PTD's for the KRU 1J-10 laterals today. Can you please e-mail over digital surveys for the four laterals in Excel or ASCII format so we can load them into Geographics Wellbase program? Also, it would save splicing time if the survey files also include those from the original mother -bore above the —10,310' KOP's. We also received two PTD's applications from Keith Herring for 2 KRU 3-26 laterals also to be drilled with CDR3-AC rig with the same 02/13/19 spud date.. We are assuming your 1J-10 laterals will be drilled first since the PTD files arrived several days earlier? Thank you, Dave Boyer Senior Geologist AOGCC Transform Points ( %t Source coordinate system State Plane 1927-AJaska Zone 4 Datum: NAD 1927 - North America Datum of 1927 (Mean) * KRLk Target coordinate system Albers Equal Area (-150) Datum: NAD 1927- 1�-(0 North America Datum of 1927 (Mean) ype values into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to opy and Ctd+V to paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. - _ <Back j� Finish Cancel Help - - - t ------ —-- TRANSMITTAL LETTER CHECKLIST WELL NAME: K R UL i J —IOL j PTD: 'et l q —1'o I it . Development Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: K LAp a r U k R %r Ve.V' POOL: Ku a er y u k R i ua.v- 10 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit / LATERAL No. '&01-6:7-1 , API No. 50- OZq--A3 010 00 v (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 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 Pilot Hole name ( PIT) and API number (50- - from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of J well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements JPer Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 Well Name: KUPARUK R(V UNIT 1J -10L1 P9ro ram DEV r. PTD#: 2190120 Company CONOCOPHILJr(PS ALASKA INC. Initial ClassRype DEV/PEND GeoArea S� Unit 11160 On/Off _ Well bore seg Shore on Annular Disposal e Appr Date '3 DLB 1/31/2019 13 _ NoWell 14 -ovate- in adefined pool- - - - .. - - - - 15 16 Yes 17 Well located Draper distance from. other wells - - - - - - - - - - 18 Engineering 19 27 Appr Date 28 VTL 2/5/2019 29 30 131 132 33 Geology Appr Date DLB 1/31/2019 - ease numberappropriate- -- - - - - - - - - - - - - - - - Yes- -Unique well name and number _ _ - - _ _ - - _ _ NoWell -ovate- in adefined pool- - - - .. - - - - YesWell located proper distance from drilling unit -boundary... - - - - - - - - - Yes Well located Draper distance from. other wells - - - - - - - - - - - Yes Sufficient acreage available in. drilling unit- - - -- - - - - - - - --- - - -- Yes If deviated, iswellboreplat included - - - - -- - - - - - - - - _Yes - - . Directional plan and pons section views are included, no land plat. Operator only affected party. ---- --.... -. Y es - Operator has appropriate bond in force Yes Permit can be issued without conservation order - - - - - _ - - - - _ - Yes _ Permit can be issued without administrative. approval - - - - - - - _ - Yes Can permit be approved before 15 -day wait - - - - Yes Well located within area and strata authorized by Injection Order # (put incomments) -(For . NA - All wells -within 1/4 mile area of review identified (For service well only).. - _ - - _ NA Pre -produced injector: duration of Pre Production less. than 3 months -(For service welt only) - - NA Nonconven, gas conforms Jo AS31,05.030Q.1.A),(j.2.A-D) _ _ - - _ .. _ NA Conductor stringprovided Conductor set. for .KRU-1J-1-0- Surface casingprotects all known -USDWs - .. - - - - .. NA .. - - - - Surface casing set in KRU 1J-10 CMT -vol adequate. to circulate on conductor & surf csg . - - - - - - _ - .... - NA - - - .... Surface casing set and fully cemented CMT. vol adequate to tie-in long string to surf csg - - - _ NA - - CMT. will coyer all known productive horizons.. - - - - - ... - - - - - - No .. - - Productive. interval will -be completed with. Uncemented slotted line_ r_ Casing designs adequate for C, T, B R -permafrost - - - - Yes Adequate tankage. or reserve pit - - - - - - - - Yes - - _ .. Rig has steel tanks; all waste to approved disposal wells If a. re -drill, has. a. 10-403 for abandonment been approved Adequate wellbore separation proposed. - - - .. Yes - - - - Anti -collision analysis complete; no major risk failures If diverter required, does it meet regulations - - - - .. - - - .... NA. - - - - - Drilling fluidprogramschematic & equip list adequate - - Yes Max formation pressure is 2914 psig(9.2 PP9 EMW); will drill w/8.6 ppg-FMW and maintain overbal w/ MPD B.OPEs, do They meet regulation- BOPE.press rating appropriate: test to -(put prig in comments). - - - - - - - Yes - MPSP is 2316 psig; will test BOPS to 3500 -prig Choke manifold complies w/API. RP -53 (May $4) - - - - - - - . - Yes Work will occur without operation shutdown- - - _ - . - - - - _ - _ _ - - _ ... - - Yes Is presence of H2S gas probable - - _ - - _ Yes - H2$ measures required- Mechanical condition of wells within AOR verified (Forservice well only) - - - NA- _ Pe[mit can be issued w/o hydrogensulfidemeasures No - - Wells. oil .1J -Pad are H2S-bearing. H2S. measures required.. U-,- presented on potential overpressure zones.. - - .... - - - . - Yes .... - - Seismic analysis of shallow gas -zones - - - . - - - NA. - - ...... Seabed condition survey (if off -shore) - - - NA - Contact name/phone for weeklyprogressreports [exploratory Only] - .. - - NA- - - Geologic EngineeringPublic Commissioner: Date: C mmissioner. Date Date Z „�/�/ Commissioner
