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218-002
DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2180020 Well Name/No. KUPARUK RIV UNIT 1C-241-1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23063-60-00 MD 11401 TVD 6435 Completion Date 7/11/2018 REQUIRED INFORMATION Mud Log No DATA INFORMATION List of Logs Obtained: Gr/Res Well Log Information: Log/ Electr Data Digital Dataset Log Log Type Med/Frmt Number Name Scale Media _ Completion Status Samples No Run Interval No Start Sto P 1-0I1- Current Status 1-OIL UIC No Directional Survey Yes (from Master Well Data/Logs) OH / Received CH Comments ED C 29541 Digital Data 7/24/2018 Electronic File: 1C-241-1 EOW - NAD27.pdf, = ED C 29541 Digital Data 7/24/2018 Electronic File: 1C-241-1 EOW - NAD27.txt Log C 29541 Log Header Scans 0 0 2180020 KUPARUK RIV UNIT 1C-241-1 LOG HEADERS ED C 29543 Digital Data 6942 11401 7/26/2018 Electronic Data Set, Filename: 1C-241-1 GAMMA RES.Ias ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-24L1 2MD Final.cgm ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 5MD Final.cgm ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 5TVDSS Final.cgm ED C 29543 Digital Data IP7/26/2018 Electronic File: 1C-241-1 2MD Final.pdf^ ED C 29543 Digital Data 07/26/2018 Electronic File: 1C-241-1 51VID Final.pdf= ED C 29543 Digital Data %97/26/2018 Electronic File: 1C-241-1 5TVDSS Final.pdf- ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 EOW - NAD27.pdf ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-24L1 EOW - NAD27.txt ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 Final Surveys TD 11401.csv ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 Final Surveys TD 11401.xlsx ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 Survey Listing.txt ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-24L1 Surveys.txt ED C 29543 Digital Data 7/26/2018 Electronic File: 1C- 241-1 _25_tapesca n_BH I_CTK.txt AOGCC Page 1 of 1, Friday, October 26, 2018 r i� DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2180020 Well Name/No. KUPARUK RIV UNIT 1C-24L1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23063-60-00 MD 11401 TVD 6435 Completion Date 7/11/2018 Completion Status 1-OIL Current Status 1-OIL UIC No ED C 29543 Digital Data 7/26/2018 Electronic File: 1C- 24L1_5_tapescan_BHI_CTK.txt ` ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-24L1_output.tap ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 2MD Final.tif ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 5MD Final.tif ' ED C 29543 Digital Data 7/26/2018 Electronic File: 1C-241-1 5TVDSS Final.tif Log C 29543 Log Header Scans 0 0 2180020 KUPARUK RIV UNIT 1C-241-1 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Production Test InformatiooNA Geologic Markers/Tops Y� COMPLIANCE HISTORY Completion Date: 7/11/2018 Release Date: 1/26/2018 Description Comments: Directional / Inclination Data Mud Logs, Image Files, Digital Data Y / fA Core Chips Y / �6 Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y / Daily Operations Summary Cuttings Samples Y / VAS Laboratory Analyses Y / Date Comments Compliance Reviewed AOGCC ` Page 2 of2. .1 / C-1 Date: - Friday, October 26, 2018 0 0 • STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 2-2018 WELL COMPLETION OR RECOMPLETION REPORT ANPbOn 1a. Well Status: Oil (] . Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: 1b. Well Class: Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Aband.: 7/11/2018 14. Permit to Drill Number / Sundry: 218-002 • 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/5/2018 15. API Number: 50-029-23063-60-00 4a. Location of Well (Governmental Section): Surface: 1667' FNL, 3990' FEL, Sec 12, T11N, R10E, UM Top of Productive Interval: 3829' FNL, 796' FEL, Sec 11, T11N, R10E, UM Total Depth: 2811' FNL, 2995' FEL, Sec 12, T11N, RI OE, UM 8. Date TD Reached: 7/8/2018 16. Well Name and Number: KRU 1C-24L1 9. Ref Elevations: KB:101.( GL: 55 BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool• 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25649. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 562298 y- 5968571 • Zone- 4 TPI: x- 660232 y- 5966393 Zone- 4 Total Depth: x- 563303 y- 5967436 Zone- 4 11. Total Depth MD/TVD: .11401/6435 • 19. DNR Approval Number: LONS 79-016 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/1 VD: 1872/1827 5. Directional or Inclination Survey: Yes I] (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: 7616/6436 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 GR/Res 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 16 62.58 H-40 42 161 42 161 24 9 cu yds High Early 9 5/8 40 L-80 41 4711 41 4413 12.25 1200 sx AS Lite, 850 sx LiteCrete 7 26 L-80 39 6835 39 6252 8.5 185 sx Class G 2 7/8 6.5 L-80 7601 111401 16435 16435 14.25 ISlotted Liner 24. Open to production or injection? Yes [2] No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SLOTTED LINER @: 7602-11401 MD and 6435-6435 TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4 1/2 6655 6658/6145 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 2 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: 7/19/2018 Method of Operation (Flowing, gas lift, etc.): GAS LIFT Date of Test: 7/22/2018 Hours Tested: 0 4 Production for Test Period Oil-Bbl: 735 Gas-MCF: 485 Water-Bbl: 3012 Choke Size: 176 Gas -Oil Ratio: 660 Flow Tubin Press. 3�0 Casinq Press: 136 Calculated 24-Hour Rate Oil-Bbl: 126 Gas-MCF: 2 • Water-Bbl: 164 Oil Gravity - API (corr): 227 1AN Form 10-407 Revised 5/2017 RBDM�AUG 0 2 Lu1D NTINUED ON PAGE 2 G Il IY� VT1- 1114-11 � �11(/ Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No 21 • Sidewall Cores: Yes ❑ No 21 If Yes, list formations and intervals cored (MD/TVD, From/To), 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 1872 1827 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7616 6436 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C4 TD 11401 6435 Formation at total depth: Ku aruk C4 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolooical report, production or well test results. AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: Keith Herrin Authorized Title: Staff CTD Engineer Contact Email: Keith. E.Herrin co .com Authorized /� Contact Phone: 263-4321 Signature: Date: 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 10407 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 Litt, 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 01 • Martin, Teddy J (DOA) From: Herring, Keith E <Keith.E.Herring @conocophillips.com> Sent: Thursday, August 2, 2018 11:40 AM To: Martin, Teddy J (DOA) Subject: RE: [EXTERNAL]PTD 218002 Incomplete 407 Well Completion Form Mr. Martin, The production test was for 14 hrs. Thanks, Keith Herring CTD Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 664 Keith.E. Herring@conocophillips.com Conocor'n- illips aska From: Martin, Teddy J (DOA) <teddy. ma rtin @a laska.gov> Sent: Thursday, August 02, 201810:06 AM To: Herring, Keith E <Keith.E.Herring@conocophillips.com> Subject: [EXTERNAL)PTD 218002 Incomplete 407 Well Completion Form Good morning Keith, Box 27 of the production test data submitted on the 407 form for well API 50-029-23063-60-00/KRU 1C-241-1 appears to be incomplete. Could you please report the # of hours the production test was performed? Thanks, Teddy Martin Statistical Technician II Alaska Oil & Gas Conservation Commission 333 W. 71h Ave, Suite 100 Anchorage, AK 99501 (907) 793-1241 teddy.martin@alaska.gov 9 • 16" 62# APISLgrB shoe @ 161' MD 9-5/8" 40# L-80 shoe @ 4711' MD 7" 26# L-80 shoe @ 6835' MD TOW @ 7,615' MD C-sand perfs 7485' - 8090' MD CIBP set at 7674' MD C-sand per s 8500' - 9215' MD 4-1/2" 12.6# L-80 shoe @ 9345' MD 4-1/2" 12.6# L-80 Tubing to surface 4-1/2" Camco DB landing nipple @ 518' RKB (3.812" min ID) 4-1/2" Camco GLM @ 2713', 4147', 5189', 5950', 6558' RKB 4-1/2" Camco DB landing nipple @ 6603' RKB (3.80" min iu) Liner too Baker GBH-22 Seal Assembly @ 6643' RKB Liner Tie Back Extension @ 6644' RKB Baker 4.5" x 7" ZXP liner top packer @ 6658' RKB Baker 4.5" x 7" HMC liner hanger @ 6666' RKB CIBP @ 7674' RKB Baker Inflatable Bridge Plug @ 8139' RKB 1C-24L1 TD @ 11, 401' MD BOL @ 11,400' MD TOL @ 7,601' MD KUP PROD 1C-24 COIlOC4f1t��IK35jQ Well Attribu MaxAngle TD Field Name Wellbore APVUWI Wellbore Status ncl (°) MD (ft Act Stm (ftKB) AI3Skd, (riC.:.KUPARUK RIVER U IT 500292306300 PROD 5 23 8 6()4.R 9 350 0 't I HIS (ppm) I Date Annotation I End Date I KB-Grd (ft) Rig Release Date NIPPLE 30 9/10/2016 Last WO: 46.42 1/28/2009 1C-24,&1r20182:56:32 PM Last Tag Vertical schematic (actual) Annotation LAST TAG: End DaM Depth (ftKB) Last jennalt Mad By __._ ._...._. _. _. Last Rev Reason HANGER; 36.4 Annotation End Date Last Mod By Rev Reason: Post CTD 8 New Lateral 7/16/2018 jennalt Casing Strings AR .............. . ... Casing Description CONDUCTOR OD (in) 16 ID (in) Top 15.06 42.0 (ftKB) Set 161.0 Depth (ftKB) Set 161.0 Depth (TVD)... WtlLen (I... 62.58 Grade Top AP151-Gr PER Thread CONDUCTOR; 42.0.1fi1 0 B Casing Description SURFACE OD (in) 95/8 ID (in) Top 8.83 41.1 (ftKB) Set 4,710.9 Depth (ftKB) Set 4,413.3 Depth (TVD)... WtlLen (I 40.00 Grade Top L-80 BTC Thread NIPPLE; 517.6 Casing Description PRODUCTION OD (in) 7 ID (in) Top 6.28 39.5 (ftKB) Set 6,835.4 Depth (ftKB) Set 6,252.5 Depth (TVD)... WtlLen (I... Grade 26.00 L-80 Top BTC-MOD Thread Annular Fiuid -Gas; 0.0.5,188.0 Casing Description LINER OD (in) 41/2 ID (in) Top 3.96 6,644.0 (ftKB) Set 9,345.0 Depth (ftKB) Set 6,547.4 Depth (TVD)... WtlLen (I... Grade 12.60 L-80 Top NSCT Thread GAS LIFT; 2,712.9 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,644.0 6,136.0 46.93 TIEBACK LINER TIE BACK EXTENSION 3,958 GAS LIFT; 4,146.5 6,658.1 6,145.6 47.63 PACKER BAKER 4.5" X 7" ZXP LINER TOP PACKER 4.300 W/HOLDDOWNS, HR PROFILE 6,666.1 6,151.0 48.03 HANGER 4.5" BAKER HMC LINER HANGER 4,420 Tubing Strings SURFACE, 41.1-0,710.9- Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ibm) Grade Top Connection TUBING 4 tl2 3.96 36.4 6,654.9 6,143.5 12.60 L-80 IBT MOD Completion Details GAS LIFT; 5,18B.7 Top Top (ftKB) (TVD) (ftKB) Top Incl (•) Item Des Com Nominal ID (in) 36.4 36.4 0.11 HANGER FMC GEN V HANGER 4.500 517.6 517.6 1.85 NIPPLE CAMCO DB NIPPLE w/ 3.812 NO GO PROFILE 3.812 GAS LIFT; 5,950.1 61602.6 6,107.2 44.97 NIPPLE CAMCO DB NIPPLE w/ 3.75 NO GO PROFILE 3.800 Annular FI,d- Inhibited Millled to 3.80" ID on 1/1512017 Seaxater, 5,1 a8.0.6,a35.0 6,641.8 6,134.51 46.82 LOCATOR BAKER NO GO LOCATOR 3.840 GAS LIFT; 6,557.6 6,642.9 5,135.31 46.88 1 SEAL ASSY IBAKER GBH-22 SEAL ASSEMBLY 3.840 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) NIPPLE; 6,602.E Top (ftKB) Top (TVD) (ftKB) Top Incl (•) Des Com Run Date ID (in) 7,599.0 6,434.8 85.37 PINCH POINT COIL TUBING(CTU-11) TAGGED PINCH POINT IN 121301201 3.500 LINER 7 LOCATOR; 6,641.E 7,615.0 6,436.0 85.66 WHIPSTOCK BOT 4.5"Monobore XL 7/3/2018 0.000 SEAL ASSY; 6,642.9 7,674.0 6,440.0 86.58 PLUG CIBP - INFLATABLE BRIDGE PLUG 12/30/ 1 0.000 7 7,699.0 6,441.4 86.81 FISH CIBP - INFLATABLE BRIDGE PLUG 12/30/201 3.500 7 8,139.2 j 6,478.1 85.2E 1 PLUG BAKER INFLATABLE BRIDGE PLUG (OAL=11.58') 3/7/2007 0.000 Perforations & Slots PRODUCTION; 39.5-6,1135.4- Shot Dens Top (ftKB) St. Top (ftKB) (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date (shotsttt ) Type Co. IPERF, 7,485.0.7520.0 7,485.0 7,520.0 6,423.6 6,427.4 C4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 7,550.0 7,670.0 6,430.4 6,439.7 C4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph PINCH POINT; 7,599.0 7,700.0 7,885.0 6,441.5 6,455A C-3, 1C-24 1/24/2002 4.0 IPERF 25". 0.32" Shot, 120 deg ph IPERF; 7,550.0-7,670.0 7,945.0 8,015.0 6,461.0 6,467.6 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph L1 LATERAL; 7,601.0-11,401.0 WHIPSTOCK; 7,615.0 7065.0 8,090.0 6,471.9 6,474.0 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph PLUG; 7.674.0 8,500.0 8,600.0 6,497.8 6,492.4 C4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph FISH; 7,699.0 8,650.0 8,750.0 6,488.3 6,483.1 C4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph IPERF; 7,700.0.7,885.0 8,800.0 8,900.0 6,480.7 6,478.5 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph IPERF; 7,945.0-8,015.0 8,950.0 9,150.0 6,480.0 6,506.3 Com, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph IPERF; 8,065.08,090.0 9,180.0 9,215.0 6,512.6 6,520.1 C-2, 1C-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph PLUG; 8,138.2 Mandrel Inserts St IPERF; 8, 500.0A,600.0 ati IPERF; 8,650.043,750.0 N Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Sam Valve Type Latch Type PortSize (in) TRORun (psi) Run Date Com 1 2,712.9 2,590.8 Camco KBG-2 1 GAS LIFT GLV BK-5 0.156 1,240.0 6/11/2002 IPERF; 8,800.0-8.900.0 2 4,146.5 3,904.3 Camco KBG-2 1 GAS LIFT GLV BK-5 0.188 1,275.0 6/10/2002 W/ STRI PPE IPERF; 8,950.0.9,150.0 DFISH NEC K IPERF; 9.180.0.9,215.0 3 5,188.71 4,846.5 jCamco KBG-2 1 1 1GAS LIFT 10V jBK 1 0.2501 0.0 7/16/2018 20181 41 5,950.1 I 5,551.5 I Camco KBG-2 1 1 IGAbLIFT JDMY BK-5 1 0.000 1 0.0 1112112002 51 5,557.7 6,074.9 Camco I KBG-2 1 1 IGAZ5 LIFT JUMY BK-5 1 0.0001 0.0 1211112002 Notes: General & Safety End Date iAnnotation LINER; 6,644.0.9,345.0 8/19/2005 NOTE: DEFORMED LINER @ 7696'-7715', MIN ID 3.4"; CALIPER SURVEY AVAILABLE 8/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 `"��� KUP PROD 1C-24L1 !`.........�1fL:"�� Well Attribut Max Angle TD �JLVii // EE1I Field Name WellboreAPVUWI Wellbore 5 atus cl l°) MD ( Act St. (ftKB) Alaska, Inc. KUPARUK RIVER UNIT 500292306360 PROD , 32 10,300.07 11.401.0 Annotation Entl Date KB-Grd (ft) 0/2016 I AST WC) dR 49 1C-24L1, SI20182:57:02 PM Last Tag Vertical echxruuc (actual) Annotation LAST TAG: End Date Depth (ftKB) Last Mod By jennalt Last Rev Reason HANGER; 36.4 Annotation Entl Date Last Mod! By Rev Reason: Post CTD 8 New Lateral 7/16/2018 jennalt Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Grade Top Thread L1 LATERAL 27/8 238 7,601.0 11,401.0 6.50 L-80 STL Notes: General & Safety End Date Annotation CONDUCTOR; 42.6161.0 NDTE'. NIPPLE; 517.8 Annual Fluid-G.; O.OS,188.0 GAS LIFT; 2,712.9 GAS LIFT, 4, 146.5 SURFACE; 41. 1-4710a- GAS LIFT', 5,188.7 GAS LIFT; 5,950.1 Annular Fluid - Inhibited Seawater, 5,188.0-6,835.0 GAS LIFT; 6,557.E NIPPLE; 6,602.6 LOCATOR; 6,641.E SEAL ASSV; 6,642.9 PRODUCTION; 39. 5-6, 835.4� IPERF; 7,485.0-7,520.0 IPERF; 7,550.0-7,670.0 PINCH POINT; 7,W9.0 LINER; 6,6440-9,345.0 L1 LATERAL; 7,601.0-11,401.0� Merations Summary (with Timelog Depths) ik f ..� 1 C-24 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 (ftKB) End Depth (ftKB) 6/30/2018 6/30/2018 2.00 MIRU MOVE CTOP P Complete changing out stripper brass, 0.0 0.0 00:00 02:00 LID 3' stripper section & PU 4' section, 6/30/2018 6/30/2018 4.00 MIRU MOVE CTOP P swap out gripper blocks, swap out 0.0 0.0 02:00 06:00 horsehead rollers, CTES counter rollers, and gooseneck rollers 6/30/2018 6/30/2018 4.00 MIRU MOVE CTOP P Crew change, Install stuffing box to 0.0 0.0 06:00 10:00 injector, Stab pipe into injector 6/30/2018 6/30/2018 5.50 MIRU MOVE CTOP P Continue / complete swapping BOPE 0.0 0.0 10:00 15:30 equipmet to big pipe / large tool configuration 6/30/2018 6/30/2018 2.50 MIRU MOVE RURD P Work Rig down checklist, blow down 0.0 0.0 15:30 18:00 stean, R/D PUTZ, Nipple down 6/30/2018 6/30/2018 1.00 MIRU MOVE RURD P Complete RD check list 0.0 0.0 18:00 19:00 6/30/2018 6/30/2018 3.00 MIRU MOVE RURD P Truck arrive at 19:00 hrs, PJSM, RU 0.0 0.0 19:00 22:00 shop & 1/2-way house to sows, RU sows to pits & pull off, RU to sub & pull off well. 6/30/2018 7/1/2018 2.00 MIRU MOVE MOB P Move from 1L-Pad to 1C-Pad 0.0 0.0 22:00 00:00 7/1/2018 7/1/2018 1.50 MIRU MOVE MOB T Arrive 1C-24, Check well status, 0.0 0.0 00:00 01:30 Attempt to bleed to pull tree cap from 150OPS1. Climbs right back up to 500 PSI. Call out DSO & Valve crew. Service tree - All good 7/1/2018 7/1/2018 1.50 MIRU MOVE MOB P Install flowcross and swab on tree 0.0 0.0 01:30 03:00 7/1/2018 7/1/2018 3.00 MIRU MOVE MOB P Spot sub over well, spot pits, lay mats 0.0 0.0 03:00 06:00 7/1/2018 7/1/2018 0.10 MIRU MOVE MOB P Spot shop & 1/2-way house, spot tiger 0.0 0.0 06:00 06:06 -tank 7/1/2018 7/1/2018 1.90 MIRU MOVE RURD P Work RU check list, safe out 0.0 0.0 06:06 08:00 walkways. Cellar spill containment 7/1/2018 7/1/2018 5.00 MIRU WHDBOP RURD P Nipple up BOPE, M/U MP line, torque 0.0 0.0 08:00 13:00 swab, three way on tree, and adapter to tree. R/U tiger tank line and air test, rig up putz, R/U steam. Test ESD on gen power. Swap to highline power. Center stack and swap riser. Prep reel iron for circulating " Rig Accept: 7/1 /18 @ 08:00 7/1/2018 7/1/2018 3.50 MIRU WHDBOP RURD P Boot both ends of a -line. Rig up to 0.0 0.0 13:00 16:30 circulate coil, fill coil. Surge coil to move wire. Hear wire move @ 4 BPM. Undo hose have -30' wire at core end. R/D circulating equipment 7/1/2018 7/1/2018 3.00 MIRU WHDBOP RURD P Install inner reel iron 0.0 0.0 16:30 19:30 7/1/2018 7/2/2018 4.50 MIRU WHDBOP RURD P Install & MU pressure bulk -head, 0.0 0.0 19:30 00:00 grease tangos & upper swab valve, grease all valves post N2 blow -down, stack, MM & choke manifold, chain inner reel iron, fluid pack, PJSM for BOPE test Page 1/13 Report Printed: 7/1612018 aerations Summary (with Timelog Depths) 1 C-24 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 7/2/2018 7/2/2018 1.50 MIRU WHDBOP BOPE P Fluid pack, shell test, BOPE test 0.0 0.0 00:00 01:30 (witness waived by Jeff Jones of the AOGCC), trouble shoot plotter after callibration by Quadco (erratic needle movement on pressure up), resolve issue Unable to hold 250 psi low on Test #1 (swab 2), appear to be taking pressure from below master & swab 1, call out valve crew to grease, move on and come back to test swab 2 7/2/2018 7/2/2018 0.70 MIRU WHDBOP BOPE P Continue BOPE test (Note: isolated to 0.0 0.0 01:30 02:12 MP guage, pressure building from below master & swab 1) 7/2/2018 7/2/2018 0.20 MIRU WHDBOP BOPE T Stop testing to allow valve crew to 0.0 0.0 02:12 02:24 grease master & swab 1 (MP climbed to 1510 psi from below mater & swab 1 before beginning to grease) 7/2/2018 7/2/2018 0.60 MIRU WHDBOP BOPE P Continue BOPE test 0.0 0.0 02:24 03:00 7/2/2018 7/2/2018 0.20 MIRU WHDBOP BOPE T Diffculty getting high test (likely 0.0 0.0 03:00 03:12 Charlie 7, grease Charlie valves) 7/2/2018 7/2/2018 3.00 MIRU WHDBOP BOPE P Continue BOPE test, get good test on 0.0 0.0 03:12 06:12 swab 2 (swab 1 / master holding) 7/2/2018 7/2/2018 1.80 MIRU WHDBOP BOPE T Test 7 test C2, C10 and tango 1. 0.0 0.0 06:12 08:00 Unable to get test. Trouble shoot back to tree valves leaking, Call out grease crew, continue on testing 7/2/2018 7/2/2018 3.00 MIRU WHDBOP BOPE T Grease crew here. Multiple attemps to 0.0 0.0 08:00 11:00 grease lock seal valve 7/2/2018 7/2/2018 1.00 MIRU WHDBOP BOPE T Consult town, Grease crew to get BPV 0.0 0.0 11:00 12:00 - Continue testing TT line, PDL 7/2/2018 7/2/2018 2.50 MIRU WHDBOP BOPE T Grease crew here, R/U BPV lubricator 0.0 0.0 12:00 14:30 and set BPV, Test tango one, Good test, Pull BPV and rid down load out lubricator 7/2/2018 7/2/2018 1.00 MIRU WHDBOP BOPE T Test inner reel iron - need to hammer 0.0 0.0 14:30 15:30 up wing X wing cross over, BOPE test complete 7/2/2018 7/2/2018 2.50 MIRU RIGMNT CTOP P PJSM Trim pipe / Slack mgmt, R/U 0.0 0.0 15:30 18:00 pipe cutter, Cut 310' pipe, Test wire 7/2/2018 7/2/2018 3.00 MIRU RIGMNT CTOP T Wire will not test, Call out electrician to 0.0 0.0 18:00 21:00 assist troubleshooting. Problem in pressure bulkhead, Rewire bulkhead - get good test 3 Hours NAD NPT 7/2/2018 7/2/2018 2.00 MIRU RIGMNT CTOP P PJSM, Boot wire and pump slack. 0.0 0.0 21:00 23:00 Surged reel 3 times @ 4.2 BPM. Unstab and wire gone. Cut 102' to find wire, 112' total. R/D cutter 7/2/2018 7/3/2018 1.00 MIRU RIGMNT CTOP P Prep coil to install CTC 0.0 0.0 23:00 00:00 7/3/2018 7/3/2018 1.00 MIRU RIGMNT CTOP P Completed installing CTC, pull test 0.0 0.0 00:00 01:00 CTC to 35K 7/3/2018 7/3/2018 1.20 MIRU RIGMNT CTOP P Head up a -line & install checks, 0.0 0.0 01:00 02:12 pressure test UQC 7/3/2018 7/3/2018 1.30 MIRU RIGMNT CIRC P MU nozzle, pump slack forward (2 coil 0.0 0.0 02:12 03:30 volumes @ 2.75 bpm) j Page 2/13 Report Printed: 7/16/2018 Sperations Summary (with Timelog Mpths) 1 C-24 $.i 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 (ftKB) End Depth (ftKB) 7/3/2018 7/3/2018 0.80 MIRU RIGMNT CIRC P WHIP @ 1690 psi, bullhead 200 bbl 0.0 0.0 03:30 04:18 seawater @ 4 bpm, pre -load PDL w/WS assembly, knock WHP down to 21 psi 7/3/2018 7/3/2018 0.30 SLOT RPEQPT OTHR P Unstab, slide back cart, clear floor, 0.0 0.0 04:18 04:36 PJSM 7/3/2018 7/3/2018 0.40 PROM RPEQPT PULD P PJSM, PD BHA#1 (WS assembly), 0.0 0.0 04:36 05:00 slid in cart, check pack -offs, MU to coil, tag up, set counters 7/3/2018 7/3/2018 2.50 PROD1 RPEQPT WAIT P Length of tool requires that we PD 0.0 0.0 05:00 07:30 against the master, which does not hold pressure, confer with town, decision made to kill well with 11.0 ppg KWF, work plan forward, transfer fluid to correct pits 7/3/2018 7/3/2018 1.40 PROM RPEQPT DISP P Bullhead 60 bbl of 11.0 ppg KWF, flow 0.0 0.0 07:30 08:54 check, circulate coil to KWF (3.25 bpm), MP = 0 psi, open swab 2, well on a significant vac, pump 9 bbl & hole still not full, decision made to close master & treat as PD 7/3/2018 7/3/2018 1.90 PROD1 RPEQPT PULD P PU BHA#1 (WS assembly), difficulty 0.0 82.0 08:54 10:48 PU tools w/ slick line winch, slide in cart, check pack -offs, MU to coil, tag up, set counters 7/3/2018 7/3/2018 1.90 PROM RPEQPT TRIP P RIH w/ BHA#1, EDC open, pumping 82.0 6,975.0 10:48 12:42 0.5 bpm, bleeding IA (from -1400 psi) 7/3/2018 7/3/2018 0.20 PROD1 RPEQPT DLOG P Log K1 for +7' correction 6,975.0 7,022.0 12:42 12:54 7/3/2018 7/3/2018 0.90 PROM RPEQPT DLOG P Log CCL from 7500' to 7580' sensor 7,022.0 7,631.0 12:54 13:48 depth (69.13' up from bit depth), touch down on plug at 7,675', PUW = 36K CCL shows collar @ 7601', putting slips at collar, confer with town, set TOWS 2' higher at 7615', PUH, close EDC, set TOWS = 7615', oriented 45' ROHS, set 5K down, PUW = 37K 7/3/2018 7/3/2018 0.70 PROD1 RPEQPT DLOG P Obtain SBHP, MD = 7622', 7,631.0 7,621.0 13:48 14:30 TVD_sensor = 6432.4', BHP = 2735 psi , EMW = 8.19 ppg 7/3/2018 7/3/2018 1.90 PROM RPEQPT DISP P Displace well over to 8.4 ppg 7,621.0 7,600.0 14:30 16:24 viscosified seawater (IA = 747 psi), pumped 144 bbl w/no returns to surface, begin filling across the top to fill the hole, get returns with -65 bbl down backside 7/3/2018 7/3/2018 2.10 PROD1 RPEQPT TRIP P POOH, filling across the top 7,600.0 60.0 16:24 18:30 7/3/2018 7/3/2018 1.00 PROM RPEQPT PULD P Bump up/space out, well on a 60.0 0.0 18:30 19:30 vacuum, flood up to stack, monitor for flow, still on vac, crew change, PJSM, hole fill 4 bbls in 30 min. Lay down BHA#1 over a dead well. losses @ - 15 bbl/hr 7/3/2018 7/3/2018 1.00 PROM RPEQPT CTOP P Inspect, tighten and torque, inner reel 0.0 0.0 19:30 20:30 iron, reel hub bolts, saddle clamps. 7/3/2018 7/3/2018 1.10 PROD1 WHPST PULD P MU/PU BHA#2 -window milling 0.0 80.0 20:30 21:36 assembly, and deploy into dead well filling hole as necessary. losses @ - 15 bbls/hr No Go mill 3.80",string reamer 3.80" Page 3/13 Report Printed: 7/16/2018 Pperations Summary Timelog tths) (with 1 C-24 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 7/3/2018 7/3/2018 1.50 PROD1 WHPST TRIP P RIH, no returns at min rate, increase 80.0 6,969.0 21:36 23:06 r;:,hr) to 1 bpm, no returns, line up to the back side, catch returns in 2 bbls, line back up down the coil. 7/3/2018 7/3/2018 0.20 PROD1 WHPST DLOG P Tie into the K1 for a +7.5' correction. 6,969.0 7,003.5 23:06 23:18 7/3/2018 7/3/2018 0.40 PROD1 WHPST TRIP P Continue to RIH. Close EDC @ 7,003.5 7,615.6 23:18 23:42 7551'. PU Wt 37 k Ibs, Dry tag TOW @ 7616' SI/d 3 k lbs. PU, 37 k Ibs, Set rate @ 2.71 bpm, RIH, 7/3/2018 7/4/2018 0.30 PROD1 WHPST WPST P CT Wt 19.33 k Ibs, CT 1654 psi, 2.66 7,615.6 7,615.6 23:42 00:00 bpm in, 0 bpm, out. Free spin diff 350 psi. Stall #1, 7615.62', PU restart, 2 stall same, 7/4/2018 7/4/2018 1.00 PROD1 WHPST WPST P Partial returns - 0:10, 0.1 bpm 7,615.6 7,615.6 00:00 01:00 increased over 10 minutes to 0.2 bpm and stabilized. S/I choke, annular @ 3890 psi, 7615.59' - Stall #3, PU 38 k Ibs - Restart @ 2.68 bpm, CT 1753, WH 6 psi, Diff 338 psi, ECD 8.68 ppg 7/4/2018 7/4/2018 1.00 PROD1 WHPST WAIT T PU Wt 37-k Ibs, Pull up hole slowly, 7,615.6 7,615.6 01:00 02:00 pumping min rate while waiting on additional fluid to arrive on location. Build 140 bbls viscosified seawater with rig water while waiting on truck. Truck on location, start building visc seawater. 7/4/2018 7/4/2018 2.20 PROD1 WHPST WPST P RBI - IA730 psi, OA71 psi 7,615.6 7,615.8 02:00 04:12 7615.56' - Stall #4, PU 38 k Ibs - Restart @ 2.71 bpm, CT 1723, WH 0 psi, Diff 346 psi, ECD 8.65 ppg 7615.84' - #5 PU 39 k Ibs 7615.84' - #6 PU 39 k Ibs 7615.88' - #7 PU 39 k Ibs 7615.84' - #8 PU 38 k Ibs 7615.84' - #9 PU 38 k Ibs, increase rate to 2.8 bpm, free spin 367 psi 7/4/2018 7/4/2018 1.00 PROD1 WHPST WPST P Saw motor work at same spot, did not 7,615.8 7,615.9 04:12 05:12 stall, WOB 0.5 k Ibs, attempting to mill ahead CT 1962 psi, 2.8 bpm in, choke closed, WH 90 psi, Annular 2977 psi. CT Wt 18.5 k Ibs, WOB 0.5 k Ibs, 7615.99 - #10 PU 39 k Ibs, pumped 10 bbI mud sweep. 7/4/2018 7/4/2018 2.00 PROD1 WHPST WPST P Continue milling from 7615.9', stalling 7,615.9 7,617.1 05:12 07:12 reduced significantly once pattern established, CWT = 15K, WOB = 1.9K, rate = 2.78 bpm, closed choke, free spin = 306 psi, BHP = 3049 psi, ECD = 9.1 ppg Stall at 7617.1', PUW = 37K & restart 7/4/2018 7/4/2018 2.00 PROD1 WHPST WPST P Milling, CWT = 15K, WOB = 1.8K, FS 7,617.1 7,617.6 07:12 09:12 = 450 psi, BHP = 3068 psi, WHP = 193 psi, 2.79 bpm, pump 5 bbls hi-vis sweep, slow progress compared to milling schedule 7/4/2018 7/4/2018 2.31 PROD1 WHPST WPST P Continue milling, progress slow, CWT 7,617.6 7,618.8 09:12 11:30 = 13K, WOB = 2.8K, rate = 2.79 bpm, BHP = 3112 psi, WHP = 245 psi, closed choke, pump 5 bbl sweep, vibration to level 5 (red) Page 4/13 Report Printed: 7/16/2018 Operations Summary (with Timelog Depths) 1 C-24 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 (W) End Depth (WB) 7/4/2018 7/4/2018 2.50 PROD1 WHPST WPST P Milling improved, vibrations reduced, 7,618.8 7,621.4 11:30 14:00 CWT = 14K, WOB = 1.61K, BHP = 3166 psi, WHP = 294 psi, rate = 2.79 bpm 7/4/2018 7/4/2018 2.40 PROD1 WHPST WPST P Milling, WOB = 2.3K, BHP 3228 psi, 7,621.4 7,626.0 14:00 16:24 WHP = 359 psi, rate 2.79 bpm, WOB deacrease observed, call BOW @ 7622', increase to 2 fph allowing string reamer to pass window 7/4/2018 7/4/2018 1.30 PROD1 WHPST WPST P PUH above WS, PUW = WHP = 428 7,626.0 7,640.0 16:24 17:42 psi, attempt to establish returns out to the TT, have returns, WHP = 44 psi, RBIH & mill rat -hole taking returns inside 7/4/2018 7/4/2018 1.20 PROD1 WHPST WPST P PU 34 k Ibs Back ream across WS @ 7,640.0 7,593.0 17:42 18:54 45°ROHS, RIH @ 45°, as milled, back ream 75 ° ROHS,RIH as milled, 45 back ream 15 ° ROHS. Dry drift clean. Over previous hr, choke worked fully open, WH 0 psi, rate in 2.8, rate out fell from 2.7 to 2.5 bpm and is dropping linearly @ - 0.2 bbl/hr. 7/4/2018 7/4/2018 1.30 PROD1 WHPST TRIP P Park, open EDC, POOH chasing 7,593.0 93.6 18:54 20:12 sweeps to surface. 7/4/2018 7/4/2018 1.50 PROD1 WHPST PULD P PJSM, bump up, space out. Flow 93.6 0.0 20:12 21:42 check no good, 69 psi surface pressure. Discuss lack of integrity of the master valve and swab #1. PUD utilizing swab #2 as the barrier and LID BHA #2. " Bit and srting reamer both 3.80 no go 7/4/2018 7/4/2018 1.90 PROD1 DRILL PULD P Reconfigure BHA to include USR, only 0.0 82.5 21:42 23:36 one PDL, PD Build BHA #3 - 2.8° AKO w HYC bicenter bit, check pack offs - good, re -run, stab injector, tag up, space out, set counters 7/4/2018 7/5/2018 0.40 PROD1 DRILL TRIP P RIH w/ build BHA#3 turning coil over 82.5 1,744.0 23:36 00:00 to power pro drilling fluid through an open EDC taking returns to the tiger tank. 7/5/2018 7/5/2018 1.00 PROD1 DRILL TRIP P RIH w/ build BHA#3 turning coil over 1,744.0 6,565.0 00:00 01:00 to power pro drilling fluid through an open EDC taking returns to the tiger tank. 7/5/2018 7/5/2018 0.20 PROD1 DRILL DLOG P Log the K1 marker correction of plus 6,565.0 6,992.7 01:00 01:12 1 +6.5', 7/5/2018 7/5/2018 1.50 PROD1 DRILL TRIP P Continue RIH, Circ well to new mud, 9,690.0 7,640.0 01:12 02:42 losses innitial 2.5 bpm in 1.6 bpm out, returns fell to 0.88 bpm. Mud back at surface. Close EDC, PUW 40 k, run through window, clean. 7/5/2018 7/5/2018 0.80 PROD1 DRILL DRLG P Ct 2667 psi, 2.49 bpm in, 0.68 bpm 7,640.0 7,660.0 02:42 03:30 out, free spin 829 psi, IA 757psi, OA 85 psi, Ct RIH Wt 17.8 k Ibs OBD, open choke, Ct Wt 15.8 k Ibs, WOB 1.92 k Ibs, ROP 45 ft/hr Multiple stalls, PU Wt 40 k Ibs Average ROP - 25 ft/hr Page 5/13 Report Printed: 7/16/2018 Pperations Summary (with Timelog Depths) 4, r • a' 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 (ftKB) End Depth (ftKB) 7/5/2018 7/5/2018 1.70 PROM DRILL DRLG P Stall, PU 42 k lbs. Increase rate to 2.7 7,660.0 8,010.0 03:30 05:12 bpm Ct 2870 psi, 2.70 bpm in, 1.27 bpm out, free spin 888 psi, OBD, Ct Wt 13.9 k Ibs, WOB 1.00 k Ibs, ROP 140-280 ft/hr 7/5/2018 7/5/2018 0.30 PROM DRILL WPRT P PU on short wiper trip, 39 k Ibs - 300' 8,010.0 8,010.0 05:12 05:30 7/5/2018 7/5/2018 0.70 PROD1 DRILL DRLG P Continue drilling to called TD of turn at 8,010.0 8,150.0 05:30 06:12 8150', rate out increased to 1.69 bpm (AV = 173 fpm, -63% returns) 7/5/2018 7/5/2018 2.10 PROM DRILL TRIP P POOH, PUW = 35K, open EDC, tag 8,150.0 82.0 06:12 08:18 up, PJSM, flow check well 7/5/2018 7/5/2018 0.80 PROD1 DRILL PULD P LID BHA#3, bleed IA down to 410 psi, 82.0 0.0 08:18 09:06 bit came out a 1-1 (reamers packed off with clay) 7/5/2018 7/5/2018 1.40 PROM DRILL PULD P PU BHA#4 (NOV agitator, 0.6-° AKO 0.0 87.0 09:06 10:30 motor, HYC B8 bit), inspect inner reel iron, saddle clamps (tightened ODS saddle clamp), & hubs, slide in cart, check pack -offs, good, MU to coil, tag up, set counters, close EDC 7/5/2018 7/5/2018 1.30 PROM DRILL TRIP P RIH w/ BHA#4, shallow test agitator, 87.0 6,965.0 10:30 11:48 good ( depth = 438', rate = 2 bpm, circ pressure = 2270 psi, bore = 997 psi, dp = 770 psi) 7/5/2018 7/5/2018 0.10 PROM DRILL DLOG P log K1 for+6' correction 6,965.0 7,002.0 11:48 11:54 7/5/2018 7/5/2018 0.50 PROM DRILL TRIP P Continue RIH, Log RA 7,002.0 8,150.0 11:54 12:24 Note: TOWS = 7616', RA = 7625', BOW = 7623' 7/5/2018 7/5/2018 0.90 PROD1 DRILL DRLG P Drilling, pumping 2.72 bpm, rate out = 8,150.0 8,358.0 12:24 13:18 1.97 bpm, CWT = 12K, WOB = 3.3K, BHP = 3182 psi, open choke 7/5/2018 7/5/2018 0.30 PROM DRILL WPRT P 200' wiper trip, PUW = 44K, RIW = 8,358.0 8,358.0 13:18 13:36 14K 7/5/2018 7/5/2018 0.70 PROM DRILL DRLG P Drilling, CWT = 10.5K, WOB = 1.9K, 8,358.0 8,504.0 13:36 14:18 BHP = 3199 psi, circ pressure = 3571 psi, rate in = 2.72 psi, rate out = 1.96 bpm, -72% returns, AV = 200 fpm 7/5/2018 7/5/2018 0.60 PROM DRILL DRLG T Differentially stuck at 8504', pull up to 8,504.0 8,504.0 14:18 14:54 85K, have returns (-2 bpm), able to orient, pump 5 x 5 sweeps, pull free @ 82K (9th attempt) 7/5/2018 7/5/2018 0.40 PROM DRILL WPRT P Wiper to window 8,504.0 7,645.0 14:54 15:18 7/5/2018 7/5/2018 0.40 PROD1 DRILL WPRT P Wiper in -hole, log RA for +6' 7,645.0 8,504.0 15:18 15:42 correction, RIW = 15K 7/5/2018 7/5/2018 2.00 PROM DRILL DRLG P BOBD, FS = 1239 psi, CWT = 10.8K, 8,504.0 8,734.0 15:42 17:42 WOB = 1.91K, BHP = 3205, pumping 2.7 bpm, -77% returns, circ pressure = 3889 psi, PUW = 55K from 8604', pump 5x5 sweeps OBD, CWT = 11.5K, WOB = 1.8K, BHP = 3229 psi, pumping 2.7 bpm, returns -80% 7/5/2018 7/5/2018 0.20 PROM DRILL WPRT P 300' short wiper, PU 44 klbs 8,734.0 8,412.0 17:42 17:54 7/5/2018 7/5/2018 0.30 PROM DRILL WPRT P RBIH, RIH Wt 14.5 k Ibs 8,412.0 8,734.0 17:54 18:12 Page 6/13 Report Printed: 7/16/2018 APerations Summary (with Timelog Depths) r IMP ;4 1 C-24 x Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 7/5/2018 7/5/2018 1.70 PROD1 DRILL DRLG P OBD, unable to build angle, reduce 8,663.0 8,960.0 18:12 19:54 pump rate to 2.28 bpm, 1.76 bpm out, CT 2755 psi, Annular 3215 psi free spin 851 psi, WOB 3.5 - 2.6 k Ibs, ROP 300-100 ft/hr. TF 10 ° holding a steady 89 °. 8920 PU 55 klbs Average ROP - 175 ft/hr 7/5/2018 7/5/2018 0.30 PROM DRILL WPRT P 800' - Wiper # 1, PU 44 klbs, 36.5 k 8,960.0 8,160.0 19:54 20:12 clean PUH Wt, Increase to full rate, 2.7 bpm in, 1.81 bpm out. motor work @ 8299', lots of solids at the shaker 7/5/2018 7/5/2018 0.30 FROM DRILL WPRT P RBIH, RIH Wt 14.5 k Ibs 8,160.0 8,960.0 20:12 20:30 7/5/2018 7/6/2018 3.50 PROM DRILL DRLG P Ct 3267 psi, 2.68 bpm in, 2.03 bpm 8,960.0 9,243.0 20:30 00:00 out, free spin diff 1064 psi, R IH Wt 11.77 k lbs OBD, CT Wt 9.8 k Ibs, WOB 1.3 k Ibs, ROP 200 ft/hr 9033 - Stall, PU 50 k Ibs, building angle again, ROPs fell to - 30 ft/hr, vibrations @ 5 Reduce rate to 2.6, vibrations @ 4, ROP 38, Increase to full drill rate. Ratty drilling, missing surveys, intermitant vibrations to 5's. Dificulty geostearing up and down, appears to be formation related. Average ROP 80.9 ft/hr 7/6/2018 7/6/2018 0.40 FROM DRILL DRLG P OBD, Ct 3696 psi, @ 2.7 bpm in, 2.2 9,243.0 9,281.0 00:00 00:24 bpm out, annular 3312 psi CT Wt 0.3 k Ibs, WOB 2 k Ibs, ROP 90 ft/hr Average ROP - 95 ft/hr 7/6/2018 7/6/2018 0.30 FROM DRILL WPRT P 800' - Wiper # 2, PU 51 k Ibs, 37 k 9,281.0 8,480.0 00:24 00:42 clean PUH Wt, 7/6/2018 7/6/2018 0.30 PROM DRILL WPRT P RBIH 8,480.0 9,281.0 00:42 01:00 7/6/2018 7/6/2018 2.10 PROM DRILL DRLG P CT 3373 psi @ 2.68 bpm in, 2.22 bpm 9,281.0 9,406.0 01:00 03:06 out, Free spin diff 1105 psi, Annular 3305 psi. WH 0, IA 415, OA 97 OBD, CT 11 k Ibs, WOB 1.2 k Ibs, ROP 85 ft/hr Stall 9287' , PU 41 k Ibs, 9369' - PU 61 k, 9381' - PU 57 k, 9382' - PU 65 k, 9406' - 60 k Ibs, Ct Wt -2.6 k Ibs, pull wiper early Average ROP - 59 ft/hr 7/6/2018 7/6/2018 0.80 PROM DRILL WPRT P Wiper to window for tie in, PU 40 k Ibs, 9,406.0 7,640.0 03:06 03:54 38 k clean PUH Wt, 8300' breif motor work 8143' motor work and CT weight through build, slow to 25 ft/min, 7/6/2018 7/6/2018 0.10 FROM DRILL DLOG P Tie into the RA tag for a +5 ' correction 7,640.0 7,663.0 03:54 04:00 7/6/2018 7/6/2018 1.10 PROM DRILL WPRT P RBIH jogging the build/turn section, 7,663.0 9,406.0 04:00 05:06 7/6/2018 7/6/2018 1.10 FROM DRILL DRLG P Ct 3425 psi, 2.68 bpm in, 2.22 bpm 9,406.0 9,496.0 05:06 06:12 out, free spin dill 1035 psi, R IHWt11.klbs OBD, CT Wt 4 k Ibs, WOB 2.6 k Ibs, ROP 318 ft/hr Page 7/13 Report Printed: 7/16/2018 r � IPerations Opths) Summary (with Timelog 1 C-24 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 7/6/2018 7/6/2018 1.70 PROM DRILL DRLG P OBD, FS = 1150 psi, CWT = 5.8K, 9,496.0 9,607.0 06:12 07:54 WOB = 2K, BHP = 3307 psi, circ pressure = 3683 psi, returns -84%,62K PUW @ 9580' (turn into BHA wiper), avg ROP = 65.3 fph, continued difficulty building over 90° 7/6/2018 7/6/2018 0.40 PROD1 DRILL WPRT P Wiper up -hole, PUW = 61 K 9,607.0 8,598.0 07:54 08:18 7/6/2018 7/6/2018 0.30 PROD1 DRILL WPRT P Wiper in -hole, RIW = 9K 8,598.0 9,607.0 08:18 08:36 7/6/2018 7/6/2018 2.40 PROM DRILL DRLG P BOBD, FS = 1050 psi, CWT = OK, 9,607.0 9,796.0 08:36 11:00 WOB = 1.61K, BHP = 3319 psi, returns = 84%, circ pressure = 3588 psi, pump 5x5 sweeps as required, PUW = 54 @ 9796, significant vibrations (4's), avg ROP = 79 fph Note: MWD advised that tools are at their hours of vibrations (if pulling for any reason, recommend replacing tools) 7/6/2018 7/6/2018 3.00 PROM DRILL DRLG P Drilling, CWT = 5.7K, WOB = 1.9K, 9,796.0 10,000.0 11:00 14:00 BHP = 3366 psi, circ = 3848 psi, rate in = 2.8 bpm, rate out = 2.33 bpm, PUW = 62K @ 9861', PU's as required, BHA wiper from 9920', PUW = 63K, pump 5x5 sweeps, unable to build past 90' Inc 7/6/2018 7/6/2018 2.90 PROM DRILL TRIP P Decision made to POOH for higher 10,000.0 82.0 14:00 16:54 bend motor, PUW = 48K, motorwork pulling through build/turn, bleeding IA, open EDC, close EDC, shallow test agitator (-200 psi drop in from initial test), tag up, flow check, have flow, open EDC 7/6/2018 7/6/2018 1.50 PROM DRILL PULD P PJSM, partially PUD BHA#4, crew 82.0 0.0 16:54 18:24 change, complete PUD. 7/6/2018 7/6/2018 1.50 PROD1 DRILL PULD P LID old tools, out of spec per 0.0 0.0 18:24 19:54 vibrations, PU new tools, only one PDL, PD #5 (new tools, new agitator, 1.0° AKO motor, new HCC P104 bit) *'*`HYC Bit graded 1-1, 7/6/2018 7/6/2018 0.50 PROM DRILL SVRG P Trouble with mast tilt, after discussion, 0.0 0.0 19:54 20:24 trouble shot out of critical path while moving forward with coil and pack off inspection. 7/6/2018 7/6/2018 0.90 PROM DRILL CTOP P Check coil wall, while running into 86.8 86.8 20:24 21:18 mouse hole, 2" and 20' above the coil connector - good, 0.19. Check packoffs - Replaced. 7/6/2018 7/6/2018 1.20 PROD1 DRILL PULD P PD BHA #5 86.8 86.8 21:18 22:30 7/6/2018 7/6/2018 1.30 PROM DRILL TRIP P Close EDC, RIH, park 500', test 86.8 6,970.0 22:30 23:48 agitator, good, RIH. 7/6/2018 7/7/2018 0.20 PROM DRILL DLO P Tie into the K1 for + 6.5' correction 6,970.0 7,002.E 23:48 00:00 7/7/2018 7/7/2018 1.00 PROM DRILL TRIP P Continue to RIH, window and build 7,002.6 10,000.0 00:00 01:00 clean. 7/7/2018 7/7/2018 0.40 PROM DRILL DRLG P CT 3506 psi, @ 2.69 bpm in, 2.33 10,000.0 10,054.0 01:00 01:24 bpm out, free spin diff 1188 psi. Annular 3283 psi, RIH Wt 10 k Ibs CT Wt 11.5 k Ibs, WOB 1.74 k Ibs, ROP 102 f /hr Average ROP 135 ft/hr Page 8/13 Report Printed: 7/16/2018 Iterations Summary (with Timelog Pepths) 1 C-24 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 (ftKB) End Depth (ftKB) 7/7/2018 7/7/2018 0.30 PROD1 DRILL CIRC P Gas at the shaker, exported returns 10,054.0 10,054.0 01:24 01:42 outside to the tiger tank. PU, 40 k Ibs, Double checked calc's, lost fluid on the trip in as well as while drilling. Must have circulated some gas out of the horizontal section. PUH slowly, Returns cleaned up, bring mud back inside, RBIH *** Lost - 50 bbls mud to the tiger tank 7/7/2018 7/7/2018 1.30 PROD1 DRILL DRLG P Ct 3550 psi, 2.67 bpm in, 2.32 bpm 10,054.0 10,192.0 01:42 03:00 out, free spin diff 1140 psi, Annular 3413 psi, 9.9 ppg @ the window CT Wt 1.3 k Ibs, WOB 1.33 k Ibs, ROP 277 ft/hr DD still having a hard time building angle, holding 90-91 ° @ HS TF. Average ROP 106 ft/hr 7/7/2018 7/7/2018 0.50 PROD1 DRILL WPRT P PU, 45 k Ibs, Geo wiper. 10,192.0 9,933.0 03:00 03:30 Discuss with slope / town engineering / geology 7/7/2018 7/7/2018 1.00 PROD1 DRILL TRIP P Trip for higher bend motor 9,933.0 7,603.0 03:30 04:30 Pump sweeps timed to exit bit at bottom of build / turn, chase up hole, 7/7/2018 7/7/2018 1.30 PROD1 DRILL TRIP P Open EDC, POOH, tag up 7,603.0 87.0 04:30 05:48 7/7/2018 7/7/2018 1.70 PROD1 DRILL PULD P Crew change, PJSM, PUD BHA#5 87.0 0.0 05:48 07:30 ( bit came out w/ 1 chipped reamer cutter) 7/7/2018 7/7/2018 1.30 PROD1 DRILL PULD P PD BHA#6 (agitator from BHA#4, 0.0 87.0 07:30 08:48 1.5° AKO motor, same bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 7/7/2018 7/7/2018 1.30 PROD1 DRILL TRIP P RIH w/ BHA#6, shallow test agitator, 87.0 6,970.0 08:48 10:06 good 7/7/2018 7/7/2018 0.10 PROD1 DRILL DLOG P Log K1 for + 6.5' correction, PUW = 6,970.0 6,993.0 10:06 10:12 37K 7/7/2018 7/7/2018 1.00 PROD1 DRILL TRIP P Continue RIH, clean though window & 6,993.0 10,192.0 10:12 11:12 build 7/7/2018 7/7/2018 0.70 PROD1 DRILL DRLG P OBD, RIW = 10K, FS = 1017 psi @ 10,192.0 10,271.0 11:12 11:54 2.77 bpm, CWT = 9K, WOB = 1.5K, BHP = 3398 psi, circ = 3545 psi, -90% returns, PUW = 62K @ 10,264', rate out dropping to 2.2 bpm. NBI = 91.4° @ 10,192: NBI = 96.1 ° @ 10,258 NBI = 98.0° @ 10,267' 7/7/2018 7/7/2018 1.60 PROD1 DRILL DRLG T Detianed at 10,271', pump 5x5 10,271.0 10,271.0 11:54 13:30 sweeps, have returns, can orient, believe differentially stuck, work pipe up to 85K multiple times, allow sweeps to come around, work pipe free @ 87K & 70 fpm. PUH allwowing for bottoms up of sweeps. 7/7/2018 7/7/2018 1.20 PROD1 DRILL DRLG P Drilling, FS = 1039 psi @ 2.8 bpm, 10,271.0 10,350.0 13:30 14:42 CWT = 9K, WOB = 1.5K, BHP = 3470 psi, circ = 4000 psi 7/7/2018 7/7/2018 1.00 PROD1 DRILL WPRT T Geo wiper, PUW = 55K, allow town 10,350.0 10,350.0 14:42 15:42 geology time to evaluate logs, decision made to continue drilling to aquire additional 4' TVD, then pull for lower bend motor, RBIH Page 9/13 Report Printed: Til 7/16/2018 11perations Summary (with Timelog Depths) ... 1 C-24 M 4 ♦,n �. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 7/7/2018 7/7/2018 0.60 FROM DRILL DRLG P Drilling, CWT = 4.6K, WOB = 1.61K, 10,350.0 10,375.0 15:42 16:18 BHP = 3432 psi, pumping 2.8 bpm, returns = 91 %, pump 5 x 5 sweeps, PUW = 82K @ 10,372' 7/7/2018 7/7/2018 2.40 PROM DRILL TRIP P POOH for lower bend motor, PUW = 10,375.0 82.0 16:18 18:42 64K 7/7/2018 7/7/2018 1.50 FROM DRILL PULD P PUD BHA #6 82.0 0.0 18:42 20:12 7/7/2018 7/7/2018 0.50 PROM DRILL BOPE P BOP function test. 0.0 0.0 20:12 20:42 7/7/2018 7/7/2018 1.40 FROM DRILL PULD P PUD BHA#7, 0.9 AKO w BH P104 0.0 82.0 20:42 22:06 cutters 7/7/2018 7/7/2018 1.20 FROM DRILL TRIP P RIH, Shallow test agitator, good, 82.0 6,970.0 22:06 23:18 continue to RIH. 7/7/2018 7/7/2018 0.20 FROM DRILL TRIP P Tie into the K1 for a 7.0 ' correction. 6,970.0 7,010.7 23:18 23:30 7/7/2018 7/8/2018 0.50 PROD1 DRILL TRIP P Continue to RIH. 7,010.7 8,752.0 23:30 00:00 7/8/2018 7/8/2018 0.60 PROM DRILL TRIP P Continue to RIH. 8,752.0 10,375.0 00:00 00:36 7/8/2018 7/8/2018 0.20 FROM DRILL DRLG P RIH Wt 9k Ibs, CT 3770 psi, 2.69 bpm 10,375.0 10,400.0 00:36 00:48 in, 2.41 bpm out, Free spin diff 1155 psi OBD, CT 8.3 k Ibs, WOB 2.86 K Ibs, ROP 167 ft/hr Ran into something hard @ 10400', ROP 60 ft/hr, 2.5 k WOB 7/8/2018 7/8/2018 5.70 PROM DRILL DRLG P Ran into something hard @ 10400', 10,400.0 10,639.0 00:48 06:30 ROP 60 ft/hr, 2.5 k WOB Gamma wrapped to 166 API @ 10,400', 10,447', PU 53 k Ibs, Turned Down. 10,468', PU 50 k Ibs, 10,487% PU 53 k Ibs, Cutting ratio went from negative slope to positive CR @ 0.85 @ - 10,435', 0.95 @ 10,500' 10,516', PU 60 k Ibs ROP increased @ 10,572', drilling in IowerAPI reservoir 7/8/2018 7/8/2018 0.40 PROM DRILL WPRT P Wiper up -hole, PUW = 50K, clean 10,639.0 9,963.0 06:30 06:54 7/8/2018 7/8/2018 0.40 FROM DRILL WPRT P Wiper in -hole, CWT falling off from 7K 9,963.0 10,639.0 06:54 07:18 @ 10,180' to OK, get weight back @ -10,625' 7/8/2018 7/8/2018 1.80 PROM DRILL DRLG P Drilling, FS = 1250 psi, CWT = OK, 10,639.0 10,801.0 07:18 09:06 WOB = 3.7K, circ = 4344, BHP = 3469 psi, avg ROP = 90 fph 7/8/2018 7/8/2018 0.40 FROM DRILL WPRT P Wiper (began as BHA, difficulty getting 10,801.0 9,951.0 09:06 09:30 to bottom stacking CWT), PUW = 50K 7/8/2018 7/8/2018 0.50 FROM DRILL WPRT P Wiper in -hole, begin losing CWT at 9,951.0 10,801.0 09:30 10:00 10,240' on start of INC increase, stacking negative CWT to get to bottom, reduce rate to 1 bpm 7/8/2018 7/8/2018 2.50 PROM DRILL DRLG P Drilling, CWT = -3K, WOB = 1.21K, 10,801.0 10,992.0 10:00 12:30 rate in = 2.7 bpm, returns = 92%, BHP = 3478 psi PUW = 47K @ 10,900' Pumped 5x5 sweeps, Avg ROP = 76 fph Page 10/13 Report Printed: 7/16/2018 IPerations Summary (with Timelog Depths) =h 1 C-24 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 (ftKB) End Depth (ftKB) 7/8/2018 7/8/2018 1.30 PROM DRILL DRLG P Drilling, CWT = -4K, WOB = 1.25K, 10,992.0 11,076.0 12:30 13:48 BHP = 3456 psi, sweeps exit bit PUW =51K@10.999' Cuttings Ratio leveled out (slightly over 1 for the lateral) Pump 5x5 sweeps Avg ROP = 65 fpm w/ decent steady state drilling 7/8/2018 7/8/2018 0.50 PROD1 DRILL WPRT P Wiper up -hole, PUW = 50K, clean 11,076.0 9,378.0 13:48 14:18 through high gamma interval (10,540' - 10,400') 7/8/2018 7/8/2018 1.10 PROM DRILL WPRT P Wiper in -hole, stack coil weight up 9,378.0 11,076.0 14:18 15:24 high DLS build beggining at 10,280', & through high gamma interval, reduce speed & push to -4K beginning at 10,630', then bounce up to +7K @ 11, 050' 7/8/2018 7/8/2018 1.60 PROM DRILL DRLG P BOBD, FS = 1130 psi @ 2.7 bpm, 11,076.0 11,187.0 15:24 17:00 CWT = -7K, WOB = 1.6K, BHP = 3470 psi, circ pressure = 4106 psi PUW = 52K @ 11,154' 7/8/2018 7/8/2018 2.80 PROM DRILL DRLG P CT4165 psi, 2.7 bpm in, 2.48 bpm 11,187.0 11,309.0 17:00 19:48 out, free spin dill 1333 psi Ct wt neutral to -8 k Ibs, WOB 1-0.7 k Ibs Average ROP over interval 44 ft/hr - 70 -30 ft/hr while on bottom Lots of pick ups, — 60 - 68 k Ibs - added 2 ppb alpine beads to high vis, little to no visible effect on CT wt or WOB with sweeps on the back side. 7/8/2018 7/8/2018 0.20 PROM DRILL DRLG P PU 60k Ibs - 800' wiper 11,309.0 10,507.0 19:48 20:00 7/8/2018 7/8/2018 1.00 PROD1 DRILL DRLG P RBIH, 10,507.0 11,309.0 20:00 21:00 Struggle with weight transfer, CT wt neutral to -10 k Ibs, RIH speeds 25 to 15 ft/min pumping — 2 bpm. 7/8/2018 7/8/2018 0.90 PROM DRILL DRLG P CT4100 psi, 2.7 bpm in, 2.5 bpm out, 11,309.0 11,359.0 21:00 21:54 Free spin diff 1330 psi, Annular 3515 psi, 10.0 ppg @ the window. CT Wt -6 k Ibs, WOB 1.2 k Ibs, ROP — 70 ft/hr PU - 11,337', 58 k - add Low torque to high vis, pump 10 bbl pill - rapid spike in differential pressure @ 21:15 and 11,330' with no change in WOB 7/8/2018 7/8/2018 0.20 FROM DRILL WPRT P Strange trends in the differential 11,359.0 11,186.0 21:54 22:06 pressure. Sudden spike to 2100 psi with no resultant WOB, PU, 58 k Ibs, PUH, reduce rate while PUH. Stage rates back up. CT now 4800 psi and free spin diff 1880 psi @ 2.7 bpm. Has been 4100 and 1330 psi respectively. 7/8/2018 7/8/2018 0.40 PROD1 DRILL WPRT P RBIH 11,186.0 11,359.0 22:06 22:30 7/8/2018 7/8/2018 0.60 FROM DRILL DRLG P CT 4400 psi at 2.7 bpm in, 2.44 bpm 11,359.0 11,400.0 22:30 23:06 out, free spin doff, 1450 psi. CT -6 k Ibs, WOB 1.6 k Ibs Average ROP 45 ft/hr Still seeing random spikes in differential pressure. Bottoms up from original incident, rubber on the shaker. Motor and or agitator chunking. Page 11/13 Report Printed: 7/16/2018 �a Iterations Summary (with Timelog epths) ., 1 C-24 r s.` s Mor 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 (ftKB) End Depth (ftKB) 7/8/2018 7/9/2018 0.90 PROD1 DRILL WPRT P TD 11,400.0 9,195.0 23:06 00:00 PU Wt 48 k Ibs, PUH on swab wiper, 2.7 bpm in , 2.25 bpm out, loosing 0.25 bpm accounting for pipe. High gamma, build, and window clean. Continue to see random spikes in diff pressure and rubber on the shaker. 7/9/2018 7/9/2018 1.90 PROD1 DRILL WPRT P Continue to POOH 9,195.0 88.0 00:00 01:54 7/9/2018 7/9/2018 1.20 PROM DRILL PULD T PUD BHA#7, bit box on motor seized 89.0 0.0 01:54 03:06 up. 7/9/2018 7/9/2018 0.50 PROM DRILL PULD T Replace motor, agitator, flow sub. 0.0 0.0 03:06 03:36 7/9/2018 7/9/2018 1.50 PROM DRILL PULD T PD BHA #8, swap out upper checks. 0.0 85.0 03:36 05:06 7/9/2018 7/9/2018 1.20 PROM DRILL TRIP P RIH 85.0 6,970.0 05:06 06:18 7/9/2018 7/9/2018 0.10 PROD! DRILL DLOG P Log K1 for+5' correction. 6,970.0 6,994.0 06:18 06:24 7/9/2018 7/9/2018 0.20 PROM DRILL TRIP P Continue RIH 6,994.0 7,600.0 06:24 06:36 7/9/2018 7/9/2018 0.30 PROM DRILL DLOG P Obtain SBHP: bit depth = 7600' MD, 7,600.0 7,600.0 06:36 06:54 TVD_sensor = 6430', BHP = 3130, EMW = 9.37, 18 minute test, still dropping Begin building 9.5 ppg LRP & KWF (to maintain close to as drilled pressure on high gamma interval) 7/9/2018 7/9/2018 1.40 PROD1 DRILL TRIP P Continue RIH, stack a bit of weight 7,600.0 11,403.0 06:54 08:18 beginning at 10.397', CWT dropping to -3K, confirm TD at 14,401', PUW = 40K 7/9/2018 7/9/2018 4.20 PROM DRILL DISP P Offload additional water, water back 11,403.0 87.0 08:18 12:30 KWF, roll coil to LRP, lay in LRP & KWF to suface (9.5 ppg), tag up, PJSM, flow check 7/9/2018 7/9/2018 1.30 PROM DRILL PULD P LID BHA #8, losses - 2 bph, clear floor 87.0 0.0 12:30 13:48 7/9/2018 7/9/2018 0.60 COMPZ1 CASING CTOP P Check for flat spots in coil, UT @ 8' 0.0 0.0 13:48 14:24 from CTC = .175" - .195" (Unable able run 16' into pipe shed) 7/9/2018 7/9/2018 3.60 COMPZ1 CASING PUTB P PJSM, PU Lower Liner Section (NP 0.0 1,480.0 14:24 18:00 BN, 47 jnts, shorty deployment sleeve) 7/9/2018 7/9/2018 1.20 COMPZ1 CASING PULD P Cerw change, PJSM, PU liner running 1,480.0 1,529.0 18:00 19:12 tools (BHA#9), slide in cart, MU to coil, tag up, set counters 7/9/2018 7/9/2018 2.90 COMPZ1 CASING RUNL P RIH w/ BHA#9 lower liner section, tie 1,529.0 11,401.0 19:12 22:06 into window flag for +1.6', PUW = 38K, smooth to bottom, PUW = 46K, RBIH , bring up pump, 1.5 bpm, release off liner, BOL = 11,401', TOIL = 9919' 7/9/2018 7/10/2018 1.90 COMPZ1 CASING TRIP P POOH, paint EOP flags (TD = 11,401.0 1,968.0 22:06 00:00 7597.68', window = 5247.68') 7/10/2018 7/10/2018 0.60 COMPZ1 CASING TRIP P Continue POOH, park short, open at 1,968.0 50.0 00:00 00:36 the stack, well on a vac, flood up to the stack, flow check good. Lost 17 bblS KW on the trip. 7/10/2018 7/10/2018 1.00 COMPZ1 CASING PULD P LD BHA#9, liner running tools - hole 50.0 0.0 00:36 01:36 1 fill 2 bbls Page 12/13 Report Printed: 7/16/2018 Merations Summary (with Timelog Pepths) 1 C-24 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 7/10/2018 7/10/2018 6.00 COMPZ1 CASING PUTB P Prep floor for running liner, inspect 50.0 2,389.0 01:36 07:36 safety joint and latch up in elevators, PU L1 upper completion,** Note Aluminum bull nose, 2.80" OD, 1" ID, 0.4' length, ( loctite bull nose threads & make up to 500 ft/lbs),74 joints, ('2.875", 6.5#, L-80, slotted liner( ID 2.37"), and a shortly deployment sleeve, (4" GS Profile, 3.70"OD, 2.37" ID, 0.79' long) Crew change 6:00 - 6:15, start out on Joint 60. 7/10/2018 7/10/2018 1.10 COMPZ1 CASING RUNL P Bump up, set counters, RIH 2,389.0 7,566.0 07:36 08:42 7/10/2018 7/10/2018 0.20 COMPZ1 CASING DLOG P Tie into flag for -2.1' correction 7,566.0 7,557.0 08:42 08:54 7/10/2018 7/10/2018 0.80 COMPZ1 CASING RUNL P PU 39 k Ibs, continue to RIH, SD, PU 7,557.0 9,916.0 08:54 09:42 Wt 50 k Ibs, RBIH, S/D, Pump off, PU Wt 33 k Ibs. 7/10/2018 7/10/2018 1.70 COMPZ1 CASING TRIP P PUH, park, reset counters, POOH. 9,916.0 49.0 09:42 11:24 7/10/2018 7/10/2018 1.00 COMPZ1 CASING PULD P Bump up, flow check, LID BHA #10. 49.0 0.0 11:24 12:24 7/10/2018 7/10/2018 0.80 DEMOB WHDBOP MPSP P Set Two Way check 0.0 0.0 12:24 13:12 7/10/2018 7/10/2018 2.00 DEMOB WHDBOP CIRC P Jet BOP stack while turning coil over 0.0 0.0 13:12 15:12 to corrosion inhibitor 7/10/2018 7/10/2018 2.00 DEMOB WHDBOP CTOP P Blow down coil to N2, bleed down, 0.0 0.0 15:12 17:12 blow down 7/10/2018 7/10/2018 0.80 DEMOB WHDBOP RURD P Rig down 0.0 0.0 17:12 18:00 7/10/2018 7/10/2018 5.00 DEMOB WHDBOP RURD P Crew change, PJSM, swap BOP rams 0.0 0.0 18:00 23:00 back to standard configuration. lock out reel and INJH, disconnect Pipe Untility Transfer Zone (PUTZ) corridor 7/10/2018 7/11/2018 1.00 DEMOB WHDBOP RURD P Start pre -move checklist, remove and 0.0 0.0 23:00 00:00 secure flow -line, prepair to fliud pack stack. 7/11/2018 7/11/2018 1.00 DEMOB WHDBOP RURD P Fliuid pack stack, PT 4,200 psi (good 0.0 0.0 00:00 01:00 integerit--test) 7/11/2018 7/11/2018 8.00 DEMOB WHDBOP RURD P Perform rig move checklist, move pits 0.0 0.0 01:00 09:00 and sub off well, stage in middle of pad 7/11/2018 7/11/2018 6.00 DEMOB WHDBOP RURD P Un Stab injector, secure coil on 0.0 0.0 09:00 15:00 shipping spool, call trucks, prep to remove storage reel. 7/11/2018 7/11/2018 7.00 DEMOB WHDBOP RURD P 7 hrs added to account for the 0.0 0.0 15:00 22:00 remainder of the reel swap to be completed during the rig maintenance. *** Rig Release Page 13/13 Report Printed: 7/1612018 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1 C-24L1 50-029-23063-60 Baker Hughes INTEQ Definitive Survey Report 20 July, 2018 BA ER I UGHES a GE company - ConocoPhillips 8Ad<ER S '=F_-..qS ConocoPhilli s p Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupi Local Co-ordinate Reference: Well 1C-24 Project: Kuparuk River Unit TVD Reference: 1C-24: @ 101.60usft (1C-24:) Site: Kuparuk IC Pad MD Reference: 1C-24: @ 101.60usft (lC-24:) Well: 1C-24 North Reference: True j Wellbore: 1C-2411 Survey Calculation Method: Minimum Curvature Design: 1C-2411 Database: EDT Alaska Sandbox 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 Well... . IC-24_ Well Position +N/S 0.00 usft Northing: 5,968,571.44usft Latitude: 70° 19' 28.773 N +E/-W 0.00 usft Easting: 562,297.94usft Longitude: 149° 29' 41.445 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1C-241-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°I (nT) BGGM2017 7/l/2018 17.05 80.91 57,464 Design IC-24L1 Audit Notes: :.... Version: 1.0 Phase: ACTUAL Tie On Depth: 7,562.49 Vertical Section: Depth From (TVD) +N/-S +El-W Direction (ustt) (usft) (usft) (°) 61.30 0.00 0.00 45.00 r Survey Program Date 7/9/2018 From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 83.00 349.10 1C-24 GYRO (1C-24) CB -GYRO -SS Camera based gyro single shot 2/5/2002 480.38 7,562.49 1C-24(1 C-24) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2/5/2002 7,616.00 7,734.27 1C-2411 MWD-INC(1C-24L1) MWD-INC_ONLY MWD-INC_ONLY_FILLER 7/l/2018 7/1/2018 7,763.34 11,362.58 1C-2411 MWD(1C-24L7) MWD MWD- Standard 7/l/2018 7/9/2018 7/202018 2: 16:01PM Page 2 COMPASS 5000.14 Build 85 0 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupt Local Coordinate Reference: Well 1C-24 Project: Kupamk River Unit ND Reference: 1C-24: @ 101.60usft (1C-24:) Site: Kupamk IC Pad MD Reference: IC-24: @ 101.60usft (lC-24:) Well: 1C-24 North Reference: True Wellbore: 1C-24L1 Survey Calculation Method: Minimum Curvature Design: 1C-24Li Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section Survey Tool Name (usft) (I (usft) (usft) (usft) (usft) (usft) IfU (ft) (°/100') Iftl 7.562.49 84.70 266.88 6.431.61 6,330.01 -2,158.52 -2,031.15 5,966,396.34 550284.98 2.80 -2,962.54 MWD-INC_ONLY(3) 7.616.00 85.68 268.40 6.436.10 6,334.50 -2,160.72 -2,084.42 5,966,393.70 560,231.73 3.37 -3,001.77 MWD-INC_0NLY(3) 7,640.00 85.84 275.60 6,437.88 6,336.28 -2,159.88 -2,108.32 5,966,394.34 560,207.82 29.93 -3,018.08 MWD-INC_ONLY(3) 7,673.94 88.43 286.18 6,439.58 6,337.98 -2,153.48 -2,141.56 5,9W,400.46 560,174.53 32.05 -3,037.06 MWD-INC _ONLY (3) 7,703.75 89.38 295.47 6,440.15 6,338.55 -2,142.90 -2,169.39 5,966,410.81 560,146.62 31.32 -3,049.25 MWD-INC_ONLY(3) 7,734.27 88.81 304.97 6,440.63 6,339.03 -2,127.56 -2,195.73 5,966,425.93 560,120.16 31.18 -3,057.02 MWD-INC _ONLY (3) 7,763.34 87.70 314.01 6,441.52 6,339.92 -2,109.10 -2,218.13 5,966,444.20 560,097.61 31.32 -3,059.81 MWD (4) 7,793.86 88.99 325.64 6,442.40 6,340.80 -2,085.83 -2,237.77 5,966,467.30 560,077.77 38.32 -3,057.25 MWD (4) 7,823.80 91.78 335.93 6,442.20 6,340.60 -2,059.74 -2,252.37 5,966,493.27 560,062.97 35.61 -3,049.12 MWD (4) 7,856.07 90.64 346.47 6,441.52 6,339.92 -2,029.24 -2,262.75 5,966,523.68 560,052.33 32.84 d,034.89 MWD (4) 7,883.82 90.92 355.55 6,441.14 6,339.54 -2,001.86 -2,267.08 5,966,551.02 560,047.77 32.73 -3,018.60 MWD (4) 7,914.08 90.89 5.76 6,440.66 6,339.06 -1,971.65 -2,266.73 5,966,581.23 560,047.87 33.74 -2,996.99 MWD (4) 7,943.90 89.69 14.71 6,440.51 6,338.91 -1,942.33 -2,261.44 5,966,610.59 560,052.92 30.28 -2,972.52 MWD (4) 7,976.26 90.18 24.59 6,440.55 6,338.95 -1,911.89 -2,250.57 5,966,641.11 560,063.53 30.57 -2,943.31 MWO(4) 8,011.36 90.95 34.95 6,440.20 6,338.60 -1,881.47 -2,233.17 5,966,671.68 560,080.68 29.60 -2,909.49 MWD (4) 8.034.16 90.43 42.28 6.439.92 6,338.32 -1,863.67 -2,218.95 5,966.689.59 560,094.75 32.23 -2,886.85 MWD (4) 8,063.64 90.89 52.27 6,439.58 6,337.98 -1,843.69 -2,197.32 5,966,709.75 560,116.21 33.92 -2,857.43 MWD (4) 8,092.88 90.12 62.41 6,439.33 6,337.73 -1,827.94 -2,172.74 5,966,725.71 560,140.66 34.78 -2,828.90 MWD (4) 8,112.69 89.26 68.99 6.439.43 6,337.83 -1,819.79 -2,154.69 5,966,734.00 560,158.63 33.50 -2,610.38 MWD (4) 8,139.53 88.83 78.93 6,439.88 6,338.28 -1,812.38 -2,128.94 5,966.741.62 560,184.33 37.06 -2,786.93 MWD (4) 8,175.68 88.25 84.37 6,440.80 6,339.20 -1,807.14 -2,093.19 5,965,747.16 560,220.02 15.13 -2,757.95 MWD (4) 8,208,48 88.25 89.20 6,441.80 6,340.21 -1,805.30 -2,060.47 5,966,749.27 560,252.72 14.72 -2,733.51 MWD (4) 8,237.56 87.08 90.82 6,442.99 6,341.39 -1,805.30 -2,031.42 5,966,749.51 560,281.77 6.87 -2,712.97 MWD(4) 8,268.74 86.52 93.37 6,444.73 6,343.13 -1,806.44 -2,000.31 5,966,748.63 560,312.89 8.36 -2,691.78 MWD (4) 8,297.00 87.88 96.46 6,446.11 6,344.51 -1,808.86 -1,972.19 5,966,746.44 560,341.02 11.93 -2,673.61 MWD(4) 8,327.69 90.58 99.82 6,446.52 6,344.92 -1,813.20 -1,941.82 5,966,742.35 560,371.43 14.04 -2,655.20 MWD (4) 8,357.47 90.58 99.30 6.446.22 6,344.62 -1,818.15 -1,912.45 5,966,737.65 560,400.83 1.75 -2,637.93 MWD (4) 8,391.38 90.49 98.48 6,445.91 6,344.31 -1,823.39 -1,878.95 5,966,732.69 560,434.37 2.43 -2,617.95 MWD (4) 8,418.43 90.43 97.64 6,445.69 6,344.09 -1,827.18 -1,852.17 5,966,729.12 560,461.10 3.11 -2,601.70 MWD (4) 8,449.50 91.14 96.62 6,445,26 6,343.66 -1,831.04 -1,821.35 5,966,725.52 560492.03 4.00 -2,582.62 MWD (4) Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 7/20/2018 2:16:01 PM Page 3 COMPASS 5000.14 Build 85 0 0 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1C-24 Project: Kuparuk River Unit TVD Reference: 1C-24: @ 101.60usft (lC-24:) Site: Kuparuk 1C Pad MD Reference: 1C-24: @ 101.60usft (1C-24:) Well: 1C-24 North Reference: True Wellbore: 1C-241-1 Survey Calculation Method: Minimum Curvature Design: 1C-241-1 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Asl TVD TVDSS +N1S *EJ-W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (-1100') Survey Tool Name (ft) (n) (h) 8,486.00 92.68 94.37 6,444.05 6,342.45 -1,834.53 -1,785.04 5,966,722.33 560,528.36 7.47 -2,559.42 MWD (4) 8,523.72 86.77 87.93 6,444.23 6,34263 -1,835.29 -1,747.36 5,9M,721.89 560,566.04 23.17 -2,533.32 MWD (4) 8,554.51 86.93 66.51 6,445.92 6,344.32 -1,833.80 -1,716.65 5,966,723.63 560,596.73 4.63 -2,510.55 MWD (4) 8,588.41 89.26 86.89 6,447.05 6,345.45 -1,831.85 -1,682.83 5,966,725.86 560,630.53 6.96 -2,485.25 MWD(4) 8,617.66 89.02 86.52 6,447.49 6,345.89 -1,830.17 -1,653.63 5,966,727.79 560,659.71 1.51 -2,463.42 MWD (4) 8,648.11 88.43 86.59 6,448.16 6,346.56 -1,828.34 -1,623.25 5,966,729.87 560,690.08 1.95 -2,440.64 MWD (4) 8,678.14 88.87 88.29 6,448.87 6,347.27 -1,827.00 -1,593.26 5,966,731.46 560,720.06 5.85 -2,418.48 MWD (4) 8,707.78 89.39 87.58 6,449.32 6,347.72 -1,825.93 -1,563.64 5,966,732.77 560,749.66 2.97 -2,396.79 MWD (4) 8,740.66 90.43 87.76 6,449.37 6,347.77 -1,824.59 -1,530.79 5,966,734.38 560,782.50 3.21 -2,372.61 MWD (4) 8,770.89 88.80 87.32 6,449.58 6,347.98 -1,823.29 -1,500.59 5,966.735.93 560,812.68 5.58 -2,350.34 MWD (4) 8,800.59 89.05 87.97 6,450.13 6,348.53 -1,822.07 -1,470.92 5,966,737.39 560,842.34 2.34 -2,328.50 MWD (4) 8,831.17 89.23 88.91 6,450.59 6,348.99 -1,821.24 -1,440.35 5,966,738.48 560,872.89 3.13 -2,306.29 MWD (4) 8,865.84 89.23 88.73 6,451.06 6,349.46 -1,820.53 -1,405.69 5,966,739.48 560,907.54 0.52 -2,281.28 MWD (4) 8,887.83 88.80 87.77 6,451.44 6,349.84 -1,819.86 -1,383.72 5,966,740.33 560,929.51 4.78 -2,265.27 MWD (4) 8,923.43 88.62 86.67 6,452.24 6,350.64 -1,618.13 -1,348.17 5,966,742.36 560,965.04 3.13 -2,238.91 MWD(4) 8,951.68 89.11 85.82 6,452.80 6,351.20 -1,816.28 -1,319.98 5,966,744.44 560,993.20 3.47 -2,217.67 MWD (4) 8,982.36 88.71 85.85 6,453.38 6,351.78 -1,814.05 -1,289.39 5,966,746.92 561,023.78 1.31 -2,194.47 MWD (4) 9,011.12 90.67 86.25 6,453.54 6,351.94 -1,812.07 -1,260.70 5,966,749.14 561,052.45 6.96 -2,172.78 MWD (4) 9,038.17 92.80 87.60 6,452.72 6,351.12 -1,810.62 -1,233.70 5,966,750.81 561,079.43 9.32 -2,152.66 MWD (4) 9,066.92 94.80 89.59 6,450.81 6,349.21 -1,809.92 -1,205.03 5,966,751.76 561,108.09 9.80 -2,131.89 MWD (4) 9,098.56 92.83 91.70 6,448.71 6,347.11 -1.810.27 -1,173.46 5,966,751.66 561,139.66 9.11 -2,109.82 MWD (4) 9,131.16 86.65 91.40 6.448.85 6,347.25 -1,811.15 -1,140.89 5,966,751.05 561,172.23 18.98 -2,087.41 MWD (4) 9,159.14 88.40 91.40 6,450.06 6,348.46 -1,811.94 -1,112.95 5,966,750.60 561,200.18 6.25 -2,068.14 MWD (4) 9,189.96 88.83 90.34 6,450.81 6,349.21 -1,812.30 -1.082.14 5,966,750.39 561,230.98 3.71 -2,046.68 MWD (4) 9,222.30 89.75 89.79 6,451.21 6,349.61 -1,812.34 -1.049.80 5,966,750.62 561,263.32 3.31 -2,023.84 MWD (4) 9,244.51 87.85 89.79 6,451.67 6,350.07 -1,812.26 -1.027.60 5,966,750.89 561,285.52 8.55 -2,008.08 MWD (4) 9,279.76 89.69 90.11 6,452.43 6,350.83 -1,812.23 -992.36 5,966,751.21 561,320.75 5.30 -1,983.14 MWD (4) 9,314.72 91.94 90.27 6,451.93 6,350.33 -1,812.34 -957.41 5,966,751.38 561,355.70 6.45 -1,958.51 MWD (4) 9,336.22 92.92 90.57 6,451.02 6,349.42 -1,812.50 -935.93 5,966,751.40 561,377.18 4.77 -1,943.43 MWD (4) 9,365.90 91.26 86.81 6,449.94 6,348.34 -1,811.82 -906.28 5,966,752.33 561.406.82 13.84 -1,921.99 MWD (4) 9,398.84 88.95 83.91 6,449,88 6,348,28 -1,809.16 -873.45 5.966,755.26 561439,62 11,26 -1, 896.89 MWD (4) 7/20)2018 2:16:01PM Page 4 Annotation COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well 1C-24 Project: Kuparuk River Unit TVD Reference: 1C-24: @ 101.60usft (1C-24:) Site: Kuparuk 1C Pad MD Reference: 1C-24: @ 101.60usft (1C-24:) Well: 1C-24 North Reference: True Wellbore: 1C-241-1 Survey Calculation Method: Minimum Curvature Design: 1 C-24L1 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS *E1-W Northing Easting DLS Section Survey Tool Name Annotation (usft) (1) (1 (usft) (use) (usft) (usft) (ft) (ft) (°1100.) (ft) 9,428.97 84.41 79.37 6,451.62 6,350.02 -1,804.79 -843.71 5,966.759.88 561,469.32 21.29 -1,872.77 MWD (4) ti9.456.01 12.12 17.47 6,414.71 6,111.11 -1,799.39 -817.33 5,966,M1.50 561,495.66 9.85 -1,850.29 MWD (4) 1.13.11 83.92 77.1 1.457.18 6,156.18 -1,191.37 190,47 5,966,771.75 111,51.1 5.11 -1,17.01 MWD (4) 9,523.62 89.97 76.75 6,460.10 6,358.50 -1,784.43 -751.74 5,966,781.00 561,561.11 15.25 -1,793.34 MWD (4) 9,554.44 89.72 76.24 6,460.19 6,358.59 -1,777.23 -721.77 5,966,788.45 561,591.01 1.84 -1,767.06 MWD (4) 9,580.06 88.53 74.80 6.460.58 6,358.98 -1,770.83 -696.97 5,966,795.06 561,615.76 7.29 -1,744.99 MWD (4) as 9,624.16 89.17 73.10 6,461.46 6,359.86 -1,758.64 -654.60 5,966,807.60 561,658.02 4.12 -1,706.41 MWD (4) 9,654.72 88.65 72.65 6,462.04 6,360A4 -1,749.64 -625.40 5,9%,816.84 561,687.15 2.25 -1,679.41 MWD (4) 9,669.02 88.43 72.14 6,462.41 6,360.81 -1,745.31 -611.77 5,966,821.27 561,700.73 3.88 -1,666.71 MWD (4) 9,718.69 89.48 72.25 6,463.31 6,361.71 -1,730.13 564.49 5,966,836.85 551,747.88 2.13 -1.622.54 MWD (4) I 9,762.59 90.03 70.73 6,463.50 6,361.90 -1,716.19 522.86 5,966,851.13 561,789.39 3.68 -1.583.25 MWD (4) y9,823.38 90.06 68.74 6,463.45 6,361.85 -1,695.14 -465.84 5,966,872.65 561,846.23 3.27 -1,528.04 MWD (4) 4 9,858.75 90.28 67.18 6,463.35 6,361.75 -1,681.87 -433.06 5,966,886.20 561,878.90 4.45 -1,495.48 MWD (4) f 9,908.71 90.22 65.73 6,463.13 6,361.53 -1,661.91 -387.26 5,966,906.53 561,924.53 2.90 -1,448.98 MWD (4) i@g 9,961.08 90.18 61.66 6,462.95 6,361.35 -1,638.71 -340.32 5,966.930.12 561,971.27 7.77 -1,399.38 MWD (4) 9,996.06 89.97 62.87 6,462.90 6,361.30 -1,622.43 509.36 5,966,946.65 562.002.09 3.51 -1,365.98 MWD (4) 10,025.92 90.83 63.69 6,462.69 6,361.09 -1,609.00 -282.69 5,966.960.30 562,028.64 3.98 -1,337.63 MWD (4) 10,053.05 90.92 66.37 6,462.28 6,360.68 -1,597.55 -258.10 5,966,971.95 562,053.13 9.88 -1,312.15 MWD (4) 10,085.98 90.37 65.44 6,461.91 6,360.31 -1,584.11 -228.04 5,966,985.64 562,083.08 3.28 -1,281.39 MWD (4) 10,115.70 90.49 64.59 6,461.69 6,360.09 -1,571.56 -201.10 5,966,998.42 562,109.91 2.89 -1.253.46 MWD (4) 10,145.37 90.58 61.53 6,461.41 6,359.81 -1,558.12 -174.66 5,967,012.08 562,136.24 10.32 -1,225.26 MWD (4) 'y 10,179.86 90.37 59.09 6,461.12 6,359.52 -1,541.04 -144.70 5,967,029.40 562,166.D5 7.10 -1,192.00 MWD (4) 10,214.08 92.09 56.00 6,460.39 6,358.79 -1,522.68 -115.84 5,967,048.00 562,194.76 10.33 -1,158.61 MWD (4) 10,249.36 YYY 100.13 57.33 6,456.64 6,355.04 -1,503.42 -86.55 5,967,067.50 562223.88 23.09 -1,124.28 MWD (4) 10,300.08 100.32 65.74 6,447.62 6,346.02 -1,479.65 -42.72 5,967,091.63 562,267.51 16.32 -1,076.47 MWD (4) 10,312.74 99.93 68.13 6,445.39 6,343.79 -1,474.77 -31.25 5,967,096.61 562,278.94 18.84 -1,064.91 MWD (4) 10,337.86 99.43 71.86 6,441.16 6,339.56 -1,466.30 -7.99 5,967,105.27 562,302.13 14.77 -1,042.48 MWD (4) 10,368.61 98.12 74.30 6,436.47 6,334.87 -1,457.45 21.09 5,967,114.35 562,331.12 8.92 -1,015.67 MWD (4) 10,398.74 96.46 75.14 6,432.65 6,331.05 -1,449.58 49.91 5,967, 122.46 562,359.88 6.16 -989.71 MWD (4) 10,428.25 94.48 71.81 6,429.84 6,328.24 -1,441.22 78.07 5,967, 131.05 562.387.96 13.08 -963.89 MWD (4) 10,458.26 91.66 70.52 6428,23 6,326.63 -1,431.55 106.43 5.967.140.96 562A16.24 10.33 -937.00 MWD (4) 7202018 2:16:01PM Page 5 COMPASS 5000.14 Build 85 0 0 ConocoPhillips Definitive Survey Report U Company: ConocoPhillips (Alaska) Inc. -Kupt Local Coordinate Reference: Well 1C-24 Project: Kuparuk River Unit TVD Reference: 1C-24: @ 101.60usft (1C-24:) Site: Kuparuk 1C Pad MD Reference: 1C-24: @ 101.60usft (1C-24:) Well: 1C-24 North Reference: True Wellbore: 1C-2411 Survey Calculation Method: Minimum Curvature Design: 1C-2411 Database: EDT Alaska Sandbox Survey Map Map Vertical MD Inc An TVD TVDSS +NIS +El-W Northing ng E DLS Section (ustt) (°) (°) (usft) (usft) (ustt) (ustt) (°I100-) SurveyTool Name Annotation (ft) (ft) (ft) 10,488.74 88.31 69.89 6,428.24 6,326.64 -1,421.23 135.10 5,967,151.52 562,444.82 11.18 -909.43 MWD (4) 10,526.33 85.43 67.63 6,430.29 6,328.69 -1,407.63 170.08 5,967,165.40 562,479.69 9.73 -875.08 MWD (4) 10,554.31 85.18 64.05 6,432.58 6,330.98 -1,396.22 195.52 5,967,177.02 562,505.03 12.78 -849.02 MWD (4) 10,588.74 85.63 59.02 6,435.34 6,333.74 -1,379.87 225.68 5,967,193.62 562,535.05 14.62 -816.13 MWD (4) 10,619.48 88.56 60.18 6.436.90 6,335.30 -1,364.34 252.16 5,967,209.37 562,561.39 10.25 -786.43 MWD (4) 10,654.56 87.51 55.42 6.438.10 6,336.50 -1,345.66 281.82 5,967,228.29 562,590.89 13.89 -752.25 MWD (4) 10,695.39 89.48 58.48 6,439.17 6,337.57 -1.323.41 316.02 5,967,250.83 562,624.91 8.91 -712.33 MWD (4) 10,744.36 87.26 63.02 6,440.57 6,338.97 -1,299.49 358.72 5,967,275.09 562,667.40 10.32 -665.23 MWD (4) 10,773.92 92.61 69.94 6,440.60 6,339.00 -1,287.71 385.80 5,967,287.10 562,694.38 29.58 -637.75 MWD (4) 10,808.60 90.83 72.02 6,439.56 6,337.96 -1,276.41 418.56 5,967,298.67 562,727.05 7.89 £06.59 MWD (4) 10,834.90 89.85 74.86 6,439.40 6,337.80 -1,268.92 443.77 5,967,306.37 562,752.19 11.42 -583.47 MWD (4) 10,862.65 89.82 78.80 6,439.48 6,337.88 -1,262.60 470.78 5,967,312.92 562,779.14 14.20 -559.90 MWD (4) 10,893.79 90.61 80.45 6,439.37 6,337.77 -1,256.99 501.41 5,967,318.78 562,809.72 5.87 -534.27 MWD (4) 10,924.01 90.95 80.14 6,438.96 6,337.36 -1,251.90 531.20 5.967,324.12 562,839.46 1.52 -509.61 MWD (4) 10,948.82 90.92 79.36 6,438.55 6,336.95 -1,247.48 555.61 5,967,328.73 562,863.83 3.15 -489.23 MWD (4) 10,973.82 91.45 80.41 6,438.03 6,336.43 -1,243.09 580.22 5,967,333.33 562,888.40 4.70 -468.72 MWD (4) 11,003.66 90.34 81.28 6,437.57 6,335.97 -1,238.34 609.67 5,967,338.32 562,917.81 4.73 -444.54 MWD (4) 11,035.23 90.40 79.02 6,437.36 6,335.76 -1,232.94 640.77 5,967,343.98 562,948.86 7.16 418.73 MWD (4) 11,076.80 90.46 77.85 6,437.05 6,335.45 -1,224.61 681.50 5,967,352.65 562,989.51 2.82 -384.04 MWD (4) 11,117.08 90.55 76.78 6,436.70 6,335.10 -1,215.77 720.79 5,967,361.82 563,028.73 2.67 -350.00 MWD (4) 11,153.49 90.86 75.97 6,436.25 6,334.65 -1,207.19 756.17 5,967,370.68 563,064.04 2.38 -318.92 MWD (4) 11,183.21 90.40 75.43 6,435.92 6,334.32 -1,199.85 784.97 5,967,378.26 563,092.77 2.39 -293.36 MWD (4) 11,220.18 89.97 74.81 6,435.80 6,334.20 -1,190.36 820.70 5,967,388.05 563,128.42 2.04 -261.39 MWD (4) 11.249.53 90.31 74.60 6,435.73 6,334.13 -1,182.61 849.01 5,967,396.03 563,156.66 1.36 -235.89 MWD (4) 11,279.79 90.22 75.37 6,435.59 6,333.99 -1,174.77 878,24 5,967,404.11 563,185.82 2.56 -209.68 MWD (4) 11,310.67 9D.18 76.58 6,435.48 6,333.88 -1,167.29 908.20 5,967,411.84 563,215.71 3.92 -183.21 MWD (4) 11,335.16 89.66 75.36 6,435.52 6,333.92 -1,161.35 931.96 5,967,417.97 563,239.41 5.42 -162.21 MWD (4) 11,362.58 90.12 73.81 6,435.57 6,333.97 -1,154.07 958.39 5,967,425.48 563,265.78 5.90 -138.37 MWD(4) 11,401.00 90.12 73.81 6,435.49 6,333.89 -1,143.35 995.28 5,967,436.50 563,302.59 0.00 -104.70 PROJECTED to TD 720/2018 2:16:01PM Page 6 COMPASS 5000.14 Build 85 0 BAJCER 0 PRINT DISTRIBUTION LIST � ��ur UGHES a GE company COMPANY ConocoPhillips Alaska, Inc. WELL NAME IC-24L1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Ridergbakerhughes.com 21 8002 29543 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE July 9, 2018 TODAYS DATE July 24, 2018 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 4 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn. Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 [tate of Alaska - AOGC1 Attn: Natural Resources 333 W. 7th Ave, Suite 10, Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alasim) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Rev. Requested by: --- FIELD I FINAL CD/DVD FINAL PRELIM (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES 1#0FCOPIES v 0 0 0 0 0 RECEIVE® 1 0 1 0 1 1 1 0 1 0 1 0 1 1 I 0 I 0 TOTALS FOR THIS PAGE: 0 1 To: 0 21 8002 29541 Letter of Transmittal Date: July 20, 2018 Meredith Guhl AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 From: Yosha Ragbirsingh / Michael Soper Baker Hughes, a GE Company 795 East 94' Avenue Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): IL-23L1 1L-23L1-02 1C-24L1 RECEIVED JUL 2 4 2018 AOGCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BHGE.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BHGE.com ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1 C-24L1 50-029-23063-60 Baker Hughes INTEQ Definitive Survey Report 20 July, 2018 UGHES a GE company 0 • ConocoPhillips )mpany: ' ConocoPhillips (Alaska) Inc. -Kupl 'oject: Kuparuk River Unit te: Kuparuk 1C Pad all: 1 C-24 ellbore: 1 C-24L1 a gn: 1C-2411 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well 1 C-24 TVD Reference: 1C-24: @ 101.60usft (1C-24:) MD Reference: 1C-24: @ 101.60usft (1C-24:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox oject Kuparuk River Unit, North Slope Alaska, United States ap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ao Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ap Zone: Alaska Zone 04 Using geodetic scale factor S F�U�CaHES GEmmpeiry ell 1 C-24 ell Position +N/-S 0.00 usft Northing: 5,968,571.44 usft Latitude: 700 19' 28.773 N +E/-W 0.00 usft Easting: 562,297.94 usft Longitude: 1490 29' 41.445 W )sition Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft ■lkY�kVLTfK v e�,% i — _ IY�n##IC>fIkadi►dg��t��ltiy�RtB Declination Dip Angle Field Strength _ g 1 _ V) (°) (nT) BGGM2017 7/1/2018 17.05 80.91 57,464 Design 1C-241-1 y� Audit Notes: From To Survey Survey (usft) (usft) Survey (Wellbore) Tool Name Description Start Date End Date 83.00 349.10 1C-24 GYRO (1C-24) CB -GYRO -SS Camera based gyro single shot 2/5/2002 480.38 7,562.49 1C-24(1C-24) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 2/5/2002 7,616.00 7,734.27 1C-241-1 MWD-INC (1C-241-1) MWD-INC_ONLY MWD-INC_ONLY_FILLER 7/1/2018 7/1/2018 7,763.34 11,362.58 1C-24L1MWD(1C-241-1) MWD MWD- Standard 7/1/2018 7/9/2018 712012018 2:16:01PM Page 2 COMPASS 5000.14 Build 85 0 � • ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 1C Pad MD Reference: Well: 1 C-24 North Reference: Wellbore: 1C-241-1 Survey Calculation Method: Design: 1 C-24L1 Database: �y - l ROO Map MD Inc Azi TVD TVDSS +N/-S +E/-W Northing (usft) V) (1) (usft) (usft) (usft) (usft) (ft) 7,562.49 84.70 266.88 6,431.61 6,330.01 -2,158.52 -2,031.15 5,966,396.34 7,616.00 85.68 268.40 6,436.10 6,334.50 -2,160.72 -2,084.42 5,966,393.70 7,640.00 85.84 275.60 6,437.88 6,336.28 -2,159.88 -2,108.32 5,966,394.34 7,673.94 88A3 286.18 6,439.58 6,337.98 -2,153.48 -2,141.56 5,966,400.46 7,703.75 89.38 295.47 6,440.15 6,338.55 -2,142.90 -2,169.39 5,966,410.81 7,734.27 88.81 304.97 6,440.63 6,339.03 -2,127.56 -2,195.73 5,966,425.93 7,763.34 87.70 314.01 6,441.52 6,339.92 -2,109.10 -2,218.13 5,966,444.20 7,793.86 88.99 325.64 6,442.40 6,340.80 -2,085.83 -2,237.77 5,966,467.30 7,823.80 91.78 335.93 6,442.20 6,340.60 -2,059.74 -2,252.37 5,966,493.27 7,856.07 90.64 346.47 6,441.52 6,339.92 -2,029.24 -2,262.75 5,966,523.68 7,883.82 90.92 355.55 6,441.14 6,339.54 -2,001.86 -2,267.08 5,966,551.02 7,914.08 90.89 5.76 6,440.66 6,339.06 -1,971.65 -2,266.73 5,966,581.23 7,943.90 89.69 14.71 6,440.51 6,338.91 -1,942.33 -2,261.44 5,966,610.59 7,976.26 90.18 24.59 6,440.55 6,338.95 -1,911.89 -2,250.57 5,966,641.11 8,011.36 90.95 34.95 6,440.20 6,338.60 -1,881.47 -2,233.17 5,966,671.68 8,034.16 90.43 42.28 6,439.92 6,338.32 -1,863.67 -2,218.95 5,966,689.59 8,063.64 90.89 52.27 6,439.58 6,337.98 -1,843.69 -2,197.32 5,966,709.75 8,092.88 90.12 62.41 6,439.33 6,337.73 -1,827.94 -2,172.74 5,966,725.71 8,112.69 89.26 68.99 6,439.43 6,33T83 -1,819.79 -2,154.69 5,966,734.00 8,139.53 88.83 78.93 6,439.88 6,338.28 -1,812.38 -2,128.94 5,966,741.62 8,175.68 88.25 84.37 6,440.80 6,339.20 -1,807.14 -2,093.19 5,966,747.16 8,208.48 88.25 89.20 6,441.80 6,340.21 -1,805.30 -2,060.47 5,966,749.27 8,237.56 87.08 90.82 6,442.99 6,341.39 -1,805.30 -2,031.42 5,966,749.51 8,268.74 86.52 93.37 6,444.73 6,343.13 -1,806.44 -2,000.31 5,966,748.63 8,297.00 87.88 96.46 6,446.11 6,344.51 -1,808.86 -1,972.19 5,966,746.44 8,327.69 90.58 99.82 6,446.52 6,344.92 -1,813.20 -1,941.82 5,966,742.35 8,357.47 90.58 99.30 6,446.22 6,344.62 -1,818.15 -1,912.45 5,966,737.65 8,391.38 90.49 98.48 6,445.91 6,344.31 -1,823.39 -1,878.95 5,966,732.69 8,418.43 90.43 97.64 6,445.69 6,344.09 -1,827.18 -1,852.17 5,966,729.12 8,449.50 91.14 96.62 6,445.26 6,343.66 -1,831.04 -1,821.35 5,966,725.52 5A%U 0 Well 1 C-24 1 C-24: @ 101.60usft (1 C-24:) 1 C-24: @ 101.60usft (1 C-24:) True Minimum Curvature EDT Alaska Sandbox Map Vertical Easting DLS (°/100') Section Survey Tool Name Annotation (ft) (ft) j 560,284.98 2.80 -2,962.54 MWD-INC-ONLY(3) TIP ) 560,231.73 3.37 -3,001.77 MWD-INC_ONLY (3) KOP 560,207.82 29.93 -3,018.08 MWD-INC_ONLY (3) Interpolated Azimuth 560,174.53 32.05 -3,037.06 MWD-INC-ONLY (3) Interpolated Azimuth 560,146.62 31.32 -3,049.25 MWD-INC-ONLY(3) Interpolated Azimuth 560,120.16 31.18 -3.057.02 MWD-INC_ONLY (3) Interpolated Azimuth 560,097.61 31.32 -3.059.81 MWD (4) 560,077.77 38.32 -3,057.25 MWD (4) 560,062.97 35.61 -3,049.12 MWD (4) 560,052.33 32.84 -3,034.89 MWD (4) 560,047.77 32.73 -3,018.60 MWD (4) 560,047.87 33.74 -2,996.99 MWD (4) 560,052.92 30.28 -2,972.52 MWD (4) 560,063.53 30.57 -2,943.31 MWD (4) 560,080.68 29.60 -2,909.49 MWD (4) 560,094.75 32.23 -2,886.85 MWD (4) 560,116.21 33.92 -2,857.43 MWD (4) 560,140.66 34.78 -2,828.90 MWD (4) 560,158.63 33.50 -2,810.38 MWD (4) 560,184.33 37.06 -2,786.93 MWD (4) 560,220.02 15.13 -2,757.95 MWD (4) 560,252.72 14.72 -2.733.51 MWD (4) 560,281.77 6.87 -2,712.97 MWD (4) ) 560,312.89 8.36 -2,691.78 MWD (4) 560,341.02 11.93 -2,673.61 MWD (4) 560,371.43 14.04 -2,655.20 MWD (4) 560,400.83 1.75 -2,637.93 MWD (4) 560,434.37 2.43 -2,617.95 MWD (4) 560,461.18 3.11 -2,601.70 MWD (4) 560,492.03 4.00 -2,582.62 MWD (4) 7/20/2018 2:16:01PM Page 3 COMPASS 5000.14 Build 85 C J • ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1 C-24 Project: Kuparuk River Unit TVD Reference: 1 C-24: @ 101.60usft (1 C-24:) Site: Kuparuk 1C Pad MD Reference: 1C-24: @ 101.60usft (1C-24:) Well: 1C-24 North Reference: True Wellbore: 1C-24L1 Survey Calculation Method: Minimum Curvature Design: 1C-2411 Database: EDT Alaska Sandbox Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +E/-W Northing East) DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (low) Survey Tool Name Ann _ a (ft) (ft) (ft) 8,486.00 9268 94.37 6,444.05 6,342.45 -1,834,53 -1,785.04 5,966,722+33 560,528.36 7.47 -2,559.42 MWD (4) 8,523.72 86.77 87.93 6,444.23 6,342.63 -1,835.29 -1,747.36 5,966,721.89 560,566.04 23.17 -2,533.32 MWD (4) 8,554.51 86.93 86.51 6,445.92 6,344.32 -1,833.80 -1,716.65 5,966,723.63 560,596.73 4.63 -2,510.55 MWD (4) 8,588.41 89.26 86.89 6,447.05 6,345.45 -1,831.85 -1,682.83 5,966,725.86 560,630.53 6.96 -2,485.25 MWD (4) 8,617.66 89.02 86.52 6,447.49 6,345.89 -1,830.17 -1,653.63 5,966,727.79 560,659.71 1.51 -2,463.42 MWD (4) 8,648.11 88.43 86.59 6,448.16 6,346.56 -1,828.34 -1,623.25 5,966,729.87 560,690.08 1.95 -2,440,64 MWD (4) 8,678.14 88.87 88.29 6,448.87 6,347.27 -1,827.00 -1,593.26 5,966,731.46 560,720.06 5.85 -2,418.48 MWD (4) 8,707.78 89.39 87.58 6,449.32 6,347.72 -1,825.93 -1,563.64 5,966,732.77 560,749+66 2.97 -2,396.79 MWD (4) 8,740.66 90.43 87.76 6,449.37 6,347.77 -1,824.59 -1,530.79 5,966,734.38 560,782.50 3.21 -2,372.61 MWD (4) 8,770.89 88.80 87.32 6,449.58 6,347.98 -1,823.29 -1,500.59 5,966,735.93 560,812.68 5.58 -2,350.34 MWD (4) 8,800.59 89.05 87.97 6,450.13 6,348.53 -1,822.07 -1,470.92 5,966,737.39 560,842.34 2.34 -2,328.50 MWD (4) 8,831.17 89.23 88.91 6,450.59 6,348.99 -1,821.24 -1,440.35 5,966,738.48 560,872.89 3.13 -2,306.29 MWD (4) 8,865.84 89.23 88.73 6,451.06 6,349.46 -1,820.53 -1,405.69 5,966,739.48 560,907.54 0.52 -2,281.28 MWD (4) 8,887.83 88.80 87.77 6,451.44 6,349.84 -1,819.86 -1,383.72 5,966,740.33 560,929.51 4.78 -2,265.27 MWD (4) 8,923.43 88.62 86.67 6,452.24 6,350.64 -1,818.13 -1,348.17 5,966,742.36 560,965.04 3.13 -2,238.91 MWD (4) 8,951.68 89.11 85.82 6,452.80 6,351.20 -1,816.28 -1,319.98 5,966,744.44 560,993.20 3.47 -2,217.67 MWD (4) 8,982.36 88.71 85.85 6,453.38 6,351.78 -1,814.05 -1,289.39 5,966,746.92 561,023.78 1.31 -2,194.47 MWD (4) 9,011.12 90.67 86.25 6,453.54 6,351.94 -1,812.07 -1,260.70 5,966,749.14 561,052.45 6.96 -2,172.78 MWD (4) 9,038.17 92.80 87.60 6,452.72 6,351.12 -1,810.62 -1,233.70 5,966,750.81 561,079.43 9.32 -2,152.66 MWD (4) 9,066.92 94.80 89.59 6,450.81 6,349.21 -1,809.92 -1,205.03 5,966,751+76 561,108.09 9.80 -2,131.89 MWD (4) 9,098.56 92.83 91.70 6,448.71 6,347.11 -1,810.27 -1,173+46 5,966,751.66 561,139.66 9.11 -2,109.82 MWD (4) 9,131.16 86.65 91.40 6,448.85 6,347.25 -1,811.15 -1,140.89 5,966,751.05 561,172.23 18.98 -2,087.41 MWD (4) 9,159.14 88.40 91.40 6,450.06 6,348.46 -1,811.84 -1,112.95 5,966,750.60 561,200.18 6.25 -2,068.14 MWD (4) 9,189.96 88.83 90.34 6,450.81 6,349.21 -1,812.30 -1,082.14 5,966,750.39 561,230.98 3.71 -2,046.68 MWD (4) 9,222.30 89.75 89.79 6,451.21 6,349.61 -1,812.34 -1,049.80 5,966,750.62 561,263.32 3.31 -2,023.84 MWD (4) 9,244.51 87.85 89.79 6,451.67 6,350.07 -1,812.26 -1,027.60 5,966,750.89 561,285.52 8.55 -2,008.08 MWD (4) 9,279.76 89.69 90.11 6,452.43 6,350.83 -1,812.23 -992.36 5,966,751.21 561,320.75 5.30 -1,983.14 MWD (4) 9,314.72 91.94 90.27 6,451.93 6,350.33 -1,812.34 -957.41 5,966,751.38 561,355.70 6.45 -1,958.51 MWD (4) 9,336.22 92.92 90.57 6,451.02 6,349.42 -1,812.50 -935.93 5,966,751.40 561,377.18 4.77 -1,943.43 MWD (4) 9,365.90 91.26 86.81 6,449.94 6,348.34 -1,811.82 -906.28 5,966,752.33 561,406.82 13.84 -1,921.99 MWD (4) 9,398,84 88.95 83.91 6,449.88 6,348.28 -1,809.16 -873.45 5,966,755.26 561,439.62 11.26 -1,896.89 MWD (4) 712012018 2:16:01PM Page 4 BAFUGHES COMPASS 5000.14 Build 85 C] • ConocoPhillips 13A ER ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well 1C-24 Project: Kuparuk River Unit TVD Reference: 1 C-24: @ 101.60usft (1 C-24:) Site: Kuparuk 1C Pad MD Reference: 1C-24: @ 101.60usft (1C-24:) Well: 1C-24 North Reference: True Wellbore: 1C-241-1 Survey Calculation Method: Minimum Curvature Design: 1C-241-1 Database: EDT Alaska Sandbox mN Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section Survey Tool Name Annotation(usft) (°) (°) (usft) (usft) (usft) (usft) O (ft) (°/100') (ft) 9,428+97 84.41 79.37 6,451.62 6,350.02 -1,804.79 -843.71 5,966,759,88 561,469.32 21.29 -1,872.77 MWD (4) 9,456.08 82.52 77.47 6,454.71 6,353.11 -1.799.39 -817.33 5,966,765.50 561,495.66 9.85 -1,850.29 MWD (4) 9,483.80 83.92 77.26 6,457.98 6,356.38 -1.793.37 -790.47 5,966,771.75 561,522.46 5.11 -1,827.05 MWD (4) 9,523.62 89.97 76.75 6,460.10 6,358.50 -1,784.43 -751.74 5,966,781.00 561,561.11 15.25 -1,793.34 MWD (4) 9,554.44 89.72 76.24 6,460.19 6,358.59 -1,777.23 -721.77 5,966,788.45 561,591.01 1.84 -1,767.06 MWD (4) 9,580.06 88.53 74.80 6,460.58 6,358.98 -1,770.83 -696.97 5,966,795.06 561,615.76 7.29 -1,744.99 MWD (4) 9,624.16 89.17 73.10 6,461.46 6,359.86 -1,758.64 -654.60 5,966,807.60 561,658.02 4.12 -1,706.41 MWD (4) 9,654.72 88.65 72.65 6,462.04 6,360.44 -1,749.64 -625.40 5,966,816.84 561,687.15 2.25 -1,679.41 MWD (4) 9,669.02 88.43 72.14 6,462.41 6,360.81 -1,745.31 -611.77 5,966,821.27 561,700.73 3.88 -1,666.71 MWD (4) 9,718.69 89.48 72.25 6,463.31 6,361.71 -1,730.13 -564.49 5,966.836.85 561,747.88 2.13 -1,622.54 MWD (4) 9,762.59 90.03 70.73 6,463.50 6,361.90 -1,716.19 -522.86 5,966,851.13 561,789.39 3.68 -1,583.25 MWD (4) 9,823.38 90.06 68.74 6,463.45 6,361.85 -1,695.14 -465.84 5,966,872.65 561,846.23 3.27 -1,528.04 MWD (4) 9,858.75 90.28 67.18 6,463.35 6,361.75 -1,681.87 -433.06 5,966,886.20 561,878.90 4.45 -1,495.48 MWD (4) 9,908.71 90.22 65.73 6,463.13 6,361.53 -1,661.91 -387.26 5,966,906.53 561,924.53 2.90 -1,448.98 MWD (4) 9,961.08 90.18 61.66 6,462.95 6,361.35 -1,638.71 -340.32 5,966,930.12 561,971.27 7.77 -1,399.38 MWD (4) 9,996.06 89.97 62.87 6,462.90 6,361.30 -1,622.43 -309.36 5,966,946.65 562.002.09 3.51 -1,365.98 MWD (4) 10,025.92 90.83 63.69 6,462.69 6,361.09 -1,609.00 -282.69 5,966,960.30 562,028.64 3.98 -1,337.63 MWD (4) 10,053.05 90.92 66.37 6,462.28 6,360.68 -1,597.55 -258.10 5,966,971.95 562,053.13 9.88 -1,312.15 MWD (4) 10,085.98 90.37 65.44 6,461.91 6,360.31 -1,584.11 -228.04 5,966,985.64 562,083.08 3.28 -1,281.39 MWD (4) 10,115.70 90.49 64.59 6,461.69 6,360.09 -1,571.56 -201.10 5,966,998.42 562,109.91 2.89 -1,253.46 MWD (4) 10,145.37 90.58 61.53 6,461.41 6,359.81 -1,558.12 -174.66 5,967,012.08 562,136.24 10.32 -1,225.26 MWD (4) 10,179.86 90.37 59.09 6,461.12 6,359.52 -1,541.04 -144.70 5,967,029.40 562,166.05 7.10 -1,192.00 MWD (4) 10,214.08 92.09 56.00 6,460.39 6,358.79 -1,522.68 -115.84 5,967,048.00 562,194.76 10.33 -1,158.61 MWD (4) 10,249.36 100.13 57.33 6,456.64 6,355.04 -1,503.42 -86.55 5,967,067.50 562,223.88 23.09 -1,124.28 MWD (4) 10,300.08 100.32 65.74 6,447.62 6,346.02 -1,479.65 42.72 5,967,091.63 562,267.51 16.32 -1,076.47 MWD (4) 10,312.74 99.93 68.13 6,445.39 6,343.79 -1,474.77 -31.25 5,967,096.61 562,278.94 18.84 -1,064.91 MWD (4) 10,337.86 99.43 71.86 6,441.16 6,339.56 -1,466.30 -7.99 5,967,105.27 562,302.13 14.77 -1,042.48 MWD (4) 10,368.61 98.12 74.30 6,436.47 6,334.87 -1,457.45 21.09 5,967,114.35 562,331.12 8.92 -1,015.67 MWD (4) 10,398.74 96.46 75.14 6,432.65 6,331.05 -1,449.58 49.91 5,967,122.46 562,359.88 6.16 -989.71 MWD (4) 10,428.25 94A8 71.81 6,429.84 6,328.24 -1,441.22 78.07 5,967,131.05 562,387.96 13.08 -963.89 MWD (4) 10,458.26 91.66 70.52 6,428.23 6,326.63 -1,431.55 106.43 5,967,140.96 562,416.24 10.33 -937.00 MWD (4) 7/20/2018 2:16:01PM Page 5 COMPASS 5000.14 Build 85 • ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit r Site: Kuparuk 1C Pad Well: 1 C-24 Wellbore: 1 C-24L1 Design: 1 C-24L1 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: Well 1C-24 TVD Reference: 1 C-24: @ 101.60usft (1 C-24:) MD Reference: 1C-24: @ 101.60usft (1C-24:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT Alaska Sandbox Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section Survey Tool Name (usft) C) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) 10,488.74 88.31 69.89 6,428,24 6,326.64 -1,421.23 135.10 5,967,151.52 562,444.82 11.18 -909.43 MWD (4) 10,526.33 85.43 67.63 6,430.29 6,328.69 -1,407.63 170.08 5,967,165.40 562,479.69 9.73 -875.08 MWD (4) 10,554.31 85.18 64.05 6,432.58 6,330.98 -1,396.22 195.52 5,967,177.02 562,505.03 12.78 -849.02 MWD (4) 10,588.74 85.63 59.02 6,435.34 6,333.74 -1,379.87 225.68 5,967,193.62 562,535.05 14.62 -816.13 MWD (4) 10,619.48 88.56 60.18 6,436.90 6,335.30 -1,364.34 252.16 5,967,209.37 562,561.39 10.25 -786.43 MWD (4) 10,654.56 87.51 55.42 6,438.10 6,336.50 -1,345.66 281.82 5,967,228.29 562,590.89 13.89 -752.25 MWD (4) 10,695.39 89.48 58.48 6,439.17 6,337.57 -1,323.41 316.02 5,967,250.83 562,624.91 8.91 -712.33 MWD (4) 10,744.36 87.26 63.02 6,440.57 6,338.97 -1,299.49 358.72 5,967,275.09 562,667.40 10.32 -665.23 MWD (4) 10,773.92 92.61 69.94 6,440.60 6,339.00 -1,287.71 385.80 5,967,287.10 562,694.38 29.58 -637.75 MWD (4) 10,808.60 90.83 72.02 6,439.56 6,337.96 -1,276.41 418.56 5,967,298.67 562,727.05 7.89 -606.59 MWD (4) 10,834.90 89.85 74.86 6,439.40 6,337.80 -1,268.92 443.77 5,967,306.37 562,752.19 11.42 -583.47 MWD (4) 10,862.65 89.82 78.80 6,439.48 6,337.88 -1,262.60 470.78 5,967,312.92 562,779.14 14.20 -559.90 MWD (4) 10,893.79 90.61 80.45 6,439.37 6,337.77 -1,256.99 501.41 5,967,318.78 562,809.72 5.87 -534.27 MWD (4) 10,924.01 90.95 80.14 6,438.96 6,337.36 -1,251.90 531.20 5,967,324.12 562,839.46 1.52 -509.61 MWD (4) 10,948.82 90.92 79.36 6,438.55 6,336.95 -1,247.48 555.61 5,967,328.73 562,863.83 3.15 -489.23 MWD (4) 10,973.82 91.45 80.41 6,438.03 6,336.43 -1,243.09 580.22 5,967.333.33 562,888.40 4.70 -468.72 MWD (4) 11,003.66 90.34 81.28 6,437.57 6,335.97 -1,238.34 609.67 5,967,338.32 562,917.81 4.73 -444.54 MWD (4) 11,035.23 90.40 79.02 6,437.36 6,335.76 -1,232.94 640.77 5,967,343.98 562,948.86 7.16 -418.73 MWD (4) 11,076.80 90.46 77.85 6,437.05 6,335.45 -1,224.61 681.50 5,967,352.65 562,989.51 2.82 -384.04 MWD (4) 11,117.08 90.55 76.78 6,436.70 6,335.10 -1,215.77 720.79 5,967,361.82 563,028.73 2.67 -350.00 MWD (4) 11,153.49 90.86 75.97 6,436.25 6,334.65 -1,207.19 756.17 5,967,370.68 563,064.04 2.38 -318.92 MWD (4) 11,183.21 90.40 75.43 6,435.92 6,334.32 -1,199.85 784.97 5,967,378.26 563,092.77 2.39 -293.36 MWD (4) 11,220.18 89.97 74.81 6,435.80 6,334.20 -1,190.36 820.70 5,967,388.05 563,128.42 2.04 -261.39 MWD (4) 11.249.53 90.31 74.60 6,435.73 6,334.13 -1,182.61 849.01 5,967,396.03 563,156.66 1.36 -235.89 MWD (4) 11,279.79 90.22 75.37 6,435.59 6,333.99 -1,174.77 878.24 5,967,404.11 563,185.82 2.56 -209.68 MWD (4) 11,310.67 90.18 76.58 6,435.48 6,333.88 -1,167.29 908.20 5,967,411.84 563,215.71 3.92 -183.21 MWD (4) 11,335.16 89.66 75.36 6,435.52 6,333.92 -1,161.35 931.96 5,967,417.97 563,239A1 5.42 -162.21 MWD (4) 11,362.58 90,12 73.81 6,435.57 6,333.97 -1,154.07 958.39 5,967,425.48 563,265.78 5.90 -138.37 MWD (4) 11,401.00 90.12 73.81 6,435.49 6,333.89 -1,143.35 995.28 5,967,436.50 563,302.59 0.00 -104.70 PROJECTED to TO Annotation B ERHES 712012018 2:16:01PM Page 6 COMPASS 5000.14 Build 85 • 0 0 p7-0 ;�/8-o0Z. Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Wednesday, April 11, 2018 8:37 AM To: Loepp, Victoria T (DOA) Subject: 1C-24 (PTD 218-002) PTD Revision Follow Up Flag: Follow up Flag Status: Flagged Good morning Victoria, As we discussed on the phone, we have decided to change the drilled hole size on our upcoming 1C-24 CTD well (PTD # 218-002). We will be drilling a 3" hole instead of the planned 4-1/4" hole, and running a 2-3/8" liner instead of the planned 2-7/8". The directional plan has not changed, just the hole/liner size. We will maintain the same BOP stack as planned, but we will not need the waiver of 20AAC 25.035(e)(2)(a)(iv) which was granted for not having pipe to fit the 2- 7/8" liner, as we will be running our standard 2-3/8" liner with pipe rams to fit it. Please let me know if you need any further information or have any questions about the change. Thanks, Mike Callahan CTD Engineer ConocoPhillips Alaska ATO 660 Office: (907) 263-4180 Cell: (907) 231-2176 THE STATE 0 GOVERNOR BILL WALKER James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 40 Alaska OiJ +t i Coyvwissiol� 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-24L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-002 Surface Location: 1667' FNL, 3990' FEL, SEC. 12, T11N, RIDE, UM Bottomhole Location: 2647' FNL, 3047' FEL, SEC. 12, T11N, RIDE, UM Dear Mr. Ohlinger: Enclosed is the approved application for permit to re -drill the above referenced development 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 thiZ day of January, 2018. Mr. %.ICI V CV STATE OF ALASKA ALAS`Gi OIL AND GAS CONSERVATION COMMISSI JAN 0 8 2018 PERMIT TO DRILL 20 AAC 25.005 A r1 r.. r_ I. 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG El Service - Disp ❑ 1 c. Specily ilTweii is proposed for: Drill ❑ Lateral. Q Stratigraphic Test ❑ Development - Oil ❑✓ , Service - Winj ❑ Single Zone ❑� . Coalbed Gas ❑ Gas Hydrates ❑ 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 1C-24L1 , 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11550' TVD: 6324' ' Kuparuk River Pool / 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1667' FNL, 3990' FEL, Sec. 12, T11 N, R10E, UM ADL 25649 Kuparuk River Oil Pool Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 3829' FNL, 805' FEL, Sec. 11, T11N, RI OE, UM LONS 79-016 1/22/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2647' FNL, 3047' FEL, Sec. 12, T11 N, R10E, UM 2560 • 13150' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 102' • 15. Distance to Nearest Well Open Surface: x- 562298 y- 5968571 Zone- 4 GL / BF Elevation above MSL (ft): 55' to Same Pool: 226', 1 C-24 16. Deviated wells: Kickoff depth: 7625' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 95 degrees Downhole: 3841 • Surface: 3198 1 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/4" 2-7/8" 6.4# L-80 ST-L 3935' 7615' 6334' 11550' 6324' Slotted 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): 9350' 6548' 7674' 9250' 6528' None Casing Length Size Cement Volume MD TVD Conductor 119, 16" 9 cu yds High Early 161' 161' Surface 4670' 9-5/8" 1200 sx AS Lite, 850 sx LiteCrete 4711' 4413' Intermediate Production 6795' 7" 185 sx Class G 68�5' 6252' Liner 2701' 4-1/2" 380 sx GasBlok 9345' 6547' Perforation Depth MD (ft): 7485' - 7520', 7550' - 7670' Perforation Depth TVD (ft): 6423' - 6427', 6430' - 6440' 7700' - 7885', 7945' - 8015' 6441' - 6455', 6461' - 6467' 8065' - 8090', 8500' - 8600' 6472' - 6474', 6497' - 6492' 8650' - 8750', 8800' - 8900' 6489' - 6483', 6481' - 6479' 8950' - 9150', 9180' - 9215' 6480' - 6507', 6513' - 5620' Hydraulic Fracture planned? Yes No 7 20. Attachments: Property Plat ❑ BOP Sketch Diverter Sketch Drilling Program ❑ Seabed Report Time v. Depth Plot Shallow Hazard Analysis ❑ Drilling Fluid Program B 20 AAC 25.050 requirements❑✓ 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. f Contact Name: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith.E.Herrin c0 .com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: Date: Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: a I S — QQ., 150- Q),— 3 Q — —M I Date: 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: 56 Other: 56 f� �Zv f fD 4 (QUO �6 r 1 I Samples req'd: Yes ❑ No[� Mud log req'd: Yes ❑ 00 r rrV � r ✓. -/0 aL5, 00j'�( HzS measures: Yes [� No ❑ Directional svy req'd: Yes [�No ❑ �O'4'+C;�.0 3 C C,)(Z) �� �t �� INvC4 J Xrrs aci exception req'd: Yes No Inclination-onl sv req'd: Yes �( p Y Y q' ❑ NoLI 1-5 rav►trd ) C' rns S�3Cd +- P 9 P q' IJ, �(� 2 _ �!g 11{ l p 11 C7 / t`r, rr r r! ►C 0 op"5� e� °-UH"f >✓ [ter 1 t"1 •` Pt ipitiaL in�ection MIT req'd: Yes ❑ No Na�rr r7rc�..� !d /' S�f�Jc�,�,�-to clas�on vnvs�"bc�et,��r L�t.,i� � . APPROVED BY Approved by: COMMISSIONER TH C MMISSION Date: S ` Submit Form and Form 10-401 Revised5/2017 This permit is valid for 24 mont h f r 20 AAC 25.005(g) Attachments in Duolicate � ConocoPhillips p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 8, 2018 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 permit to drill a single lateral out of the Kuparuk River Unit 1C-24 (PTD# 201-248) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in January 2018. The objective will be to drill one lateral 1C-241_1 targeting the Kuparuk C-sand. ✓ ConocoPhillips is requesting a waiver from the requirements of 20 AAC 25.035(e)(2)(a)(iv) to not include pipe rams sized to fit the 2-7/8" slotted liner in the BOP stack while drilling and completing 1C-24L1. A detailed well control plan is provided in the liner running section of the 1 C-24L1 permit to drill summary document. Attached to this application are the following documents: - Permit to Drill Application Form (10-401) for 1 C-241_1 - Detailed Summary of Operations - Directional Plans for 1C-241_1 - Current wellbore schematic - Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska 0 i Kuparuk CTD Lateral 1 C -24 L 1 NABOR'sa♦caSKA Application for Permit to Drill Document q 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 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)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................ 4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................ 4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 5 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments.................................................................................................................................... 6 Attachment 1: Directional Plans for 1C-24L1 lateral........................................................................................................6 Attachment 2: Current Well Schematic for 1 C-24............................................................................................................6 Attachment 3: Proposed Well Schematic for 1 C-241-1 lateral..........................................................................................6 Page 1 of 6 January 04, 2018 PTD Application: 1C-241-1 1. Well Name and Classification (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)) The proposed lateral described in this document is 1 C-241-1. The lateral will be classified as a "Development - Oil" well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This lateral will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1C-241-1. 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�psi. Using the maximum formation pressure in the area of 3,841'psi in 1C-02 (i.e. 11.4 ppg EMW), the maximum potential surface pressure in 1C-24L1, assuming a gas gradient of 0.1 psi/ft, would be 3,198 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 1C-24 was measured to be 2,438 psi (7.7 ppg EMW) on 7/04/2016. The maximum downhole pressure in the 1C-24 vicinity is the 1C-02 producer at 3,841 psi (11.4 ppg EMW) from January of 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) The offset injection wells to 1 C-24 have injected gas, so there is a possibility of encountering free gas while drilling the 1 C-241-1 lateral. If significant 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 1C-241-1 lateral will be shale instability across faults. Managed pressure drilling (MPD) may 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 1 C-241-1 lateral 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 04, 2018 9 U PTD Aaalication: 1C-241_1 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 MD MD TVDSS TVDSS 1 C-241_1 7615' 11550' 6334' 6324' 2-7/8 , 6.4#, L-80, ST-L slotted liner; deployment sleeve Existing Casing/Liner Information Category OD Weight Grade Connection Top MD Btm MD Top TVD Btm TVD Burst psi Collapse psi Conductor 16" 62.5 H-40 Welded 0' 161' 0' 161' 1640 670 Surface 9-5/8" 40.0 L-80 BTC 0' 4711' 0' 4413' 5750 3090 Production 7" 26.0 L-80 BTC-MOD 0' 6835' 0' 6252' 7240 5410 Liner 4-1/2" 12.6 L-80 NSCT 6644' 9345' 6136' 6547' 7780 6350 Tubing 4-1/2" 12.6 L-80 IBT-MOD 0' 6655' 0' 6144' 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 FloPro mud (8.7 ppg) — Drilling operations: Chloride -based FloPro mud (8.7 ppg). This mud weight will not hydrostatically overbalance the maximum reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The well will be loaded with 11.4 ppg NaBr completion fluid in order to provide formation over -balance and well bore stability while running completions. Managed Pressure Drilling Practice If returns can be established, managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability 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 1 C-24L1 lateral we will target a constant BHP of 11.4 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 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. Page 3 of 6 January 04, 2018 9 PTD Application: 1 C-241-1 Pressure at the 1C-24L1 Window (7620' MD, 6436' TVD) Using MPD - 2 3/8" Coiled Tubing Pumps On 2.7 b m Pumps Off C-sand Formation Pressure 7.7 2577 psi 2577 psi Mud Hydrostatic 8.7 2912 psi 2912 psi Annular friction i.e. ECD, 0.06 si/ft 458 psi 0 psi Mud + ECD Combined no chokepressure) 3370 psi Overbalanced -793psi) 2912 psi Overbalanced -335 psi Tar-'"- at Window 11.4 3815 psi 3815 psi Choke Pressure Required to Maintain 445 psi 903 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 Background 1C-24 is a Kuparuk C-sand producer equipped with 4-1/2" tubing and 4-1/2" production liner. The CTD sidetrack will utilize a single lateral to target a sheltered reservoir area to the west of the parent wellbore. The new lateral will increase C-sand resource recovery and throughput. Prior to CTD operations, slickline will install a new gas lift design, fluid pack the IA, and pressure test the tubing. Service coil will mill the DB nipple at 6603' MD to 3.80" ID and e-line will set a mechanical whipstock in the 4-1/2" liner at 7625' MD. The 1C-241-1 lateral will exit the 4-1/2" liner at 7625' MD and TD at 11550' MD, targeting the C3/C4-sand to the west. It will be completed with 2-7/8" slotted liner from TD up into the 4-1/2" liner to 7516' MD with a deployment sleeve. Pre-CTD Work 1. RU Slickline: Install new gas lift design, fluid pack IA, and pressure test. 2. RU Service Coil: Mill out DB-nipple to 3.80" at 6603' MD. 3. RU E-Line: Set 4-1/2" XL Monobore Whipstock at 7625' MD. 4. Prep site for Nabors CDR3-AC. Page 4 of 6 January 04, 2018 PTD Aaalication: 1C-24L1 Rig Work 1. MIRU Nabors CDR3-AC rig using 2-3/8" coil tubing. NU 7-1/16" BOPE, test. 2. 1C-241_1 Lateral (Kuparuk C-Sand) a. Mill 3.80" window at 7625' MD. b. Drill 4-1/4" bi-center lateral to TD of 11550' MD. c. Run 2-7/8" slotted liner with deployment sleeve from TD up to 7615' MD. 3. Freeze protect, obtain SBHP, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. 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 and double ball valves in the BHA, and a slick -line lubricator. 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 moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — The 1 C-241_1 lateral will be displaced to an overbalancing fluid (11.4 ppg NaBr) prior to running liner. See "Drilling Fluids" section for more details. — While running 2-7/8" 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 2-7/8" 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 (1 R-18 or 1 B disposal facilities) or Prudhoe DS-4 of 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). Page 5 of 6 January 04, 2018 PTD Application: 1C-241-1 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 Literal brae � an�c�►' 1 C-24L1 13150' — Distance to Nearest Well within Pool 1 C-24L1 226' 1 C-24 16. Attachments Attachment 1: Directional Plans for 1 C-24L 1 lateral Attachment 2: Current Well Schematic for 1 C-24 Attachment 3: Proposed Well Schematic for 1C-24L1 lateral Page 6 of 6 January 04, 2018 ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk I Pad 1 C-24 IC-24L1 Plan: IC-24L1_wp03 Standard Planning Report 03 January, 2018 • ConocoPhillips Database`. EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk I Pad Well: 1 C-24 Wellbore: 1 C-24L1 Design: 1 C-24L1_wp03 ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: BATIGHES a GE company Well 1 C-24 Mean Sea Level 1 C-24: @ 101.60usft (1 C-24:) 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 1C Pad -- ---- Site Position: Northing: 5,968,522.46usft Latitude: 70° 19' 28.285 N', From: Map Easting: 562,372.05 usft Longitude: 149° 29' 39.293 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.48 ° i 1 Well 1 C-24 1 Well Position +N/S 0.00 usft Northing: 5,968,571.44 usft Latitude: 70° 19' 28.773 N +E/-W 0.00 usft Easting: 562,297.94 usft Longitude: 149° 29' 41.445 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft ----- Wellbore --------------- 1C-24L1 _ - _ Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (1) (nT) L — BGGM2017 2/1/2018 17.29 80.92 57,478 -- Design 1C-24L1 wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,562.49 Vertical Section: Depth From (TVD) +N/S +E/-W Direction (usft) (usft) (usft) (I -40.30 0.00 0.00 45.00 11312018 11:35:43AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips BA_ DER ConocoPhillips Planning Report UGHES a GE company Database: EDT Alaska Sandbox Local Coordinate Reference: Well 1 C-24 Company: ConocoPhillips (Alaska) Inc. -Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 C-24: @ 101.60usft (1 C-24:) Site: Kuparuk I Pad North Reference: True Well: 1C-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 C-24L1 Design: 1C-24L1_wp03 Plan Sections Measured Depth Inclination Azimuth (usft) V) (I 7,562.49 84.70 266.88 7,625.00 85.84 268,66 7,650.00 87.96 270.78 7,680.00 94.75 277.58 7,710.00 94.68 287.21 7,805.00 79.53 313.68 7,900.00 90.77 342.07 8,050.00 90.52 30.07 8,150.00 92.56 62.02 8,220.00 92.36 84.44 8,420.00 88.71 97.96 8,570.00 92.30 88.09 8,845.00 90.53 107.27 9,050.00 85.65 93.76 9,350.00 89.50 73.09 9,600.00 88.02 90.53 9,875.00 90.76 71.48 10,150.00 92.03 52.26 10,500.00 91.85 76.78 10,850.00 94.99 52.43 10,950.00 90.03 57.38 11,050.00 88.82 64.27 11,250.00 88.85 50.27 11,550.00 88.93 71.27 TVD Below System +N/.S +E/-W (usft) (usft) (usft) 6,330.01 -2,158.52 -2,031.15 6,335.17 -2,160.95 -2,093.39 6,336.52 -2,161.07 -2,118.35 6,335.81 -2,158.89 -2,148.23 6,333.34 -2,152.48 -2,177.40 6,338.20 -2,105.10 -2,258.31 6,346.39 -2,025.78 -2,307.88 6,344.60 -1,880.96 -2,292.47 6,341.85 -1,812.47 -2,221.45 6,338.81 -1,792.42 -2,154.91 6,336.94 -1,796.61 -1,955.46 6,335.62 -1,804.52 -1,805.89 6,328.77 -1,841.10 -1,534.72 6,335.65 -1,878.42 -1,333.81 6,348.49 -1,844.22 -1,037.73 6,353.95 -1,808.75 -791.30 6,356.92 -1,765.95 -520.97 6,350.17 -1,636.96 -279.66 6,338.13 -1,487.62 33.71 6,316.93 -1,339.05 346.95 6,312.54 -1,281.65 428.64 6,313.55 -1,232.94 515.90 6,317.63 -1,125.09 683.69 6,323.50 -979.44 943.97 Dogleg Rate (°M 00ft) 0.00 3.37 12.00 32.00 32.00 32.00 32.00 32.00 32.00 32.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 7.00 Build Turn Rate Rate (°1100ft) (°1100ft) 0.00 0.00 1.82 2.85 8.49 8.49 22.62 22.65 -0.22 32.11 -15.95 27.86 11.83 29.89 -0.17 32.00 2.04 31.95 -0.28 32.03 -1.83 6.76 2.40 -6.58 -0.65 6.97 -2.38 -6.59 1.28 -6.89 -0.59 6.98 1.00 -6.93 0.46 -6.99 -0.05 7.00 0.90 -6.96 -4.96 4.94 -1.21 6.89 0.02 -7.00 0.03 7.00 TFO V) Target 0.00 57.35 45.00 45.00 90.00 120.00 70.00 90.00 86.00 90.00 105.00 290.00 95.00 250.00 280.00 95.00 278.00 274.00 90.00 278.00 135.00 100.00 270.00 90.00 11312018 11:35:43AM Page 3 COMPASS 5000.14 Build 85 Il ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk I Pad Well: 1 C-24 Weilbore: IC-24L1 Design: 1C-24L1_wp03 ConocoPhillips Planning Report Local Coordinate Reference: Well 1 C-24 TVD Reference: Mean Sea Level MD Reference: 1 C-24: @ 101.60usft (1 C-24:) North Reference: True Survey Calculation Method: Minimum Curvature BA ER F IGHES BAT GE company Planned Survey i Measured TVD Below Vertical Dogleg Tooiface Map i Map Depth Inclination Azimuth System +N/-S +El-W Section Rate Azimuth Northing Easting (usft) ('1 l'i (usft) (usft) (usft) (usft) (°/100ft) ('i (usft) (usft) 7,562.49 84.70 266.88 6,330.01 -2,158.52 -2,031.15 -2,962.54 0.00 0.00 5,966,396.34 560,284.98 TIP 7,600.00 85.38 267.95 6,333.25 -2,160.21 -2,068.48 -2,990.13 3.37 57.35 5,966,394.34 560,247.66 ! 7,625.00 85.84 268.66 6,335.17 -2,160.95 -2,093.39 -3,008.27 3.37 57.26 5,966,393.40 560,222.76 KOP 7,650.00 87.96 270.78 6,336.52 -2,161.07 -2,118.35 -3,026.01 12.00 45.00 5,966,393.07 560,197.80 j End 12 dis, Start 32 dis 7,680.00 94.75 277.58 6,335.81 -2,158.89 -2,148.23 -3,045.59 32.00 45.00 5,966,395.00 560,167.91 4 7,700.00 94.72 284.00 6,334.16 -2,155.16 -2,167.80 -3,056.79 32.00 90.00 5,966,398.57 560,148.31 j 7,710.00 94.68 287.21 6,333.34 -2,152.48 -2,177.40 -3,061.68 32.00 90.53 5,966,401.17 560,138.69 5 7,800.00 80.30 312.25 6,337.33 -2,108.45 -2,254.71 -3,085.22 32,00 120.00 5,966,444.55 560,061.03 7,805.00 79.53 313.68 6,338.20 -2,105.10 -2,258.31 -3,085.39 32.00 118.88 5,966,447.87 560,057.40 6 7,900.00 90.77 342.07 6,346.39 -2,025.78 -2,307.88 -3,064.36 32.00 70.00 5,966,526.77 560,007.18 1 7 8,000.00 90.65 14.07 6,345.12 -1,927.14 -2,311.20 -2,996.96 32.00 90.00 5,966,625.37 560,003.04 8,050.00 90.52 30.07 6,344.60 -1,880.96 -2,292.47 -2,951.06 32.00 90.41 5,966,671.70 560,021.38 8 8,100.00 91.60 46.04 6,343.68 -1,841.72 -2,261.75 -2,901.60 32.00 86.00 5,966,711.18 560,051.77 8,150.00 92.56 62.02 6,341.85 -1,812.47 -2,221.45 -2,852.41 32.00 86.30 5,966,740.77 560,091.83 9 8,200.00 92.46 78.04 6,339.65 -1,795.46 -2,174.65 -2,807.29 32.00 90.00 5,966,758.16 560,138.48 I 8,220.00 92.36 84.44 6,338.81 -1,792.42 -2,154.91 -2,791.19 32.00 90.70 5,966,761.36 560,158.19 End 32 dis, Start 7 dis i 8,300.00 90.90 89.85 6,336.53 -1,788.45 -2,075.08 -2,731.92 7.00 105.00 5,966,766.00 560,237.98 8,400.00 89.07 96.61 6,336.55 -1,794.08 -1,975.30 -2,665.35 7.00 105.15 5,966,761.20 560,337.79 8,420.00 88.71 97.96 6,336.94 -1,796.61 -1,955.46 -2,653.12 7.00 105.15 5,966,758.83 560,357.65 11 8,500.00 90.63 92.70 6,337.40 -1,804.04 -1,875.84 -2,602.07 7.00 -70.00 5,966,752.06 560,437.32 8,570.00 92.30 88.09 6,335.62 -1,804.52 -1,805.89 -2,552.94 7.00 -69.97 5,966,752.16 560,507.27! 12 8,600.00 92.12 90.19 6,334.46 -1,804.07 -1,775.91 -2,531.43 7.00 95.00 5,966,752.86 560,537.23 8,700.00 91.48 97.16 6,331.32 -1,810.47 -1,676.23 -2,465.47 7.00 95.08 5,966,747.29 560,636.96 8,800.00 90.83 104.13 6,329.30 -1,828.93 -1,578.03 -2,409.09 7.00 95.30 5,966,729.65 560,735.29 i 8,845.00 90.53 107.27 6,328.77 -1,841.10 -1,534.72 -2,387.07 7.00 95.44 5,966,717.84 560,778.70 13 i 8,900.00 89.21 103.65 6,328.90 -1,855.76 -1,481.72 -2,359.95 7.00 -110.00 5,966,703.62 560,831.82 9,000.00 86.83 97.06 6,332.36 -1,873.72 -1,383.47 -2,303.18 7.00 -109.99 5,966,686.48 560,930.20 9,050.00 85.65 93.76 6,335.65 -1,878.42 -1,333.81 -2,271.39 7.00 -109.76 5,966,682.19 560,979.90 14 9,100.00 86.26 90.30 6,339.17 -1,880.19 -1,283.97 -2,237.40 7.00 -80.00 5,966,680.84 561,029.74 9,200.00 87.53 83.41 6,344.59 -1,874.71 -1,184.33 -2,163.07 7.00 -79.76 5,966,687.14 561,129.33 9,300.00 88.84 76.53 6,347.76 -1,857.32 -1,085.97 -2,081.22 7.00 -79.38 5,966,705.35 561,227.53 9,350.00 89.50 73.09 6,348.49 -1,844.22 -1,037.73 -2,037.84 7.00 -79.16 5,966,718.85 561,275.66 15 9,400.00 89.19 76.58 6,349.06 -1,831.14 -989.48 -1,994.48 7.00 95.00 5,966,732.32 561,323.79 9,500.00 88.59 83.55 6,350.99 -1,813.90 -891.06 -1,912.70 7.00 94.96 5,966,750.37 561,422.05 9,600.00 88.02 90.53 6,353.95 -1,808.75 -791.30 -1,838.51 7.00 94.83 5,966,756.35 561,521,76 11 16 i 9,700.00 89.00 83.60 6,356.55 -1,803.64 -691.53 -1,764.35 7.00 -82.00 5,966,762.29 561,621.48 1 11312018 11:35:43AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project: Kuparuk River Unit Site: Kuparuk 1 C Pad Well: 1 C-24 Wellbore: 1 C-24L1 Design: 1 C-24L1_wp03 0 ConocoPhillips BAj{IG Planning Report UHES a GE company Local Co-ordinate Reference: Well 1 C-24 TVD Reference: Mean Sea Level MD Reference: 1 C-24: @ 101.60usft (1 C-24:) North Reference: True Survey Calculation Methods Minimum Curvature Planned Survey i Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (a) (1 (usft) (usft) (usft) (usft) (°/100ft) (I (usft) (usft) 9,800.00 90.01 76.67 6,357.42 -1,786.52 -593.07 -1,682.63 7.00 -81.82 5,966,780.23 561,719.78 9,875.00 90.76 71.48 6,356.92 -1,765.95 -520.97 -1,617.10 7.00 -81.76 5,966,801.39 561,791.69 17 9,900.00 90.88 69.73 6,356.57 -1,757.65 -497.40 -1,594.56 7.00 -86.00 5,966,809.89 561,815.20 10,000.00 91.36 62.75 6,354.61 -1,717.39 -405.95 -1,501.43 7.00 -86.02 5,966,850.90 561,906.30 10,100.00 91,81 55.76 6,351.84 -1,666.32 -320.09 -1,404.60 7.00 -86.16 5,966,902.68 561,991.72 10,150.00 92.03 52.26 6,350.17 -1,636.96 -279.66 -1,355.25 7.00 -86.35 5,966,932.37 562,031.90 18 10,200.00 92.03 55.77 6,348.39 -1,607.60 -239.24 -1,305.91 7.00 90.00 5,966,962.06 562,07: 08 10,300.00 92.00 62.77 6,344.88 -1,556.56 -153.39 -1,209.12 7.00 90.12 5,967,013.81 562,15.7 10,400.00 91.94 69.77 6,341.44 -1,516.37 -61.95 -1,116.04 7.00 90.37 5,967,054.75 562,248.58 10,500.00 91.85 76.78 6,338.13 -1,487.62 33.71 -1,028.08 7.00 90.61 5,967,084.29 562,343.99 19 10,600.00 92.81 69.84 6,334.06 -1,458.94 129.35 -940.16 7.00 -82.00 5,967,113.76 562,439.39 10,700.00 93.72 62.89 6,328.36 -1,418.94 220.76 -847.24 7.00 -82.28 5,967,154.52 562,530.45 10,800.00 94.59 55.92 6,321.10 -1,368.21 306.55 -750.70 7.00 -82.68 5,967,205.95 562,615.81 10,850.00 94.99 52.43 6,316.93 -1,339.05 346.95 -701.52 7.00 -83.18 5,967,235.44 562,655.96 20 10,900.00 92.51 54.91 6,313.65 -1,309.50 387.14 -652.21 7.00 135.00 5,967,265.32 562,695.90 10,950.00 90.03 57.38 6,312.54 -1,281.65 428.64 -603.17 7.00 135.16 5,967,293.51 562,737.17 21 11,000.00 89.42 60.82 6,312.78 -1,255.98 471.54 -554.68 7.00 100.00 5,967,319.54 562,779.84 11,050.00 88.82 64.27 6,313.55 -1,232.94 515.90 -507.02 7.00 99.98 5,967,342.95 562,824.00 22 11,100.00 88.82 60.77 6,314.58 -1,209.87 560.24 -459.36 7.00 -90.00 5,967,366.38 562,868.15 11,200.00 88.84 53.77 6,316.62 -1,155.85 644.29 -361.73 7.00 -89.93 5,967,421.09 562,95134 11,250.00 88.85 50.27 6,317.63 -1,125.09 683.69 -312.12 7.00 -89.78 5,967,452.17 562,990.88 23 11,300.00 88.86 53.77 6,318.63 -1,094.33 723.08 -262.51 7.00 90.00 5,967,483.26 563,030.01 11,400.00 88.87 60.77 6,320.61 -1,040.30 807.13 -164.87 7.00 89.93 5,967,537.97 563,113.61 11,500.00 88.91 67,77 6,322.55 -996.92 897.15 -70.55 7.00 89.79 5,967,582.09 563,203.25 11,550,011 88.93 71.27 6,323.50 -979.44 943.97 -25.08 7.00 89.66 5,967,599.97 563,249.92 Planned TD at 11550.00 11312018 11:35:43AM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk I Pad Wolf: 1 C-24 Welihore: 10-24L1 Design: 1 C-24L1_wp03 I Targeffi Target Name 0 ConocoPhillips BT�UtEE R Planning Report GHES company Local Co-ordinate Reference: Well 1C-24 TVD Reference: Mean Sea Level MD Reference: 1 C-24: @ 101.60usft (1 C-24:) North Reference: True Survey Calculation Method: Minimum Curvature hitlmiss target Dip Angle Dip Dir. TVD +Nl-S +El-W Northing Shape (I V) (usft) (usft) (usft) (usft) 1C-24 CTD Polygon 0.00 0.00 0.00 -12,025.761,138,008.23 5,965,994,00 -plan misses target center by 1137135.50usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) - Polygon Point 1 0.00 0.00 0.00 5,965,994.00 Point 2 0.00 32.61-194.76 5,966,024.99 Point 3 0.00 146.64-317.83 5,966,137.98 Point 4 0.00 317.19-381.43 5,966,307.98 Point 5 0.00 510.88-340.83 5,966,501.98 Point 6 0.00 631.95-226.82 5,966,623.98 Point 7 0.00 678.30 -25.41 5,966,672.00 Point 8 0.00 614.21 832.18 5,966,615.04 Point 9 0.00 687.52 1,523.87 5,966,694.08 Point 10 0.00 1,483.66 2,973.63 5,967,502.15 Point 11 0.00 1,643.69 3,214.98 5,967,664.16 Point 12 0.00 1,317.17 3,273.29 5,967,338.17 Point 13 0.00 1,199.64 3,092.30 5,967,219.15 Point 14 0.00 768.28 2,402.65 5,966,782.12 Point 15 0.00 368.40 1,533.24 5,966,375.08 Point 16 0.00 278.24 823.40 5,966,279.04 Point 17 0.00 376.00 6.10 5,966,370.00 Point 18 0.00 0.00 0.00 5,965,994.00 1C-24L1_T01 0.00 0.00 6,337.00 -11,822.381,137,844.90 5,966,196.00 plan misses target center by 1136952.63usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point 1C-24L1_T09 0.00 0.00 6,313.00 -10,969.901,140,571.33 5,967,071.00 plan misses target center by 1139671.15usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point 1C-241_1_T08 0.00 0.00 6,341.00 -11,229.501,140.037A0 5,966,807.00 plan misses target center by 1139139.25usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point 1C-241_1_T10 0.00 0.00 6,323.00 -10,710.401,140,996.54 5,967,334.00 plan misses target center by 1140094.10usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point IC-24L1 T05 0.00 0.00 6,329.00 -11,562,561,138,593.15 5,966,462.00 plan misses target center by 1137698.40usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point 1C-240_T03 0.00 0.00 6,339.00 -11:506.171,137,944.53 5,966,513.00 plan misses target center by 1137049.29usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point 1C-24L1_T04 0.00 0.00 6,337.00 -11,517.491,138,223.48 5,966,504.00 plan misses target center by 1137328.33usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point 1C-241_1_T06 0.00 0.00 6,348.00 -11,557.451,139,061.25 5,966,471.00 plan misses target center by 1138166.44usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point 1C-24L1_T07 0.00 0.00 6,357.00 -11,493.331,139,530.85 5,966,539.00 plan misses target center by 1138635.42usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point IC-24L1 T02 0.00 0.00 6,345.00 -11,640.891,137,788.40 5,966,377.00 plan misses target center by 1136894.42usft at 11550.00usft MD (6323.50 TVD,-979.44 N, 943.97 E) Point Easting (usft) latitude Longitude 1,700,258.00 70' T 29.375 N 140' 21' 26.544 W 1,700,258.00 1,700,062.99 1,699,938.99 1,699,873.99 1, 699, 912.97 1,700, 025.96 1,700,226.96 1,701, 084.97 1,701,775.96 1,703,218.93 1,703,458.92 1, 703, 519.93 1,703, 339.94 1,702,653.96 1,701,787.98 1,701, 078.98 1,700,260.96 1,700,258.00 1, 700, 093.00 70' T 31.589 N 140° 21' 30.315 W I 1,702,812.00 70° 3' 35.858 N 140° 20' 9.093 W 1,702,280.00 70' 3' 34.124 N 140' 20' 25.407 W 1,703.235.00 70' T 37.752 N 140° 19' 55.879 W 1,700,839.00 70' 3' 33.013 N 140° 21' 7.913 W 1,700,190.00 70' 3' 34.513 N 140° 21' 26.121 W 1,700,469.00 70' T 33.993 N 140° 21' 18.235 W 1,701,307.00 70' 3' 32.375 N 140° 20' 54.577 W 1,701,776.00 70' 3' 32.307 N 140' 20' 40.943 W i 1,700,035.00 70' 3' 33.434 N 140' 21' 31.141 W 11312018 11,35:43AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Database: EDT Alaska Sandbox Company: ConocoPhillips (Alaska) Inc. -Kup1 Project Kuparuk River Unit Site: Kuparuk 1C Pad Well: 1 C-24 Welibore: 1 C-24 L 1 Design: 1 C-24L1_wp03 ConocoPhillips Planning Report Local Co-ordinate Reference: Well 1 C-24 TVD Reference: Mean Sea Level MD Reference: 1C-24: @ 101.60usft (1C-24:) North Reference: True Survey Calculation Method: Minimum Curvature BA IGHEs T GE company Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 11,550.00 6,323.50 2 3/8" 2.375 3.000 Plan Annotations -- - Measured Depth Vertical Depth Local CoordinatesNN +N/-S +EI W��� (usft) (usft) Comment " (usft) (usft) E�� �g'�H., . 7,562.49 6,330.01 -2,158.52 -2,031.15 TIP 7,625.00 6,335.17 -2,160.95 -2,093.39 KOP 7,650.00 6,336.52 -2,161.07 -2,118.35 End 12 dis, Start 32 dls 7,680.00 6.335.81 -2,158.89 -2,148.23 4 7,710.00 6,333.34 -2,152.48 -2,177.40 5 7,805.00 6,338.20 -2,105.10 -2,258.31 6 7,900.00 6,346.39 -2,025.78 -2,307.88 7 8,050.00 6,344.60 -1,880.96 -2,292.47 8 8,150.00 6,341.85 -1,812.47 -2,221.45 9 8,220.00 6,338.81 -1,792.42 -2,154.91 End 32 dls, Start 7 dls 8,420.00 6,336.94 -1,796.61 -1,955.46 11 8,570.00 6,335.62 -1,804.52 -1,805.89 12 8,845.00 6,328.77 -1,841.10 -1,534.72 13 9,050.00 6,335.65 -1,878.42 -1,333.81 14 9,350.00 6,348.49 -1,844.22 -1,037.73 15 9,600.00 6,353.95 -1,808.75 -791.30 16 9,875.00 6,356.92 -1,765.95 -520.97 17 10,150.00 6,350.17 -11636.96 -279.66 18 10,500.00 6,338.13 -1,487.62 33,71 19 10,850.00 6,316.93 -1,339.05 346.95 20 10,950.00 6,312.54 -1,281.65 428.64 21 11,050.00 6,313.55 -1,232.94 515.90 22 11,250.00 6,317.63 -1,125.09 683.69 23 11,550.00 6,323.50 -979.44 943.97 Planned TD at 11550.00 11312018 11:35:43AM Page 7 COMPASS 5000.14 Build 85 0 0 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk I Pad Site Error. 0.00 usft Reference Well: 1C-24 Well Error. 0.00 usft Reference Welibore 1 C-24L1 Reference Design: 1C-241-1_wp03 ConocoPhillips BA BAT Travelling Cylinder Report a GE company Local Co-ordinate Reference: Well 1 C-24 TVD Reference: 1 C-24: @ 101.60usft (1 C-24:) MD Reference: 1C-24: @ 101.60usft (1C-24:) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1,00 sigma Database: EDT Alaska Prod Offset TVD Reference: Offset Datum Reference IC-24L1_wp03 Filtertype: GLOBAL FILTER APPLIED: All welipaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,562.49 to 11,550.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,348.87 usft Error Surface: Pedal Curve Survey Tool Program Date 1/3/2018 From i To (usft) (usft) Survey (Weilbore) Tool Name Description 83.00 349.10 1C-24 GYRO (1C-24) CB -GYRO -SS Camera based gyro single shot 480.38 7,562.49 1C-24 (1C-24) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,562.49 11,550.00 1C-241-1_wp03 (1C-241-1) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 11,550.00 6,425.10 23/8" 2-3/8 3 ------------------------------ 'Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Weilbore - Design (usft) (usft) (usft) (usft) Kuparuk 1C Pad 1 C-01 - 1 C-01 - 1 C-01 Out of range 1 C-01 - 1 C-01 L1 - 1 C-01 Li Out of range 1 C-01 - 1 C-01 L1-01 - 1 C-01 L1-01 Out of range 1 C-01 - 1 C-01 L1-02 - 1 C-01 L1-02 Out of range 1 C-01 - 1 C-01 L1-03 - 1 C-01 L1-03 Out of range 1 C-02 - 1 C-02 - 1 C-02 9,950.00 7,000.00 706.17 157.66 548.37 Pass - Major Risk 1 C-03 - 1 C-03 - 1 C-03 Out of range 1 C-03 - 1 C-03A - 1 C-03A Out of range 1 C-10 - 1 C-10 - 1 C-10 Out of range 1 C-133 - 1 C-133 - 1 C-133 Out of range 1 C-14 - 1 C-14 - 1 C-14 Out of range 1 C-14 - 1 C-14A - 1 C-14A Out of range 1 C-15 - 1 C-15 - 1 C-15 Out of range 1 C-15 - 1 C-151-1 - 1 C-151-1 Out of range 1 C-150 - 1 C-150 - 1 C-150 Out of range 1 C-154 - 1 C-154 - 1 C-154 Out of range 1 C-155 - 1 C-155 - 1 C-155 Out of range 1 C-178 - 1 C-178 - 1 C-178 Out of range 1 C-178 - 1 C-178L1 - 1 C-1781-1 Out of range 1 C-178 - 1 C-1781-1 P131 - 1 C-178L1 PB1 Out of range 1 C-178 - 1 C-178L1 P62 - 1 C-1781-1 PB2 Out of range 1 C-184 - 1 C-184 - 1 C-184 Out of range 1 C-19 - 1 C-19 - 1 C-19 Out of range i C-190 - 1 C-190 - 1 C-190 Out of range 1 C-20 - 1 C-20 - 1 C-20 Out of range i C-20 - 1 C-20 - Plan: 1 C-20 (wpl0) Out of range 1 C-20 - 1C-20PB1 - 1C-20PB1 Out of range 1 C-21 - 1 C-21 - 1 C-21 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11312018 9:38:38AM Page 2 COMPASS 5000.14 Build 65 0 ConocoPhillips Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Reference Site: Kuparuk 1C Pad Site Error. 0.00 usft Reference Well: 1C-24 Well Error: 0.00 usft Reference Welibore 1C-24L1 Reference Design: 1 C-241-1 _wp03 Summary Site Name Offset Well -Weilbore - Design Kuparuk 1C Pad 1 C-21 - 1 C-21 L1 - 1 C-21 1-1 1 C-21 - 1 C-21 L2 - 1 C-21 L2 1 C-21 - 1 C-21 1-3 - 1 C-21 1-3 1 C-22 - 1 C-22 - 1 C-22 i C-23 - i C-23 - 1 C-23 1 C-23 - 1 C-23A - 1 C-23A 1C-23- 1C-23ALl - 1C-23AL1 1 C-23 - 1 C-23AL2 - 1 C-23AL2 1 C-23 - 1 C-23AL2-01 - 1 C-23AL2-01 1 C-23 - 1 C-23AL2-02 - 1 C-23AL2-02 1 C-23 - 1 C-23AL3 - 1 C-23AL3_wp00 i C-23 - 1 C-23AL3-01 - 1 C-23AL3-01 wp00 1C-23- 1C-23PB1 - 1C-23PB1 1 C-24 - 1 C-24 - 1 C-24 1 C-25 - 1 C-25 - 1 C-25 1C-25- 1C-251-1 - 1C-251-1 1 C-26 - 1 C-26 - 1 C-26 1 C-27 - 1 C-27 - 1 C-27 1 C-28 - 1 C-28 - 1 C-28 1 C-28 - 1 C-28L1 - 1 C-28L1 1 C-28 - 1 C-28 P B 1- 1 C-28 PB 1 Plan: 1 C-156 - Plan: 1 C-156 - 1 C-156wp06 Plan: 1 C-157 - Plan: 1 C-157 - 1 C-157wp05 ConocoPhillips Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 8,994.33 6,900.00 225.65 BA TER UGI ES a GE company Well 1 C-24 1C-24: @ 101.60usft (1C-24:) 1C-24: @ 101.60usft (1C-24:) True Minimum Curvature 1.00 sigma EDT Alaska Prod Offset Datum No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 36.01 195.10 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Offset Design Kuparuk 1 C Pad - 1 C-02 - 1 C-02 - 1 C-02 onset site Error. 0.00 usft Survey Program: 100-GYD-CT-CMS Rule Assigned: Major Risk Offset Wetl Error: 0.00 usft Reference offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset To (face + Offset Wellbore Centre Casing - Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NIS +E1-w Hole Size Centre Distance ....(usft) Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) f') (usft) (usft) 9,834.05 6,458.92 7,615.00 6,957.41 26.70 18.82 -162.28 -2,516.04 -349,66 11-1/2 919.31 157.40 781.11 Pass - Major Risk 9,836.47 6,458.90 7,600.00 6,943.31 26.73 18.79 -163.13 -2,512.94 -345.57 11.1/2 910.06 157.41 771.16 Pass - Major Risk 9,850.00 6,458.80 7.500.00 6,849.45 26.91 18.59 -168.93 -2,492.08 -318.12 11.1 /2 852.23 157.39 708.71 Pass - Major Risk 9,850.00 6,458.80 7,525.00 6,872.86 26.91 18.64 -167.66 -2,497.38 -325.11 11.112 866.04 157.52 723.56 Pass - Major Risk 9,850.00 6,458.80 7,550.00 6,896.33 26.91 18.69 -166.42 -2,502.59 -331.96 11-1/2 880.32 157.66 738.91 Pass- Major Risk 9,850,00 6,458.80 7,575.00 6,919.82 26.91 18.74 -165,22 -2,507.76 -338,77 11-1/2 895.07 157.79 754.74 Pass- Major Risk 9,857.32 6,458.73 7,475.00 6,826.07 27.01 18.54 -170.75 -2,486.75 -311.04 11-1/2 838.89 157.51 694.12 Pass - Major Risk 9,861.69 6,458.68 7,450.00 6,802.69 27.06 18.49 -172,41 -2,481.46 -303.94 11-1/2 826.10 157.53 680.17 Pass - Major Risk 9,866.10 6,458.63 7,425.00 6,779.31 27.12 18.44 -174,12 -2,476.20 -296.82 11-112 813.87 157.55 666.80 Pass - Major Risk 9,875.00 6,458.52 7,350.00 6.709.16 27.24 18.30 -179.20 -2,460.65 -275.33 11-1/2 760.79 157.44 630.62 Pass - Major Risk 9,875.00 6,458.52 7,375.00 6,732.55 27.24 18,35 -177.67 -2,465.79 -282.50 11-1/2 791.17 157.58 641.90 Pass - Major Risk 9,875.00 6,458.52 7,400.00 6,755.93 27.24 18.40 -176.18 -2,470.97 -289,67 11-1/2 802.24 157.72 653.90 Pass - Major Risk 9,884.16 6,458,40 7,325.00 6,685.75 27.35 18.25 178.58 -2,455.56 -268.16 11-1/2 771.02 157.61 619.67 Pass - Major Risk 9,888.74 6,458.33 7,300.00 6,662.34 27.41 18.21 176.64 -2,450.53 -260.99 11-1/2 761.95 157.62 609.64 Pass - Major Risk 9,893.35 6,458.27 7,275.00 6,638.93 27.47 18.16 174.67 -2,445.47 -253.81 11-t12 753.54 157.62 600.33 Pass - Major Risk 9,900.00 6,458.17 7,200.00 6,568.83 27,55 18.02 169.05 -2,429,77 -232.28 11-1/2 732.13 157.41 576.94 Pass - Major Risk 9,900,00 6,458.17 7,225.00 6,592.18 27,55 18.07 170.79 -2,435.09 -239.46 11-1/2 738.59 157.55 583.88 Pass - Major Risk 9,900.00 6,458.17 7,250.00 6,615.55 27,55 18.11 172.51 -2 440.32 -246.63 11-1 /2 745.75 157.69 591.61 Pass - Major Risk 9,912,17 6,457.97 7,175.00 6,545.48 27.70 17.97 166.41 -2,424,39 -225.15 11.1/2 726.22 157.63 570.09 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1/3/2018 9:38:38AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips - -------------------------------- -------- Project: Kupanik River Unit Site: Kuparuk 1C Pad Maa,x N nh North Me9neto Fleld WELLBORE DETAILS: 1C-24L1 REFERENCE INFORMATION Parent Wellbore: 1C-24 Coordinete(WE) Reference. Well 1C-24,Tme North Well: 1C-24 Strength 57476.7.nT Tie on MD: 7562.49 Vertical (TVDj Reference: Mean Sea Level Wellbore: IC-24L1 Dip Angle: 80.92° Section (VS Reference: Slot-(O.DON, D.00E) Plan: 1C-24L1 wp03 (1C-24/1 C-24L7) Date: V112D/ Model'BGGM2011 Meewred Dept, Reference: 1C-24: @ 10l.60wft (1C-24:) Calc.%fbn Method: A%nimurn Curvature WELL DETAILS: 1C-24 +N/-S +E/-W Northing Easting Latitude Longitude 0.00 0.00 5968571.44 562297.94 70e 19' 28.773 N 149° 29' 41.445 W Sec MD Inc Azi TV + +E/-W Dleg TFace V ect Annotation 1 7562.49 84.70 266.88 6330.01 -2158.52 -2031.15 0.00 0.00 -2962.54 TIP 2 7625.00 85.84 268.66 6335.17 -2160.95 -2093.39 3.37 57.35 -3008.27 KOP 3 7650.00 87.96 270.78 6336.52 -2161.07 -2118.35 12.00 45.00 -3026.01 End 12 d1s, Start 32 dls 4 7680.00 94.75 277.58 6335.81 -2158.89 -2148.23 32.00 45.00 -3045.59 4 5 7710.00 94.68 287.21 6333.34 -2152,48 -2177.40 32.00 90.00 -3061.68 5 6 7805.00 79.53 313.68 6338.20 -2105.10 -2258.31 32.00 120.00 -3085.39 6 7 7900.00 90.77 342.07 6346.39 -2025.78 -2307.88 32.00 70.00 -3064.36 7 8 8050.00 90.52 30.07 6344.60 -1880.96 -2292.47 32.00 90.00 -2951.06 8 9 8150.00 92.56 62.02 6341.85 -1812.47 -2221.45 32.00 86.00 -2852.41 9 10 8220.00 92.36 84.44 6338.81 -1792.42 -2154.91 32.00 90.00 -2791.19 End 32 d1s, Start 7 dtls 11 8420.00 88.71 97.96 6336.94 -1796.61 -1955.46 7.00 105.00 -2653.12 11 12 8570.00 92.30 88.09 6335.62 -1804.52 -1805.89 7.00 290,00 -2552.94 12 13 8845.00 90.53 107.27 6328.77 -1841.10 -1534.72 7.00 95.00 -2387.07 13 14 9050.00 85.65 93.76 6335.65 -1878.42 -1333.81 7.00 250,00 -2271.39 14 15 9350.00 89.50 73.09 6348.49 -1844.22 -1037.73 7.00 280.00 -2037.84 15 16 9600.00 88.02 90.53 6353.95 -1808.75 -791.30 7.00 95.00 -1838,51 16 1 17 9875.00 90.76 71.48 6356.92 -1765.95 -520.97 7.00 278.00 -1617.10 17 18 10150.00 92.03 52.26 6350.17 -1636.96 -279.66 7.00 274.00 -1355.25 18 19 10500.00 91.85 76.78 6338.13 -1487.62 33.71 7.00 90.00 -1028.08 19 20 10850.00 94.99 52.43 6316.93 -1339.05 346.95 7.00 278.00 -701.52 20 21 10950.00 90.03 57.38 6312.54 -1281.65 428.64 7.00 135.00 -603.17 21 22 11050.00 88.82 64.27 6313.55 -1232.94 515.90 7.00 100.00 -507.02 22 j 23 11250.00 88.85 50.27 6317.63 -1125.09 683.69 7.00 270.00 -312.12 23 24 I 11550.00 88.93 71.27 6323.50 -979.44 943.97 7.00 90.00 -25.08 Planned TD at 11550.0 c Mean i West( -)Bast(+) (250 usft/in) BAEI2 UGHES a GE compary Vertical Section at 45.000 (95 usft./in) ConocoPhillips Project: Kuparuk River Unit Site: Ku aruk 1C Pad P Azimutln 1, T-11aM MaprM. Nash: 17.28' MaOnecio Field WELLBORE DETAILS: 1C-24L1 REFERENCE INFORMATION Parent Welibore: 1 C-24 Co-ordnate (NIE) Reference: Wall @ 1 True North Vertical (TVD) Reference: IC-24: � 101.60usft (iG24-,) Well: 1C-24 Strength: 67476.7snT Tie on MD: 7562.49 Section NS)Reference: Slot-(D.DDN,D.00E) Wellbore: 1 C-24L1 Dip Angk: 80.92' Dme. 2/12D7 Measured Depth Reference: 1C-24: tOi.60usft (IC-24) Plan: 1C-24L1_wp03 (1C-2411C-241-1) Model: BGGM2017 Calculation Method : Minimun Curvature IC-15211C-152 IC-15411C-154 West( -)/East(+) (900 usft/in) 1C-24: @ 101.60usft (1C-24:) A <E t�UGHES a GE company 0 s ,i-"-- -\*UP PROD 0 1C-24 ConocoPhillips I L Well Attributes jMaxAnqIe&MD ITO Wellbore API/UWI 11.11 Name Wellbore Status 5002923D.. KUPARUK RIVER UNIT PROD ncl C) MD(RKU) 1,15 349.02 Act Hm("KB) 9,350.0 Comment HIS (ppm) Date SSSV: NIPPLE 30 7l30/2015 Annotation End Date Last WO: KS-Grtl (fi) Rig Release Date 46A2 1/26/2002 iC-24.8/3_ 01613214PM ertice ac emalic lacfUal) AnDepth (ftKB) End Dale Annotation Last Mod By End Date _......._....... Last Tag: Rev Reason: H2S, SET CSV, GLV C/O, PULL pproven 8/30/2016 CSV HANGER; 36.4Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt(Len (I... Grade Top Thread CONDUCTOR 16 15,062 42.0 161.0 161.0 '2.68 API5LGr PEB B Casing Description 00 (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... WtlLen (I... Grade Top Thread T SURFACE 95/8 8.835 41.1 4, 710.9 40.00 L-80 BTC Casing Description OD (in) ID (in) Top IRKS) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread PRODUCTION 7 6.27E 39.5 6,835A 26.00 L-80 BTC-MOD IIIIIIIII-Al CONDUCTOR:42.0.16i.0 Casing Description OD (in) LINER 4112 ID (in) 3.958 Top (ftKB) 6,644.0 Set Depth (ftKB) Set 9,345.0 Depth (TVD)... WtlLen (I... Grade 12'60 L-80 Top Thread NSCT NIPPLE; 517.E Liner Details Nominal ID Top (ftKB) Top (ND) (ftKB) Top Incl (') Item Des Co. (i n) " 6.644.0 TIEBACK LINER TIE BACK EXTENSION 3,958 6,658.1 PACKER BAKER 4.5"X7" ZXP LINER TOP PACKER 4,300 W/HOLDDOWNS, HR PROFILE GAS LIFT, 2.712.9 6,666 1 HANGER 4.5" BAKER HMC LINER HANGER 4.420 Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) I.,, Wt (Ib/R) Grade Top Connection TUBING 41/2 3.958 36.4 6,654.9 12.60 L-80 IBT MOD GAS LIFT; 4,146.5 Completion Details Nominal ID Top (ftKB) Top (ND) (ftKB) Top Incl (") Item Des Com (in) 36A 364 0.11 HANGER FMC GEN V HANGER 4,500 517.6 NIPPLE CAMCO DB NIPPLE w/ 3.812 NO GO PROFILE 3.812 6,602,E NIPPLE CAMCO DB NIPPLE wl 3.75 NO GO PROFILE 3.750 SURFACE: 41-1-4.7109- I 6,641.8 LOCATOR BAKER NO GO LOCATOR 3.840 6.642.9 SEALASSY BAKER GBH-22 SEAL ASSEMBLY 3.840 GAS LIFT; 5,188.7 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top(ND) Top Intl Top (ftKB) (ftKB) Des Com Run Con Dale ID (in) 8, 139.2 1 PLUG I BAKER INFLATABLE BRIDGE PLUG (OAL=11.SS-) 3/7/2007 0.000 Perforations & Slots GAS LIFT, 5.950.1 Shot Dens Top (ND) Bt. (TVD) (shotslf Top (ftKB) at. (ftKB) (ftKB) (ftKB) Zone Date q Type Com 7,485.0 7,520.0 C-0,1C-24 1/24/2002 4.0 IPERF 2,5", 0.32" Shot, 120 deg GAS LIFT:6,5576 ph 7,550.0 7,670.0 C-4, 1C-24 1/24/2002 4.0 IPERF 2.5". 0,32" Shot, 120 deg ph NIPPLE. 6,602.E 7,700.0 7,885.0 C-3,1C-24 1/24/2002 4.0 IPERF 2,5". 0,32"Shot, P 120 deg 7,945.0 8,015.0 C-2, IC-24 1/24/2002 4,0 IPERF 2.5", 0.32" Shot, 120 deg Ph LOCATOR; 6541 a 8,065.0 8,090.0 C-2, 1 C-24 1 /24/2002 4.0 IPERF 2.5", 0.32" Shot, 120 deg ph SEAL ASSY; 6.642.9 8,500.0 8,600.0 C-4,1C-24 1/24/2002 4,0 IPERF 2.5", 0.32" Shot, 120 deg Ph 8,650.0 8.750.0 C-4, 1C-24 1/24/2002 4,0 IPERF 2.5", 0.32" Shot, 120 deg ph 8,800.0 3,900.0 C-4,IC-24 1/24/2002 4.0 IPERF 2.5". 0.32" Shot, 120 deg ph 8.950.0 9.150.0 C-4, 1024 1/24/2002 4.0 IPERF 2.5", 0.32" Shot, 120 deg ph 9.180.0 9.215.0 C-2,1C-24 1/24/2002 4,0 IPERF 2.5". 0.32"Shot, 120 tleg PRODUCTION; 39.5.6.835.4- j Ph j IPERF; 7,485.0.7.520d Mandrel Inserts St all IPERF; 7.550.0-7,6700 N Top (ftKB) Top (ND) (ftKB) Make Model OD (in) S., Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Co. 2,712.9 Camco KBG-2 1 GAS LIFT GLV BK-5 0,156 1,240.0 6/11/2002 IPERF; 7.700.0-7,885.0 2 41146.5 Camco KBG-2 1 GA LIFT GLV SK-5 0.188 1,275.0 6/10/2002 3 5,188.7 Camco KBG-2 1 GAS LIFT OV BK 0.250 0.0 8/28/2016 IPERF;7.9450-8.0150 4 5,950.1 Camco KBG-2 i GAS LIFT DMY SK-5 0.000 0.0 1/21/2002 5 6,557.7 Camco KBG-2 i I GAS LIFT DMY BK-5 0.000 0.0 2/11/2002 IPERF; 8.0650.8,090.0 Notes: General & Safety End Date Annotation PLUG; 8,139.2 8/19/2005 1 NOT DEFORMED LINER A 7696'-7715', MIN ID 3.4": CALIPER SURVEY AVAILABLE 8/16/2010 NOTE: View Schematic w/ Alaska Schematic9O IPERF, 8,500.M500.0 IPERF; 8.650.0-8,750.0 IPERF; 8.800.0-8.900.0 IPERF; 8,950.0-9.1500 IPERF; 9,1800-9,2150 LINER: 6.644.05.3450 1C-24 Proposed CTD Schematic 16" 62# A 51-grB shoe @ 161' MD 9-5/8" 40# L-80 shoe @ 4711' MD 7" 26# L-80 shoe @ 6835' MD IC -sand perfs 7485' - 9215' MD CIBP set at 7674' MD 4-1/2" 12.6# L-80 shoe @ 9345' MD KOP @ 7625' MD 4-1/2" 12.6# L-80 Tubing to surface 4-1/2" Camco DB landing nipple @ 518' MD (3.812" min ID) 4-1/2" Camco gas lift mandrels @ 2713', 4147', 5189', 5950% 6558' 4-1/2" Camco DB landing nipple @ 6603' MD (3.75" min ID) Liner top Baker GBH-22 Seal Assembly @ 6643' MD Liner Tie Back Extension @ 6644' MD Baker 4.5" x 7" ZXP liner top packer @ 6658' MD Baker 4.5" x 7" HMC liner hanger @ 6666' MD Baker Inflatable Bridge Plug @ 8139' RKB 1C-241-1 wp03 TD @ 11, 550' MD 0 0 9 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development _Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: _ POOL: t,Ji1l�,J Qi1� 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. , API No. 50- - - - (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 ( PH) 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' sam le intervals throu tar et 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 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 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. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1C-24L1 _ Program DEV Well bore seg PTD#: 2180020 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven, gas conforms to AS31.05.030Q.1.A),(y2.A-p) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - - - - - - - _ - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - - 1 Permitfeeattached--------------------------------------------- NA----------------------------------------------- --------------- 2 Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - ADL0025649, entire wellbore------------------ - - - - _ - - - _ - - 3 Uniquewell nameandnumber _____________________________________ Yes-------KRU1C-24L1_-_------______________--------_-- 4 Well located in_a_defined -pool ---------------------------------------- es - - - - - - - KUPARUK RIVER,_KUPARUK RIV OIL _- 490100,_govemed_by Conservation_ Order No. 432D- - - - - - - - - - - 5 Well located proper distance from drilling unit boundary - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ - CO 432D contains no spacing restrictions with_ respect to drilling unit boundaries. - - - - - - - - 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - CO 432D has no interwell spacing restrictions- _ _ - - - - - - - - - - - - - - - - 7 Sufficient acreage -available in_drilling unit_ - - - - - - - - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ------------------- 8 if deviated, is_welibore plat_included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - _ - - Wellbore_will be more than 500' from an external property line where ownership or landownership_ changes. 10 Operator has -appropriate bond in force - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 11 Permit can be issued without conservation order- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 12 Permit can be issued without administrative approval - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - _ - _ - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - PKB 1 /10/2018 _ _ _ _ _ _ _ _ 13 Can permit beapprov_edbefore l5-daywait-------------------------------- Yes--------------------------------------------------------------------------- 14 Well located within area and -strata authorized by -Injection Order # (put 10# in -comments)- (For- NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells_within 114_mil-e area of review identified (For service well only) - - - - - - - - - - - - - - - -NA- - - - - - - - - - _ _ - - - _ _ _ _ - - - - - _ - - _ - _ - - - - - - - - _ - - _ - 16 Pre -produced injector; duration of pre _production less than 3 months_ (For_service well only) NA_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor string -provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - - Con-ductor set-in KRU 1C-24 _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ Engineering 19 -Surface -casing- protects all -known USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ Surface casing set in KRU 1C-24 - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - 20 CMT_vol adequate to circulate -on conductor & surf _csg - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ Surface casing set and fully cemented - - - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - 21 CMT_voladequate_totie-inlongstringtos-urfcsg----------------------------NA------------ ------------------------------- 22 CMT_wili cover all known_productive horizons_ - - - - - - - - - - No_ _ _ _ _ _ _ _ Productive interval will be completed with slotted liner 23 Casing designs adequate for C,_T, B &_permafrost_ - - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ _ _ Rig has steel tanks, all _waste _to approved disposal wells_ - _ - _ - - - - - - - - 25 -if a_re-drill,has_a10-403for abandonment been approved---------------------- NA ------------------------------------------ 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Anti -collision analysis complete; no major risk failures - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - - - - 27 lfdiverterrequired,does -it meet regulations -------------------------------- A_ - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling fluid_ program schematic_& equip -list-adequate _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Max formation_ pressure is_3841 ps_ig(11.4 ppg_EMW); will drill_w/ 8.7_ppg EMW and_maintain ov_erbal_w/ MPD VTL1/24/2018 29 BOPEs,_dotheymeetregulation------------------------------------ Yes--------------------- - --------------- - ---------------------------- 30 BOPE_press rating appropriate; test to -(put prig in comments)- - - - - - - - - - - - - - - - - - - - Yes - - - - - - - MPSP fs 3198 psig; will test SOPs_to 4000-psig; 20AAC25.035e(2)(a)(iv_) waiver wl conditions 31 _ hokei manifold compiles w - - - - -53 May $4 - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ------------- 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ _ _ - - - - _ _ _ _ _ _ _ _ _ _ _ _ 33 is presence of H2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ H2$ measures required_ - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - 34 Mechanical -condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - - NA _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - _ _ _ _ No- - - - _ - - - Wells- on_1C-Pad are H2S4bearing_ H2S measures_required. - - - - - - - _ _ _ _ _ _ _ - - - _ _ - - _ - - - - - - - - - - Geology 36 _D_ata_presented on potential overpressure zones Yes _ Maximum potential reservoir pressure_is 11.4 ppg_EMW;_will be drilled_ using 8.7_ppg mud and MPD technique._ Appr Date 37 Sei_smicanalysisofshallowgas-zones - --- -- - - - - -- - -- - - - - - - - - - - - - -- - - - - - NA_ _ _ _ - _ ---------------------------------------------------------------------- PKB 1/10/2018 38 Seabed condition survey _(ifoff_-shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - -------------------------------------------------------------------- 39 Contact name/phone for week -progress reports [exploratory only] - - - - - - - - - - - - - - - - NA_ - - - - - - - Onshore developmentlateral to be drilled. _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ _ _ Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date � � ►-B?
