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216-085
ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 2S-06 50103207470000 2160850 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com • • ConocoPhillips RECEIVED Alaska SEP 2 6 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC C September 24,2017 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sin rely, Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/25/2017 2S pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2S-05 501032073900 216-039-0 22" 0.05 11" 6/7/2017 1.7 9/10/2017 2S-06 501032074700 216-085-0 4' 0.25 15" 6/10/2017 3.4 9/10/2017 2S-07 501032071300 215-079-0 22" 0.16 11" 6/7/2017 3.4 9/10/2017 2S-08 501032072200 215-174-0 17" 0.10 13" 6/7/2017 3.4 9/10/2017 2S-09A 501032074901 216-128-0 39" 0.30 12" 6/10/2017 4.25 9/20/2017 2S-10 501032071700 215-110-0 10' 1.50 9" 6/10/2017 1.7 9/10/2017 2S-11 501032073200 215-219-0 20" 0.10 10" 6/7/2017 3.4 9/10/2017 2S-12 501032074300. 216-074-0 25" 0.10 13" 6/7/2017 4.8 9/10/2017 2S-13A 501032072001 216-104-0 30" 0.40 9" 6/7/2017 3.4 9/10/2017 2S-14 501032073300 215-220-0 27" 0.24 12" 6/7/2017 3.9 9/10/2017 i DATA SUBMITTAL COMPLIANCE REPORT 12/15/2016 Permit to Drill 2160850 Well Name/No. KUPARUK RIV UNIT 2S-06 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20747-00-00 MD 17998 TVD 6399 Completion Date 9/12/2016 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Mud Log RT5,1�% � Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Sonic/Periscope/Mud Log Well Log Information: Log/ OH / Electr Data Digital Dataset Type Med/Frmt Number Name ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data Log C 27584 Log Header Scans ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data ED C 27584 Digital Data ED C 27585 Digital Data ED C 27585 Digital Data ED C 27585 Digital Data AOGCC (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 9/19/2016 Electronic File: 2S-06 2MD DEL.emf • �� 9/19/2016 1 Electronic File: 2S-06 2MD FEL.emf ' V 9/19/2016 Electronic File: 2S-06 2MD GRL.emf P 9/19/2016 Electronic File: 2S-06 2MD DEL.pdf. P 9/19/2016 Electronic File: 2S-06 2MD FEL.pdf ' P9/19/2016 Electronic File: 2S-06 2MD GRL.pdf ' 9/19/2016 Electronic File: 2S-06 2MD DEL.tif- 9/19/2016 Electronic File: 2S-06 2MD FEL.tif 9/19/2016 Electronic File: 2S-06 2MD GRL.tif ' 0 0 2160850 KUPARUK RIV UNIT 2S-06 LOG HEADERS 2668 7631 10/10/2016 Electronic Data Set, Filename: 2S-06 Chromatograph.las 2667 7630 10/10/2016 Electronic Data Set, Filename: 2S-06 Lith Cuttings.las 2660 7630 10/10/2016 Electronic Data Set, Filename: 2S-06 Lith Interp.las 2667 7631 10/10/2016 Electronic Data Set, Filename: 2S-06 Mudlog.las -2 2667 9/23/2016 Electronic Data Set, Filename: CPAI 2S-06 , VISION Service RM LWD001.1as 2462 7630 9/23/2016 Electronic Data Set, Filename: CPAI 2S-06 VISION Service RM LWD002.las ' 7498 17998 9/23/2016 Electronic Data Set, Filename: CPA[ 2S-06 . VISION Service RM LWD003.las Page 1 of�, Thursday, December 15, 2016 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2016 Permit to Drill 2160850 Well Name/No. KUPARUK RIV UNIT 2S-06 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20747-00-00 MD 17998 TVD 6399 Completion Date 9/12/2016 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 27585 Digital Data -14 17998 9/23/2016 Electronic Data Set, Filename: CPAI 2S-06 VISION Service RM.las +l�^' ED C 27585 Digital Data 102 17998 9/23/2016 Electronic Data Set, Filename: CPAI 2S-06 VISION Service Customer Channel LAS.las ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI 2S-06 VISION Service RM ' LWD001 DLIS.dlis ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI 2S-06 VISION Service RM LWD001 DLIS.html ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI 2S-06 VISION Service RM • LWD002 DLIS.dlis ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI 2S-06 VISION Service RM . LWD002 DLIS.html ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI 2S-06 VISION Service RM LWD003 DLIS.dlis ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI 2S-06 VISION Service RM. LWD003 DLIS.html ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI 2S-06 VISION Service RM DLIS.dlis ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI 2S-06 VISION Service RM DLIS.html ED C 27585 Digital Data 9/23/2016 Electronic File: CPA] _2S- 06_VISION_Service_2in_MD.pdf ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI_2S- 06 VISION Service_2in_TVD.pdf• ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI_2S- 06_VISION_Service_5in_MD.pdf ' ED C 27585 Digital Data 9/23/2016 Electronic File: CPAI_2S- 06 VISION Service 5in TVD.pdf ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad27 EOW CompassSurveys.pdf ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad27 [Canvas].txt ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad27 [Macro].txt ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad27 [Petrel].txt ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad27 [Surveys].txt AOGCC Page 2 o1 3 Thursday, December 15, 2016 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2016 Permit to Drill 2160850 Well Name/No. KUPARUK RIV UNIT 2S-06 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20747-00-00 MD 17998 TVD 6399 Completion Date 9/12/2016 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad83 EOW - CompassSurveys.pdf ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad83 [Canvas].txt ' ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad83 [Macro].txt ' ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad83 [Petrel].txt ' ED C 27585 Digital Data 9/23/2016 Electronic File: 2S-06 Nad83 [Surveys].txt ' Log C 27585 Log Header Scans 0 0 2160850 KUPARUK RIV UNIT 2S-06 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report Production Test Information Y / �A Geologic Markers/Tops COMPLIANCE HISTORY Completion Date: 9/12/2016 Release Date: 7/20/2016 Description Comments: Compliance Reviewed By: AOGCC Directional / Inclination Data Mechanical Integrity Test Information YON Daily Operations Summary D Date Comments Page 3 ot`� Mud Logs, Image Files, Digital Dat<Y / NA Core Chips Y /6 Composite Logs, Image, Data Files I _ Core Photographs Y / Cuttings Samples Y / t�fA� Laboratory Analyses Y /6 - 1 l Date: 2-651 f 5 / 1(0 -—Thursday, December 15, 2016 ConocoPhilli s TRANSMITTAL FROM: Sandra D. Lemke, AT0704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. Th Ave:, Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2S-06 (216-085-0) DATE: 10/10/2016 Kuparuk River Unit, Alaska 2S-06 Halliburton Mud log data E-mail delivery Mud log las Chromatograph las Lith cuttings las Lith interp las �. I Co 085 Please promptly sign, scan and return electronically to 5andra.D.Lemke0ConocophLXs.com 2S-06 transmittal folder, production well files, eSearch Receipt:// ipt:/ /l Date: GIS -Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph; 907.265.6947 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 062015 WELL COMPLETION OR RECOMPLETION REPORT AN LQ 1a. Well Status: Oil R] , Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: - - 20AAC 25.105 20AAC 25.110 Development ❑� Exploratory ❑ ` GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 9/12/2016 216-085 / 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 8/19/2016 50-103-20747-00-00 r 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 2236' FSL, 1408' FEL, Sec 17, T10N, R8E, UM 9/5/2016 KRU 2S-06 Top of Productive Interval: 9. Ref Elevations: KB:159.1 17. Field / Pool(s): 3993' FNL, 1259' FEL, Sec 17, T1 ON, R8E GL: 120 BF: Kupurak River Field/Kuparuk Oil Po Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3563' FNL, 3859' FEL, Sec 29, TION, R8E, UM n/a ADL 25603, ADL 25608 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 481162 y- 5930005 Zone- 4 17998/6399 2677, 2681 TPI: x- 481312 y- 5929055 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 478717 y- 5918933 Zone- 4 N/A 1453/1428 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 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/Sonic/Periscope/Mud Log L 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 62.5 H-40 41 121 41 121 24 Pre -driven, cement to surfac 10.75 45.5 L-80 41 2657 41 2550 13.5 959 sx 11.Oppg LiteCrete, 264 sx 15.8 ppg ClassG 7.625 29.7 L-80 38 7620 38 6357 9.875 Stage 1: 703 sx 15.8ppg ClassG. Stage 2: 256 sx 15.8 ppg ClassG 4.5 12.6 L-80 7480 15375 6338 6371 6.75 Liner 24. Open to production or injection? Yes 2 No ❑ 25. TUBING RECORD If Yes, list each interval open (MD[TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD Size and Number): 31/2 7504 7178/6268 FRAC PORT @ 7846 MD and 6371 TVD, FRAC PORT @ 8348 MD and 6374 TVD 7480/6338 FRAC PORT @ 8892 MD and 6387 TVD, FRAC PORT @ 9439 MD and 6379 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. FRAC PORT @ 9985 MD and 6362 TVD, FRAC PORT @ 10491 MD and 6359 TVD FRAC PORT @ 10975 MD and 6362 TVD, FRAC PORT @ 11550 MD and 6375 TVD FRAC PORT @ 12164 MD and 6364 TVD, FRAC PORT @ 12735 MD and 6389 TVD Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED FRAC PORT @ 13311 MD and 6396TVD, FRAC PORT @ 13921 MD and 6405 TVD FRAC PORT @ 14536 MD and 6398 TVD, FRAC SLEEVE @ 15027 MD and 6378 TVD 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOKUP Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period -1111l. I Flow Tubing Casinq Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate Form 1Q-407 Rise ,12015 �L l 0`/ 2/1 l CCO�TI / D ON PAGE 2 RBDMS 1- -' OCT 10 2016 Submit ORIGINIAL onl 28. CORE DATA Conventional Core(s): Yes ❑ No E Sidewall Cores: Yes ❑ No 2 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 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1453 1428 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7532 6346 information, including reports, per 20 AAC 25.071. Kuparuk C (top C4) 7446 6332 Kuparuk A5 7513 6343 TD (A5) 17998 6399 Formation at total depth: Kuparuk A Sand + 31. List of Attachments: Daily Operations Summary, Cement Report, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolociical report, roduction or well test results. er 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kurt Alexa 263-4933 Email: Kurt. J.Alexa co .com Printed Name: G.L. Alvord Title: Alaska Drilling Manager Signature: /cxDA 441Ai Phone: 265-6120 Date: /47' INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only 2S-06 Interval Name MD TVD Permafrost - Top Surface Surface Permafrost - Base 1453 1428 Top of Productive Interval 7532 6346 Top W Sak 1921 1864 Base W. Sak 2653 2547 C-80 3062 2927 C-37 5036 4837 H RZ 6566 6015 Top upper Kalubik 6869 6160 Top Lower Kalubik 7094 6242 Kuparuk C (top C4) 7446 6332 Kuparuk A 7513 6343 Kuparuk C (top C4) 15636 6386 TD(A5) 17998 6399 Formation at total depth: Kuparuk A Sand KUP PLOD 2S-06 C nowPhiffips Well Attribut. Max Angle J TD Alaska Inc jWeIIboreAPIIUWI I Field Name Wellbore Status nci M MD (ftKB) Act etm (ftKB) 501032074700 KUPARUK RIVER UNIT PROD 94.60 17,569.03 17,99 SSSV- NONF I I II ast WO: 1 1 39.101 9/12/2016 ertce. .msec ,,,,,,,,,,,,, ,,,,,,,,,,,,,,,,,,,„______,____ ........................ HANGER: 36.6' """"""""" Annotation Depth (ftKB) Entl Date Last Tag: Annotation Rev Reason: GLV C/O, PULL RHC PLUG 8 Last Mod By pproven End Date 9/212016 BALL nROD awing rings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (1... Grade Top Thread XO REDUCING; 69.2 CONDUCTOR 16 15.250 41.1 121.1 121.1 62.50 H�0 Welded Casing Description OD (in) IO (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR; 41.1-121.1L SURFACE 10 3/4 9.950 41.3 2,657.0 2,550.5 45.50 L-80 HYD 563 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen p... Gretle Top Thread SURFACE; 41.3-2.657.0 INTERMEDIATE 7518 6.875 38.5 7,620.7 6,357.4 29.70 L-80 Hyd563 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND)... VYtlLen (1... Gratle Top Thread GAS LIFT; 3,667.3 LINER 41/2 3.958 7,479.6 15,375.0 6,370.9 12.60 L-80 TenarisXP BTC -m Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Co. (in) GAS LIFT; 6,825.4 7,479.6 6,337.6 80.41 PACKER Baker "HRD" ZXP 5.5" x 7.63" Flex -Lock Liner 4.850 Hanger 5-1/2'.'Q-125 Hyd 563 pin x pin GAS LIFT; 7,071.6 7,498.9 6,340.8 80.78 NIPPLE Baker 5.5" "RS" Packoff Seal Nipple 17# L-80 4.250 Hyd 563 box x box SLEEVE; 7,130.7 GAUGE, 7,154.4 7,501.3 6,341.2 80.82 HANGER Baker 5.5" x 7.63" " DG" Flex -Lack Liner hanger 4.800 XO Threads; 7,169.0 P110 Hyd 563 pin x pin PACKER; 7,178.8 XO Threads; 7,185.4 7,510.6 6,342.7 81.00 XO Reducing 5.5" Hyd 563 15.5 # box x 4.5" 12.6# Tenaris XP -BTC 3.900 NIPPLE; 7,205.6 pin Crossover LOCATOR; 7,4746 LOCATOR; 7,475.fi 7,693.6 6,363.4 86.22 SWELL PACKER Baker - "Swell Packer #15"- "0" 6. 38" OD SN: 049168-001-14 3.900 7,845.8 6,371.1 86.94 FRAC PORT Baker 4-112" Frac Sleeve #13 - (2.625" Ball, Drift ID 2.573 2.563") PN:10437088 SHOE; 7,501.5 8,074.5 6,381.5 90.11 SWELL Baker -"Swell Packer #14"- "N" 6.38" OD SN: 3.900 PACKER 049168-001-17 8,348.1 6,373.7 91.06 FRAC PORT Baker 4-12" Frac Sleeve #12 - 2.563" Ball, Drift w/ 2.510 2.50" PN:10437087 INTERMEDIATE; 38.8-7,820.7 8,620.1 6,374.3 87.47 SWELL Baker- "Swell Packer #13"- "M" 6.38" OD SN: 3.900 PACKER 049168-001-25 8,892.5 6,387.4 87.75 FRAC PORT Baker 4-1/2" Frac Sleeve #11 - (2.5" Ball, Drift w/ 2.438") PN:10437086 2.448 9,166.2 6,390.5 91.27 SWELL Baker -"Swell Packer #12"- "L" 6.38"OD SN: 3.990 PACKER 049168-001-38 1117 9,439.4 6,3792 92.81 FRAC PORT Baker 4-1/2" Frac Sleeve #10 - (2.438" Ball, Drift w/ 2.375") PN:10437085 2.385 9,710.4 6,370.2 91.55 SWELL Baker- "Swell Packer #11"- "K" 6.38" OD SN: 3.890 PACKER 049168-001-20 9,985.1 6,362.2 91.48 FRAC PORT Baker 4-12" Frac Sleeve #9 - (2.375" Ball, Drift w/ 2.313") PN:10437084 2.323 10,257.6 6,359.7 89.91 SWELL Baker- "Swell Packer #10"- "J" 6.38" OD SN: 3.880 PACKER 049168-001-37 10,490.7 6,358.7 89.50 FRAC PORT Baker 4-1/2" Frac Sleeve #8 - (2.313" Ball, Drift w/ 2.260 2.25") PN10437083 10,753.9 6,361.9 89.52 SWELL Baker -"Swell Packer #9"- "1"5.75"OD SN: 3.970 PACKER 051333-010-8 10,975.3 6,362.4 90.38 FRAC PORT Baker 4-12" Frac Sleeve #7 - (2.25" Ball, Drift w/ 2.198 2.188") PN:10437082 11,238.5 6,365.1 88.00 SWELL Baker -"Swell Packer #8"- "H" 5.75"OD SN: 3.970 PACKER 051333-010-17 11,550.3 6,375.4 89.58 FRAC PORT Baker 4-1/2" Frac Sleeve #6 - (2.188" Ball, Drift w/ 2.125") PN:10457516 2.135 11,854.0 6,369.5 91.94 SWELL Baker -"Swell Packer #7"- "G" 5.75" OD SN: 3.970 PACKER 05133-010-19 12,164.2 6,363.7 90.62 FRAC PORT Baker 4-1/2" Frac Sleeve #5 - (2.125" Ball, Drift w/ 2.073 2.063") PN:10437070 12,425.1 6,372.1 86.61 SWELL Baker- "Swell Packer #6"- "F" 5.75" OD SN: 3.970 PACKER 051333-010-26 12,735.9 6,389.0 87.64 FRAC PORT Baker 4-1/2" Frac Sleeve #4 - (2.063" Ball, Drift wl 2.011 2.00") PN:H810-09-0416 13,041.1 6,396.3 89.99 SWELL Baker -"Swell Packer #5"- "E" 5.75" OD SN: 3.970 PACKER 051333-010-22 13,311.1 6,396.2 90.85 FRAC PORT Baker 4-1/2" Frac Sleeve #3 - (2" Ball, Drift w/ 1.938") 1.948 PN:H810-09-0417 13,613.0 6,394.7 89.89 SWELL PACKER Baker -"Swell Packer #4"- "D" 5.75" OD SN: 051333-010-14 3.970 13,921.6 6,405.5 88.13 FRAC PORT Baker 4-12" Frac Sleeve #2 - (1.938" Ball, Drift w/ 1.886 1.875") PN:H810-09-0418 14,226.8 6,405.6 90.42 SWELL Baker -"Swell Packer #Y- "C" 5.75" OD SN: 3.970 PACKER 051333-010-3 14,536.3 6,398.2 92.78 FRAC PORT Baker 4-1/2" Frac Sleeve #1 - (1.875" Ball, Drift w/ 1.823 1.813") PN:H810-09-0419 14,799.2 6,385.4 92.71 SWELL Baker -"Swell Packer #2"- "B" 5.75" DO SN: 3.970 PACKER 051333-010.4 15,027.6 6,378.2 91.81 FRAC SLEEVE Baker 4-12" Alpha Sleeve PN H810-07-0027 3.010 15,210.3 6,372.1 91.92 SWELL Baker- "Swell Packer #1"- "A" 5.75" OD SN: 3.970 PACKER 051333-010-24 15,235.0 6,371.3 91.42 SLEEVE Baker 4-1/2" Wellbore Isolation Valve (WIV) PN H809 -89-0011 closed w 1.25" ball Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (it Set Depth (TVD)J( ... Wt (Ibnt) Grade Top Connection TUBING 4 1/2" to 3 3 1/2 2.992 36.6 7,504.5 6,34.7 9.30 L-80 EUE-m LINER; 7,479.6-15,375.0 KUP PKIOD 2S-06 C_onocoMillips R Alaska, Inc. HORIZONTAL- 2S-06,1016=16 8:12:20 AM emca aen, ........................ HANGER: 36.6 .................. ............................................................. CompletionDetails Nominal ID XO REDUCING; 69.2 L Top (ftKB) Top (TVD) (ftKB) Top Ind (°) Item Des Com (in) 36.6 36.6 0.00 HANGER Cameron 11" x 4-1/2" IBT-m Tubing Hanger 3.900 CONDUCTOR; 41.1-121.1 69.2 69.2 0.09 XO X0, 4-1/2"12.6# L-80 IBTM box x 3-1/2" 9.3# L-80 EUE 3.063 REDUCING pin SURFACE; 41.32,657.0 7,130.7 6,253.6 71.98 SLEEVE Baker 31/." CMU in closed position w/ 2.813" DS Profile 2.810 GAS LIFT; 3,687.3 7,154.4 6,260.8 72.53 GAUGE Schlumberger Gauge Carrier 31/." TC -II Pin X EUE 8RD- 2.897 Mod Box C13GM-0100 7,178.8 6,268.0 73.05 PACKER Baker Premier Production Packer 659-287 2.870 7,205.6 6,275.7 73.58 NIPPLE Camco 2.75 D nipple 4%" OD (w/ RHC plug body (-73°) 2.750 GAS LIFT; 6,825.4 PULLED 9/18/2016) 7,474.6 6,336.8 80.32 LOCATOR Baker 7.625' x 3.5' Shear pinned Fluted No -Go Sub- 3.000 GAS LIFT; 7,071.9 Large OD SLEEVE; 7,130.7 GAUGE; 7,154.4 -_small 7,475.6 6,337.0 80.34 LOCATOR Baker 7.625' x 3.5' Shear pinned Fluted No -Go Sub- OD 3.000 xo T ; 7,169.0 PACKER; 7178.8 , 7,503.5 6,341.5 80.86 SHOE Mule shoe WLEG, 3-1/2" IBT box 3.010 XO Th -ft:. z185.a NIPPLE; 7,205.6 Mandrel Inserts St LOCATOR; 7,474.6 all LOCATOR; 7,475.6 N Top (ftKB) Top (TVD) Valve Latch PortSize TRORun (ftKB) Make Model 000n) Sew Type Type (tn) (psi) Run Date Co. 1 3,687.3 3,513.6 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 9/11/2016 SHOE; 7,503.5 2 6,825.4 6,141.5 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 9/11/2016 3 7,071.9 6,234.7 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/18/2016 Notes: General & Safety INTERMEDIATE; 3B.6-7,620.7 End Date Annol tion NOTE: 1� IN u LINER; 7,479.6-15,375.0 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (MB) 8/18/2016 8/18/2016 6.00 MIRU MOVE MOB P PJSM- move pipe shed & stage on 0.0 0.0 00:00 06:00 pad. Skid rig floor to moving position & raise stomper boxes. Hook up moving tongue to sub base, then onto sow. Pull sub base off 2S-14. Shuffle mats on pad to keep sub on mats for move. Stage well head equipment behind well. Spot sub base over 2S-06. 8/18/2016 8/18/2016 6.00 MIRU MOVE MOB P PJSM- remove tongue on sub. Lower 0.0 0.0 06:00 12:00 stomper boxes & skid rig floor to drilling position. Spot pit, pump, rock washer, motor, & pipe modules to sub base. Rig up high psi mud lines, hydraulic lines, & electrical connections. Install landings & stairs. Berm around cellar & cuttings box. 8/18/2016 8/18/2016 3.50 MIRU MOVE NUND P PJSM- install risers on surface stack & 0.0 0.0 12:00 15:30 install 4" valves on conductor outlets. Finish service & electrical interconnects. Take on water to pits for making spud mud @ 15:30 hrs. Swap to rig generators from cold starts @ 12:30 hrs. Swap to shore power @ 15:30 hrs. 8/18/2016 8/18/2016 2.00 MIRU MOVE RURD P PJSM- load & strap 5" DP in the pipe 0.0 0.0 15:30 17:30 shed. Install mouse hole in the rotary table. Install service loop guard on the torque tube. Install final section of diverter. Rig accepted at 16:00 hrs. 8/18/2016 8/18/2016 1.00 MIRU MOVE NUND P Energize seals on diverter adapter to 0.0 0.0 17:30 18:30 1400 psi & test to 500 psi for 5 minutes. Set slips on head. 8/18/2016 8/18/2016 0.50 MIRU MOVE SFTY P Pre -spud meeting with Marmon's 0.0 0.0 18:30 19:00 crew. Review 2S-06 pre -spud power point. 8/18/2016 8/19/2016 5.00 MIRU MOVE PULD P PJSM- pick up & rack back 50 stands 0.0 0.0 19:00 00:00 of 5" DP. 8/19/2016 8/19/2016 4.00 MIRU MOVE PULD P PJSM- P/U 32 stands of 5" DP and 0.0 0.0 00:00 04:00 rack back. torque 28K 8/19/2016 8/19/2016 1.00 MIRU MOVE PULD P P/U 6 stands of HWDP and rack back 0.0 0.0 04:00 05:00 - tag TOC @ 110' 8/19/2016 8/19/2016 2.00 MIRU MOVE BOPE P Perform Diverter test. Witness waived 0.0 0.0 05:00 07:00 by Bob Noble Annular close time 36 sec, Knife valve open time 6 sec. Sys press 3000psi After close 1900 psi 200 psi re -charge 6 sec full recharge time 47 sec. 8/19/2016 8/19/2016 3.00 MIRU MOVE BHAH P PJSM- PU jewelry for BHA #1 - stage 0.0 110.0 07:00 10:00 on Rig floor. Load GYRO pulse tool. PU 7" DC and rack back. PU BHA #1 with 13 1/2" Milled tooth bit as per SLB DD f/ 0-110' MD. 8/19/2016 8/19/2016 0.25 MIRU MOVE SEQP P PJSM - flood all lines & fill hole 110.0 110.0 10:00 10:15 checking for leaks. Test surface lines to 3500 psi for 5 min. Page 1/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/19/2016 8/19/2016 1.75 SURFAC DRILL DDRL P DDrill 13-1/2" surface section f/ 110'- 110.0 212.0 10:15 12:00 212' MD, 212' TVD, 212 gpm, 400 psi, 50 rpm, Tq on 3K, off 1 K, WOB 15K, FO 23%, PU 71 K, SO 69K, ROT 62K, ADT .57, AST 0, Bit .57, Jars 29.23, Gas 0 units, footage 102' MD. 8/19/2016 8/19/2016 6.00 SURFAC DRILL DDRL P DDrill 13-1/2" surface section f/ 212' - 212.0 614.0 12:00 18:00 614' MD, 614' TVD, 450 gpm, 575 psi, 50 rpm, Tq on 4K, off 1 K, WOB 19K, FO 25%, PU 86K, SO 89K, ROT 88K, ADT 1.65, AST 1.2, Bit 3.42, Jars 30.2, Gas 0 units, footage 402' MD. 8/19/2016 8/19/2016 1.00 SURFAC DRILL RGRP T Drag chain to rock washer bound up & 614.0 614.0 18:00 19:00 stopped. Clear drag chain box of cuttings & find paddle caught on cross brace. Remove cross braces to return to service. 8/19/2016 8/19/2016 0.75 SURFAC DRILL DDRL P DDrill 13-1/2" surface section f/ 614' - 614.0 682.0 19:00 19:45 682' MD, 682' TVD, 450 gpm, 800 psi, 50 rpm, Tq on 4K, off 1 K, WOB 20K, FO 25%, PU 86K, SO 89K, ROT 88K, ADT .75, AST .14, Bit 4.17, Jars 30.95, Gas 0 units, footage 68' MD. 8/19/2016 8/19/2016 0.25 SURFAC DRILL SVRG P PJSM- service & adjust drag chain. 682.0 682.0 19:45 20:00 8/19/2016 8/19/2016 2.75 SURFAC DRILL DDRL P DDrill 13-1/2" surface section f/ 682' - 682.0 922.0 20:00 22:45 922' MD, 920' TVD, 500 gpm, 970 psi, 50 rpm, Tq on 5K, off 1 K, WOB 26K, FO 30%, PU 86K, SO 89K, ROT 89K, ADT 1.72, AST 1.2, Bit 5.89, Jars 32.67, Gas 0 units, footage 240' MD. 8/19/2016 8/19/2016 0.25 SURFAC DRILL SVRG P PJSM- service & adjust drag chain. 922.0 922.0 22:45 23:00 8/19/2016 8/19/2016 0.50 SURFAC DRILL DDRL P DDrill 13-1/2" surface section f/ 922' - 922.0 974.0 23:00 23:30 974' MD, 970' TVD, 500 gpm, 960 psi, 50 rpm, Tq on 5K, off 2K, WOB 26K, FO 30%, PU 87K, SO 88K, ROT 87K, ADT .5, AST .26, Bit 6.39, Jars 33.17, Gas 0 units, footage 52' MD. 8/19/2016 8/20/2016 0.50 SURFAC DRILL RGRP T Drag chain to rock washer bound up & 974.0 974.0 23:30 00:00 stopped. Clear drag chain box of cuttings & find paddle caught on another cross brace. Begin removing cross brace. 8/20/2016 8/20/2016 1.00 SURFAC DRILL RGRP T Drag chain to rock washer bound up & 974.0 974.0 00:00 01:00 stopped. Clear drag chain box of cuttings & find paddle bound up in cutting chute section of drag chain. Free up & return to service. 8/20/2016 8/20/2016 1.00 SURFAC DRILL DDRL P DDrill 13-1/2" surface section f/ 974'- 974.0 1,044.0 01:00 02:00 1044' MD, 1038' TVD, 500 gpm, 890 psi, 50 rpm, Tq on 5K, off 2K, WOB 17 -26K, FO 30%, PU 98K, SO 97K, ROT 95K, Gas 0 units, footage 70' MD. Page 2/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftK8) 8/20/2016 8/20/2016 1.25 SURFAC DRILL RGRP T Drag chain to rock washer bound up & 1,044.0 1,044.0 02:00 03:15 stopped. Clear drag chain box of cuttings & find rock between link of the chain, not allowing it to pass sprocket. Remove rock, adjust chain tension, & return to service. 8/20/2016 8/20/2016 2.75 SURFAC DRILL DDRL P DDrill 13-1/2" surface section f/ 1044'- 1,044.0 1,248.0 03:15 06:00 1248' MD, 1237' TVD, 500 gpm, 1150 psi, 50 rpm, Tq on 5K, off 2K, WOB 20 -26K, FO 30%, PU 99K, SO 97K, ROT 95K, Gas 0 units, footage 70' MD. ADT 2.89, AST 1.42, BIT 9.28, JARS 36.06 total hrs f/ 00:00-06:00 hrs. 8/20/2016 8/20/2016 6.00 SURFAC DRILL DDRL P DDrill 13-1/2" surface section f/ 1248'- 1,248.0 1,817.0 06:00 12:00 1817' MD, 1767' TVD, 600 gpm, 1430 psi, 50 rpm, Tq on 5K, off 3K, WOB 5- 26K, FO 34%, PU 117K, SO 106K, ROT 11 OK, Gas 0 units, footage 569' MD. ADT 4.35, AST 2.6, BIT 13.63, JARS 40.41 hrs total for previous 6 hrs. 8/20/2016 8/20/2016 7.00 SURFAC DRILL DDRL P DDrill 13-1/2" surface section to TD, f/ 1,817.0 2,667.0 12:00 19:00 1817'- 2667' MD, 2560' TVD, 750 gpm, 2340 psi, 80 rpm, Tq on 6K, off 4K, WOB 27K, FO 31 %, PU 131 K, SO 122K, ROT 127K, Gas 0 units, footage 850' MD. ADT 4.74, AST .22, BIT 17.57, JARS 44.35 hrs total for previous 7 hrs. 8/20/2016 8/20/2016 1.00 SURFAC CASING CIRC P Circulate & condition f/ 2667'-2575' 2,667.0 2,575.0 19:00 20:00 MD, 725 gpm, 1994 psi, 80 rpm, Tq 4K, PU 131 K, SO 122K, pumped 9883 strokes. 8/20/2016 8/20/2016 0.50 SURFAC CASING OWFF P Monitor well, static. SIMOPS mobilize 2,575.0 2,575.0 20:00 20:30 casing equipment to rig floor. 8/20/2016 8/20/2016 2.75 SURFAC CASING BKRM P PJSM- BROOH f/ 2575'-1630' MD, 2,575.0 1,630.0 20:30 23:15 700 gpm, 1790 psi, FO 31%, 60 rpm, Tq 3.5K, 1000 fph, PU 11 OK, SO 107K, ROT 106K. 8/20/2016 8/21/2016 0.75 SURFAC CASING BKRM P PJSM- BROOH f/ 1630'-1440' MD, 1,630.0 1,440.0 23:15 00:00 600 gpm, 1290 psi, FO 28%, 60 rpm, Tq 3.5K, 300 fph, PU 106K, SO 105K, ROT 105K. 8/21/2016 8/21/2016 2.00 SURFAC CASING TRIP P TOOH on elevators UW = 68K, DW = 1,440.0 770.0 00:00 02:00 68K Monitor well on trip tank 8/21/2016 8/21/2016 3.00 SURFAC CASING BHAH P Lay down BHA#1 and clear rig floor. 770.0 0.0 02:00 05:00 8/21/2016 8/21/2016 1.50 SURFAC CASING RURD P Clean up rig floor of BHA subs and 0.0 0.0 05:00 06:30 handling equipment. R/U casing handling equipment & Volant CRT. 8/21/2016 8/21/2016 1.50 SURFAC CASING PUTB P PJSM - P/U 10.3/4" 45.5#, L-80 0.0 165.0 06:30 08:00 dopeless Hyd 563 casing, M/U shoe track & check floats, baker lock first four connections, install Bow spring centralizers 10' above shoe and 10' below float collar. Page 3/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 416.0 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (WB) End Depth (ftKB) 8/21/2016 8/21/2016 5.50 SURFAC CASING PUTB P Continue to run casing f/ 166- 1428' 165.0 1,428.0 08:00 13:30 MD, installing bow spring centralizers on every collar. M/U torque 19,500#, fill every 10 joints, monitor returns. PU 107K, SO 47K. 8/21/2016 8/21/2016 0.75 SURFAC CASING CIRC P Circulate & condition mud f/ 1428'- 1,428.0 1,466.0 13:30 14:15 1466' MD, stage up pump to 4.5 bpm, ICP 239 psi, FCP 56 psi, PU 107K, SO 92K, pumped 1396 strokes. 8/21/2016 8/21/2016 3.25 SURFAC CASING PUTB P Continue to run casing f/ 1466' - 2612' 1,466.0 2,612.0 14:15 17:30 MD, installing bow spring centralizers on every collar. M/U torque 19,500#, fill every 10 joints, monitor returns. PU 107K, SO 47K. 8/21/2016 8/21/2016 0.50 SURFAC CASING HOSO P PJSM- make up hanger & landing 2,612.0 2,657.0 17:30 18:00 joint, wash down at 1 bpm, 105 psi, FO 3%, PU 164K, SO 115K, land hanger on landing ring at 2657' MD. 8/21/2016 8/21/2016 0.25 SURFAC CEMENT RURD P PJSM- blow down topdrive & rig up 2,657.0 2,657.0 18:00 18:15 cement hose. 8/21/2016 8/21/2016 3.25 SURFAC CEMENT CIRC P Circulate & condition mud for cement 2,657.0 2,657.0 18:15 21:30 job. Stage up pumps 1 - 6 bpm, ICP 105 psi, FCP 150 psi, FO 15%. PU 146K, SO 126K with pumps on. 8/21/2016 8/22/2016 2.50 SURFAC CEMENT CMNT P Flood lines with H2O & test to 3500 2,657.0 2,657.0 21:30 00:00 psi. Pump 20 bbls CW -100 at 5.8 bpm, 105 psi. Pump 75.5 bbls 10.5 ppg MPII w/red dye at 3.5-4 bpm, 100 psi. Shut down and drop bottom Davis Lynch anti -rotation plug. Pumped 340 bbls 11 ppg LiteCRETE lead cement at 6.8 bpm, 190 psi. Reciprocate pipe 10' with full returns. Pumped 54.6 bbls 15.8 ppg Class G tail cement at 5 bpm, 300 psi. Observe MPII spacer at surface 52 bbls into tail cement pumped. Drop Davis Lynch anti - rotation top plug. Kicked top plug out with 10 bbls of H2O. Swapped to rig pumps and displaced cement with 10.0 ppg spud mud @ 6 bpm, 250 psi. Slow pump to 3 bpm, 62 psi after diverting flow to cellar with cement returns. Pumped 639 strokes of displacement at 24:00 hrs. 8/22/2016 8/22/2016 1.00 SURFAC CEMENT CMNT P PJSM- displaced cement with 10.0 2,657.0 0.0 00:00 01:00 ppg spud mud @ 4-6 bpm / 170 psi increasing to 620 psi, Observed lead cement at surface 85 bbls into displacement. Slow rate to 3bpm at 10 bbls prior to calculated displacement. Bumped plug @ 2263 strokes, FCP = 620 psi. Pressured up to 1150 psi and held for 5 min then bled off and checked floats - floats held. CIP @ 00:40 hrs 8-22-16. 143 bbls of lead cement returned to surface. Cement 24" below top of conductor. Page 4/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/22/2016 8/22/2016 2.00 SURFAC CEMENT RURD P PJSM- flush stack and clear of 0.0 0.0 01:00 03:00 cement. Blow & rig down all lines. Lay down CRT & landing joint. Clean & clear rig floor of all casing running equipment. 8/22/2016 8/22/2016 3.50 SURFAC WHDBOP NUND P PJSM- nipple down surface stack & 0.0 0.0 03:00 06:30 diverter system. 8/22/2016 8/22/2016 2.50 SURFAC WHDBOP NUND P PJSM- nipple down diverter adapter. 0.0 0.0 06:30 09:00 Nipple up well head & test seals to 5000 psi for 10 minutes as per CIW Rep, CPAI witnessed. 8/22/2016 8/22/2016 4.00 SURFAC WHDBOP NUND P PJSM- nipple up adapter & spacer 0.0 0.0 09:00 13:00 spools. Nipple up BOP stack to spacer spool. Hook up Kill & Choke lines. 8/22/2016 8/22/2016 4.00 SURFAC CEMENT MPDA P PJSM- install RCD & air valve to the 0.0 0.0 13:00 17:00 same. Hook up all MPD lines & hoses. SIMOPS mobilize split bushings & trip nipple to the rig floor. 8/22/2016 8/22/2016 1.00 SURFAC WHDBOP RURD P PJSM- pick up 5" test joint. Change 0.0 0.0 17:00 18:00 out seals on test plug, then install. 8/22/2016 8/22/2016 1.00 SURFAC WHDBOP BOPE P PJSM- perform shell test on BOP 0.0 0.0 18:00 19:00 stack after BWM. Replace seal rings at gray-loc connections on Kill & Choke lines then retest. 8/22/2016 8/22/2016 3.50 SURFAC WHDBOP BOPE P All tests with 5" TJ. 250/3500 psi, 0.0 0.0 19:00 22:30 charted for 5 minutes each. 1) Annular; CV #1, 12, 13, 14, 4" Kill line Demco on mud manifold, & 4-1/2" IF Dart valve. 2) Upper 3-1/2" X 6" VBR's, CV #9,11, Mezzanine Kill line Demco, & 4-1/2" IF FOSV. 3) CV #8, 10, & HCR Kill 4)CV#6&7. 5) Super choke & manual choke tested to 1500 psi. 6) CV #2, 5 & Manual Kill 7) HCR Choke & upper Top Drive IBOP 8) Manual Choke & lower Top Drive IBOP. 9) Lower 3-1/2" X 6" VBR's 10) Blind rams, CV #3, 4, Perform Koomey draw down test initial system pressure 3000 psi, after closure 1800 psi, 200 psi attained in 6 sec, full pressure attained in 44 sec, 6 nitrogen bottles with an average pressure of 2633 psi. Test pit level & flow out alarms. All H2S and Combustible gas alarms tested. Witness waived by AOGCC Rep. Bob Noble. SIMOPS rig up MPD choke skid & mobilize BHA 2 to rig floor. 8/22/2016 8/22/2016 0.25 SURFAC WHDBOP RURD P PJSM- remove test joint, drain stack & 0.0 0.0 22:30 22:45 remove trip nipple. 8/22/2016 8/22/2016 0.50 SURFAC CEMENT MPDA P PJSM- install MPD test cap. Test air 0.0 0.0 22:45 23:15 valve & LT -4 to 250 / 1500 psi, charted 5 minutes each. Page 5/30 Report Printed: 911412016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 8/22/2016 8/23/2016 0.75 SURFAC CEMENT MPDA P Remove RCD test cap & install trip 0.0 0.0 23:15 00:00 nipple. Pull test plug & install 10" ID wear bushing, RILDS x2. Blow down all test equipment. 8/23/2016 8/23/2016 0.50 SURFAC CEMENT RURD P PJSM- clear & clean rig floor. 0.0 0.0 00:00 00:30 8/23/2016 8/23/2016 3.00 SURFAC CEMENT BHAH P PJSM- pick up BHA 2 as per SLB to 0.0 789.0 00:30 03:30 789' MD. 8/23/2016 8/23/2016 1.50 SURFAC CEMENT TRIP P PJSM- TIH f/ 789'- 2398' MD, PU 789.0 2,398.0 03:30 05:00 131 K, SO 109K. 8/23/2016 8/23/2016 0.75 SURFAC CEMENT CIRC P Circulate & condition at 605 gpm, 2,398.0 2,398.0 05:00 05:45 1590 psi, FO 23%, MW 10.0 ppg. 8/23/2016 8/23/2016 0.50 SURFAC CEMENT RURD P PJSM- rig up to test casing. Line up & 2,398.0 2,398.0 05:45 06:15 pump through kill line. 8/23/2016 8/23/2016 0.50 SURFAC CEMENT PRTS T PJSM- pressure up to 2400 psi & 2,398.0 2,398.0 06:15 06:45 observe chart recorder pressure stop. Down & trouble shoot. Replace sensator hose to retest. 8/23/2016 8/23/2016 0.50 SURFAC CEMENT 1 PRTS P Pressure test 10-3/4", 45.5#, surface 2,398.0 2,398.0 06:45 07:15 casing to 3500 psi for 30 minutes, charted. Pumped 3.7 bbls and bled back 3.7 bbls. 8/23/2016 8/23/2016 0.50 SURFAC CEMENT RURD P PJSM- rig down test equipment & 2,398.0 2,398.0 07:15 07:45 blow down lines. 8/23/2016 8/23/2016 1.00 SURFAC CEMENT WASH P Wash down f/ 2398'-2549' MD, 171 2,398.0 2,549.0 07:45 08:45 gpm, 135 psi, obtain slow circulating rates. TOC 2549' MD. SCR @ 2497' MD, 2396' TVD, MW 10.0 ppg, 08:30 hrs. #1 @ 30=110; @ 40=160 psi #2 @ 30=110; @ 40=160 psi 8/23/2016 8/23/2016 2.75 SURFAC CEMENT DRLG P Drill out cement, plugs, float collar, 2,549.0 2,667.0 08:45 11:30 shoe & rat hole f/ 2549'-2667' MD, 300 -500 gpm, 460-1150 psi, 30-60 rpm, Tq 4-81K, FO 20%, WOB 5-20K, PU 131 K, SO 109K, ROT 122K. 8/23/2016 8/23/2016 0.25 SURFAC CEMENT DDRL P Directional drill f/ 2667'-2687' MD, 500 2,667.0 2,687.0 11:30 11:45 gpm, 1150 psi, 60 rpm, Tq on 6K, off 5K, FO 22%, WOB 5-7K, PU 131 K, SO 109K, ROT 122K. ADT .20, BIT .20, JARS .20 total footage 20' MD. 8/23/2016 8/23/2016 1.25 SURFAC CEMENT CIRC P Circulate & condition at 350 gpm, 550 2,687.0 2,592.0 11:45 13:00 psi, 43 rpm, Tq 5-6K, PU 140K, SO 112K, ROT 127K, pumped 5815 strokes. 8/23/2016 8/23/2016 0.75 SURFAC CEMENT LOT P Perform LOT @ 2657' MD, 2550' TVD, 2,592.0 2,592.0 13:00 13:45 MW 9.7 ppg to an EMW of 14.9 ppg. Pressured up to 800 psi with 1.0 bbls @ 6 spm. Observed pressure deviate at 690 psi. Shut in and observe pressure for 10 minutes. Pressure decreased from 800 psi to 630 psi. Bled back 1.0 bbls. 8/23/2016 8/23/2016 1.25 INTRM1 DRILL REAM P Wash & ream down f/ 2592'-2687' MD, 2,592.0 2,687.0 13:45 15:00 650 gpm, 1325 psi, FO 24%, 70 rpm, Tq 5K. Page 6/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/23/2016 8/23/2016 2.00 INTRM1 DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 2,687.0 2,780.0 15:00 17:00 f/ 2687'-2780' MD, 2664' TVD, 700 gpm, 1425 psi, 100 rpm, Tq on 5K, off 4K, WOB 10K, FO 25%, PU 140K, SO 112K, ROT 127K, Gas 0 units, footage 93' MD. ADT 1.69, AST .22, BIT 1.89, JARS 1.89 hrs. SIMOPS displace well to 9.2 ppg LSND mud system. 8/23/2016 8/23/2016 0.50 INTRM1 DRILL CIRC P Break connection & pump down RFID 2,780.0 2,780.0 17:00 17:30 chips per WFT Rep to open reamer. Drop pump rate to 300 gpm while RFID chips pass tool, then stage back up to 700 gpm, initial pressure 1460 psi dropping to 1215 psi, MWD turbine speed dropped from 2773 rpm to 2226 rpm indicating knives opened. Pull up to shoe & observe 5K over pull to verify reamer open. 8/23/2016 8/23/2016 3.50 INTRMI DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 2,780.0 3,081.0 17:30 21:00 f/ 2780'-3081' MD, 2945' TVD, 800 gpm, 1586 psi, 140 rpm, Tq on 7K, off 4K, WOB 7K, FO 26%, PU 141 K, SO 112K, ROT 125K, ECD 9.96, Gas 3 units, footage 301' MD. ADT X, BIT X, JARS X hrs. 8/23/2016 8/23/2016 0.50 INTRMI DRILL SVRG P Service top drive, grease wash pipe, & 3,081.0 3,081.0 21:00 21:30 change out swab on #1 MP. 8/23/2016 8/24/2016 2.50 INTRM1 DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 3,081.0 3,310.0 21:30 00:00 f/ 3081'-3310' MD, 3157' TVD, 800 gpm, 1620 psi, 150 rpm, Tq on 8K, off 5K, WOB 9K, FO 26%, PU 153K, SO 124K, ROT 136K, ECD 9.98, Gas 3 units, footage 229' MD. ADT 4.07, BIT 5.96, JARS 5.96 hrs. 8/24/2016 8/24/2016 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 3,310.0 3,917.0 00:00 06:00 f/ 3310'-3917' MD, 3737' TVD, 800 gpm, 1830 psi, 150 rpm, Tq on 8-11 K, off 7K, WOB 12-14K, FO 28%, PU 173K, SO 132K, ROT 145K, ECD 10.26, Gas 3 units, footage 607' MD. ADT 4.41, BIT 10.37, JARS 10.37 hrs. SCR @ 3348' MD, 3193' TVD, MW 9.2 ppg, 00:20 hrs. #1 @ 30=140; @ 40=180 psi #2 @ 30=140; @ 40=180 psi 8/24/2016 8/24/2016 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 3,917.0 4,515.0 06:00 12:00 f/ 3917'-4515' MD, 4330' TVD, 800 gpm, 1798 psi, 150 rpm, Tq on 9-12K, off 12-17K, WOB 12-14K, FO 29%, PU 187K, SO 138K, ROT 158K, ECD 10.33, Gas 37 units, footage 598' MD. ADT 4.73, BIT 15.10, JARS 15.10 hrs. SCR @ 4391' MD, 4206' TVD, MW 9.2 ppg, 10:35 hrs. #1 @ 30=200; @ 40=250 psi #2 @ 30=200; @ 40=250 psi Page 7130 Report Printed: 9/14/2016 g 4_ Operations Summary (with Timelog Depths) tea; -�_ 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/24/2016 8/24/2016 3.50 INTRM1 DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 4,515.0 4,865.0 12:00 15:30 f/ 4515'-4865' MD, 4674' TVD, 800 gpm, 2237 psi, 150 rpm, Tq on 6-13K, off 8K, WOB 16K, FO 29%, PU 206K, SO 144K, ROT 167K, ECD 10.50, MW 9.4+, Gas 32 units, footage 350' MD. ADT 2.6, BIT 17.68, JARS 17.68 hrs. 8/24/2016 8/24/2016 1.00 INTRM1 DRILL MPDA P PJSM- remove trip nipple & install 4,865.0 4,865.0 15:30 16:30 drain nipple. Stab bearing on a stand & make up to RCD. SCR @ 4868' MD, 4678' TVD, MW 9.4+ ppg, 16:30 hrs. #1 @ 30=200; @ 40=230 psi #2 @ 30=200; @ 40=230 psi 8/24/2016 8/24/2016 6.25 INTRM1 DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 4,865.0 5,516.0 16:30 22:45 f/ 4865'-5516' MD, 5269' TVD, 800 gpm, 2525 psi, 150 rpm, Tq on 6-15K, off 10K, WOB 18K, FO 31%, PU 214K, SO 153K, ROT 176K, ECD 10.73, MW 9.2+, Gas 70 units, footage 651' MD. 8/24/2016 8/24/2016 0.25 INTRM1 DRILL OTHR T Loose shore power, fire up rig 5,516.0 5,516.0 22:45 23:00 generators. Line up on rig power, pick up off bottom, establish drilling parameters. Kick w/ Drilling CRT 136 sec @ 22:40 hrs. 8/24/2016 8/25/2016 1.00 INTRMI DRILL DDRL P DDrill 9-7/8"X11 intermediate section 5,516.0 5,560.0 23:00 00:00 f/ 5516'-5560' MD, 5339' TVD, 800 gpm, 2525 psi, 150 rpm, Tq on 6-15K, off 1 OK, WOB 18K, FO 31 %, PU 214K, SO 153K, ROT 176K, ECD 10.73, MW 9.2+, Gas 70 units, footage 44' MD. ADT 5.6, BIT 23.3, JARS 23.3 hrs. SCR @ 5516' MD, 5272' TVD, MW 9.2+ ppg, 23:20 hrs. #1 @ 30=210; @ 40=230 psi #2 @ 30=220; @ 40=235 psi 8/25/2016 8/25/2016 3.25 INTRMI DRILL DDRL P DDrill 9-7/8"X11 intermediate section 5,560.0 5,930.0 00:00 03:15 f/ 5560'-5930' MD, 5598' TVD, 825 gpm, 2705 psi, 140 rpm, Tq on 12- 17K, off 12K, WOB 21 K, FO 31 %, PU 221 K, SO 159K, ROT 180K, ECD 10.69, MW 9.6+, Gas 137 units, footage 370' MD. ADT 2.45, BIT 25.75, JARS 25.75 hrs. 8/25/2016 8/25/2016 0.75 INTRMI DRILL FIT P PJSM- perform dynamic open hole 5,930.0 5,930.0 03:15 04:00 FIT to an EMW of 12.03 ppg with a MW of 9.7 ppg. Begin test pumping at 700 gpm, 2082 psi, choke position 100%, choke pressure 34 psi, ECD 10.42 ppg, 50 rpm, Tq 10K. Incrementally close the choke position to 42%, choke pressure 515 psi, pumps 2506 psi, & 12.03 ECD. Both choke position & pressure remained constant while observing a 12.03 ppg for 2 minutes. Stepped down back pressure incrementally to chokes 100% open. Page 8/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/25/2016 8/25/2016 2.00 INTRM1 DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 5,930.0 6,128.0 04:00 06:00 f/ 5930'-6128' MD, 5925' TVD, 825 gpm, 2765 psi, 150 rpm, Tq on 13- 20K, off 12K, WOB 20-24K, FO 32%, PU 223K, SO 160K, ROT 181 K, ECD 10.62, MW 9.6+, Gas 260 units, footage 198' MD. ADT 1.51, BIT 27.26, JARS 27.26 hrs. SCR @ 6097' MD, 5725' TVD, MW 9.6+ ppg, 05:35 hrs. #1 @ 30=200; @ 40=250 psi #2 @ 30=200; @ 40=250 psi 8/25/2016 8/25/2016 6.00 INTRM1 DRILL DDRL P DDrill 9-7/8"X11"" intermediate section 6,128.0 6,775.0 06:00 12:00 f/ 6128'-6775' MD, 6120' TVD, 825 gpm, 2810 psi, 150 rpm, Tq on 12- 18K, off 13K, WOB 15-24K, FO 32%, PU 238K, SO 158K, ROT 187K, ECD 11.26, MW 10.0, Gas 384 units, footage 647' MD. ADT 4.25, BIT 31.51, JARS 31.51 hrs. Kick w/ Drilling CRT 180 sec @ 07:43 hrs. SCR @ 6477' MD, 5968' TVD, MW 9.85 ppg, 09:00 hrs. #1 @ 30=210; @ 40=270 psi #2 @ 30=210; @ 40=270 psi 8/25/2016 8/25/2016 3.25 INTRM1 DRILL DDRL P DDrill 9-7/8"X11 intermediate section 6,775.0 7,146.0 12:00 15:15 f/ 6775'-7146' MD, 6258' TVD, 810 gpm, 3117 psi, 150 rpm, Tq on 14- 17K, off 12K, WOB 30K, FO 32%, PU 251K, SO 1584K, ROT 188K, ECD 11.44, MW 10. 0, Gas 211 units, footage 371' MD. ADT 2.19, BIT 33.70, JARS 33.70 hrs. Spill Drill CRT 126 sec @ 14:25 hrs. SCR @ 7043' MD, 6231' TVD, MW 10.0 ppg, 14:20 hrs. #1 @ 30=250; @ 40=300 psi #2 @ 30=250; @ 40=300 psi 8/25/2016 8/25/2016 1.00 INTRM1 DRILL CIRC P C&C mud system at 808 gpm, 3123 7,146.0 7,146.0 15:15 16:15 psi, 150 rpm, Tq 12K, FO 29%, 11.14 ECD, strokes pumped 6350. 8/25/2016 8/25/2016 0.50 INTRM1 DRILL LOT P Perform static open hole LOT to an 7,146.0 7,146.0 16:15 16:45 EMW of 11.6 ppg with 10.0 ppg MW at 7144' MD, 6364' TVD. Stage up pressure f/ 0-495 psi at 2 spm. Observed pressure break over at 495 psi & decrease next 2 strokes. Shut in & observe pressure for 10 minutes decreasing from 434 to 338 psi. Pumped 3.3 bbls & bleed back 3 bbls. 8/25/2016 8/25/2016 0.75 INTRM1 DRILL DDRL P DDrill 9-7/8"X11 intermediate section 7,146.0 7,263.0 16:45 17:30 f/ 7146'-7263' MD, 6291' TVD, 810 gpm, 3123 psi, 150 rpm, Tq on 14- 17K, off 12K, WOB 30K, FO 32%, PU 251 K, SO 154K, ROT 188K, ECD 11.37, MW 10.0, Gas 211 units, footage 117' MD. Page 9/30 Report Printed: 9/14/2016 - Operations Summary (with Timelog Depths) 2S-06 .... I IMF Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftK8) 8/25/2016 8/25/2016 1.75 INTRM1 DRILL CIRC P C&C mud system at 808 gpm, 3070 7,263.0 7,263.0 17:30 19:15 psi, 600 rpm, Tq 14K, FO 29%,11.04 ECD, strokes pumped 20784. Confer w/ town & begin well bore strengthening mud system w/ 1 ppb nut plug fine, 2 ppb Safe -Garb 40, 2 ppb Safe-Carb 250. 8/25/2016 8/26/2016 4.75 INTRM1 DRILL DDRL P DDrill 9-7/8"X11 intermediate section 7,263.0 7,451.0 19:15 00:00 f/ 7263'-7451' MD, 6334' TVD, 800 gpm, 3045 psi, 150 rpm, Tq on 9-17K, off 12K, WOB 30K, FO 32%, PU 251 K, SO 154K, ROT 188K, ECD 11.06, MW 10.0, Gas 411 units, footage 188' MD. ADT 3.94, BIT 38.21, JARS 38.25 hrs. 8/26/2016 8/26/2016 4.50 INTRMI DRILL DDRL P DDrill 9-7/8"X11 intermediate section 7,451.0 7,629.0 00:00 04:30 f/ 7451'-7629' MD, 6358' TVD, 800 gpm, 2930 psi, 150 rpm, Tq on 12- 17K, off 15K, WOB 10-15K, FO 30%, PU 260K, SO 133K, ROT 181K, ECD 11. 15, MW 10.3, Gas 327 units, footage 178' MD. ADT 3.57, BIT 41.78, JARS 41.78 hrs. SCR @ 7521' MD, 6349' TVD, MW 10.4 ppg, 01:30 hrs. #1 @ 30=250; @ 40=335 psi #2 @ 30=270; @ 40=355 psi 8/26/2016 8/26/2016 0.50 INTRM1 CASING SRVY P Shoot final surveys, obtain T&D, & 7,629.0 7,629.0 04:30 05:00 SCR's. SCR @ 7629' MD, 6359' TVD, MW 10.3+ ppg, 04:42 hrs. #1 @ 30=250; @ 40=320 psi #2 @ 30=250; @ 40=320 psi 8/26/2016 8/26/2016 0.50 INTRMI CASING OWFF P Perform no flow test w/ MPD. Open 7,629.0 7,629.0 05:00 05:30 choke to 50% for 5 seconds & shut in. Observe pressure build up, decrease each time over a 3 minute interval. Continue until, well static. 8/26/2016 8/26/2016 0.75 INTRM1 CASING CIRC P PJSM- close under reamer as per 7,629.0 7,629.0 05:30 06:15 WFT Rep. f/ 7629'-7618' MD, pump down 6 RFID closing chips at 300 gpm, 750 psi. Wait 10 minutes. Pump at 600 gpm, 2128 psi, 60 rpm, Tq 17K, turbine 2421 rpm. Initial parameters 600 gpm, 1875 psi, 60 rpm, Tq 15- 17K, turbine 1992 rpm. 8/26/2016 8/26/2016 5.25 INTRMI CASING PMPO P PJSM- pump out of hole f/ 7629'-6574' 7,629.0 6,574.0 06:15 11:30 MD, @ 650-600 gpm, 2400-2150 psi, ECD 11.3 ppg. Slowed pulling rate & pump speed to keep under 11.3 ppg ECD. 8/26/2016 8/26/2016 0.75 INTRM1 CASING CIRC P CBU f/ 6574'-6479' MD, 650 gpm, 6,574.0 6,479.0 11:30 12:15 2346 psi, 120 rpm, Tq 9-15K. Fire Drill CRT 180 sec @ 11:41 hrs. 8/26/2016 8/26/2016 0.75 INTRM1 CASING OWFF P Monitor well at 10 rpm, Tq 12K, static. 6,479.0 6,479.0 12:15 13:00 SIMOPS blow down TD & PT MPD high pressure line to 1000 psi. 8/26/2016 8/26/2016 4.50 INTRM1 CASING SMPD P PJSM- TOH f/ 6479'-2590' MD, 6,479.0 2,590.0 13:00 17:30 holding 90 psi out of slips, 40 psi in slips, PU 135K, SO 111 K. Page 10/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/26/2016 8/26/2016 1.00 INTRM1 CASING CIRC P Circulate hole clean at 654 gpm, 1830 2,590.0 2,590.0 17:30 18:30 psi, FO 32%, 60 rpm, Tq 5K, send downlinks to MWD. 8/26/2016 8/26/2016 1.00 INTRM1 CASING OWFF P Monitor well with slight increase 2,590.0 2,590.0 18:30 19:30 circulating across the top of the hole. Open port on RCD to observe well static. 8/26/2016 8/26/2016 1.00 INTRM1 CASING MPDA P PJSM- remove MPD riser & RCD. 2,590.0 2,590.0 19:30 20:30 Install trip nipple. 8/26/2016 8/26/2016 2.50 INTRM1 CASING TRIP P PJSM- TOH f/ 2590'-789' MD, PU 2,590.0 789.0 20:30 23:00 87K, SO 89K. 8/26/2016 8/26/2016 0.50 INTRM1 CASING OWFF P Monitor well at the HWDP, static. 789.0 789.0 23:00 23:30 SIMOPS mobilize casing equipment to the rig floor. 8/26/2016 8/27/2016 0.50 INTRM1 CASING BHAH P PJSM- TOH laying down 8-5" HWDP 789.0 510.0 23:30 00:00 & the JARS, 789'-510' MD. 8/27/2016 8/27/2016 4.00 INTRM1 CASING BHAH P PJSM- continue laying down HWDP & 510.0 0.0 00:00 04:00 BHA 2 as per SLB DD. 8/27/2016 8/27/2016 1.00 INTRM1 CASING WWWH P PJSM- pick up stack washer & flush 0.0 0.0 04:00 05:00 stack at 382 gpm, 20 rpm. Pull wear ring. 8/27/2016 8/27/2016 2.00 INTRM1 CASING BOPE P PJSM- change out upper rams to 0.0 0.0 05:00 07:00 7.625" solid body rams. SIMOPS clear & clean rig floor; rig up to run casing. 8/27/2016 8/27/2016 1.50 INTRM1 CASING BOPE P PJSM- install test plug & rig up to test 0.0 0.0 07:00 08:30 w/ 7.625" joint. Test annular to 250 / 2500 psi for 5 minutes each. Test upper 7.625" rams to 250 / 3500 psi for 5 minutes each. All tests charted. Rig down test equipment. 8/27/2016 8/27/2016 5.50 INTRM1 CASING PUTB P PJSM- run 7.625", 29.7#, L-80, Hyd 0.0 2,653.0 08:30 14:00 562 DL casing as per detail to 2653' MD. Pick up & Baker -Loc shoe track. Check floats, good. Installed 3 centralizers per 2 joints as per detail on joints 1-44. Install WFT stage tool between joints 62 & 63, torqued to 12,400 ft/lbs. SO 104K 8/27/2016 8/27/2016 0.75 INTRM1 CASING CIRC P CBU staging up pump rate to 7 bpm, 2,653.0 2,653.0 14:00 14:45 185 psi, FO 16%, MW 10.3, PU 117K, SO 108K, pumped 2393. 8/27/2016 8/27/2016 1.75 INTRM1 CASING PUTB P PJSM- run 7.625", 29.7#, L-80, Hyd 2,653.0 3,840.0 14:45 16:30 562 DL casing as per detail f/ 2653'- 3840' MD, torqued to 12,400 ft/lbs. Installed 3 centralizers per 2 joints as per detail on joints 62-77. SO 104K. Ran a total of 90 Hydroform centralizers & 180 stop rings. 8/27/2016 8/27/2016 1.00 INTRM1 CASING CIRC P CBU staging up pump rate to 5 bpm, 3,840.0 3,840.0 16:30 17:30 175 psi, FO 10%, pumped 2100 strokes. 8/27/2016 8/27/2016 2.00 INTRM1 CASING PUTB P PJSM- run 7.625", 29.7#, L-80, Hyd 3,840.0 5,086.0 17:30 19:30 562 DL casing as per detail f/ 3840'- 5086' MD, torqued to 12,400 ft/lbs, SO 141 K. 8/27/2016 8/27/2016 2.50 INTRM1 CASING CIRC P CBU staging up pump rate to 5 bpm, 5,086.0 5,086.0 19:30 22:00 215 psi. Reduce rate due to slight losses to 4.5 bpm, 205 psi, FO 10%, PU 191 K, SO 149K, pumped 4200 strokes. Page 11/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/27/2016 8/28/2016 2.00 INTRM1 CASING PUTB P PJSM- run 7.625", 29.7#, L-80, Hyd 5,086.0 6,150.0 22:00 00:00 562 DL casing as per detail f/ 5086'- 6150' MD, torqued to 12,400 ft/lbs, SO 158K, calculated displacement 61.5, actual 45.79 bbls. Total losses to formation 39 bbls. 8/28/2016 8/28/2016 1.00 INTRM1 CASING PUTB P PJSM- run 7.625", 29.7#, L-80, Hyd 6,150.0 6,521.0 00:00 01:00 562 DL casing as per detail f/ 6150'- 6521' MD, torqued to 12,400 ft/lbs. 8/28/2016 8/28/2016 2.50 INTRMI CASING CIRC P CBU staging up pump rate to 5 bpm, 6,521.0 6,521.0 01:00 03:30 298 psi, FO 10%. PU 235K, SO 162K, pumped 4200 strokes. 8/28/2016 8/28/2016 2.75 INTRM1 CASING PUTB P PJSM- run 7.625", 29.7#, L-80, Hyd 6,521.0 7,579.0 03:30 06:15 562 DL casing as per detail f/ 6521'- 7579' MD, torqued to 12,400 ft/lbs. 8/28/2016 8/28/2016 0.50 INTRM1 CASING HOSO P PJSM- make up hanger & landing 7,579.0 7,620.0 06:15 06:45 joint. Wash down at 1 bpm, 260 psi, FO 2%, PU 260K, SO 161 K. Land out hanger at 7620' MD. 8/28/2016 8/28/2016 0.25 INTRMI CEMENT RURD P PJSM- rig up cement hose to side 7,620.0 7,620.0 06:45 07:00 entry sub on Volant CRT. 8/28/2016 8/28/2016 3.75 INTRM1 CEMENT CIRC P Circulate & condition mud staging up 7,620.0 7,620.0 07:00 10:45 pump rate to 7 bpm, 445 psi, FO 13%, PU 257K, SO 158K. SIMOPS PJSM for cement job. 8/28/2016 8/28/2016 3.25 INTRM1 CEMENT CMNT P Cement 7-5/8" casing as per SLB 7,620.0 7,620.0 10:45 14:00 cementing program. Pump 5 bbls of H2O, test trips & PT lines to 4000 psi, good. Pump 42.9 bbls of 12.5 ppg MPII at 2.3 bpm, 250 psi. Drop bottom plug. Pump 152.5 bbls of 15.8 ppg Sharks Tooth slurry at 5.2 bpm, 215 psi. Drop top plug & pump 10 bbls of H2O at 2.2 bpm, 20 psi. Swap to rig & displace with 10.3 ppg LSND at 7 bpm, 150 psi, FO 10%, Slow rate (losses @ 1794 strokes) to 4.5 bpm, 650 psi, FCP 720 psi @ 3 bpm. Bump plug at 3280 strokes. Check floats, good. CIP @ 13:52 hrs. Total Losses for first stage 8 bbls. 8/28/2016 8/28/2016 0.25 INTRM1 CEMENT CIRC P Pressure up to 3160 psi to shear open 7,620.0 7,620.0 14:00 14:15 stage tool. Circulate through stage tool to confirm activation with 5 bpm, 435 psi, FO 9%. Page 12/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/28/2016 8/28/2016 2.50 INTRMI CEMENT CMNT P Pump second stage cement as per 7,620.0 0.0 14:15 16:45 SLB cementing program. Pump 42.1 bbls of 12.5 ppg MPII at 3 bpm, 225 psi. Pump 52.6 bbls of 12.5 ppg Sharks Tooth slurry at 4.5 bpm, 190 psi. Drop closing plug. Pump 10 bbls of H2O at 2 bpm, 20 psi. Swap to rig & displace with 10.3 ppg LSND at 5 bpm, 440 psi, FO 7%. Slow pump rate as losses were observed to 2 bpm, 400 psi. Loose returns at 1800 strokes( cement at stage tool), slow pump to 1 bpm, 420 psi, FO 0%. Bump plug at 2207 strokes, pressuring up to 1700 psi to shift stage collar closed. Observed closing at 1300 psi. Hold for 5 minutes, bleed off, & check for flow. Tool closed. CIP @ 16:28 hrs. Total Losses for second stage 41.7 bbls. 8/28/2016 8/28/2016 0.75 INTRM1 CEMENT RURD P PJSM- rig down cementing /casing 0.0 0.0 16:45 17:30 equipment. Pull landing joint. 8/28/2016 8/28/2016 2.00 INTRMI CEMENT WWSP P PJSM- pull landing joint & make up 0.0 0.0 17:30 19:30 XO & 7-5/8" X 10-3/4" pack off. Set pack off & RILDS. Energize seals & test to 5000 psi for 10 minutes, witnessed by CPAI. Lay down landing joint. SIMOPS rig down Volant CRT. 8/28/2016 8/28/2016 1.00 INTRM1 CEMENT RURD P PJSM- change out elevators, install 0.0 0.0 19:30 20:30 bushings, install mouse hole, & mobilize thread protectors to rig floor. 8/28/2016 8/29/2016 3.50 INTRM1 CEMENT PULD P PJSM- lay down 30 stands of 5" DP 0.0 0.0 20:30 00:00 from derrick using mouse hole. 8/29/2016 8/29/2016 1.50 INTRM1 CEMENT PULD P PJSM- lay down 11 stands of 5" DP 0.0 0.0 00:00 01:30 from derrick using mouse hole. 8/29/2016 8/29/2016 2.50 INTRM1 CEMENT FRZP P PJSM- flush 10-3/4" X 7-5/8" OA w/ 0.0 0.0 01:30 04:00 116 bbis of H2O. Pressure up & observe pressure build to 290 psi in 8 strokes, then decrease to 275 psi over the next barrel. Continue flush at 2.5 bpm, 540-650 psi. Shut in pressure 500 psi. Line up to LRS to pump Isotherm. LRS pump 98 bbls of Isotherm at 2.75 bpm, ICP 900 psi, FCP 1300psi, shut in OA 800 psi. SIMOPS lay down 23 stands of 5" DP from derrick. 8/29/2016 8/29/2016 1.50 INTRM1 CEMENT PULD P PJSM- lay down 10 stands of 5" DP 0.0 0.0 04:00 05:30 from derrick using mouse hole. 8/29/2016 8/29/2016 2.50 INTRMI CEMENT BOPE P PJSM- change out upper rams to 3- 0.0 0.0 05:30 08:00 1/2" X 6" VBR's. SIMOPS change out saver sub on top drive to 4" XT39. Load 90 joints of 4" HWDP in the pipe shed. Page 13/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/29/2016 8/29/2016 4.00 INTRM1 CEMENT RURD P PJSM- continue loading HWDP & 282 0.0 0.0 08:00 12:00 joints of 4" DP in pipe shed. Strap & tally drill pipe. SIMOPS perform MP2 on top drive, blocks, crown & derrick. Seal weld around Iron Roughneck pedestal & pipe racks. Load 290 bbls of 10.0 ppg FloPro mud into pits. 8/29/2016 8/29/2016 6.00 INTRM1 CEMENT PULD P PJSM- pick up 43 stands of 4" XT39 0.0 0.0 12:00 18:00 drill pipe & rack back in the derrick, using the mouse hole. 8/29/2016 8/30/2016 6.00 INTRM1 CEMENT PULD P PJSM- pickup 51 stands of 4" XT39 0.0 0.0 18:00 00:00 drill pipe & rack back in the derrick, using the mouse hole. 8/30/2016 8/30/2016 5.50 INTRM1 CEMENT PULD P Continue pick up and rack back in 0.0 0.0 00:00 05:30 derrick 4" DP, and 30 stands of 4" HWDP. 8/30/2016 8/30/2016 1.00 INTRM1 WHDBOP RURD P RU to test BOP's. Held PJSM. Discuss 0.0 0.0 05:30 06:30 safety and hazard recognition. Discuss RU and testing procedure. Install the test plug with 3 1/2" test joint. 8/30/2016 8/30/2016 4.50 INTRM1 WHDBOP BOPE P Test BOP's. Witness of test waived by 0.0 0.0 06:30 11:00 AOGCC rep Guy Cook. Test #1 with 3 1/2" test joint, testing Annular, CV#1, #12, #13, #14 and 4" kill line valve on mud manifold. Test UBOP. Test #2 - Top Pipe rams, CV # 9, #11, mezzanine kill valve, and LBOP Test #3- CV #5, #8, #10, HCR Kill, and XT39 Dart Valve. Test #4 - CV #4, #6, #7, and XT39 FOSV, and manula kill. Test #5 - CV #2 Test #6 - Lower Pipe rams Perform Koomey draw down test. Observed initial system pressure at ACC- 2925 PSI, MAN - 1500 PSI, and annular - 800 PSI. After Closure observed ACC - 1750 PSI, MAN - 1350 PSI, and Annular - 600 PSI. Obtained initial 200 PSI increase in 6 seconds, and full pressures at 47 seconds. Observed 6 nitrogen bottles with an average PSI of 2400 PSI. TEst #7 - Blind rams, CV #3 Test #8 - Super Choke, and manual operated choke to 1500 PSI. Installed 4 1/2" test joint. Test #9 - Annular, HCR Choke. Test #10 Top Pipe rams, Manual choke Test #11 - Lower Pipe rams All tests to 250 / 3500 PSI, recorded on chart. 8/30/2016 8/30/2016 0.50 INTRM1 Pull test plug. Install wear bushing, 0.0 0.0 11:00 11:30 �VVHDB71RDT- and RILDS. ID - 10", OD 10.75" Length - 1.08'. Page 14130 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/30/2016 8/30/2016 0.50 INTRM1 CEMENT BHAH P PJSM, clean & clear rig floor, 0.0 0.0 11:30 12:00 housekeeping. Load rig floor with BHA tools, subs, stabilizers and crossovers. 8/30/2016 8/30/2016 0.50 INTRM1 CEMENT BHAH P Continue to bring BHA componets to 0.0 0.0 12:00 12:30 the floor. 8/30/2016 8/30/2016 0.25 INTRM1 CEMENT SFTY P Pre job safety meeting on picking up 0.0 0.0 12:30 12:45 BHA. 8/30/2016 8/30/2016 1.00 INTRM1 CEMENT BHAH P Make up BHA to 137' 0.0 137.0 12:45 13:45 8/30/2016 8/30/2016 0.25 INTRM1 CEMENT BHAH P Load radioactive sources. 137.0 137.0 13:45 14:00 8/30/2016 8/30/2016 0.75 INTRM1 CEMENT BHAH P Continue to work 6-3/4" BHA f/ 137' to 137.0 212.0 14:00 14:45 212' 8/30/2016 8/30/2016 0.50 INTRM1 CEMENT BHAH P Pick up (5) 4" HWDP and Weatherford 212.0 396.0 14:45 15:15 jars f/ 212' to 396'. PU wt 64k, SO wt 64k. 8/30/2016 8/30/2016 1.50 INTRM1 CEMENT PULD P Trip in the hole w/ 6-3/4" BHA, picking 396.0 1,533.0 15:15 16:45 up 4" xt39 drill pipe from the pipe shed f/ 396' to 1533'. 8/30/2016 8/30/2016 0.25 INTRM1 CEMENT DHEQ P Shallow test MWD, pumping 220 gpm 1,533.0 1,533.0 16:45 17:00 w/ 1185 psi, 13% flow out. Good test. 8/30/2016 8/30/2016 2.75 INTRM1 CEMENT PULD P Continue trip in the hole w/ 6-3/4" 1,533.0 3,997.0 17:00 19:45 BHA, picking up 4" Xt39 drill pipe from the pipe shed f/ 1533' to 3997'. Down wt 96k. 8/30/2016 8/30/2016 0.75 INTRM1 CEMENT QEVL P Fill pipe downlink to activate logging 3,997.0 3,997.0 19:45 20:30 tools. Pumping 220 gpm w/ 1495 psi, 12% flow out. 8/30/2016 8/31/2016 3.50 INTRM1 CEMENT PULD P Continue trip in the hole w/ 6-3/4" 3,997.0 5,035.0 20:30 00:00 BHA, picking up 4" Xt39 drill pipe from the pipe shed f/ 3997' to 5035'. MAD pass w/ 8007hr. from 3997' to 5035'. Tag up w/ 15k down wt on cement stringer. PU wt 136k, SO wt 100k. 8/31/2016 8/31/2016 4.50 INTRM1 CEMENT DRLG P Make a top drive connection with a 5,035.0 5,090.0 00:00 04:30 stand of 4" XT -39 drill pipe from the derrick to drill stage collar. Note 49 stands (147 jts) were picked up from the pipe shed while singling in the hole w/ 4" XT -39 drill pipe. Drill cement from 5035' to the shut off plug which appeared to be @ 5077', then the stage collar @ 5090'. Varied parameter of 2-17k weight on bit, flow rates of 180 to 220 gpm w/ 970 to 1400 psi. RPM'S were adjusted from 40-60 rpm's w/ 4 to 6k ft lbs of torque. 8/31/2016 8/31/2016 0.50 INTRM1 CEMENT CIRC P Circulate a bottom's up while reaming 5,090.0 5,130.0 04:30 05:00 through the stage collar multiple times from 5035' to 5130'. Pumping 223 gpm w/ 1470 psi. Rotae 60 rpm w/ 5k ft lbs of torque. Stand back the stand used to drill the stage collar. Blow down the top drive. Page 15/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 8/31/2016 8/31/2016 5.75 INTRMI CEMENT PULD P Continue trip in the hole w/ 6-3/4" 5,130.0 7,309.0 05:00 10:45 BHA, picking up 4" xt39 drill pipe from the pipe shed f/ 5035' to 7309'. MADD pass w/ 8007hr. from 5035' to 7309'. PU wt 185k, SO wt 108k. Monitor well on the trip tank, fill pipe every 45 jts picked up. 8/31/2016 8/31/2016 0.75 INTRM1 CEMENT COCF P Wash down f/ 7309' to tag top of 7,309.0 7,457.0 10:45 11:30 cement @ 7457'. Pumping 87 gpm w/ 541 psi and 8% flow out. Tag cement w/ 10k weight. 8/31/2016 8/31/2016 0.50 INTRM1 CEMENT CIRC P Circulate and condition mud for casing 7,457.0 7,457.0 11:30 12:00 test. Pumping 221 gpm w/ 1667 psi, 13% flow out. Rotate 40 rpm's w/ 9k ft lbs of torque. Rotating weight = 132k. 8/31/2016 8/31/2016 0.75 INTRM1 CEMENT CIRC P Continue to circulate and condition 7,457.0 7,457.0 12:00 12:45 mud for casing test. Pumping 220 gpm w/ 1600 psi, 11 % flow out. Rotate 40 rpm's w/ 8.5 k ft lbs of torque. Rotating weight = 133k. Mud weight 10.2 ppg. Final circulating pressure 1710 psi. 8/31/2016 8/31/2016 0.50 INTRM1 CEMENT RURD P Rig up to test 7-5/8" 29.7 ppf L-80 Hyd 7,457.0 7,457.0 12:45 13:15 563 casing to 3500 psi. 8/31/2016 8/31/2016 1.00 INTRM1 CEMENT PRTS P Test casing to 3550 psi for 30 7,457.0 7,457.0 13:15 14:15 minutes. Lost 100 psi in 30 min. Good test. Pumped 4.6 bbls. Top of cement @ 7457' MD (6333.81' TVD). 8/31/2016 8/31/2016 2.00 INTRM1 CEMENT SLPC P Slip and cut 102' of drilling line. 7,457.0 7,457.0 14:15 16:15 Service the top drive. 8/31/2016 8/31/2016 1.75 INTRM1 CEMENT DRLG P Drill cement from 7457'to 7491' 7,457.0 7,491.0 16:15 18:00 appearing to tag plug high @ 7487'. Pumping 220 gpm w/ 1655 psi and 10% flow out. Rotate 60 rpm w/ 9k ft lbs of torque. Drill w/ 5-8k wt on bit. 8/31/2016 8/31/2016 1.25 INTRM1 CEMENT DRLG P Drill landing collar @ 7491'to 7493'. 7,491.0 7,493.0 18:00 19:15 Pumping 220 gpm w/ 1700 psi and 10% flow out. Rotate 60 rpm. Drilling w/ 10-18k weight on bit. 8/31/2016 8/31/2016 1.75 INTRM1 CEMENT DRLG P Drill cement from 7493'to 7524'. 7,493.0 7,524.0 19:15 21:00 Pumping 220 gallons per minute w/ 1720 psi and 10% flow out. Rotate 40 to 60 rpm with 7 to 12k ft lbs of torque. Drill w/ 12k weight on bit. 8/31/2016 9/1/2016 3.00 INTRM1 CEMENT DRLG P Appear to tag the bottom plug @ 7,524.0 7,532.0 21:00 00:00 7524', drill plug and cement from 7524' to 7532'. Pumping 225 gpm w/ 1740 psi and 10% flow out. Rotate 40- 80 rpm w/ 8-11 k ft lbs of torque. Drill w/ 10-18k weight on bit. Pumped a 30 bbl nut plug sweep while drilling @ 7530'. OA pressure =780 psi. Page 16/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKS) 9/1/2016 9/1/2016 2.50 INTRM1 CEMENT DRLG P Drill out shoe track from 7532'- 7620'. 7,532.0 7,620.0 00:00 02:30 (88') @ 220 GPM, 1623 PSI, 10% flow - 40-60 RPMs, 9-1 OK TQ, 6-16K WOB. Drill out shoe at 1830 PSI, 90 RPMs, 9K TQ, 1-2 K WOB, Top of shoe at 7618' MD, Work through Float collar and shoe 3 times. 9/1/2016 9/1/2016 0.50 INTRM1 CEMENT DDRL P Continue drill rat hole and 20' of new 7,620.0 7,650.0 02:30 03:00 formation from 7620'- 7650' MD. Drilled at 221 GPM, 1700 PSI, 10% Flow, 60 RPMs, 9-11 KTQ, 1 OK WOB, UP WT - 193K, DN WT - 105K, ROT WT - 133K. (K TQ. ADT -.22 HRS, Bit -.22 HRS, Jars - .22 HRS. 9/1/2016 9/1/2016 1.25 INTRM1 CEMENT CIRC P Circulate bottoms up rotating and 7,650.0 7,650.0 03:00 04:15 reciprocation drill string from 7594'- 7499', at 220 GPM - 1610 PSI, with 60 RPM's, 9K TQ, 10% flow. Mud weight in/ out - 10.1 PPG. Flow check - 10 minutes. 9/1/2016 9/1/2016 1.00 INTRM1 CEMENT FIT P Rig up and perform FIT test to 13.1 7,650.0 7,650.0 04:15 05:15 EMW with 980 PSI, 1.7 BBLS pumped, and 1.4 BBLS bled back. RD and blow down test equipmernt. Tested w/ 20' new hole @ 7650' MD (6360.47' TVD, mud weight 10.1 ppg. Shoe depth 7620.70' (6357.72' TVD). 9/1/2016 9/1/2016 1.00 PROD1 DRILL MPDA P Held PJSM on changing out trip nipple 7,650.0 7,650.0 05:15 06:15 and installing RCD bearing. Install RCD bearing. 9/1/2016 9/1/2016 2.00 PROD1 DRILL DISP P Held PJSM, Pump a 35 BBL HiVisc 7,650.0 7,650.0 06:15 08:15 pill, and displace well from 10.1 ppg LSND to a 10.0 PPG flo pro mud system with pumps at 223 GPM, 1560 PSI, 80 RPMs- 6-7K TQ. 9/1/2016 9/1/2016 1.00 PROD1 DRILL OWFF P Observe well for flow. Calibrate MPD 7,650.0 7,650.0 08:15 09:15 as per rig engineer. 9/1/2016 9/1/2016 2.75 PROD1 DRILL DDRL P Held PJSM. Directional Drill from 7,650.0 7,842.0 09:15 12:00 7650' - 7842'. (192') @ 270 GPM, 2140 PSI, 13% flow 80-100 RPMs, 8.50K TQ ON BTM, TQ OFF BTM - 7K, 6-10K WOB. UP WT - 173K, DN WT - 106K, ROT WT - 135K ECD's - 10.79 EMW, Max Gas Units observed - 237. ADT - 2.05 HRS, Bit HRS - 2.27, Jar HRS - 2.27 Obtained SPR's @ 7650' MD - 6360' TVD Pump#1 - 20 SPM - -400 PSI, 30 SPM - 640 PSI Pump #2 - 20 SPM - 400 PSI, 30 SPM - 640 PSI Crew Change Page 17/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -x Operation (ftKB) End Depth (ftKB) 9/1/2016 9/1/2016 6.00 PROD1 DRILL DDRL P Held PJSM. Directional Drill from 7,842.0 8,490.6- 12:00 18:00 7842' - 8490'. (648') Pumping @ 283 GPM w/ 2400 psi, 13% flow out. Rotate 180 RPM'S w/ 9K Tq on bottom, 7.3k Tq off bottom. Weight on bit 10-12k. PU wt 172k, SO wt 106k, Rot wt 133k. ECD's - 11.14 EMW, Max Gas Units observed - 976. ADT - 3.91 HRS, Bit HRS - 6.18, Jar HRS - 6.18 Fault # 1 @ 8427' 1' fault. Obtained SPR's @ 8254' MD - 6379' TVD Pump#1 - 20 SPM - -405 PSI, 30 SPM - 635 PSI Pump #2 - 20 SPM - 405 PSI, 30 SPM - 600 PSI 9/1/2016 9/1/2016 3.75 PROD1 DRILL DDRL P Directional Drill from 8490'- 8823'. 8,490.0 8,823.0 18:00 21:45 (333') Pumping @ 281 GPM w/ 2420 psi, 12% flow out. Rotate 170 RPM'S w/ 9.5K Tq on bottom, 7.5k Tq off bottom. Weight on bit 10k. PU wt 173k, SO wt 106k, Rot wt 133k. ECD's - 11.2 EMW, Max Gas Units observed - 974. ADT - 2.77 HRS, Bit HRS - 8.95, Jar HRS - 8.95 9/1/2016 9/1/2016 0.75 PROD1 DRILL CIRC T Due to failure of MPD bearing 8,823.0 8,823.0 21:45 22:30 assembly (no oil pressure- seal leaking to wellbore), Circulate bottom's up. Circulate and condition mud, pumping 283 gpm w/ 2380 psi, 13% flow out. Rotate 100 rpm's (due to shocks to BHA) w/ 8k ft lbs of torque. Circulated 302 bbls 10.1+ ppg FloPro mud. Stand back a stand. 9/1/2016 9/1/2016 0.25 PROD1 DRILL OWFF T Observe well for flow- static. Monitor 8,823.0 8,823.0 22:30 22:45 with MPD choke open. 9/1/2016 9/1/2016 1.00 PROD1 DRILL EQRP T Change out Weatherford MPD bearing 8,823.0 8,823.0 22:45 23:45 due to inner bearing seal failure (165 hrs on bearing). 9/1/2016 9/2/2016 0.25 PROD1 DRILL REAM T Wash and ream down f/ 8728'to 8,823.0 8,823.0 23:45 00:00 8823'. Pumping 279 gpm w/ 2340 psi, 13% flow out. Stage rotation up to 170 rpm breaking in new bearing assembly. OA pressure = 680 psi. Page 18/30 Report Printed: 9/14/2016 fi Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Cade Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/2/2016 9/2/2016 6.00 PROD1 DRILL DDRL P Directional Drill from 8823'- 9489'. 8,823.0 9,489.6- 00:00 06:00 6376' TVD (666') Pumping @ 279 GPM w/ 2370 psi, 13% flow out. Rotate 150 RPM'S w/ 11 K Tq on bottom,8.5K Tq off bottom. Weight on bit 1 OK. PU wt 170k, SO wt 104k, Rot wt 133k. ECD's - 11.12 EMW, Max Gas Units observed - 357. ADT - 4.07 HRS, Bit HRS - 13.02, Jar HRS - 13.02 Obtained SPR's @ 9291' MD - 6388' TVD 10.5 ppg MW @ 0405 hrs. Pump#1 - 20 SPM - -440 PSI, 30 SPM - 680 PSI Pump #2 - 20 SPM - 440 PSI, 30 SPM - 700 PSI 9/2/2016 9/2/2016 6.00 PROD1 DRILL DDRL P Directional Drill from 9489'- 10259'. 9,489.0 10,259.0 06:00 12:00 6359' TVD (770') Pumping @ 277 GPM w/ 2445 psi, 13% flow out. Rotate 170 RPM'S w/ 10.9K Tq on bottom,8.5k Tq off bottom. Weight on bit 12k. PU wt 170k, SO wt 105k, Rot wt 131 k. ECD's - 11.14 EMW, Max Gas Units observed - 700. ADT - 4.45 HRS, Bit HRS - 17.47, Jar HRS - 17.47 Obtained SPR's @ 9770' MD - 6368' TVD 10ppg MW@ 0742 hrs. Pump#1 - 20 SPM - -440 PSI, 30 SPM - 700 PSI Pump #2 - 20 SPM - 440 PSI, 30 SPM - 710 PSI 9/2/2016 9/2/2016 6.00 PROD1 DRILL DDRL P Directional Drill from 10259'-11092'. 10,259.0 11,092.0 12:00 18:00 6362' TVD (833') Pumping @ 275 GPM w/ 2610 psi, 15% flow out. Rotate 170 RPM'S w/ 12K Tq on bottom,9k Tq off bottom. Weight on bit 12k. PU wt 175k, SO wt 101 k, Rot wt 134k. ECD's - 11.43 EMW, Max Gas Units observed - 980. ADT - 4.2 HRS, Bit HRS - 21.67, Jar HRS - 21.67 Fault # 2 @ 10370' 7' fault. Fault # 3 @ 11062' 4' fault. Page 19/30 Report Printed: 9/14/2016 x Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/2/2016 9/3/2016 6.00 PROD1 DRILL DDRL P Directional Drill from 11092'-11852'. 11,092.0 11,852.0 18:00 00:00 6367' TVD (770') Pumping @ 276 GPM w/ 2650 psi, 13% flow out. Rotate 160 RPM'S w/ 13K Tq on bottom,9.2k Tq off bottom. Weight on bit 16k. PU wt 180k, SO wt 95k, Rot wt 132k. ECD's - 11.54 EMW, Max Gas Units observed - 1000. ADT - 3.96 HRS, Bit HRS - 25.63, Jar HRS - 25.63 Obtained SPR's @ 11379' MD - 6388' TVD 10ppg MW@ 2010 hrs. Pump#1 - 20 SPM - -510 PSI, 30 SPM - 770 PSI Pump #2 - 20 SPM - 500 PSI, 30 SPM - 770 PSI Outer annulus pressure= 640 psi 9/3/2016 9/3/2016 6.00 PROD1 DRILL DDRL P Directional Drill from 11852'-12515'. 11,852.0 12,515.0 00:00 06:00 6378' TVD (663') Pumping @ 275 GPM w/ 2705 psi, 16% flow out. Rotate 160 RPM'S w/ 13K Tq on bottom,10k Tq off bottom. Weight on bit 16k. PU wt 182k, SO wt 98k, Rot wt 129k. ECD's - 11.56 EMW, Max Gas Units observed - 1057 units. ADT - 3.56 HRS, Bit HRS - 29.19, Jar HRS - 29.19 Fault # 5 @ 12096' 8' fault. Obtained SPR's @ 12137' MD - 6363' TVD 10ppg MW@ 0230 hrs. Pump#1 - 20 SPM - -570 PSI, 30 SPM - 860 PSI Pump #2 - 20 SPM - 570 PSI, 30 SPM - 840 PSI Page 20/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (W) 9/3/2016 9/3/2016 6.00 PROD1 DRILL DDRL P Directional Drill from 12515'- 13369'. 12,515.0 13,369.0 06:00 12:00 6378' TVD (854') Pumping @ 275 GPM w/ 2880 psi, 16% flow out. Rotate 160 RPM'S w/ 13K Tq on bottom,1 Ok Tq off bottom. Weight on bit 15k. PU wt 183k, SO wt 98k, Rot wt 133k. ECD's - 11.62 EMW, Max Gas Units observed - 537 units. ADT - 4.08 HRS, Bit HRS - 33.27, Jar HRS - 33.27 Obtained SPR's @ 13084' MD - 6399' TVD 10ppg MW@ 1000 hrs. Pump#1 - 20 SPM - -620 PSI, 30 SPM - 880 PSI Pump #2 - 20 SPM - 580 PSI, 30 SPM - 860 PSI 9/3/2016 9/3/2016 6.00 PROD1 DRILL DDRL P Directional Drill from 13369'- 13939'. 13,369.0 13,939.0 12:00 18:00 6406' TVD (570') Pumping @ 276 GPM w/ 2955 psi, 14% flow out. Rotate 170 RPM's w/ 12.5 k Tq on bottom, 8.5 k Tq off bottom. Weight on bit 16k. PU wt 182k, SO wt 93k, Rot wt 133k. ECD's - 11.80 EMW, Max Gas Units observed - 788 units. ADT - 3.42 HRS, Bit HRS - 36.69, Jar HRS - 36.69 Fault # 6 @ 13581' 5' fault. 9/3/2016 9/4/2016 6.00 PROD1 DRILL DDRL P Directional Drill from 13939'- 14614'. 13,939.0 14,614.0 18:00 00:00 6397' TVD (675') Pumping @ 275 GPM w/ 3085 psi, 14% flow out. Rotate 170 RPM'S w/ 13.2 k Tq on bottom, 8.8 k Tq off bottom. Weight on bit 18.5k. PU wt 180k, SO wt 92k, Rot wt 131 k. ECD's - 11.83 EMW, Max Gas Units observed - 550 units. ADT - 3.91 HRS, Bit HRS - 340.6, Jar HRS - 40.6 Obtained SPR's @ 14413' MD - 6403' TVD 10ppg MW@ 2140 hrs. Pump#1 - 20 SPM - -760 PSI, 30 SPM - 1000 PSI Pump #2 - 20 SPM - 730 PSI, 30 SPM 1000 PSI Page 21/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (W) End Depth (ftKB) 9/4/2016 9/4/2016 6.00 PROD1 DRILL DDRL P Directional Drill F/ 14,614'T/ 15,361'. 14,614.0 15,361.0 00:00 06:00 TVD (6367") Pumping @ 275 GPM w/ 3100 psi, 14% flow out. Rotate 160 RPM'S w/ 14 k Tq on bottom, 12 k Tq off bottom. Weight on bit 6-18 k. PU wt 174k, SO wt 89 k, Rot wt 133 k. ECD's - 12.0 EMW, Max Gas Units observed - 1000 units. ADT - 4.27 HRS, Bit HRS - 44.87, Jar HRS - 44.87 9/4/2016 9/4/2016 6.00 PROD1 DRILL DDRL P Directional Drill F/ 15,361'T/ 15,675'. 15,361.0 15,675.0 06:00 12:00 TVD (6390") Pumping @ 275 GPM w/ 3150 psi, 13% flow out. Rotate 160 RPM'S w/ 12 k Tq on bottom, 9 k Tq off bottom. Weight on bit 12 k. PU wt 174k, SO wt 89 k, Rot wt 133 k. ECD's - 12.03 EMW, Max Gas Units observed - 1000 units. ADT -4.74 HRS, Bit HRS - 49.61, Jar HRS - 49.61 Enter Kalubik @ 15,420' MD and employed MPD system, Apply 40 PSI average pressurew. Obtained SPR's @ 15,172' MD - 6,374' TVD 10.0 ppg MW@ 03:40 hrs. Pump#1 - 20 SPM - -780 PSI, 30 SPM - 1050 PSI Pump #2 - 20 SPM - 780 PSI, 30 SPM - 1090 PSI 9/4/2016 9/4/2016 6.00 PROD1 DRILL DDRL P Directional Drill F/ 15,6751'T/ 16,310'. 15,675.0 16,310.0 12:00 18:00 TVD (6310") Pumping @ 275 GPM w/ 3220 psi, 13% flow out. Rotate 180 RPM'S w/ 14 k Tq on bottom, 9.8 k Tq off bottom. Weight on bit 15 k. PU wt 205k, SO wt 70 k, Rot wt 129 k. ECD's - 12.17 EMW, Max Gas Units observed - 920 units. ADT 3.71 HRS, Bit HRS - 53.32, Jar HRS - 53.32 MPD holding 515 psi Back pressure on connections.. Page 22/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/4/2016 9/5/2016 6.00 PROD1 DRILL DDRL P Directional Drill F/ 16,310 T/ 16,878'. 16,310.0 16,878.0 18:00 00:00 TVD (6461 ") Pumping @ 275 GPM w/ 3320 psi, 13% flow out. Rotate 180 RPM'S w/ 14 k Tq on bottom, 12 k Tq off bottom. Weight on bit 16 k. PU wt 174k, SO wt N/A k, Rot wt 120 k. ECD's - 12.17 EMW, Max Gas Units observed - 665 units. ADT - 3.22 HRS, Bit HRS - 56.54, Jar HRS - 56.54 Hrs. (Holding 515 psi BP on connections Obtained SPR's @ ' MD - 16,877' TVD 10 ppg MW@ 23.55 hrs. Pump#1 - 20 SPM -800 PSI, 30 SPM - 1095 PSI Pump #2 - 20 SPM - 790 PSI, 30 SPM - 1070 PSI 9/5/2016 9/5/2016 6.00 PROD1 DRILL DDRL X Directional Drill F/ 16,878'T/ 17,417'. 16,878.0 17,362.0 00:00 06:00 TVD (6441 ") Pumping @ 275 GPM w/ 3350 psi, 13% flow out. Rotate 180 RPM'S w/ 14 k Tq on bottom, 12 k Tq off bottom. Weight on bit 15 k. PU wt 200 k, SO wt N/A k, Rot wt 125 k. ECD's - 12.16 EMW, Max Gas Units observed - 20 units. ADT - 3.81 HRS, Bit HRS -60.35, Jar HRS - 60.35 Hrs. (Holding 37 psi BP on connections Obtained SPR's @ 17,809?' MD - 6410' TVD 10ppg MW@ 10:00 hrs. Pump#1 - 20 SPM - -760 PSI, 30 SPM - 1100 PSI Pump #2 - 20 SPM - 750 PSI, 30 SPM - 1080 PSI 9/5/2016 9/5/2016 6.00 PROD1 DRILL DDRL X Directional Drill F/ 17,417'T/ 17,998'. 17,362.0 17,998.0 06:00 12:00 TVD (6400") Pumping @ 275 GPM w/ 3450 psi, 13% flow out. Rotate 180 RPM'S w/ 15 k Tq on bottom, 13 k Tq off bottom. Weight on bit 15 k. PU wt 206 k, SO wt N/A k, Rot wt 123 k. ECD's - 12.16 EMW, Max Gas Units observed - 20 units. ADT - 4.07 HRS, Bit HRS -64.42, Jar HRS - 64.42 Hrs. (Holding 515 psi BP on connections. Page 23/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 9/5/2016 9/5/2016 1.00 PROD1 CASING BKRM X Back ream out F/ 17,998' MD T/ 17,998.0 17,812.0 12:00 13:00 17,812' MD wityh 275 gpm, 3465 psi, 12% flow 140 RPM, 12.03 ECD's 9/5/2016 9/5/2016 0.50 PROD1 CASING OWFF P Perform draw down test, with 15 RPM, 17,812.0 17,812.0 13:00 13:30 8.5 tq, 11 % flow,Shut chokes to 530 psi, down to 380 psi, bleed down for 10 sec, close chokes & observed 145 psi increase, bleed off for 10 sec, shut chokes & observed 2 psi (Well Static) 9/5/2016 9/5/2016 1.50 PROD1 CASING CIRC P CBU with 275 gpm, 3430 psi,11% 17,812.0 17,724.0 13:30 15:00 flow, 11.91 ECD, 170 RPM, 10.5 Tq,and stand back one stand. Zero gas observed. 9/5/2016 9/5/2016 2.50 PROD1 CASING BKRM X BROOH F/ 17,724' MD T/ 16,848 MD 17,724.0 16,848.0 15:00 17:30 with 275 gpm, 3340 psi, 14% flow, 11.75 ECD,170 RPM, 9 TQ, Holding 530 psi on connections. 9/5/2016 9/5/2016 2.25 PROD1 CASING BKRM P BROOH F/ 16,848' MD T/ 15,933 MD 16,848.0 15,933.0 17:30 19:45 with 275 gpm, 3340 psi, 14% flow, 11.75 ECD,170 RPM, 9 TQ, Holding 530 psi on connections. 9/5/2016 9/5/2016 2.50 PROD1 CASING SMPD P Strip out of hole F/ 15,933' MD T/ 15,933.0 15,364.0 19:45 22:15 15,360' MD holding 530 psi, work tight spots @ 15,661', 15,530'-15,476', 15,380'-15364, Up= 185K down= 87 K, while pulling through Kaliubik 9/5/2016 9/6/2016 1.75 PROD1 CASING CIRC P Circulate bottoms up with 275 gpm, 15,364.0 15,364.0 22:15 00:00 3090 psi, 11 % flow, 170 RPM, 9 Tq, 123 K RT WT, 11.67 ECD, Holding 50 psi Back pressure due to leaking RCD sealing element leaking., (Actual Losses= 32.75 bbls, Calculated= 14.25 bbls, Tour losses= 18.5 bbls). 9/6/2016 9/6/2016 0.50 PROD1 CASING CIRC P Continue to circulate with 275 gpm, 15,364.0 15,364.0 00:00 00:30 3090 psi holding 50 psi due to leaking RCD elerment. 9/6/2016 9/6/2016 0.50 PROD1 CASING OWFF P Perform draw down to determine well 15,364.0 15,364.0 00:30 01:00 breathing. 9/6/2016 9/6/2016 1.00 PROD1 CASING MPDA T Change out RCD bearing due to 15,364.0 15,364.0 01:00 02:00 leaking element issues. 9/6/2016 9/6/2016 0.50 PROD1 CASING CIRC P Pump low vis sweep followed by high 15,364.0 15,364.0 02:00 02:30 vis sweep through the bit. 276 gpm, 3000 psi, (30 bbls each on sweeps) 9/6/2016 9/6/2016 0.50 PROD1 CASING BKRM P Continue to BROOH F/ 15364' MD T/ 15,364.0 14,870.0 02:30 03:00 14870' MD, 100 RPM, 1 OK Tq, 275 gpm, 3000 psi 9/6/2016 9/6/2016 1.50 PROD1 CASING CIRC P Stopped BROOM and circulate out 14,870.0 14,870.0 03:00 04:30 sweeps saw 20% increase in cutting coming back with sweeps, worked pipe with 100 RPM, 275 gpm, 3000 psi. 9/6/2016 9/6/2016 1.50 PROD1 CASING BKRM P Continue to BROOH F/ 14,870.0 T/ 14,870.0 14,390.0 04:30 06:00 14,390' MD, rotate @ 100 rpm's w/ 8K Tq. Pump @ 270 gpm= 2900 psi. 9/6/2016 9/6/2016 4.75 PROD1 CASING BKRM P Continue to BROOH f/ 14390' MD to 14,390.0 12,270.0 06:00 10:45 12270' MD, rotate @ 120 rpm's w/ 8K Tq. Pump @ 275 gpm= 2900 psi. Page 24/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/6/2016 9/6/2016 1.25 PROM CASING BKRM T When BROOH @ 12,270' MD, 12,270.0 12,292.0 10:45 12:00 observed a 300 psi packoff and stalled rotary @ 15K Tq. RIH to 12,326' MD and establish circulation. BROOH @ 120 rpm w/ 6-71K Tq, pump @ 270 gpm=2780 psi 9/6/2016 9/6/2016 2.50 PROM CASING BKRM P Cont to BROOH thought tight hole f/ 12,292.0 12,134.0 12:00 14:30 12292' MD to 12134' MD, BROOH @ 120 rpm w/ 6-7K Tq, pump @ 270 gpm=2780 psi. Observed packoff @ 12284' MD, 12250' MD, 12233' MD and 12,203' MD. Worked down past packoffs @ 1 bpm w/ no rotary, good. 9/6/2016 9/6/2016 7.75 PROM CASING BKRM P Cont to BROOH f/ 12134' MD to 8920' 12,134.0 8,920.0 14:30 22:15 MD @ 1000 fph. Rotate @ 120 rpm's w/ 7K Tq, pump @ 275 gpm= 2600 psi to 2400 psi. ROT wt= 127K. Closing MPD chokes on connections. 9/6/2016 9/7/2016 1.75 PROD1 CASING BKRM P Slow BROOH speed to 500 fph @ 8,920.0 8,420.0 22:15 00:00 8920' MD, before upper stab enters upper A4. Cont BROOH f/ 8920' MD to 8420' MD, Rotate @ 120 rpm's w/ 7K Tq, pump @ 275 gpm= 2370 psi. Observed slight 100 psi packoffs @ 8673' and 8420', no overpull observed. Calculated displacement= 26.65 bbls Actual displacement= 43.15 bbls ( 17.5 MIS lost to hole) 9/7/2016 9/7/2016 1.00 PROD1 CASING BKRM P Cont to BROOH @ 500 fph H f/ 8420' 8,420.0 8,351.0 00:00 01:00 MD to 8351' MD, Rotate @ 120 rpm's w/ 7K Tq, pump @ 275 gpm= 2350 psi.11% FO, ECD= 11.0 ppg. Observed slight 100 -150 psi intermittent packoffs 9/7/2016 9/7/2016 2.50 PROD1 CASING BKRM P Cont to BROOH f/ 8351' MD to inside 8,351.0 7,585.0 01:00 03:30 casing shoe @ 7620' MD @ 1000 fph, Rotate @ 120 rpm's w/ 7K Tq, pump @ 275 gpm= 2250 psi. Closing MPD chokes on connections. 9/7/2016 9/7/2016 2.50 PROM CASING CIRC P Circulate hole clean, pump @ 275 7,585.0 7,585.0 03:30 06:00 gpm=2180 psi and rotate @ 80 rpm's. SIMOPS, hold PJSM for displacing well to kill weight brine. 9/7/2016 9/7/2016 0.25 PROM CASING OWFF P Close MPD chokes and monitor 7,585.0 7,585.0 06:00 06:15 chokes for pressure, 0 PSI. 9/7/2016 9/7/2016 2.75 PROM CASING DISP P Displace well to 11.8 ppg brine as 7,585.0 7,115.0 06:15 09:00 follows. Pumped 60 bbls of high viscosity brine and pumped down to bit. POOH w/ pump at 2 bpm @ 2400 fph laying in high viscosity spacer from 7585' MD to 7115' MD followed by 11.8 ppg brine. Adjusted pump rate as need for ECD. Started at 200 gpm= 1300 psi, FCP 150 gpm=680 psi. 9/7/2016 9/7/2016 0.50 PROM CASING OWFF P OWFF, static 7,115.0 7,115.0 09:00 09:30 Page 25130 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/7/2016 9/7/2016 1.00 PROD1 CASING MPDA P Remove MPD bearing and install trip 7,115.0 7,115.0 09:30 10:30 nipple 9/7/2016 9/7/2016 4.00 PROD1 CASING TRIP P Drop 2-3/8" metal drift on 100' of wire. 7,115.0 396.0 10:30 14:30 POOH on elevators f/ 7115' MD to 396' MD. P/U= 54K, S/0=54K 9/7/2016 9/7/2016 0.25 PROD1 CASING OWFF P OWFF, static. 396.0 396.0 14:30 14:45 9/7/2016 9/7/2016 0.50 PROD1 CASING PULD P POOH L/D 5 joints of 4" HWDP and 396.0 212.0 14:45 15:15 jars f/ 396' MD to 212' MD. 9/7/2016 9/7/2016 2.00 PROD1 CASING BHAH P L/D BHA # 3 as per SLB rep. Actual 212.0 0.0 15:15 17:15 displacement = 67.95 bbls, Calculated displacement= 45.6 bbls. Bit Grade= 1 -2 -CT -S -X -IN -JD -TD 9/7/2016 9/7/2016 0.75 PROD1 CASING BHAH P Clean and clear rig floor of SLB tools 0.0 0.0 17:15 18:00 and RCD. 9/7/2016 9/7/2016 1.50 COMPZN CASING RURD P R/U to run 4-1/2" liner, C/O handling 0.0 0.0 18:00 19:30 equipment and rig up power tongs. 9/7/2016 9/8/2016 4.50 COMPZN CASING PUTB P RIH w/ 4-1/2" Tenaris XP BTC, 12.6#, 0.0 2,318.0 19:30 00:00 L-80 liner. M/U shoe track w/ TopCo shoe and WFT float collar and test floats, good. Cont to pick up liner to 2318' MD. Filling pipe every 10 joints. P/U= 65K, S/0= 66K. Actual displacement= 5.1 bbls, Calculated displacement= 5.4 bbls. 9/8/2016 9/8/2016 6.00 COMPZN CASING PUTB P RIH w/ 4-1/2" Tenaris XP BTC, 12.6#, 2,318.0 5,770.0 00:00 06:00 L-80 liner f/ 2318' MD to 5770' MD. Filling pipe every 10 joints. P/U= 113K, S/0= 94K. 9/8/2016 9/8/2016 4.00 COMPZN CASING PUTB P RIH w/ 4-1/2" Tenaris XP BTC, 12.6#, 5,770.0 7,619.0 06:00 10:00 L-80 liner f/ 5570' MD to casing shoe@ 7619' MD. Filling pipe every 10 joints. P/U= 116K, S/0= 98K. 9/8/2016 9/8/2016 2.00 COMPZN CASING DISP P R/U to circulate, M/U head pin and bail 7,619.0 7,619.0 10:00 12:00 extensions. Displace well to 10.0 ppg FloPro NT as follows, pump 30 bbis of high viscosity spacer and chase with 10.0 ppg FloPro NT mud. Pumped a total of 469 bbls keeping pump pressure under 1200 PSI. ECP: 170 gpm= 650 psi, FCP: 260 gpm= 800 psi. Obtain parameters, P/U= 129K, S/0= 105K, ROT= 115K @ 10 rpm w/ 4K Tq. 9/8/2016 9/8/2016 0.75 COMPZN CASING PUTB P RIH w/ 4-1/2" Tenaris XP BTC, 12.6#, 7,619.0 7,86-0 0 12:00 12:45 L-80 liner f/7619' MD to 7860' MD. Filling pipe every 10 joints. P/U= 129K, S/0= 104K. 9/8/2016 9/8/2016 0.50 COMPZN CASING OTHR P M/U liner hanger and ZXP liner top 7,860.0 7,999.0 12:45 13:15 packer and fill tie back sleeve w/ Palmix. M/U XO and 1st stand of 4" DP. P/U= 129K, S/O=106K 9/8/2016 9/8/2016 0.50 COMPZN CASING CIRC P Establish circulation @ 2 bpm= 400 7,999.0 7,999.0 13:15 13:45 psi, 7% FO, good circulation pumping 40 bbls. Page 26/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 9/8/2016 9/8/2016 4.25 COMPZN CASING RUNL P RIH w/ 4-1/2" liner on 4" drill pipe f/ 7,999.0 12,337.0 13:45 18:00 7999' MD to 12337' MD. Worked liner down through tight spots @ 9278' to 9434', 10434', 11247' to 11453' and 12300' to 12337'. P/U= 147K, S/O= 96K ( 105K after working pipe) 9/8/2016 9/9/2016 6.00 COMPZN CASING RUNL P RIH w/ 4-1/2" liner on 4" drill pipe f/ 12,337.0 14,815.0 18:00 00:00 12337' MD to 14900' MD Worked liner down through tight spots @ 12337' to 12393', 13440' to 13900' ,14520' and 14715' to 14815'. P/U= 170K, S/O= 106K. Actual displacement= 47.1 bbls, Calculated displacement= 48.9 bbls. 9/9/2016 9/9/2016 14.00 COMPZN CASING RUNL P Continue to TIH with Liner assembly 14,815.0 15,375.0 00:00 14:00 on 4" DP working thru tight spots. Attempt to break circulation @ 14,815' pumping 0.5 bpm / 500 psi - no returns. Shut down pumps. Continue workng pipe in hole. Up weight 175K / Down weight 11 OK. Pipe began to work free @ 15, 288'. P/U final stand to liner setting depth @ 15, 375' 9/9/2016 9/9/2016 1.50 COMPZN CASING RUNL P Work string at setting depth 190K up 15,375.0 15,375.0 14:00 15:30 weight / 125 K down. Establish returns @ 0.5 bpm / 600 psi, slowly stage up pump to 2 bpm max pressure 920 psi with returns. Total strokes 1380. 9/9/2016 9/9/2016 0.25 COMPZN CASING OTHR P P/U to tool joint and break stand, drop 15,375.0 15,375.0 15:30 15:45 1.5" ball to close WIV. Liner at setting depth. BOL = 15,375' TOL = 7479' 9/9/2016 9/9/2016 1.50 COMPZN CASING CIRC P Pump ball down @ 2 bpm: ICP=686 15,375.0 15,375.0 15:45 17:15 psi, FCP=603 psi, w/ 7% FO. Ball on seat @ 1849 strokes. Pressure up to 1200 psi to close WIV. 9/9/2016 9/9/2016 0.25 COMPZN CASING PACK P Pressure up to 2400 psi to set liner 15,375.0 15,375.0 17:15 17:30 hanger, S/O to ensure liner is hung off. Pressure up to 3600 to shear HRD , bleed off and pick up. Released, P/U another 5' and shear dogs, observed shear. Rotate @ 20 rpm's and set down 50K on dogs to confirm ZXP is set. P/U= 179K, S/O= 152K, ROT= 164K @ 20 rpm's. Top liner ZXP @ 7479.56' MD 9/9/2016 9/9/2016 0.75 COMPZN CASING PRTS P R/U and pressure test ZXP liner top 15,375.0 7,470.0 17:30 18:15 packer to 3000 psi f/ 10 min on chart, good. Page 27/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/9/2016 9/9/2016 1.50 COMPZN WELLPR DISP P Pick up 15' to pull out of RS packoff, 7,470.0 7,405.0 18:15 19:45 establish circulation @ 2 bpm= 250 psi, 8% FO. Increase pump rate to 4 bpm= 540 psi and displace well to seawater as follows. Pump 30 bbls of high viscosity seawater w/ both pumps and chase with seawater @ 4 bpm=797 psi, once clean seawater is inside packer P/U out of tieback sleeve and increase pumps to 12 bpm=3240 psi. after clean seawater was observed in pits, CBU to ensure wellbore is clean.Pumped a total of 6400 stokes. 9/9/2016 9/9/2016 0.50 COMPZN WELLPR OWFF P OWFF, static. 7,405.0 7,405.0 19:45 20:15 9/9/2016 9/10/2016 3.75 COMPZN WELLPR PULD P POOH UD HWDP and 4" DP f/ 7405' 7,405.0 4,407.0 20:15 00:00 MD to 4407' MD. L/D. L/D 90 joints of 4" WWDP and 9 joints of 4" DP. Good hole fill. 9/10/2016 9/10/2016 5.50 COMPZN WELLPR PULD P PJSM, Cont to POOH L/D 4" DP f/ 4,407.0 0.0 00:00 05:30 4407' MD to surface. L/D Baker running tools. UD a total of 141 joints of 4" DP. Good hole fill 9/10/2016 9/10/2016 1.00 COMPZN WELLPRPULD P UD 6 more stands ( 18 joints) of 4" DP 0.0 0.0 05:30 06:30 from derrick to clear room on drillers JWVVWH side for running 3-1/2" upper completion. 9/10/2016 9/10/2016 1.00 COMPZN RPCOMP P Pull wear bushing and wash out 0.0 0.0 06:30 07:30 wellhead w/ stack washing tool. 9/10/2016 9/10/2016 2.00 COMPZN RPCOMP RURD P PJSM, Rig up to run 3-1/2" EUE upper 0.0 0.0 07:30 09:30 completion. Rig up I -wire spool, hang sheave, rig up power tongs. C/O slips and elevators. Moblize clamps to rig floor and count. 9/10/2016 9/10/2016 1.00 COMPZN RPCOMP SFTY P Hold rig move planning and 0.0 0.0 09:30 10:30 optimization meeting with crews and discuss optimization/ SIMOPS for upcoming rig move. 9/10/2016 9/10/2016 1.00 COMPZN RPCOMP PUTB P RIH w/ 3-1/2" EUE-M , 9.3#, L-80 as 0.0 351.0 10:30 11:30 per tally to SLB gauge carrier @ 351' MD. 9/10/2016 9/10/2016 0.50 COMPZN RPCOMP PRTS P Install gauge and 1 -wire cable. 351.0 351.0 11:30 12:00 Pressure test gauge carrier to 5000 psi for 15 minutes. Test electrical function as per Cameo rep - good test. 9/10/2016 9/10/2016 6.00 COMPZN RPCOMP PUTB P RIH w/ 3-1/2" EUE-M , 9.3#, L-80 as 351.0 3,600.0 12:00 18:00 per tally f/ 351' MD to 3600' MD. Install cannon clamp every joint and test (- wire every 2000' as per Cameo. 9/10/2016 9/11/2016 6.00 COMPZN RPCOMP PUTB P RIH w/ 3-1/2" EUE-M , 9.3#, L-80 as 3,600.0 7,085.0 18:00 00:00 per tally f/ 3600' MD to 7085' MD. Install cannon clamp every joint and test 1 -wire every 2000' as per Cameo. 9/11/2016 9/11/2016 1.00 COMPZN RPCOMP PUTB P Continue PIU 3.5" Tubing with cannon 7,085.0 7,508.0 00:00 01:00 clamps on each conneciton. Page 28/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 .... .. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 9/11/2016 9/11/2016 3.50 COMPZN RPCOMP HOSO P Locate liner hanger - P/U weight 7,508.0 7,508.0 01:00 04:30 108K / DN 90K. Space out. Lay down 3 joints, P/U 2 EUE pups ( 8.23' & 10.19') and 1 full joint of 4" IBT. M/U hanger and landing joint. Install I wire on hanger. 9/11/2016 9/11/2016 0.50 COMPZN RPCOMP THGR P Land hanger - test hanger seals to 7,508.0 7,508.0 04:30 05:00 5000 psi / 15 mins. 9/11/2016 9/11/2016 1.00 COMPZN RPCOMP CRIH P Pump 20 bbis of CI SW, chase and 7,508.0 7,508.0 05:00 06:00 spot around bottom of tubing to lower GLM (SOV). 9/11/2016 9/11/2016 2.00 COMPZN RPCOMP PRTS T Drop ball and rod, wait for it land. Test 7,508.0 7,508.0 06:00 08:00 tubing to 4000 psi, observe 1000 psi loss in 15 mins. Pressure up again with same results. Bleed off pressure, change valve alignment and install additional surface valves to isolate mud manifold. Open IA and attempt tubing test again - same result with minimal leaking out the IA - pressure expansion. Tubing pressure bleeding falling off at the same rate. 9/11/2016 9/11/2016 1.00 COMPZN RPCOMP PRTS T Discuss options with town - call out SL 7,508.0 7,508.0 08:00 09:00 unit. R/U MP line to cellar, pressure up on tubing to 1000 psi, pressure up on IA to 2000 psi. IA held solid, tubing leaking off. (indicates Ball and Rod leaking by). 9/11/2016 9/11/2016 1.50 COMPZN RPCOMP PRTS P Test IA to 3500 psi for 30 mins while 7,508.0 7,508.0 09:00 10:30 holkding constant pressure on tubing to 2000 psi. Good test. Bleed off and OWFF for 15 mins - static. 9/11/2016 9/11/2016 3.00 COMPZN WHDBOP MPSP P Pump down IA and SOV @ 2500 psi. 7,508.0 7,508.0 10:30 13:30 Install BPV and test to 2500 psi/30 mins from below. 200 psi leak off below BPV, no surface leaks (leaking past ball and rod down hole). 9/11/2016 9/11/2016 0.25 COMPZN WHDBOP SFTY P PJSM for laying down 4" DP and 0.0 0.0 13:30 13:45 SIMOPS: ND MPD & BOP equipment. 9/11/2016 9/12/2016 10.25 COMPZN WHDBOP PULD P L/D 110 stands ( 330 joints) out of 0.0 0.0 13:45 00:00 derrick via mouse hole. SIMOPS: empty fluid from mud pits, blow down choke and kill line, blow down mud lines, disconnect pit and pump room interconnects. Rig down MPD air valve, flanges from RCD. Remove drip pan around annular, remove studs around RCD head and blow down all MPD lines. Rig down circulating lines from squeeze manifold. Remove kill and choke lines from BOPE. C/O pop off on mud pump 1 & 2 and clean suction manifolds. Page 29/30 Report Printed: 9/14/2016 Operations Summary (with Timelog Depths) 2S-06 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation ^8) End Depth ^13) 9/12/2016 9/12/2016 2.00 COMPZN WHDBOP PULD P Continue laying down 4" DP, 20 0.0 0.0 00:00 02:00 stands ( 60 joints) SIMOPS: Break down BOPE choke hose. Filter Koomey hydraulic fluid. Beak flange studs and interconnects 9/12/2016 9/12/2016 2.50 COMPZN WHDBOP NUND P Remove MPD flow line, bearing clamp 0.0 0.0 02:00 04:30 and spool from annular. Secure stack with cranes, remove remaining studs. NDBOPE and stand back. ND WH spool and set in cellar. 9/12/2016 9/12/2016 4.50 COMPZN WHDBOP NUND P NU adapter spool, termninate, test 1 0.0 0.0 04:30 09:00 wire and test pack offs. Hanger void - 250/5000/ 15 mins Tubing head SRL seals - 250/10,000 psi/15 mins. 9/12/2016 9/12/2016 2.00 COMPZN WHDBOP NUND P NU 10K frac tree, N/U wing valves, 0.0 0.0 09:00 11:00 torque bolts. SIMOPS - load 99 joints of 5" DP for surface hole. C/O valve and seats on MP #1 9/12/2016 9/12/2016 1.00 COMPZN WHDBOP PRTS P Test frac tree with diesel 10k for 15 0.0 0.0 11:00 12:00 min, good. 9/12/2016 9/12/2016 1.00 COMPZN WHDBOP MPSP P RD test lines and pull BPV 0.0 0.0 12:00 13:00 9/12/2016 9/12/2016 3.00 COMPZN WHDBOP FRZP P R/U LRS and freeze protect well using 0.0 0.0 13:00 16:00 80 bbls of diesel pumping down IA taking returns up tubing to cuttings tank. Pump 2 bpm @ 800 psi. Let well U tube. 9/12/2016 9/12/2016 1.00 COMPZN WHDBOP MPSP P Set type H BPV - test 1000 psi/5 min's 0.0 0.0 16:00 17:00 from below w/ LRS. R/D LRS circulating lines. 9/12/2016 9/12/2016 1.00 DEMOB MOVE MOB RDMO - Rig Release 18:00 0.0 0.0 17:00 18:00 IP I Page 30/30 Report Printed: 9/14/2016 NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-06 Definitive Survey Report 20 September, 2016 Schlumberq r DeffrtitiVe Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 25-06 Database: OAKEDM P2 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 2S-06 Date Well Position +N/ -S 0.00 usft Northing: 5,930,004.80 usft Latitude: 70° 13' 11.746 N +E/ -W 0.00 usft Easting: 481,162.27 usft Longitude: 1500 9'7.098 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 25-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 25-06 Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,009.85 2S-06 Srvy 1 - SLB_GWD70 (2S-06) (usft) (usft) (usft) (I 1,069.89 39.10 0.00 0.00 195.00 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.32 1,009.85 2S-06 Srvy 1 - SLB_GWD70 (2S-06) GYD-GC-SS Gyrodata gyro single shots 8/19/2016 8:31: 1,069.89 2,583.95 2S-06 Srvy 2 - SLB_MWD+GMAG (25-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/19/2016 8:36: 2,616.38 2,616.38 2S-06 Srvy 3 - SLB _INC -Filler (2S-06) INC+TREND Inclinometer + known azi trend 8/23/2016 12:07 2,706.90 7,560.16 2S-06 Srvy 4 - SLB_MWD+GMAG (25-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/23/2016 12:09 7,659.93 17,933.76 2S-06 Srvy 5 - SLB_MWD+GMAG (2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/31/2016 9:45: Survey g72W-2M6 T.D7.24FM Page 2 COMPASS 5".1 Duald 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5,930,004.80 481,162.27 0.00 0.00 UNDEFINED 100.32 0.19 343.22 100.32 -58.78 0.10 -0.03 5,930,004.90 481,162.24 0.31 -0.09 GYD-GC-SS(1) 161.19 0.28 47.50 161.19 2.09 0.29 0.05 5,930,005.10 481,162.32 0.43 -0.30 GYD-GC-SS(1) 257.39 0.28 349.16 257.39 98.29 0.68 0.18 5,930,005.49 481,162.45 0.28 -0.71 GYD-GC-SS(1) 356.17 1.32 5.68 356.16 197.06 2.05 0.25 5,930,006.85 481,162.52 1.07 -2.05 GYD-GC-SS (1) 448.44 3.10 1.21 448.36 289.26 5.61 0.41 5,930,010.41 481,162.69 1.94 -5.52 GYD-GC-SS(1) 539.12 4.03 4.40 538.86 379.76 11.23 0.70 5,930,016.03 481,163.00 1.05 -11.03 GYD-GC-SS(1) 631.94 4.15 3.74 631.44 472.34 17.84 1.17 5,930,022.63 481,163.49 0.14 -17.53 GYD-GC-SS(1) 725.12 6.56 4.25 724.21 565.11 26.51 1.79 5,930,031.31 481,164.12 2.59 -26.07 GYD-GC-SS (1) 820.98 7.86 0.26 819.31 660.21 38.53 2.22 5,930,043.32 481,164.59 1.45 -37.79 GYD-GC-SS(1) g72W-2M6 T.D7.24FM Page 2 COMPASS 5".1 Duald 74 Schlumberger Definitve Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 915.97 9.77 359.98 913.17 754.07 53.08 2.25 5,930,057.87 481,164.65 2.01 -51.86 GYD-GC-SS (1) 1,009.85 11.04 0.30 1,005.51 846.41 70.04 2.29 5,930,074.83 481,164.74 1.35 -68.24 GYD-GC-SS (1) 1,069.89 12.12 357.28 1,064.33 905.23 82.08 2.02 5,930,086.87 481,164.50 2.06 -79.81 MWD+IFR-AK-CAZ-SC (2) 1,164.35 15.48 357.78 1,156.05 996.95 104.59 1.06 5,930,109.38 481,163.59 3.56 -101.30 MWD+IFR-AK-CAZ-SC (2) 1,259.97 17.70 357.04 1,247.68 1,088.58 131.86 -0.18 5,930,136.65 481,162.42 2.33 -127.32 MWD+IFR-AK-CAZ-SC (2) 1,354.34 22.39 358.48 1,336.31 1,177.21 164.17 -1.40 5,930,168.96 481,161.28 5.00 -158.22 MWD+IFR-AK-CAZ-SC (2) 1,449.30 22.33 358.93 1,424.13 1,265.03 200.29 -2.22 5,930,205.08 481,160.55 0.19 -192.89 MWD+IFR-AK-CAZ-SC (2) 1,543.75 21.70 6.01 1,511.71 1,352.61 235.60 -0.72 5,930,240.38 481,162.14 2.89 -227.39 MWD+IFR-AK-CAZSC (2) 1,639.06 20.62 12.61 1,600.60 1,441.50 269.51 4.79 5,930,274.27 481,167.73 2.74 -261.56 MWD+IFR-AK-CAZ-SC (2) 1,734.09 20.28 21.23 1,689.66 1,530.56 301.20 14.41 5,930,305.93 481,177.43 3.19 -294.66 MWD+IFR-AK-CAZ-SC (2) 1,828.64 20.70 29.92 1,778.25 1,619.15 330.96 28.68 5,930,335.66 481,191.77 3.24 -327.11 MWD+IFR-AK-CAZ-SC (2) 1,923.75 21.30 30.53 1,867.05 1,707.95 360.41 45.84 5,930,365.06 481,209.00 0.67 -359.99 MWD+IFR-AK-CAZ-SC (2) 2,019.13 21.52 30.73 1,955.84 1,796.74 390.37 63.58 5,930,394.97 481,226.82 0.24 -393.52 MWD+IFR-AK-CAZ-SC (2) 2,113.70 21.72 30.68 2,043.76 1,884.66 420.33 81.37 5,930,424.88 481,244.68 0.21 -427.07 MWD+IFR-AK-CAZ-SC (2) 2,208.31 21.57 30.95 2,131.70 1,972.60 450.30 99.25 5,930,454.81 481,262.63 0.19 -460.64 MWD+IFR-AK-CAZSC (2) 2,303.63 21.24 31.39 2,220.44 2,061.34 480.06 117.25 5,930,484.53 481,280.71 0.39 -494.05 MWD+IFR-AK-CAZ-SC (2) 2,398.00 21.07 31.06 2,308.45 2,149.35 509.19 134.91 5,930,513.60 481,298.43 0.22 -526.75 MWD+IFR-AK-CAZ-SC (2) 2,492.84 20.74 31.71 2,397.05 2,237.95 538.08 152.53 5,930,542.44 481,316.13 0.43 -559.22 MWD+IFR-AK-CAZ-SC (2) 2,583.95 20.48 30.41 2,482.33 2,323.23 565.55 169.08 5,930,569.87 481,332.74 0.58 -590.04 MWD+IFR-AK-CAZ-SC (2) 2,616.38 20.94 28.37 2,512.66 2,353.56 575.54 174.70 5,930,579.85 481,338.39 2.64 -001.15 INC+TREND (3) 2,657.00 21.66 27.42 2,550.51 2,391.41 588.58 181.60 5,930,592.87 481,345.32 1.98 -615.53 MWD+IFR-AK-CAZ-SC (4) 10 314" x 13-112" 2,706.90 22.56 26.33 2,596.74 2,437.64 605.34 190.09 5,930,609.60 481,353.85 1.98 -633.91 MWD+IFR-AK-CAZ-SC (4) 2,802.11 21.33 26.32 2,685.05 2,525.95 637.23 205.87 5,930,641.45 481,369.71 1.29 -668.80 MWD+IFR-AK-CAZ-SC (4) 2,897.25 21.41 26.24 2,773.65 2,614.55 668.31 221.22 5,930,672.49 481,385.13 0.09 -702.80 MWD+IFR-AK-CAZ-SC (4) 2,993.26 21.37 25.31 2,863.04 2,703.94 699.84 236.45 5,930,703.98 481,400.44 0.36 -737.19 MWD+IFR-AK-CAZ-SC (4) 3,088.38 21.41 28.17 2,951.62 2,792.52 730.82 252.05 5,930,734.92 481,416.12 1.10 -771.15 MWD+IFR-AK-CAZ-SC (4) 3,181.81 21.48 30.50 3,038.58 2,879.48 760.59 268.78 5,930,764.64 481,432.92 0.91 -804.24 MWD+IFR-AK-CAZ-SC (4) 3,276.28 21.33 32.60 3,126.53 2,967.43 789.97 286.82 5,930,793.97 481,451.03 0.83 -837.28 MWD+IFR-AK-CAZ-SC (4) 3,371.37 21.36 31.82 3,215.10 3,056.00 819.25 305.27 5,930,823.21 481,469.55 0.30 -870.34 MWD+IFR-AK-CAZ-SC (4) 3,465.85 21.25 31.30 3,303.12 3,144.02 848.50 323.23 5,930,852.41 481,487.59 0.23 -903.25 MWD+IFR-AK-CAZ-SC (4) 3,561.35 18.21 29.24 3,393.01 3,233.91 876.32 339.52 5,930,880.18 481,503.94 3.27 -934.33 MWD+IFR-AK-CAZ-SC (4) 3,655.34 15.98 29.72 3,482.84 3,323.74 900.37 353.11 5,930,904.20 481,517.59 2.38 -961.08 MWD+IFR-AK-CAZ-SC (4) 3,750.54 14.03 31.67 3,574.79 3,415.69 921.57 365.66 5,930,925.37 481,530.20 2.12 -984.81 MWD+IFR-AK-CAZ-SC (4) 3,845.52 12.17 35.54 3,667.30 3,508.20 939.52 377.53 5,930,943.28 481,542.11 2.16 -1,005.22 MWD+IFR-AK-CAZ-SC (4) 3,940.31 10.68 40.03 3,760.21 3,601.11 954.38 388.99 5,930,958.11 481,553.60 1.83 -1,022.54 MWD+IFR-AK-CAZSC (4) 4,035.52 8.89 49.14 3,854.03 3,694.93 965.95 400.23 5,930,969.65 481,564.87 2.48 -1,036.62 MWD+IFR-AK-CAZ-SC (4) 4,130.41 7.52 65.73 3,947.96 3,788.86 973.30 411.44 5,930,976.97 481,576.09 2.87 -1,046.62 MWD+IFR-AK-CAZ-SC (4) 4,224.72 6.54 86.87 4,041.58 3,882.48 976.13 422.43 5,930,979.78 481,587.09 2.91 -1,052.20 MWD+IFR-AK-CAZ-SC (4) 4,318.81 6.05 110.03 4,135.12 3,976.02 974.72 432.44 5,930,978.35 481,597.09 2.73 -1,053.43 MWD+IFR-AK-CAZ-SC (4) 4,414.63 5.80 131.61 4,230.44 4,071.34 969.78 440.80 5,930,973.38 481,605.45 2.33 -1,050.82 MWD+IFR-AK-CAZ-SC (4) 972072, 416 1:07Z41 M PAP IrPASS Wit- I Bm#9 74 Schlumberger Def ni"We Surrey Rem Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 25-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aai TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1 0 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,509.52 6.70 145.00 4,324.77 4,165.67 962.06 447.56 5,930,965.64 481,612.19 1.80 -1,045.11 MWD+IFR-AK-CAZ-SC (4) 4,602.96 8.28 154.35 4,417.41 4,258.31 951.53 453.60 5,930,955.10 481,618.20 2.13 -1,036.51 MWD+IFR-AK-CAZ-SC (4) 4,698.31 10.35 159.47 4,511.50 4,352.40 937.31 459.58 5,930,940.87 481,624.14 2.34 -1,024.32 MWD+IFR-AK-CAZ-SC (4) 4,795.38 12.33 163.82 4,606.67 4,447.57 919.19 465.52 5,930,922.74 481,630.04 2.22 -1,008.36 MWD+IFR-AK-CAZ-SC (4) 4,891.21 15.18 171.56 4,699.75 4,540.65 896.95 470.22 5,930,900.49 481,634.68 3.53 -988.09 MWD+IFR-AK-CAZ-SC (4) 4,983.13 18.66 182.89 4,787.70 4,628.60 870.34 471.24 5,930,873.88 481,635.64 5.20 -962.65 MWD+IFR-AK-CAZ-SC (4) 5,077.82 21.35 186.13 4,876.67 4,717.57 838.07 468.64 5,930,841.62 481,632.95 3.07 -930.81 MWD+IFR-AK-CAZ-SC (4) 5,172.97 23.11 186.29 4,964.75 4,805.65 802.28 464.74 5,930,805.84 481,628.97 1.85 -895.23 MWD+IFR-AK-CAZ-SC (4) 5,267.99 25.18 184.68 5,051.45 4,892.35 763.60 461.05 5,930,767.17 481,625.18 2.29 -856.91 MWD+IFR-AK-CAZ-SC (4) 5,362.20 27.85 182.73 5,135.75 4,976.65 721.63 458.37 5,930,725.22 481,622.39 2.98 -815.68 MWD+IFR-AK-CAZ-SC (4) 5,456.29 30.15 181.68 5,218.03 5,058.93 676.06 456.63 5,930,679.65 481,620.54 2.50 -771.20 MWD+IFR-AK-CAZ-SC (4) 5,551.84 32.57 182.46 5,299.62 5,140.52 626.37 454.82 5,930,629.97 481,618.61 2.57 -722.74 MWD+IFR-AK-CAZ-SC (4) 5,646.69 34.35 183.61 5,378.75 5,219.65 574.15 452.04 5,930,577.77 481,615.70 1.99 -671.58 MWD+IFR-AK-CAZ-SC (4) 5,742.29 36.67 185.54 5,456.57 5,297.47 518.81 447.58 5,930,522.44 481,611.10 2.69 -616.98 MWD+IFR-AK-CAZ-SC (4) 5,836.35 39.20 186.16 5,530.75 5,371.65 461.29 441.68 5,930,464.95 481,605.06 2.72 559.89 MWD+IFR-AK-CAZ-SC (4) 5,931.08 41.51 185.02 5,602.93 5,443.83 400.25 435.72 5,930,403.92 481,598.95 2.56 499.38 MWD+IFR-AK-CAZ-SC (4) 6,026.45 45.01 185.20 5,672.37 5,513.27 335.16 429.90 5,930,338.86 481,592.96 3.67 435.01 MWD+IFR-AK-CAZ-SC (4) 6,120.04 45.88 186.91 5,738.04 5,578.94 268.85 422.86 5,930,272.57 481,585.75 1.60 -369.13 MWD+IFR-AK-CAZ-SC (4) 6,215.81 47.85 189.14 5,803.52 5,644.42 199.66 413.08 5,930,203.41 481,575.81 2.67 -299.77 MWD+IFR-AK-CAZ-SC (4) 6,310.93 50.59 190.26 5,865.64 5,706.54 128.68 400.93 5,930,132.46 481,563.48 3.02 -228.06 MWD+IFR-AK-CAZ-SC (4) 6,405.93 52.94 191.11 5,924.43 5,765.33 55.36 387.09 5,930,059.19 481,549.46 2.57 -153.66 MWD+IFR-AK-CAZ-SC (4) 6,500.66 55.78 190.33 5,979.63 5,820.53 -20.28 372.78 5,929,983.60 481,534.96 3.07 -76.89 MWD+IFR-AK-CAZ-SC (4) 6,595.44 58.80 190.78 6,030.84 5,871.74 -98.67 358.17 5,929,905.25 481,520.15 3.21 2.61 MWD+IFR-AK-CAZ-SC (4) 6,690.21 60.69 191.24 6,078.59 5,919.49 -179.02 342.53 5,929,824.95 481,504.32 2.04 84.27 MWD+IFR-AK-CAZ-SC (4) 6,785.50 62.79 191.62 6,123.70 5,964.60 -261.28 325.90 5,929,742.73 481,487.48 2.23 168.03 MWD+IFR-AK-CAZ-SC (4) 6,879.60 65.85 192.52 6,164.47 6,005.37 -344.20 308.16 5,929,659.87 481,469.54 3.36 252.71 MWD+IFR-AK-CAZSC (4) 6,974.39 68.87 193.50 6,200.96 6,041.86 429.43 288.46 5,929,574.70 481,449.63 3.33 340.14 MWD+IFR-AK-CAZ-SC (4) 7,072.08 70.63 194.04 6,234.77 6,075.67 -518.44 266.64 5,929,485.75 481,427.59 1.87 431.76 MWD+IFR-AK-CAZ-SC (4) 7,165.22 72.78 194.69 6,264.01 6,104.91 -604.10 244.70 5,929,400.15 481,405.44 2.40 520.18 MIND+IFR-AK-CAZ-SC (4) 7,260.57 74.67 195.07 6,290.73 6,131.63 592.55 221.19 5,929,311.77 481,381.71 2.02 611.71 MWD+IFR-AK-CAZ-SC (4) 7,355.40 77.20 194.53 6,313.77 6,154.67 -781.48 197.70 5,929,222.91 481,358.00 2.72 703.69 MWD+IFR-AK-CAZ-SC (4) 7,450.21 79.86 194.98 6,332.62 6,173.52 -871.33 174.04 5,929,133.13 481,334.11 2.84 796.59 MWD+IFR-AK-CAZ-SC (4) 7,544.25 81.63 195.83 6,347.75 6,188.65 -960.80 149.38 5,929,043.72 481,309.24 2.08 889.40 MWD+IFR-AK-CAZ-SC (4) 7,560.16 81.91 194.66 6,350.02 6,190.92 -975.99 145.24 5,929,028.55 481,305.06 7.49 905.15 MWD+IFR-AK-CAZ-SC (4) 7,620.00 84.07 194.52 6,357.33 6,198.23 -1,033.47 130.28 5,928,971.11 481,289.96 3.62 964.54 MWD+IFR-AK-CAZ-SC (5) 7-6/8" x 9-7/8 by 11 7,659.93 85.51 194.42 6,360.95 6,201.85 -1,071.97 120.35 5,928,932.64 481,279.93 3.62 1,004.30 MWD+IFR-AK-CAZ-SC (5) 7,720.54 86.78 193.65 6,365.03 6,205.93 -1,130.64 105.68 5,928,874.02 481,265.12 2.45 1,064.76 MWD+IFR-AK-CAZ-SC (5) 7,814.02 87.59 193.09 6,369.62 6,210.52 -1,221.47 84.09 5,928,783.24 481,243.31 1.05 1,158.09 MWD+IFR-AK-CAZ-SC (5) 7,908.65 85.65 191.90 6,375.20 6,216.10 -1,313.70 63.66 5,928,691.08 481,222.64 2.40 1,252.46 MWD+IFR-AK-CAZ-SC (5) 111926MM 10,72" page 4 SSS '9 Irrild 74 Schhunberger Defntrve SuTvey Repod Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (13142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°l100-) (ft) Survey Tool Name 8,003.37 88.05 193.10 6,380.40 6,221.30 -1,406.02 43.19 5,928,598.82 481,201.94 2.83 1,346.94 MWD+IFR-AK-CAZ-SC (5) 8,099.44 90.83 192.15 6,381.34 6,222.24 -1,499.75 22.19 5,928,505.15 481,180.72 3.06 1,442.91 MWD+IFR-AK-CAZ-SC (5) 8,192.83 92.63 192.76 6,378.52 6,219.42 -1,590.90 2.06 5,928,414.06 481,160.36 2.03 1,536.16 MWD+IFR-AK-CAZ-SC (5) 8,288.33 91.51 193.66 6,375.07 6,215.97 -1,683.81 -19.75 5,928,321.21 481,138.32 1.50 1,631.55 MWD+IFR-AK-CAZ-SC (5) 8,383.03 90.79 193.19 6,373.17 6,214.07 -1,775.90 -41.73 5,928,229.19 481,116.11 0.91 1,726.19 MWD+IFR-AK-CAZ-SC (5) 8,477.83 91.19 194.21 6,371.53 6,212.43 -1,867.99 -64.18 5,928,137.16 481,093.44 1.16 1,820.95 MWD+IFR-AK-CAZ-SC (5) 8,572.36 87.79 194.99 6,372.38 6,213.28 -1,959.45 -88.00 5,928,045.77 481,069.39 3.69 1,915.46 MWD+IFR-AK-CAZ-SC (5) 8,667.34 87.16 195.52 6,376.56 6,217.46 -2,050.99 -112.97 5,927,954.30 481,044.19 0.87 2,010.35 MWD+IFR-AK-CAZ-SC (5) 8,762.25 86.92 195.94 6,381.46 6,222.36 -2,142.23 -138.66 5,927,863.14 481,018.27 0.51 2,105.12 MWD+IFR-AK-CAZ-SC (5) 8,857.34 87.64 198.27 6,385.97 6,226.87 -2,233.00 -166.60 5,927,772.44 480,990.11 2.56 2,200.03 MWD+IFR-AK-CAZ-SC (5) 8,951.68 87.94 196.32 6,389.61 6,230.51 -2,323.01 -194.62 5,927,682.52 480,961.87 2.09 2,294.22 MWD+IFR-AK-CAZ-SC (5) 9,046.32 89.63 196.28 6,391.62 6,232.52 -2,413.82 -221.18 5,927,591.78 480,935.09 1.79 2,388.81 MWD+IFR-AK-CAZ-SC (5) 9,140.92 91.07 195.77 6,391.04 6,231.94 -2,504.74 -247.29 5,927,500.94 480,908.75 1.61 2,483.40 MWD+IFR-AK-CAZ-SC (5) 9,236.56 91.82 196.40 6,388.63 6,229.53 -2,596.60 -273.78 5,927,409.15 480,882.04 1.02 2,578.99 MWD+IFR-AK-CAZ-SC (5) 9,330.87 92.92 193.85 6,384.73 6,225.63 -2,687.56 -298.37 5,927,318.26 480,857.23 2.94 2,673.21 MWD+IFR-AK-CAZ-SC (5) 9,425.67 92.95 193.14 6,379.87 6,220.77 -2,779.62 -320.46 5,927,226.27 480,834.90 0.75 2,767.85 MWD+IFR-AK-CAZ-SC (5) 9,520.28 91.99 191.61 6,375.80 6,216.70 -2,871.94 -340.72 5,927,134.00 480,814.42 1.91 2,862.27 MWD+IFR-AK-CAZ-SC (5) 9,614.77 91.58 191.76 6,372.85 6,213.75 -2,964.43 -359.84 5,927,041.58 480,795.06 0.46 2,956.55 MWD+IFR-AK-CAZ-SC (5) 9,710.02 91.55 191.65 6,370.25 6,211.15 -3,057.66 -379.16 5,926,948.40 480,775.52 0.12 3,051.61 MWD+IFR-AK-CAZ-SC (5) 9,804.02 91.99 191.76 6,367.35 6,208.25 -3,149.66 -398.22 5,926,856.45 480,756.23 0.48 3,145.41 MWD+IFR-AK-CAZ-SC (5) 9,898.90 91.48 191.29 6,364.48 6,205.38 -3,242.59 -417.17 5,926,763.59 480,737.05 0.73 3,240.07 MWD+IFR-AK-CAZ-SC (5) 9,993.23 91.48 190.95 6,362.04 6,202.94 -3,335.12 435.36 5,926,671.11 480,718.63 0.36 3,334.15 MWD+IFR-AK-CAZ-SC (5) 10,088.12 91.24 191.75 6,359.79 6,200.69 -3,428.12 1154.03 5,926,578.16 480,699.74 0.88 3,428.82 MWD+IFR-AK-CAZ-SC (5) 10,182.57 89.40 191.14 6,359.26 6,200.16 -3,520.69 -472.77 5,926,485.65 480,680.77 2.05 3,523.09 MWD+IFR-AK-CAZ-SC (5) 10,277.60 90.04 192.21 6,359.72 6,200.62 -3,613.75 -492.00 5,926,392.65 480,661.31 1.31 3,617.95 MWD+IFR-AK-CAZ-SC (5) 10,371.79 90.79 193.57 6,359.04 6,199.94 -3,705.56 -513.01 5,926,300.90 480,640.07 1.65 3,712.07 MWD+IFR-AK-CAZ-SC (5) 10,467.10 89.76 194.59 6,358.58 6,199.48 -3,798.01 -536.19 5,926,208.53 480,616.65 1.52 3,807.37 MWD+IFR-AK-CAZ-SC (5) 10,560.70 88.72 193.84 6,359.83 6,200.73 -3,888.73 -559.17 5,926,117.87 480,593.45 1.37 3,900.95 MWD+IFR-AK-CAZ-SC (5) 10,656.41 89.63 194.87 6,361.20 6,202.10 -3,981.44 -582.90 5,926,025.23 480,569.49 1.44 3,996.64 MWD+IFR-AK-CAZ-SC (5) 10,750.53 89.52 195.47 6,361.90 6,202.80 -4,072.28 -607.53 5,925,934.46 480,544.64 0.65 4,090.76 MWD+IFR-AK-CAZ-SC (5) 10,845.40 89.63 195.88 6,362.61 6,203.51 -4,163.62 -633.16 5,925,843.19 480,518.78 0.45 4,185.62 MWD+IFR-AK-CAZ-SC (5) 10,939.33 90.38 196.07 6,362.60 6,203.50 -4,253.92 -659.01 5,925,752.97 480,492.71 0.82 4,279.53 MWD+IFR-AK-CAZ-SC (5) 11,034.67 90.38 196.52 6,361.97 6,202.87 -4,345.43 -685.76 5,925,661.53 480,465.73 0.47 4,374.85 MWD+IFR-AK-CAZ-SC (5) 11,128.07 89.11 197.53 6,362.38 6,203.28 -4,434.73 -713.11 5,925,572.31 480,438.17 1.74 4,468.18 MWD+IFR-AK-CAZ-SC (5) 11,223.12 88.19 197.31 6,364.62 6,205.52 -4,525.39 -741.55 5,925,481.72 480,409.50 1.00 4,563.12 MWD+IFR-AK-CAZ-SC (5) 11,318.26 87.04 198.01 6,368.58 6,209.48 -0,615.97 -770.39 5,925,391.23 480,380.44 1.41 4,658.08 MWD+IFR-AK-CAZ-SC (5) 11,412.87 87.98 197.49 6,372.69 6,213.59 -4,705.99 -799.21 5,925,301.29 480,351.40 1.14 4,752.49 MWD+IFR-AK-CAZ-SC (5) 11,506.96 89.22 197.87 6,374.99 6,215.89 11,795.61 -827.77 5,925,211.75 480,322.61 1.38 4,846.44 MWD+IFR-AK-CAZ-SC (5) 11,600.80 90.00 196.64 6,375.63 6,216.53 -4,885.22 -855.61 5,925,122.22 480,294.56 1.55 4,940.21 MWD+IFR-AK-CAZ-SC (5) 11,695.98 91.34 195.76 6,374.51 6,215.41 A,976.61 -882.16 5,925,030.91 480,267.78 1.68 5,035.36 MWD+1FR-AK-CAZ-SC (5) 9/2"'t•S 1107.24PJW fade 5 COMPASS 55WO. 9 Budd 74 Schlumberger Defirntive, Survey Rem Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Aai TVD TVDSS +NIS +E/ -W Northing Easting DLS Section NO) (°) (°j (uaft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,790.89 92.03 194.87 6,371.72 6,212.62 -5,068.11 -907.22 5,924,939.48 480,242.50 1.19 5,130.22 MWD+IFR-AK-CAZ-SC (5) 11,886.13 91.89 194.86 6,368.47 6,209.37 -5,160.11 -931.63 5,924,847.55 480,217.85 0.15 5,225.41 MWD+IFR-AK-CAZ-SC (5) 11,981.33 91.14 195.00 6,365.95 6,206.85 -5,252.06 -956.15 5,924,755.67 480,193.11 0.80 5,320.57 MWD+IFR-AK-CAZ-SC (5) 12,076.19 90.55 194.91 6,364.55 6,205.45 -5,343.70 -980.63 5,924,664.10 480,168.41 0.63 5,415.42 MWD+IFR-AK-CAZ-SC (5) 12,170.11 90.62 194.78 6,363.59 6,204.49 -5,434.48 -1,004.69 5,924,573.39 480,144.12 0.16 5,509.33 MWD+IFR-AK-CAZ-SC (5) 12,264.91 88.84 194.93 6,364.04 6,204.94 -5,526.10 -1,028.99 5,924,481.83 480,119.59 1.88 5,604.13 MWD+IFR-AK-CAZ-SC (5) 12,360.29 86.31 197.84 6,368.07 6,208.97 -5,617.51 -1,055.87 5,924,390.50 480,092.49 4.04 5,699.38 MWD+IFR-AK-CAZ-SC (5) 12,455.37 86.75 197.03 6,373.83 6,214.73 -5,708.06 -1,084.30 5,924,300.04 480,063.83 0.97 5,794.20 MWD+IFR-AK-CAZ-SC (5) 12,549.05 86.61 196.28 6,379.25 6,220.15 -5,797.65 -1,111.11 5,924,210.52 480,036.81 0.81 5,887.68 MWD+IFR-AK-CAZ-SC (5) 12,643.85 86.88 196.76 6,384.64 6,225.54 -5,888.39 -1,138.02 5,924,119.85 480,009.67 0.58 5,982.29 MWD+IFR-AK-CAZ-SC (5) 12,739.28 87.67 195.70 6,389.17 6,230.07 -5,979.92 -1,164.66 5,924,028.41 479,982.80 1.38 6,077.59 MWD+IFR-AK-CAZ-SC (5) 12,834.87 88.32 195.31 6,392.52 6,233.42 -6,071.97 -1,190.20 5,923,936.43 479,957.04 0.79 6,173.12 MWD+IFR-AK-CAZ-SC (5) 12,929.92 88.52 192.86 6,395.14 6,236.04 -6,164.12 -1,213.32 5,923,844.34 479,933.69 2.59 6,268.11 MWD+IFR-AK-CAZ-SC(5) 13,024.14 90.05 192.49 6,396.32 6,237.22 -6,256.03 -1,233.99 5,923,752.49 479,912.79 1.67 6,362.25 MWD+IFR-AK-CAZ-SC (5) 13,117.94 89.70 192.08 6,396.52 6,237.42 -6,347.69 -1,253.95 5,923,660.90 479,892.61 0.57 6,455.94 MWD+IFR-AK-CAZ-SC (5) 13,212.28 89.90 191.25 6,396.85 6,237.75 -6,440.08 -1,273.02 5,923,568.56 479,873.30 0.90 6,550.12 MWD+IFR-AK-CAZ-SC (5) 13,307.28 90.86 190.77 6,396.22 6,237.12 -6,533.32 -1,291.17 5,923,475.37 479,854.93 1.13 6,644.88 MWD+IFR-AK-CAZ-SC (5) 13,402.84 90.66 190.96 6,394.95 6,235.85 -6,627.16 -1,309.18 5,923,381.59 479,836.69 0.29 6,740.19 MWD+IFR-AK-CAZ-SC (5) 13,497.52 89.72 192.49 6,394.64 6;235.54 -6,719.86 -1,328.42 5,923,288.95 479,817.22 1.90 6,834.71 MWD+IFR-AK-CAZ-SC (5) 13,592.34 90.14 192.19 6,394.75 6,235.65 -6,812.49 -1,348.68 5,923,196.38 479,796.73 0.54 6,929.43 MWD+IFR-AK-CAZ-SC (5) 13,688.98 88.98 191.98 6,395.50 6,236.40 -6,906.99 -1,368.91 5,923,101.94 479,776.26 1.22 7,025.94 MWD+IFR-AK-CAZ-SC (5) 13,782.05 87.28 192.72 6,398.53 6,239.43 -6,997.85 -1,388.81 5,923,011.14 479,756.14 1.99 7,118.85 MWD+IFR-AK-CAZ-SC (5) 13,877.26 86.75 192.82 6,403.49 6,244.39 -7,090.58 -1,409.82 5,922,918.47 479,734.90 0.57 7,213.86 MWD+IFR-AK-CAZ-SC (5) 13,973.14 89.74 193.09 6,406.43 6,247.33 -7,183.96 -1,431.31 5,922,825.15 479,713.18 3.13 7,309.62 MWD+IFR-AK-CAZ-SC (5) 14,067.15 90.59 193.71 6,406.16 6,247.06 -7,275.41 -1,453.09 5,922,733.76 479,691.17 1.12 7,403.60 MWD+IFR-AK-CAZ-SC (5) 14,161.38 89.85 192.83 6,405.79 6,246.69 -7,367.12 -1,474.72 5,922,642.12 479,669.31 1.22 7,497.78 MWD+IFR-AK-CAZ-SC (5) 14,257.29 90.69 193.02 6,405.34 6,246.24 -7,460.60 -1,496.17 5,922,548.70 479,647.63 0.90 7,593.63 MWD+IFR-AK-CAZ-SC (5) 14,352.28 91.14 193.36 6,403.83 6,244.73 -7,553.07 -1,517.85 5,922,456.29 479,625.73 0.59 7,688.56 MWD+IFR-AK-CAZ-SC (5) 14,447.26 91.58 193.53 6,401.57 6,242.47 -7,645.42 -1,539.92 5,922,364.01 479,603.42 0.50 7,783.47 MWD+IFR-AK-CAZ-SC (5) 14,541.68 92.85 193.04 6,397.92 6,238.82 -7,737.25 -1,561.60 5,922,272.25 479,581.52 1.44 7,877.78 MWD+IFR-AK-CAZ-SC (5) 14,636.48 92.64 194.98 6,393.38 6,234.28 -7,829.12 -1,584.53 5,922,180.44 479,558.37 2.06 7,972.45 MWD+IFR-AK-CA7-SC (5) 14,731.94 92.95 193.55 6,388.73 6,229.63 -7,921.52 -1,608.02 5,922,088.11 479,534.64 1.53 8,067.79 MWD+IFR-AK-CA7-SC (5) 14,826.68 92.61 193.62 6,384.13 6,225.03 -8,013.50 -1,630.25 5,921,996.19 479,512.19 0.37 8,162.39 MWD+IFR-AK-CAZ-SC (5) 14,921.26 91.15 192.70 6,381.03 6,221.93 -8,105.54 -1,651.77 5,921,904.21 479,490.44 1.82 8,256.86 MWD+IFR-AK-CAZ-SC (5) 15,016.01 91.79 194.04 6,378.60 6,219.50 -8,197.69 -1,673.67 5,921,812.13 479,468.31 1.57 8,351.54 MWD+IFR-AK-CAZ-SC (5) 15,110.55 91.96 196.90 6,375.50 6,216.40 -8,288.75 -1,698.87 5,921,721.14 479,442.89 3.03 8,446.02 MWD+IFR-AK-CAZ-SC (5) 15,206.22 92.00 195.97 6,372.20 6,213.10 -8,380.46 -1,725.92 5,921,629.51 479,415.61 0.97 8,541.60 MWD+IFR-AK-CAZ-SC (5) 15,300.84 90.11 195.03 6,370.46 6,211.36 -8,471.61 -1,751.20 5,921,538.43 479,390.11 2.23 8,636.20 MWD+IFR-AK-CAZ-SC (5) 15,375.00 89.27 195.26 6,370.86 6,211.76 -8,543.20 -1,770.58 5,921,466.90 479,370.55 1.17 8,710.35 MWD+IFR-AK-CAZ-SC (5) 41/2" x 6-3/4 M=2016 1:)0724PM 'page's COWASSSOM I BIAW :74 Schlumberger DefinItive Survey Rem Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MID Inc AzI TVD TVDSS +N1 -S +E/ -W Northing Easting DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (°h00-) (ft) Survey Tool Name 15,395.58 89.04 195.33 6,371.16 6,212.06 -8,563.04 -1,776.01 5,921,447.07 479,365.07 1.17 8,730.93 MWD+IFR-AK-CAZSC (5) 15,489.89 87.53 195.78 6,373.98 6,214.88 -8,653.86 -1,801.29 5,921,356.33 479,339.57 1.67 8,825.19 MWD+IFR-AK-CAZSC (5) 15,585.60 85.06 196.96 6,380.17 6,221.07 -8,745.49 -1,828.20 5,921,264.78 479,312.43 2.86 8,920.66 MWD+IFR-AK-CAZSC (5) 15,679.44 82.22 197.26 6,390.56 6,231.46 -8,834.61 -1,855.64 5,921,175.73 479,284.78 3.04 9,013.85 MWD+IFR-AK-CAZ-SC (5) 15,774.24 84.51 196.42 6,401.51 6,242.41 -8,924.73 -1,882.91 5,921,085.69 479,257.28 2.57 9,107.96 MWD+IFR-AK-CAZ-SC (5) 15,868.49 85.51 196.39 6,409.71 6,250.61 -9,014.80 -1,909.43 5,920,995.69 479,230.54 1.06 9,201.83 MWD+IFR-AK-CAZSC (5) 15,963.28 86.71 196.18 6,416.14 6,257.04 -9,105.58 -1,935.95 5,920,904.99 479,203.80 1.29 9,296.37 MWD+IFR-AK-CAZ-SC (5) 16,058.46 87.12 196.38 6,421.26 6,262.16 -9,196.81 -1,962.59 5,920,813.84 479,176.93 0.48 9,391.39 MWD+IFR-AK-CAZ-SC (5) 16,153.67 86.47 196.08 6,426.59 6,267.49 -9,288.08 -1,989.16 5,920,722.64 479,150.13 0.75 9,486.43 MWD+IFR-AK-CAZSC (5) 16,249.50 86.44 194.57 6,432.51 6,273.41 -9,380.32 -2,014.44 5,920,630.47 479,124.63 1.57 9,582.07 MWD+IFR-AK-CAZSC (5) 16,343.48 86.85 194.45 6,438.01 6,278.91 -9,471.15 -2,037.95 5,920,539.71 479,100.90 0.45 9,675.89 MWD+IFR-AK-CAZ-SC (5) 16,435.09 87.78 195.14 6,442.30 6,283.20 -9,559.62 -2,061.31 5,920,451.30 479,077.31 1.26 9,767.39 MWD+IFR-AK-CAZ-SC (5) 16,532.66 87.40 194.87 6,446.41 6,287.31 -9,653.78 -2,086.55 5,920,357.22 479,051.84 0.48 9,864.88 MWD+IFR-AK-CAZSC (5) 16,627.31 87.36 194.72 6,450.73 6,291.63 -9,745.20 -2,110.70 5,920,265.87 479,027.47 0.16 9,959.43 MWD+IFR-AK-CAZ-SC (5) 16,722.09 87.63 194.37 6,454.88 6,295.78 -9,836.85 -2,134.48 5,920,174.29 479,003.46 0.47 10,054.11 MWD+IFR-AK-CAZ-SC (5) 16,817.05 89.52 192.84 6,457.24 6,298.14 -9,929.11 -2,156.80 5,920,082.09 478,980.91 2.56 10,149.01 MWD+IFR-AK-CAZ-SC (5) 16,912.69 90.86 192.69 6,456.92 6,297.82 -10,022.39 -2,177.94 5,919,988.88 478,959.54 1.41 10,244.57 MWD+IFR-AK-CAZSC (5) 17,008.25 90.93 192.85 6,455.43 6,296.33 -10,115.57 -2,199.06 5,919,895.76 478,938.19 0.18 10,340.05 MWD+IFR-AK-CAZ-SC (5) 17,102.51 90.72 191.32 6,454.07 6,294.97 -10,207.73 -2,218.79 5,919,803.66 478,918.23 1.64 10,434.18 MWD+IFR-AK-CAZSC (5) 17,197.82 90.99 193.29 6,452.65 6,293.55 -10,300.84 -2,239.10 5,919,710.61 478,897.70 2.09 10,529.37 MWD+IFR-AK-CAZSC (5) 17,292.46 92.79 195.45 6,449.53 6,290.43 -10,392.46 -2,262.57 5,919,619.06 478,874.00 2.97 10,623.94 MWD+IFR-AK-CAZSC (5) 17,386.12 94.34 191.64 6,443.70 6,284.60 -10,483.32 -2,284.46 5,919,528.26 478,851.88 4.38 10,717.37 MWD+IFR-AK-CAZ-SC (5) 17,476.93 94.43 192.68 6,436.76 6,277.66 -10,571.83 -2,303.53 5,919,439.81 478,832.59 1.15 10,807.80 MWD+IFR-AK-CAZ-SC (5) 17,569.03 94.60 192.39 6,429.51 6,270.41 -10,661.45 -2,323.46 5,919,350.24 478,812.44 0.36 10,899.53 MWD+IFR-AK-CAZ-SC (5) 17,661.49 94.57 191.97 6,422.12 6,263.02 -10,751.54 -2,342.90 5,919,260.21 478,792.77 0.45 10,991.58 MWD+IFR-AK-CAZ-SC (5) 17,752.49 94.47 192.22 6,414.95 6,255.85 -10,840.24 -2,361.91 5,919,171.57 478,773.55 0.30 11,082.18 MWD+IFR-AK-CAZSC (5) 17,842.86 93.50 192.40 6,408.67 6,249.57 -10,928.32 -2,381.13 5,919,083.54 478,754.11 1.09 11,172.23 MWD+IFR-AK-CAZSC (5) 17,933.76 93.57 194.45 6,403.06 6,243.96 -11,016.57 -2,402.20 5,918,995.36 478,732.83 2.25 11,262.92 MWD+IFR-AK-CAZ-SC (5) 17,998.00 93.57 194.45 6,399.06 6,239.96 -11,078.65 -2,418.19 5,918,933.32 478,716.67 0.00 11,327.03 PROJECTED to TD 9 wNs 11:07'2" Pie 7 COAMW WW I Bod 74 Cement Detail Report 41 2S-06 String: Conductor Cement Job: DRILLING ORIGINAL, 8/18/2016 00:00 Cement Details Description Conductor Cement Cementing Start Date 12/15/2014 09:50 Cementing End Date 12/15/2014 15:40 Wellbore Name 2S-06 Comment Peak drilled 98" hole to 6' deep, then drilled 42" hole to 82' below ground level. Set 16" 62.58# APISL Grade B Insulated Conductor at 80'. SLB cemented in two stages with 15.7ppg Arctic Set 1 cement, total 60.3 bbls pumped. Sealed Pan Cellar is 5' deep, 6' wide. Cement Stages Stage # 1 Description Conductor Cement Objective Top Depth (ftKB) Bottom Depth (ftKB) Tack conductor in place 97.0 120.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No I Stroke (ft) I Rotated? No I Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 66 x sacks of Arctic Set 1 Cement slurry at 15.7ppg, 71'F slurry temp, -12°F ambient temp, 71 °F water temp. Cement in place @ 11:50 hrs. Pumped 10.8 bbls Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Stage # 2 Description Conductor Cement Objective Cement to surface Top Depth (ftKB) 40.0 Bottom Depth (ftKB) 97.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 299 x sacks of Arctic Set 1 Cement slurry at 15.7ppg, 70°F slurry temp, -12°F ambient temp, 68°F water temp. Cement in place at 15:40 hrs. Pumped 49.5 bbls. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft' /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 1/1 Report Printed: 10/5/2016 Cement Detail Report 2S-06 String: Surface Casing Cement Job: DRILLING ORIGINAL, 8/18/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 8/21/2016 22:25 8/21/2016 23:37 2S-06 Comment Flood lines with H2O & test to 3500 psi. Pump 20 bbls CW-100 at 5.8 bpm, 105 psi. Pump 75.5 bbls 10.5 ppg MPII w/red dye at 3.5-4 bpm, 100 psi. Shut down and drop bottom Davis Lynch anti-rotation plug. Pumped 340 bbls 11 ppg LiteCRETE lead cement at 6.8 bpm, 190 psi. Reciprocate pipe 10' with full returns. Pumped 54.6 bbls 15.8 ppg Class G tail cement at 5 bpm, 300 psi. Observe MPII spacer at surface 52 bbls into tail cement pumped. Drop Davis Lynch anti- rotation top plug. Kicked top plug out with 10 bbls of H2O. Swapped to rig pumps and displaced cement with 10.0 ppg spud mud @ 4-6 bpm / 170 psi increasing to 620 psi, Observed lead cement at surface 85 bbls into displacement. Slow rate to 3bpm at 10 bbls prior to calculated displacement. Bumped plug @ 2263 strokes, FCP = 620 psi. Pressured up to 1150 psi and held for 5 min then bled off and checked floats - floats held. CIP @ 00:40 hrs 8-22-16. 143 bbls of lead cement returned to surface. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement I 1 42.1 2,667.0 No Yes Yes Q Pump Init (bbl/m...Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) m P Plug Bup (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 6 6 620.0 620.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 42.1 2,167.0 I 959 LiteCRETE 340.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal)Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) 1.99 6.99 11.00 68.4 I 5.50 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D185 0.02 gal/sx Additive Type Concentration Conc Unit label Acelerator (Calcium Chloride) D186 0.2 gal/sx Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,167.0 2,667.0 264 G 54.6 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa-s) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.09 15.80 151.8 3.95 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.35 %BWOC Page 1/1 Report Printed: 10/5/2016 Cement Detail Report 2S-06 String: Intermediate Job: DRILLING ORIGINAL, 8/18/2016 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 8/28/201610:45 8/28/201616:45 2S-06 Comment Cement 7-5/8" casing as per SLB cementing program. Pump 5 bbls of H2O, test trips & PT lines to 4000 psi, good. Pump 42.9 bbls of 12.5 ppg MPII at 2.3 bpm, 250 psi. Drop bottom plug. Pump 152.5 bbls of 15.8 ppg Sharks Tooth slurry at 5.2 bpm, 215 psi. Drop top plug & pump 10 bbls of H2O at 2.2 bpm, 20 psi. Swap to rig & displace with 10.3 ppg LSND at 7 bpm, 150 psi, FO 10%, Slow rate to 4.5 bpm, 650 psi, FCP 720 psi @ 3 bpm. Bump plug at 3280 strokes. Check floats, good. CIP @ 13:52 hrs. Total Losses for first stage 8 bbls. Pump second stage cement as per SLB cementing program. Pump 52.6 bbls of 12.5 ppg Sharks Tooth slurry at 4.5 bpm, 190 psi. Drop closing plug. Pump 10 bbls of H2O at 2 bpm, 20 psi. Swap to rig & displace with 10.3 ppg LSND at 5 bpm, 440 psi, FO 7%. Slow pump rate as losses were observed to 2 bpm, 400 psi. Loose returns at -1800 strokes( cement at stage tool), slow pump to 1 bpm, 420 psi, FO 0%. Bump plug at 2207 strokes, pressuring up to 1700 psi to shift stage collar closed. Observed closing at 1300 psi. Hold for 5 minutes, bleed off, & check for flow. Tool closed. CIP @ 16:28 hrs. Total Losses for second stage 41.7 bbls. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Cement to top of CAIRN 5,874.0 7,630.0 No Yes Yes @ 5874' Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 4 6 232.0 787.0 Yes 10.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 7,457.0 Drill Bit 7,630.0 63/4 Comment Cement 7-5/8" casing as per SLB cementing program. Pump 5 bbls of H2O, test trips & PT lines to 4000 psi, good. Pump 42.9 bbls of 12.5 ppg MPII at 2.3 bpm, 250 psi. Drop bottom plug. Pump 152.5 bbls of 15.8 ppg Sharks Tooth slurry at 5.2 bpm, 215 psi. Drop top plug & pump 10 bbls of H2O at 2.2 bpm, 20 psi. Swap to rig & displace with 10.3 ppg LSND at 7 bpm, 150 psi, FO 10%, Slow rate to 4.5 bpm, 650 psi, FCP 720 psi @ 3 bpm. Bump plug at 3280 strokes. Check floats, good. CIP @ 13:52 hrs. Total Losses for first stage 8 bbls. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 5,405.0 5,874.0 42.9 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Shark Tooth Blend 5,874.0 7,630.0 703 G 152.5 Cement Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.16 15.80 Additives Additive Type Concentration Cone Unit label D046 Antifoam 0.15 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.6 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.8 %BWOC Additive Type Concentration Cone Unit label D177 Retarder 1 0.01 gal/sx Stage # 2 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate 4,510.0 5,090.2 No No No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 3 4 5 454.0 381.0 No I No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 5,035.0 Drill Bit 5,094.0 63/4 Comment Pump second stage cement as per SLB cementing progam. Pump 52.6 bbls of 12.5 ppg Sharks Tooth slurry at 4.5 bpm, 190 psi. Drop closing plug. Pump 10 bbls of H2O at 2 bpm, 20 psi. Swap to rig & displace with 10.3 ppg LSND at 5 bpm, 440 psi, FO 7%. Slow pump rate as losses were observed to 2 bpm, 400 psi. Loose returns at -1800 strokes( cement at stage tool), slow pump to 1 bpm, 420 psi, FO 0%. Bump plug at 2207 strokes, pressuring up to 1700 psi to shift stage collar closed. Obsereved closing at 1300 psi. Hold for 5 minutes, bleed off, & check for flow. Tool closed. CIP @ 16:28 hrs. Total Losses for second stage 41.7 bbls. Page 1/2 Report Printed: 10/5/2016 Cement Detail Report 2S-06 String: Intermediate Job: DRILLING ORIGINAL, 8/18/2016 00:00 Cement Fluids & Additives Fluid Fluid Type Mud Push Fluid Description Estimated Top (ftKB) 4,032.0 Est Stm (ftKB) 4,500.0 Amount (sacks) Class Volume Pumped (bbl) 42.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) 12.50 Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Additive Type Concentration Cone Unit label Additive Type Concentration Cone Unit label Fluid Fluid Type Shark Tooth Blend Cement Fluid Description Estimated Top (ftKB) 4,510.0 Est Btm (ftKB) 5,090.2 Amount (sacks) 256 Class Volume G Pumped (bbl) 52.6 Yield (ft'/sack) 1.16 Mix H2O Ratio (gal/sa... 5.06 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 3.66 1 (psi) Additives Additive D046 Type Antifoam Concentration 0.15 Cone Unit label %BWOC Additive D065 Type Dispersant Concentration 0.6 Cone Unit label %BWOC Additive D167 Type Fluid Loss Concentration 0.8 Cone Unit label %BWOC Page 212 Report Printed: 10/5/2016 Schlumbugep Drilling & Measurements MWD/LWD Log Product Delivery Customer: ConocoPhillips Alaska Dispatched To: Well No: 2S-06 Date Dispatched: Job#: 16AKA0111 Dispatched By: 21 6085 27 585 Transmittal #: 23SEP16-SP02 DATA LOGGED 9 ZG/20IG M. K. BENDER AOGCC: Makana Bender 23 -Sep -16 Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E -Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2" TVD x x VISION*Service 5" MD x x VISION*Service 5" TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As -Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: pdf/tiff x Surveys: pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(o)conocophillips.com Alaska PTS PrintCenter anslb.com Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 Received By: tyu�i 2 16085 27 585 RECEIVED FINAL NADConversion Kuparuk River Unit Kuparuk 2S Pad 2S-06 SEP 232016 AOGCC Definitive Survey Report 20 September, 2016 NAD 27 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKE DM P2 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 2S-06 Well Position +N/ -S 0.00 usft Northing: 5,930,004.80 usft Latitude: 70° 13' 11.746 N +E/ -W 0.00 usft Easting: 481,162.27 usft Longitude: 150° 9'7.098 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) C) (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 2S-06 Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,009.85 2S-06 Srvy 1 - SLB_GWD70 (2S-06) (usft) (usft) (usft) (1) 1,069.89 39.10 0.00 0.00 195.00 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.32 1,009.85 2S-06 Srvy 1 - SLB_GWD70 (2S-06) GYD-GC-SS Gyrodata gyro single shots 8/19/2016 8:31: 1,069.89 2,583.95 2S-06 Srvy 2 - SLB_MWD+GMAG (2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/19/2016 8:36: 2,616.38 2,616.38 25-06 Srvy 3 - SLB_INC-Filler (2S-06) INC+TREND Inclinometer + known azi trend 8/23/2016 12:07 2,706.90 7,560.16 2S-06 Srvy 4 - SLB_MWD+GMAG (2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/23/2016 12:09 7,659.93 17,933.76 2S-06 Srvy 5 - SLB_MWD+GMAG (2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/31/2016 9:45: Survey 9/20/2016 1:07:24PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) C) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5,930,004.80 481,162.27 0.00 0.00 UNDEFINED 100.32 0.19 343.22 100.32 -58.78 0.10 -0.03 5,930,004.90 481,162.24 0.31 -0.09 GYD-GC-SS (1) 161.19 0.28 47.50 161.19 2.09 0.29 0.05 5,930,005.10 481,162.32 0.43 -0.30 GYD-GC-SS (1) 257.39 0.28 349.16 257.39 98.29 0.68 0.18 5,930.005.49 481,162.45 0.28 -0.71 GYD-GC-SS (1) 356.17 1.32 5.68 356.16 197.06 2.05 0.25 5.930,006.85 481,162.52 1.07 -2.05 GYD-GC-SS (1) 448.44 3.10 1.21 448.36 289.26 5.61 0.41 5,930,010.41 481,162.69 1.94 -5.52 GYD-GC-SS(1) 539.12 4.03 4.40 538.86 379.76 11.23 0.70 5,930,016.03 481,163.00 1.05 -11.03 GYD-GC-SS (1) 631.94 4.15 3.74 631.44 472.34 17.84 1.17 5,930,022.63 481,163.49 0.14 -17.53 GYD-GC-SS(1) 725.12 6.56 4.25 724.21 565.11 26.51 1.79 5,930,031.31 481,164.12 2.59 -26.07 GYD-GC-SS (1) 820.98 7,86 0.26 819.31 660.21 38.53 2.22 5,930,043.32 481,164.59 1.45 -37.79 GYD-GC-SS(1) 9/20/2016 1:07:24PM Page 2 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 915.97 9.77 359.98 913.17 754.07 53.08 2.25 5,930,057.87 481,164.65 2.01 -51.86 GYD-GC-SS(1) 1,009.85 11.04 0.30 1,005.51 846.41 70.04 2.29 5,930,074.83 481,164.74 1.35 -68.24 GYD-GC-SS (1) 1,069.89 12.12 357.28 1,064.33 905.23 82.08 2.02 5,930,086.87 481,164.50 2.06 -79.81 MWD+IFR-AK-CAZ-SC (2) 1,164.35 15.48 357.78 1,156.05 996.95 104.59 1.06 5,930,109.38 481,163.59 3.56 -101.30 MWD+IFR-AK-CAZ-SC (2) 1,259.97 17.70 357.04 1,247.68 1,088.58 131.86 -0.18 5,930,136.65 481,162.42 2.33 -127.32 MWD+IFR-AK-CAZ-SC (2) 1,354.34 22.39 358.48 1,336.31 1,177.21 164.17 -1.40 5,930,168.96 481,161.28 5.00 -158.22 MWD+IFR-AK-CAZ-SC (2) 1,449.30 22.33 358.93 1,424.13 1,265.03 200.29 -2.22 5,930,205.08 481,160.55 0.19 -192.89 MWD+IFR-AK-CAZ-SC (2) 1,543.75 21.70 6.01 1,511.71 1,352.61 235.60 -0.72 5,930,240.38 481,162.14 2.89 -227.39 MWD+IFR-AK-CAZ-SC (2) 1,639.06 20.62 12.61 1,600.60 1,441.50 269.51 4.79 5,930,274.27 481,167.73 2.74 -261.56 MWD+IFR-AK-CAZ-SC (2) 1,734.09 20.28 21.23 1,689.66 1,530.56 301.20 14.41 5,930,305.93 481,177.43 3.19 -294.66 MWD+IFR-AK-CAZ-SC (2) 1,828.64 20.70 29.92 1,778.25 1,619.15 330.96 28.68 5,930,335.66 481,191.77 3.24 -327.11 MWD+IFR-AK-CAZ-SC (2) 1,923.75 21.30 30.53 1,867.05 1,707.95 360.41 45.84 5,930,365.06 481,209.00 0.67 -359.99 MWD+IFR-AK-CAZ-SC (2) 2,019.13 21.52 30.73 1,955.84 1,796.74 390.37 63.58 5,930,394.97 481,226.82 0.24 -393.52 MWD+IFR-AK-CAZ-SC (2) 2,113.70 21.72 30.68 2,043.76 1,884.66 420.33 81.37 5,930,424.88 481,244.68 0.21 -427.07 MWD+IFR-AK-CAZ-SC (2) 2,208.31 21.57 30.95 2,131.70 1,972.60 450.30 99.25 5,930,454.81 481,262.63 0.19 -460.64 MWD+IFR-AK-CAZ-SC (2) 2,303.63 21.24 31.39 2,220.44 2,061.34 480.06 117.25 5,930,484.53 481,280.71 0.39 -494.05 MWD+IFR-AK-CAZ-SC (2) 2,398.00 21.07 31.06 2,308.45 2,149.35 509.19 134.91 5,930,513.60 481,298.43 0.22 -526.75 MWD+IFR-AK-CAZ-SC (2) 2,492.84 20.74 31.71 2,397.05 2,237.95 538.08 152.53 5,930,542.44 481,316.13 0.43 -559.22 MWD+IFR-AK-CAZ-SC (2) 2,583.95 20.48 30.41 2,482.33 2,323.23 565.55 169.08 5,930,569.87 481,332.74 0.58 -590.04 MWD+IFR-AK-CAZ-SC (2) 2,616.38 20.94 28.37 2,512.66 2,353.56 575.54 174.70 5,930,579.85 481,338.39 2.64 -601.15 INC+TREND (3) 2,657.00 21.66 27.42 2,550.51 2,391.41 588.58 181.60 5,930,592.87 481,345.32 1.98 -615.53 NOT an Actual Survsy 10 3/4" x 13-1/2" 2,706.90 22.56 26.33 2,596.74 2,437.64 605.34 190.09 5,930,609.60 481,353.85 1.98 -633.91 MWD+IFR-AK-CAZ-SC (4) 2,802.11 21.33 26.32 2,685.05 2,525.95 637.23 205.87 5,930,641.45 481,369.71 1.29 -668.80 MWD+IFR-AK-CAZ-SC (4) 2,897.25 21.41 26.24 2,773.65 2,614.55 668.31 221.22 5,930,672.49 481,385.13 0.09 -702.80 MWD+IFR-AK-CAZ-SC (4) 2,993.26 21.37 25.31 2,863.04 2,703.94 699.84 236.45 5,930,703.98 481,400.44 0.36 -737.19 MWD+IFR-AK-CAZ-SC (4) 3,088.38 21.41 28.17 2,951.62 2,792.52 730.82 252.05 5,930,734.92 481,416.12 1.10 -771.15 MWD+IFR-AK-CAZ-SC (4) 3,181.81 21.48 30.50 3,038.58 2,879.48 760.59 268.78 5,930,764.64 481,432.92 0.91 -804.24 MWD+IFR-AK-CAZ-SC (4) 3,276.28 21.33 32.60 3,126.53 2,967.43 789.97 286.82 5,930,793.97 481,451.03 0.83 -837.28 MWD+IFR-AK-CAZ-SC (4) 3,371.37 21.36 31.82 3,215.10 3,056.00 819.25 305.27 5,930,823.21 481,469.55 0.30 -870.34 MWD+IFR-AK-CAZ-SC (4) 3,465.85 21.25 31.30 3,303.12 3,144.02 848.50 323.23 5,930,852.41 481,487.59 0.23 -903.25 MWD+IFR-AK-CAZ-SC (4) 3,561.35 18.21 29.24 3,393.01 3,233.91 876.32 339.52 5,930,880.18 481,503.94 3.27 -934.33 MWD+IFR-AK-CAZ-SC (4) 3,655.34 15.98 29.72 3,482.84 3,323.74 900.37 353.11 5,930,904.20 481,517.59 2.38 -961.08 MWD+IFR-AK-CAZ-SC (4) 3,750.54 14.03 31.67 3,574.79 3,415.69 921.57 365.66 5,930,925.37 481,530.20 2.12 -984.81 MWD+IFR-AK-CAZ-SC (4) 3,845.52 12.17 35.54 3,667.30 3,508.20 939.52 377.53 5,930,943.28 481,542.11 2.16 -1,005.22 MWD+IFR-AK-CAZ-SC (4) 3,940.31 10.68 40.03 3,760.21 3,601.11 954.38 388.99 5,930,958.11 481,553.60 1.83 -1,022.54 MWD+IFR-AK-CAZ-SC (4) 4,035.52 8.89 49.14 3,854.03 3,694.93 965.95 400.23 5,930,969.65 481,564.87 2.48 -1,036.62 MWD+IFR-AK-CAZ-SC (4) 4,130.41 7.52 65.73 3,947.96 3,788.86 973.30 411.44 5,930,976.97 481,576.09 2.87 -1,046.62 MWD+IFR-AK-CAZ-SC (4) 4,224.72 6.54 86.87 4,041.58 3,882.48 976.13 422.43 5,930,979.78 481,587.09 2.91 -1,052.20 MWD+IFR-AK-CAZ-SC (4) 4,318.81 6.05 110.03 4,135.12 3,976.02 974.72 432.44 5,930,978.35 481,597.09 2.73 -1,053.43 MWD+IFR-AK-CAZ-SC (4) 4,414.63 5.80 131.61 4,230.44 4,071.34 969.78 440.80 5,930,973.38 481,605.45 2.33 -1,050.82 MWD+IFR-AK-CAZ-SC (4) 9/20/2016 1:07:24PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 25-06 Project: Kuparuk River Unit TVD Reference: 25-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 25-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,509.52 6.70 145.00 4,324.77 4,165.67 962.06 447.56 5,930,965.64 481,612.19 1.80 -1,045.11 MWD+IFR-AK-CAZ-SC (4) 4,602.96 8.28 154.35 4,417.41 4,258.31 951.53 453.60 5,930,955.10 481,618.20 2.13 -1,036.51 MWD+IFR-AK-CAZ-SC (4) 4,698.31 10.35 159.47 4,511.50 4,352.40 937.31 459.58 5,930,940.87 481,624.14 2.34 -1,024.32 MWD+IFR-AK-CAZ-SC (4) 4,795.38 12.33 163.82 4,606.67 4,447.57 919.19 465.52 5,930,922.74 481,630.04 2.22 -1,008.36 MWD+IFR-AK-CAZ-SC (4) 4,891.21 15.18 171.56 4,699.75 4,540.65 896.95 470.22 5,930,900.49 481,634.68 3.53 -988.09 MWD+IFR-AK-CAZ-SC (4) 4,983.13 18.66 182.89 4,787.70 4,628.60 870.34 471.24 5,930,873.88 481,635.64 5.20 -962.65 MWD+IFR-AK-CAZ-SC (4) 5,077.82 21.35 186.13 4,876.67 4,717.57 838.07 468.64 5,930,841.62 481,632.95 3.07 -930.81 MWD+IFR-AK-CAZ-SC (4) 5,172.97 23.11 186.29 4,964.75 4,805.65 802.28 464.74 5,930,805.84 481,628.97 1.85 -895.23 MWD+IFR-AK-CAZ-SC (4) 5,267.99 25.18 184.68 5,051.45 4,892.35 763.60 461.05 5,930,767.17 481,625.18 2.29 -856.91 MWD+IFR-AK-CAZ-SC (4) 5,362.20 27.85 182.73 5,135.75 4,976.65 721.63 458.37 5,930,725.22 481,622.39 2.98 -815.68 MWD+IFR-AK-CAZ-SC (4) 5,456.29 30.15 181.68 5,218.03 5,058.93 676.06 456.63 5,930,679.65 481,620.54 2.50 -771.20 MWD+IFR-AK-CAZ-SC (4) 5,551.84 32.57 182.46 5,299.62 5,140.52 626.37 454.82 5,930,629.97 481,618.61 2.57 -722.74 MWD+IFR-AK-CAZ-SC (4) 5,646.69 34.35 183.61 5,378.75 5,219.65 574.15 452.04 5,930,577.77 481,615.70 1.99 -671.58 MWD+IFR-AK-CAZ-SC (4) 5,742.29 36.67 185.54 5,456.57 5,297.47 518.81 447.58 5,930,522.44 481,611.10 2.69 -616.98 MWD+IFR-AK-CAZ-SC (4) 5,836.35 39.20 186.16 5,530.75 5,371.65 461.29 441.68 5,930,464.95 481,605.06 2.72 -559.89 MWD+IFR-AK-CAZ-SC (4) 5,931.08 41.51 185.02 5,602.93 5,443.83 400.25 435.72 5,930,403.92 481,598.95 2.56 -499.38 MWD+IFR-AK-CAZ-SC (4) 6,026.45 45.01 185.20 5,672.37 5,513.27 335.16 429.90 5,930,338.86 481,592.96 3.67 -435.01 MWD+IFR-AK-CAZ-SC (4) 6,120.04 45.88 186.91 5,738.04 5,578.94 268.85 422.86 5,930,272.57 481,585.75 1.60 -369.13 MWD+IFR-AK-CAZ-SC (4) 6,215.81 47.85 189.14 5,803.52 5,644.42 199.66 413.08 5,930,203.41 481,575.81 2.67 -299.77 MWD+IFR-AK-CAZ-SC (4) 6,310.93 50.59 190.26 5,865.64 5,706.54 128.68 400.93 5,930,132.46 481,563.48 3.02 -228.06 MWD+IFR-AK-CAZ-SC (4) 6,405.93 52.94 191.11 5,924.43 5,765.33 55.36 387.09 5,930,059.19 481,549.46 2.57 -153.66 MWD+IFR-AK-CAZ-SC (4) 6,500.66 55.78 190.33 5,979.63 5,820.53 -20.28 372.78 5,929,983.60 481,534.96 3.07 -76.89 MWD+IFR-AK-CAZ-SC (4) 6,595.44 58.80 190.78 6,030.84 5,871.74 -98.67 358.17 5,929,905.25 481,520.15 3.21 2.61 MWD+IFR-AK-CAZ-SC (4) 6,690.21 60.69 191.24 6,078.59 5,919.49 -179.02 342.53 5,929,824.95 481,504.32 2.04 84.27 MWD+IFR-AK-CAZ-SC (4) 6,785.50 62.79 191.62 6,123.70 5,964.60 -261.28 325.90 5,929,742.73 481,487.48 2.23 168.03 MWD+IFR-AK-CAZ-SC (4) 6,879.60 65.85 192.52 6,164.47 6,005.37 -344.20 308.16 5,929,659.87 481,469.54 3.36 252.71 MWD+IFR-AK-CAZ-SC (4) 6,974.39 68.87 193.50 6,200.96 6,041.86 -429.43 288.46 5,929,574.70 481,449.63 3.33 340.14 MWD+IFR-AK-CAZ-SC (4) 7,072.08 70.63 194.04 6,234.77 6,075.67 -518.44 266.64 5,929,485.75 481,427.59 1.87 431.76 MWD+IFR-AK-CAZ-SC (4) 7,165.22 72.78 194.69 6,264.01 6,104.91 -604.10 244.70 5,929,400.15 481,405.44 2.40 520.18 MWD+IFR-AK-CAZ-SC (4) 7,260.57 74.67 195.07 6,290.73 6,131.63 -692.55 221.19 5,929,311.77 481,381.71 2.02 611.71 MWD+IFR-AK-CAZ-SC (4) 7,355.40 77.20 194.53 6,313.77 6,154.67 -781.48 197.70 5,929,222.91 481,358.00 2.72 703.69 MWD+IFR-AK-CAZ-SC (4) 7,450.21 79.86 194.98 6,332.62 6,173.52 -871.33 174.04 5,929,133.13 481,334.11 2.84 796.59 MWD+IFR-AK-CAZ-SC (4) 7,544.25 81.63 195.83 6,347.75 6,188.65 -960.80 149.38 5,929,043.72 481,309.24 2.08 889.40 MWD+IFR-AK-CAZ-SC (4) 7,560.16 81.91 194.66 6,350.02 6,190.92 -975.99 145.24 5,929,028.55 481,305.06 7.49 905.15 MWD+IFR-AK-CAZ-SC (4) 7,620.00 84.07 194.52 6,357.33 6,198.23 -1,033.47 130.28 5,928,971.11 481,289.96 3.62 964.54 NOTanActual Suney 7-5/8" x 9-7/8 by 11 7,659.93 85.51 194.42 6,360.95 6,201.85 -1,071.97 120.35 5,928,932.64 481,279.93 3.62 1,004.30 MWD+IFR-AK-CAZ-SC (5) 7,720.54 86.78 193.65 6,365.03 6,205.93 -1,130.64 105.68 5,928,874.02 481,265.12 2.45 1,064.76 MWD+IFR-AK-CAZ-SC (5) 7,814.02 87.59 193.09 6,369.62 6,210.52 -1,221.47 84.09 5,928,783.24 481,243.31 1.05 1,158.09 MWD+IFR-AK-CAZ-SC (5) 7,908.65 85.65 191.90 6,375.20 6,216.10 -1,313.70 63.66 5,928,691.08 481,222.64 2.40 1,252.46 MWD+IFR-AK-CAZ-SC (5) 9/20/2016 1:0724PM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 25-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,003.37 88.05 193.10 6,380.40 6,221.30 -1,406.02 43.19 5,928,598.82 481,201.94 2.83 1,346.94 MWD+IFR-AK-CAZ-SC (5) 8,099.44 90.83 192.15 6,381.34 6,222.24 -1,499.75 22.19 5,928,505.15 481,180.72 3.06 1,442.91 MWD+IFR-AK-CAZ-SC (5) 8,192.83 92.63 192.76 6,378.52 6,219.42 -1,590.90 2.06 5,928,414.06 481,160.36 2.03 1,536.16 MWD+IFR-AK-CAZ-SC (5) 8,288.33 91.51 193.66 6,375.07 6,215.97 -1,683.81 -19.75 5,928,321.21 481,138.32 1.50 1,631.55 MWD+IFR-AK-CAZ-SC (5) 8,383.03 90.79 193.19 6,373.17 6,214.07 -1,775.90 41.73 5,928,229.19 481,116.11 0.91 1,726.19 MWD+IFR-AK-CAZ-SC (5) 8,477.83 91.19 194.21 6,371.53 6,212.43 -1,867.99 -64.18 5,928,137.16 481,093.44 1.16 1,820.95 MWD+IFR-AK-CAZ-SC (5) 8,572.36 87.79 194.99 6,372.38 6,213.28 -1,959.45 -88.00 5,928,045.77 481,069.39 3.69 1,915.46 MWD+IFR-AK-CAZ-SC (5) 8,667.34 87.16 195.52 6,376.56 6,217.46 -2,050.99 -112.97 5,927,954.30 481,044.19 0.87 2,010.35 MWD+IFR-AK-CAZ-SC (5) 8,762.25 86.92 195.94 6,381.46 6,222.36 -2,142.23 -138.66 5,927,863.14 481,018.27 0.51 2,105.12 MWD+IFR-AK-CAZ-SC (5) 8,857.34 87.64 198.27 6,385.97 6,226.87 -2,233.00 -166.60 5,927,772.44 480,990.11 2.56 2,200.03 MWD+IFR-AK-CAZ-SC (5) 8,951.68 87.94 196.32 6,389.61 6,230.51 -2,323.01 -194.62 5,927,682.52 480,961.87 2.09 2,294.22 MWD+IFR-AK-CAZ-SC (5) 9,046.32 89.63 196.28 6,391.62 6,232.52 -2,413.82 -221.18 5,927,591.78 480,935.09 1.79 2,388.81 MWD+IFR-AK-CAZ-SC (5) 9,140.92 91.07 195.77 6,391.04 6,231.94 -2,504.74 -247.29 5,927,500.94 480,908.75 1.61 2,483.40 MWD+IFR-AK-CAZ-SC (5) 9,236.56 91.82 196.40 6,388.63 6,229.53 -2,596.60 -273.78 5,927,409.15 480,882.04 1.02 2,578.99 MWD+IFR-AK-CAZ-SC (5) 9,330.87 92.92 193.85 6,384.73 6,225.63 -2,687.56 -298.37 5,927,318.26 480,857.23 2.94 2,673.21 MWD+IFR-AK-CAZ-SC (5) 9,425.67 92.95 193.14 6,379.87 6,220.77 -2,779.62 -320.46 5,927,226.27 480,834.90 0.75 2,767.85 MWD+IFR-AK-CAZ-SC (5) 9,520.28 91.99 191.61 6,375.80 6,216.70 -2,871.94 -340.72 5,927,134.00 480,814.42 1.91 2,862.27 MWD+IFR-AK-CAZ-SC (5) 9,614.77 91.58 191.76 6,372.85 6,213.75 -2,964.43 -359.84 5,927,041.58 480,795.06 0.46 2,956.55 MWD+IFR-AK-CAZ-SC (5) 9,710.02 91.55 191.65 6,370.25 6,211.15 -3,057.66 -379.16 5,926,948.40 480,775.52 0.12 3,051.61 MWD+IFR-AK-CAZ-SC (5) 9,804.02 91.99 191.76 6,367.35 6,208.25 -3,149.66 -398.22 5,926,856.45 480,756.23 0.48 3,145.41 MWD+IFR-AK-CAZ-SC (5) 9,898.90 91.48 191.29 6,364.48 6,205.38 -3,242.59 417.17 5,926,763.59 480,737.05 0.73 3,240.07 MWD+IFR-AK-CAZ-SC (5) 9,993.23 91.48 190.95 6,362.04 6,202.94 -3,335.12 -435.36 5,926,671.11 480,718.63 0.36 3,334.15 MWD+IFR-AK-CAZ-SC (5) 10,088.12 91.24 191.75 6,359.79 6,200.69 -3,428.12 -454.03 5,926,578.16 480,699.74 0.88 3,428.82 MWD+IFR-AK-CAZ-SC (5) 10,182.57 89.40 191.14 6,359.26 6,200.16 -3,520.69 -472.77 5,926,485.65 480,680.77 2.05 3,523.09 MWD+IFR-AK-CAZ-SC (5) 10,277.60 90.04 192.21 6,359.72 6,200.62 -3,613.75 -492.00 5,926,392.65 480,661.31 1.31 3,617.95 MWD+IFR-AK-CAZ-SC (5) 10,371.79 90.79 193.57 6,359.04 6,199.94 -3,705.56 -513.01 5,926,300.90 480,640.07 1.65 3,712.07 MWD+IFR-AK-CAZ-SC (5) 10,467.10 89.76 194.59 6,358.58 6,199.48 -3,798.01 -536.19 5,926,208.53 480,616.65 1.52 3,807.37 MWD+IFR-AK-CAZ-SC (5) 10,560.70 88.72 193.84 6,359.83 6,200.73 -3,888.73 -559.17 5,926,117.87 480,593.45 1.37 3,900.95 MWD+IFR-AK-CAZ-SC (5) 10,656.41 89.63 194.87 6,361.20 6,202.10 -3,981.44 -582.90 5,926,025.23 480,569.49 1.44 3,996.64 MWD+IFR-AK-CAZ-SC (5) 10,750.53 89.52 195.47 6,361.90 6,202.80 -4,072.28 -607.53 5,925,934.46 480,544.64 0.65 4,090.76 MWD+IFR-AK-CAZ-SC (5) 10,845.40 89.63 195.88 6,362.61 6,203.51 -4,163.62 -633.16 5,925,843.19 480,518.78 0.45 4,185.62 MWD+IFR-AK-CAZ-SC (5) 10,939.33 90.38 196.07 6,362.60 6,203.50 -4,253.92 -659.01 5,925,752.97 480,492.71 0.82 4,279.53 MWD+IFR-AK-CAZ-SC (5) 11,034.67 90.38 196.52 6,361.97 6,202.87 -4,345.43 -685.76 5,925,661.53 480,465.73 0.47 4,374.85 MWD+IFR-AK-CAZ-SC (5) 11,128.07 89.11 197.53 6,362.38 6,203.28 -4,434.73 -713.11 5,925,572.31 480,438.17 1.74 4,468.18 MWD+IFR-AK-CAZ-SC (5) 11,223.12 88.19 197.31 6,364.62 6,205.52 -4,525.39 -741.55 5,925,481.72 480,409.50 1.00 4,563.12 MWD+IFR-AK-CAZ-SC (5) 11,318.26 87.04 198.01 6,368.58 6,209.48 -4,615.97 -770.39 5,925,391.23 480,380.44 1.41 4,658.08 MWD+IFR-AK-CAZ-SC (5) 11,412.87 87.98 197.49 6,372.69 6,213.59 4,705.99 -799.21 5,925,301.29 480,351.40 1.14 4,752.49 MWD+IFR-AK-CAZ-SC (5) 11,506.96 89.22 197.87 6,374.99 6,215.89 -4,795.61 -827.77 5,925,211.75 480,322.61 1.38 4,846.44 MWD+IFR-AK-CAZ-SC (5) 11,600.80 90.00 196.64 6,375.63 6,216.53 -4,885.22 -855.61 5,925,122.22 480,294.56 1.55 4,940.21 MWD+IFR-AK-CAZ-SC (5) 11,695.98 91.34 195.76 6,374.51 6,215.41 4,976.61 -882.16 5,925,030.91 480,267.78 1.68 5,035.36 MWD+IFR-AK-CAZ-SC (5) 9/20/2016 1:07.24PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,790.89 92.03 194.87 6,371.72 6,212.62 -5,068.11 -907.22 5,924,939.48 480,242.50 1.19 5,130.22 MWD+IFR-AK-CAZ-SC (5) 11,886.13 91.89 194.86 6,368.47 6,209.37 -5,160.11 -931.63 5,924,847.55 480,217.85 0.15 5,225.41 MWD+IFR-AK-CAZ-SC (5) 11,981.33 91.14 195.00 6,365.95 6,206.85 -5,252.06 -956.15 5,924,755.67 480,193.11 0.80 5,320.57 MWD+IFR-AK-CAZ-SC (5) 12,076.19 90.55 194.91 6,364.55 6,205.45 -5,343.70 -980.63 5,924,664.10 480,168.41 0.63 5,415.42 MWD+IFR-AK-CAZ-SC (5) 12,170.11 90.62 194.78 6,363.59 6,204.49 -5,434.48 -1,004.69 5,924,573.39 480,144.12 0.16 5,509.33 MWD+IFR-AK-CAZ-SC (5) 12,264.91 88.84 194.93 6,364.04 6,204.94 -5,526.10 -1,028.99 5,924,481.83 480,119.59 1.88 5,604.13 MWD+IFR-AK-CAZ-SC (5) 12,360.29 86.31 197.84 6,368.07 6,208.97 -5,617.51 -1,055.87 5,924,390.50 480,092.49 4.04 5,699.38 MWD+IFR-AK-CAZ-SC (5) 12,455.37 86.75 197.03 6,373.83 6,214.73 -5,708.06 -1,084.30 5,924,300.04 480,063.83 0.97 5,794.20 MWD+IFR-AK-CAZ-SC (5) 12,549.05 86.61 196.28 6,379.25 6,220.15 -5,797.65 -1,111.11 5,924,210.52 480,036.81 0.81 5,887.68 MWD+IFR-AK-CAZ-SC (5) 12,643.85 86.88 196.76 6,384.64 6,225.54 -5,888.39 -1,138.02 5,924,119.85. 480,009.67 0.58 5,982.29 MWD+IFR-AK-CAZ-SC (5) 12,739.28 87.67 195.70 6,389.17 6,230.07 -5,979.92 -1,164.66 5,924,028.41 479,982.80 1.38 6,077.59 MWD+IFR-AK-CAZ-SC (5) 12,834.87 88.32 195.31 6,392.52 6,233.42 -6,071.97 -1,190.20 5,923,936.43 479,957.04 0.79 6,173.12 MWD+IFR-AK-CAZ-SC (5) 12,929.92 88.52 192.86 6,395.14 6,236.04 -6,164.12 -1,213.32 5,923,844.34 479,933.69 2.59 6,268.11 MWD+IFR-AK-CAZ-SC (5) 13,024.14 90.05 192.49 6,396.32 6,237.22 -6,256.03 -1,233.99 5,923,752.49 479,912.79 1.67 6,362.25 MWD+IFR-AK-CAZ-SC (5) 13,117.94 89.70 192.08 6,396.52 6,237.42 -6,347.69 -1,253.95 5,923,660.90 479,892.61 0.57 6,455.94 MWD+IFR-AK-CAZ-SC (5) 13,212.28 89.90 191.25 6,396.85 6,237.75 -6,440.08 -1,273.02 5,923,568.56 479,873.30 0.90 6,550.12 MWD+IFR-AK-CAZ-SC (5) 13,307.28 90.86 190.77 6,396.22 6,237.12 -6,533.32 -1,291.17 5,923,475.37 479,854.93 1.13 6,644.88 MWD+IFR-AK-CAZ-SC (5) 13,402.84 90.66 190.96 6,394.95 6,235.85 -6,627.16 -1,309.18 5,923,381.59 479,836.69 0.29 6,740.19 MWD+IFR-AK-CAZ-SC (5) 13,497.52 89.72 192.49 6,394.64 6,235.54 -6,719.86 -1,328.42 5,923,288.95 479,817.22 1.90 6,834.71 MWD+IFR-AK-CAZ-SC (5) 13,592.34 90.14 192.19 6,394.75 6,235.65 -6,812.49 -1,348.68 5,923,196.38 479,796.73 0.54 6,929.43 MWD+IFR-AK-CAZ-SC (5) 13,688.98 88.98 191.98 6,395.50 6,236.40 -6,906.99 -1,368.91 5,923,101.94 479,776.26 1.22 7,025.94 MWD+IFR-AK-CAZ-SC (5) 13,782.05 87.28 192.72 6,398.53 6,239.43 -6,997.85 -1,388.81 5,923,011.14 479,756.14 1.99 7,118.85 MWD+IFR-AK-CAZ-SC (5) 13,877.26 86.75 192.82 6,403.49 6,244.39 -7,090.58 -1,409.82 5,922,918.47 479,734.90 0.57 7,213.86 MWD+IFR-AK-CAZ-SC (5) 13,973.14 89.74 193.09 6,406.43 6,247.33 -7,183.96 -1,431.31 5,922,825.15 479,713.18 3.13 7,309.62 MWD+IFR-AK-CAZ-SC (5) 14,067.15 90.59 193.71 6,406.16 6,247.06 -7,275.41 -1,453.09 5,922,733.76 479,691.17 1.12 7,403.60 MWD+IFR-AK-CAZ-SC (5) 14,161.38 89.85 192.83 6,405.79 6,246.69 -7,367.12 -1,474.72 5,922,64Z 12 479,669.31 1.22 7,497.78 MWD+IFR-AK-CAZ-SC (5) 14,257.29 90.69 193.02 6,405.34 6,246.24 -7,460.60 -1,496.17 5,922,548.70 479,647.63 0.90 7,593.63 MWD+IFR-AK-CAZ-SC (5) 14,352.28 91.14 193.36 6,403.83 6,244.73 -7,553.07 -1,517.85 5,922,456.29 479,625.73 0.59 7,688.56 MWD+IFR-AK-CAZ-SC (5) 14,447.26 91.58 193.53 6,401.57 6,242.47 -7,645.42 -1,539.92 5,922,364.01 479,603.42 0.50 7,783.47 MWD+IFR-AK-CAZ-SC (5) 14,541.68 92.85 193.04 6,397.92 6,238.82 -7,737.25 -1,561.60 5,922,272.25 479,581.52 1.44 7,877.78 MWD+IFR-AK-CAZ-SC (5) 14,636.48 92.64 194.98 6,393.38 6,234.28 -7,829.12 -1,584.53 5,922,180.44 479,558.37 2.06 7,972.45 MWD+IFR-AK-CAZ-SC (5) 14,731.94 92.95 193.55 6,388.73 6,229.63 -7,921.52 -1,608.02 5,922,088.11 479,534.64 1.53 8,067.79 MWD+IFR-AK-CAZ-SC (5) 14,826.68 92.61 193.62 6,384.13 6,225.03 -8,013.50 -1,630.25 5,921,996.19 479,512.19 0.37 8,162.39 MWD+IFR-AK-CAZ-SC (5) 14,921.26 91.15 192.70 6,381.03 6,221.93 -8,105.54 -1,651.77 5,921,904.21 479,490.44 1.82 8,256.86 MWD+IFR-AK-CAZ-SC (5) 15,016.01 91.79 194.04 6,378.60 6,219.50 -8,197.69 -1,673.67 5,921,812.13 479,468.31 1.57 8,351.54 MWD+IFR-AK-CAZ-SC (5) 15,110.55 91.96 196.90 6,375.50 6,216.40 -8,288.75 -1,698.87 5,921,721.14 479,442.89 3.03 8,446.02 MWD+IFR-AK-CAZ-SC (5) 15,206.22 92.00 195.97 6,372.20 6,213.10 -8,380.46 -1,725.92 5,921,629.51 479,415.61 0.97 8,541.60 MWD+IFR-AK-CAZ-SC (5) 15,300.84 90.11 195.03 6,370.46 6,211.36 -8,471.61 -1,751.20 5,921,538.43 479,390.11 2.23 8,636.20 MWD+IFR-AK-CAZ-SC (5) 15,375.00 89.27 195.26 6,370.86 6,211.76 -8,543.20 -1,770.58 5,921,466.90 479,370.55 1.17 8,710.35 JN0T8nACWM;q 4 1/2" x 9/20/2016 1:07:24PM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,395.58 89.04 195.33 6,371.16 6,212.06 -8,563.04 -1,776.01 5,921,447.07 479,365.07 1.17 8,730.93 MWD+IFR-AK-CAZ-SC (5) 15,489.89 87.53 195.78 6,373.98 6,214.88 -8,653.86 -1,801.29 5,921,356.33 479,339.57 1.67 8,825.19 MWD+IFR-AK-CAZ-SC (5) 15,585.60 85.06 196.96 6,380.17 6,221.07 -8,745.49 -1,828.20 5,921,264.78 479,312.43 2.86 8,920.66 MWD+IFR-AK-CAZ-SC (5) 15,679.44 82.22 197.26 6,390.56 6,231.46 -8,834.61 -1,855.64 5,921,175.73 479,284.78 3.04 9,013.85 MWD+IFR-AK-CAZ-SC (5) 15,774.24 84.51 196.42 6,401.51 6,242.41 -8,924.73 -1,882.91 5,921,085.69 479,257.28 2.57 9,107.96 MWD+IFR-AK-CAZ-SC (5) 15,868.49 85.51 196.39 6,409.71 6,250.61 -9,014.80 -1,909.43 5,920,995.69 479,230.54 1.06 9,201.83 MWD+IFR-AK-CAZ-SC (5) 15,963.28 86.71 196.18 6,416.14 6,257.04 -9,105.58 -1,935.95 5,920,904.99 479,203.80 1.29 9,296.37 MWD+IFR-AK-CAZ-SC (5) 16,058.46 87.12 196.38 6,421.26 6,262.16 -9,196.81 -1,962.59 5,920,813.84 479,176.93 0.48 9,391.39 MWD+IFR-AK-CAZ-SC (5) 16,153.67 86.47 196.08 6,426.59 6,267.49 -9,288.08 -1,989.16 5,920,722.64 479,150.13 0.75 9,486.43 MWD+IFR-AK-CAZ-SC (5) 16,249.50 86.44 194.57 6,432.51 6,273.41 -9,380.32 -2,014.44 5,920,630.47 479,124.63 1.57 9,582.07 MWD+IFR-AK-CAZ-SC (5) 16,343.48 86.85 194.45 6,438.01 6,278.91 -9,471.15 -2,037.95 5,920,539.71 479,100.90 0.45 9,675.89 MWD+IFR-AK-CAZ-SC (5) 16,435.09 87.78 195.14 6,442.30 6,283.20 -9,559.62 -2,061.31 5,920,451.30 479,077.31 1.26 9,767.39 MWD+IFR-AK-CAZ-SC (5) 16,532.66 87.40 194.87 6,446.41 6,287.31 -9,653.78 -2,086.55 5,920,357.22 479,051.84 0.48 9,864.88 MWD+IFR-AK-CAZ-SC (5) 16,627.31 87.36 194.72 6,450.73 6,291.63 -9,745.20 -2,110.70 5,920,265.87 479,027.47 0.16 9,959.43 MWD+IFR-AK-CAZ-SC (5) 16,722.09 87.63 194.37 6,454.88 6,295.78 -9,836.85 -2,134.48 5,920,174.29 479,003.46 0.47 10,054.11 MWD+IFR-AK-CAZ-SC (5) 16,817.05 89.52 192.84 6,457.24 6,298.14 -9,929.11 -2,156.80 5,920,082.09 478,980.91 2.56 10,149.01 MWD+IFR-AK-CAZ-SC (5) 16,912.69 90.86 192.69 6,456.92 6,297.82 -10,022.39 -2,177.94 5,919,988.88 478,959.54 1.41 10,244.57 MWD+IFR-AK-CAZ-SC (5) 17,008.25 90.93 192.85 6,455.43 6,296.33 -10,115.57 -2,199.06 5,919,895.76 478,938.19 0.18 10,340.05 MWD+IFR-AK-CAZ-SC (5) 17,102.51 90.72 191.32 6,454.07 6,294.97 -10,207.73 -2,218.79 5,919,803.66 478,918.23 1.64 10,434.18 MWD+IFR-AK-CAZ-SC (5) 17,197.82 90.99 193.29 6,452.65 6,293.55 -10,300.84 -2,239.10 5,919,710.61 478,897.70 2.09 10,529.37 MWD+IFR-AK-CAZ-SC (5) 17,292.46 92.79 195.45 6,449.53 6,290.43 -10,392.46 -2,262.57 5,919,619.06 478,874.00 2.97 10,623.94 MWD+IFR-AK-CAZ-SC (5) 17,386.12 94.34 191.64 6,443.70 6,284.60 -10,483.32 -2,284.46 5,919,528.26 478,851.88 4.38 10,717.37 MWD+IFR-AK-CAZ-SC (5) 17,476.93 94.43 192.68 6,436.76 6,277.66 -10,571.83 -2,303.53 5,919,439.81 478,832.59 1.15 10,807.80 MWD+IFR-AK-CAZ-SC (5) 17,569.03 94.60 192.39 6,429.51 6,270.41 -10,661.45 -2,323.46 5,919,350.24 478,812.44 0.36 10,899.53 MWD+IFR-AK-CAZ-SC (5) 17,661.49 94.57 191.97 6,422.12 6,263.02 -10,751.54 -2,342.90 5,919,260.21 478,792.77 0.45 10,991.58 MWD+IFR-AK-CAZ-SC (5) 17,752.49 94.47 192.22 6,414.95 6,255.85 -10,840.24 -2,361.91 5,919,171.57 478,773.55 0.30 11,082.18 MWD+IFR-AK-CAZ-SC (5) 17,842.86 93.50 192.40 6,408.67 6,249.57 -10,928.32 -2,381.13 5,919,083.54 478,754.11 1.09 11,172.23 MWD+IFR-AK-CAZ-SC (5) 17,933.76 93.57 194.45 6,403.06 6,243.96 -11,016.57 -2,402.20 5,918,995.36 478,732.83 2.25 11,262.92 MWD+IFR-AK-CAZ-SC (5) 17,998.00 93.57 194.45 6,399.06 6,239.96 -11,078.65 -2,418.19 5,918,933.32 478,716.67 0.00 11,327.03 PROJECTED to TO 9/20/2016 1:07:24PM Page 7 COMPASS 5000.1 Build 74 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Q Yes ❑ No I have checked to the best of my ability that the following data Is correct., Q Surface Coordinates p Declination & Convergence Q GRS Survey Corrections Vincent ggtallysigned by "nrentO as � Survey Tool Codes °Nai-"ncent0s°�°• o -Schlumberger, ou a5chlumberger, Osara a Mwsa a�slb.mm. r -U5 SLB DE: Dat W16.N20 1314:15-08•oa Client Representative: '(V-,P'T k»xIt) Date: 20 -Sep -2016 21 6085 275'5 FINAL SEP 2 3 2016 -i OGCC, ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad 2S-06 Definitive Survey Report 20 September, 2016 NAD 83 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: 2S-06 Wellbore: 2S-06 Design: 2S-06 Schlumberger Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2S-06 2S-06 actual @ 159.10usft (D142) 2S-06 actual @ 159.10usft (D142) True Minimum Curvature OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2S-06 Date 9/20/2016 Well Position +N/ -S 0.00 usft Northing: 5,929,754.39 usft Latitude: 70° 13' 10.625 N +E/ -W 0.00 usft Easting: 1,621,195.59 usft Longitude: 150° 9' 18.248 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore 2S-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 2S-06 Date 9/20/2016 Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 39.10 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 1,009.85 2S-06 Srvy 1 - SLB_GWD70 (2S-06) (usft) (usft) (usft) (1) 1,069.89 39.10 0.00 0.00 195.00 Survey Program Date 9/20/2016 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.32 1,009.85 2S-06 Srvy 1 - SLB_GWD70 (2S-06) GYD-GC-SS Gyrodata gyro single shots 8/19/2016 8:31: 1,069.89 2,583.95 25-06 Srvy 2 - SLB_MWD+GMAG (2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/19/2016 8:36: 2,616.38 2,616.38 25-06 Srvy 3 - SLB_INC-Filler (2S-06) INC+TREND Inclinometer + known azi trend 8/23/2016 12:07 2,706.90 7,560.16 2S-06 Srvy 4 - SLB_MWD+GMAG (2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/23/2016 12:09 7,659.93 17,933.76 2S-06 Srvy 5 - SLB_MWD+GMAG (2S-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/31/2016 9:45: Survey 9/20/2016 11:35:06AM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.10 0.00 0.00 39.10 -120.00 0.00 0.00 5.929,754.39 1,621,195.59 0.00 0.00 UNDEFINED 100.32 0.19 343.22 100.32 -58.78 0.10 -0.03 5.929,754.49 1,621,195.56 0.31 -0.09 GYD-GC-SS (1) 161.19 0.28 47.50 161.19 2.09 0.29 0.05 5,929,754.69 11621,195.64 0.43 -0.30 GYD-GC-SS (1) 257.39 0.28 349.16 257.39 98.29 0.68 0.18 5,929,755.07 1,621,195.77 0.28 -0.71 GYD-GC-SS (1) 356.17 1.32 5.68 356.16 197.06 2.05 0.25 5,929,756.44 1,621,195.84 1.07 -2.05 GYD-GC-SS (1) 448.44 3.10 1.21 448.36 289.26 5.61 0.41 5,929,759.99 1,621,196.01 1.94 -5.52 GYD-GC-SS (1) 539.12 4.03 4.40 538.86 379.76 11.23 0.70 5,929,765.62 1,621,196.32 1.05 -11.03 GYD-GC-SS (1) 631.94 4.15 3.74 631.44 472.34 17.84 1.17 5,929,772.22 1,621,196.81 0.14 -17.53 GYD-GC-SS (1) 725.12 6.56 4.25 724.21 565.11 26.51 1.79 5,929,780.89 1,621,197.44 2.59 -26.07 GYD-GC-SS (1) 820.98 7.86 0.26 819.31 660.21 38.53 2.22 5,929,792.91 1,621,197.91 1.45 -37.79 GYD-GC-SS (1) 9/20/2016 11:35:06AM Page 2 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 25-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 915.97 9.77 359.98 913.17 754.07 53.08 2.25 5,929,807.46 1,621,197.97 2.01 -51.86 GYD-GC-SS (1) 1,009.85 11.04 0.30 1,005.51 846.41 70.04 2.29 5,929,824.42 1,621,198.06 1.35 -68.24 GYD-GC-SS (1) 1,069.89 12.12 357.28 1,064.33 905.23 82.08 2.02 5,929,836.46 1,621,197.82 2.06 -79.81 MWD+IFR-AK-CAZ-SC (2) 1,164.35 15.48 357.78 1,156.05 996.95 104.59 1.06 5,929,858.97 1,621,196.92 3.56 -101.30 MWD+IFR-AK-CAZ-SC (2) 1,259.97 17.70 357.04 1,247.68 1,088.58 131.86 -0.18 5,929,886.24 1,621,195.74 2.33 -127.32 MWD+IFR-AK-CAZ-SC (2) 1,354.34 22.39 358.48 1,336.31 1,177.21 164.17 -1.40 5,929,918.55 1,621,194.61 5.00 -158.22 MWD+IFR-AK-CAZ-SC (2) 1,449.30 22.33 358.93 1,424.13 1,265.03 200.29 -2.22 5,929,954.66 1,621,193.88 0.19 -192.89 MWD+IFR-AK-CAZ-SC (2) 1,543.75 21.70 6.01 1,511.71 1,352.61 235.60 -0.72 5,929,989.97 1,621,195.47 2.89 -227.39 MWD+IFR-AK-CAZ-SC (2) 1,639.06 20.62 12.61 1,600.60 1,441.50 269.51 4.79 5,930,023.86 1,621,201.06 2.74 -261.56 MWD+IFR-AK-CAZ-SC (2) 1,734.09 20.28 21.23 1,689.66 1,530.56 301.20 14.41 5,930,055.52 1,621,210.76 3.19 -294.66 MWD+IFR-AK-CAZ-SC (2) 1,828.64 20.70 29.92 1,778.25 1,619.15 330.96 28.68 5,930,085.24 1,621,225.11 3.24 -327.11 MWD+IFR-AK-CAZ-SC (2) 1,923.75 21.30 30.53 1,867.05 1,707.95 360.41 45.84 5,930,114.65 1,621,242.34 0.67 -359.99 MWD+IFR-AK-CAZ-SC (2) 2,019.13 21.52 30.73 1,955.84 1,796.74 390.37 63.58 5,930,144.56 1,621,260.15 0.24 -393.52 MWD+IFR-AK-CAZ-SC (2) 2,113.70 21.72 30.68 2,043.76 1,884.66 420.33 81.37 5,930,174.47 1,621,278.02 0.21 427.07 MWD+IFR-AK-CAZ-SC (2) 2,208.31 21.57 30.95 2,131.70 1,972.60 450.30 99.25 5,930,204.39 1,621,295.97 0.19 460.64 MWD+IFR-AK-CAZ-SC (2) 2,303.63 21.24 31.39 2,220.44 2,061.34 480.06 117.25 5,930,234.11 1,621,314.05 0.39 -494.05 MWD+IFR-AK-CAZ-SC (2) 2,398.00 21.07 31.06 2,308.45 2,149.35 509.19 134.91 5,930,263.18 1,621,331.78 0.22 -526.75 MWD+IFR-AK-CAZ-SC (2) 2,492.84 20.74 31.71 2,397.05 2,237.95 538.08 152.53 5,930,292.03 1,621,349.47 0.43 -559.22 MWD+IFR-AK-CAZ-SC (2) 2,583.95 20.48 30.41 2,482.33 2,323.23 565.55 169.08 5,930,319.45 1,621,366.09 0.58 -590.04 MWD+IFR-AK-CAZ-SC (2) 2,616.38 20.94 28.37 2,512.66 2,353.56 575.54 174.70 5,930,329.43 1,621,371.74 2.64 -601.15 INC+TREND (3) 2,657.00 21.66 27.42 2,550.51 2,391.41 588.58 181.60 5,930,342.45 1,621,378.67 1.98 -615.53 1 NOT an Actual Survey 10 3/4" x 13-1/2" 2,706.90 22.56 26.33 2,596.74 2,437.64 605.34 190.09 5,930,359.18 1,621,387.20 1.98 -633.91 MWD+IFR-AK-CAZ-SC (4) 2,802.11 21.33 26.32 2,685.05 2,525.95 637.23 205.87 5,930,391.03 1,621,403.06 1.29 -668.80 MWD+IFR-AK-CAZ-SC (4) 2,897.25 21.41 26.24 2,773.65 2,614.55 668.31 221.22 5,930,422.07 1,621,418.49 0.09 -702.80 MWD+IFR-AK-CAZ-SC (4) 2,993.26 21.37 25.31 2,863.04 2,703.94 699.84 236.45 5,930,453.56 1,621,433.79 0.36 -737.19 MWD+IFR-AK-CAZ-SC (4) 3,088.38 21.41 28.17 2,951.62 2,792.52 730.82 252.05 5,930,484.49 1,621,449.48 1.10 -771.15 MWD+IFR-AK-CAZ-SC (4) 3,181.81 21.48 30.50 3,038.58 2,879.48 760.59 268.78 5,930,514.22 1,621,466.28 0.91 -804.24 MWD+IFR-AK-CAZ-SC (4) 3,276.28 21.33 32.60 3,126.53 2,967.43 789.97 286.82 5,930,543.55 1,621,484.39 0.83 -837.28 MWD+IFR-AK-CAZ-SC (4) 3,371.37 21.36 31.82 3,215.10 3,056.00 819.25 305.27 5,930,572.78 1,621,502.91 0.30 -870.34 MWD+IFR-AK-CAZ-SC (4) 3,465.85 21.25 31.30 3,303.12 3,144.02 848.50 323.23 5,930,601.98 1,621,520.95 0.23 -903.25 MWD+IFR-AK-CAZ-SC (4) 3,561.35 18.21 29.24 3,393.01 3,233.91 876.32 339.52 5,930,629.75 1,621,537.30 3.27 -934.33 MWD+IFR-AK-CAZ-SC (4) 3,655.34 15.98 29.72 3,482.84 3,323.74 900.37 353.11 5,930,653.77 1,621,550.95 2.38 -961.08 MWD+IFR-AK-CAZ-SC (4) 3,750.54 14.03 31.67 3,574.79 3,415.69 921.57 365.66 5,930,674.94 1,621,563.56 2.12 -984.81 MWD+IFR-AK-CAZ-SC (4) 3,845.52 12.17 35.54 3,667.30 3,508.20 939.52 377.53 5,930,692.85 1,621,575.47 2.16 -1,005.22 MWD+IFR-AK-CAZ-SC (4) 3,940.31 10.68 40.03 3,760.21 3,601.11 954.38 388.99 5,930,707.68 1,621,586.97 1.83 -1,022.54 MWD+IFR-AK-CAZ-SC (4) 4,035.52 8.89 49.14 3,854.03 3,694.93 965.95 400.23 5,930,719.22 1,621,598.24 2.48 -1,036.62 MWD+IFR-AK-CAZ-SC (4) 4,130.41 7.52 65.73 3,947.96 3,788.86 973.30 411.44 5,930,726.54 1,621,609.46 2.87 -1,046.62 MWD+IFR-AK-CAZ-SC (4) 4,224.72 6.54 86.87 4,041.58 3,882.48 976.13 422.43 5,930,729.34 1,621,620.46 2.91 -1,052.20 MWD+IFR-AK-CAZ-SC (4) 4,318.81 6.05 110.03 4,135.12 3,976.02 974.72 432.44 5,930,727.91 1,621,630.46 2.73 -1,053.43 MWD+IFR-AK-CAZ-SC (4) 4,414.63 5.80 131.61 4,230.44 4,071.34 969.78 440.80 5,930,722.95 1,621,638.81 2.33 -1,050.82 MWD+IFR-AK-CAZ-SC (4) 9/20/2016 11:35:06AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 25-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,509.52 6.70 145.00 4,324.77 4,165.67 962.06 447.56 5,930,715.21 1,621,645.55 1.80 -1,045.11 MWD+IFR-AK-CAZ-SC (4) 4,602.96 8.28 154.35 4,417.41 4,258.31 951.53 453.60 5,930,704.66 1,621,651.57 2.13 -1,036.51 MWD+IFR-AK-CAZ-SC (4) 4,698.31 10.35 159.47 4,511.50 4,352.40 937.31 459.58 5,930,690.44 1,621,657.51 2.34 -1,024.32 MWD+IFR-AK-CAZ-SC (4) 4,795.38 12.33 163.82 4,606.67 4,447.57 919.19 465.52 5,930,672.30 1,621,663.41 2.22 -1,008.36 MWD+IFR-AK-CAZ-SC (4) 4,891.21 15.18 171.56 4,699.75 4,540.65 896.95 47022 5,930,650.05 1,621,668.04 3.53 -988.09 MWD+IFR-AK-CAZ-SC (4) 4,983.13 18.66 182.89 4,787.70 4,628.60 870.34 471.24 5,930,623.44 1,621,669.00 5.20 -962.65 MWD+IFR-AK-CAZ-SC (4) 5,077.82 21.35 186.13 4,876.67 4,717.57 838.07 468.64 5,930,591.18 1,621,666.31 3.07 -930.81 MWD+IFR-AK-CAZ-SC (4) 5,172.97 23.11 186.29 4,964.75 4,805.65 802.28 464.74 5,930,555.41 1,621,662.33 1.85 -895.23 MWD+IFR-AK-CAZ-SC (4) 5,267.99 25.18 184.68 5,051.45 4,892.35 763.60 461.05 5,930,516.74 1,621,658.54 2.29 -856.91 MWD+IFR-AK-CAZ-SC (4) 5,362.20 27.85 182.73 5,135.75 4,976.65 721.63 458.37 5,930,474.78 1,621,655.75 2.98 -815.68 MWD+IFR-AK-CAZ-SC (4) 5,456.29 30.15 181.68 5,218.03 5,058.93 676.06 456.63 5,930,429.22 1,621,653.89 2.50 -771.20 MWD+IFR-AK-CAZ-SC (4) 5,551.84 32.57 182.46 5,299.62 5,140.52 626.37 454.82 5,930,379.54 1,621,651.96 2.57 -722.74 MWD+IFR-AK-CAZ-SC (4) 5,646.69 34.35 183.61 5,378.75 5,219.65 574.15 452.04 5,930,327.33 1,621,649.04 1.99 -671.58 MWD+IFR-AK-CAZ-SC (4) 5,742.29 36.67 185.54 5,456.57 5,297.47 518.81 447.58 5,930,272.01 1,621,644.45 2.69 -616.98 MWD+IFR-AK-CAZ-SC (4) 5,836.35 39.20 186.16 5,530.75 5,371.65 461.29 441.68 5,930,214.51 1,621,638.40 2.72 -559.89 MWD+IFR-AK-CAZ-SC (4) 5,931.08 41.51 185.02 5,602.93 5,443.83 400.25 435.72 5,930,153.49 1,621,632.29 2.56 -499.38 MWD+IFR-AK-CAZ-SC (4) 6,026.45 45.01 185.20 5,672.37 5,513.27 335.16 429.90 5,930,088.42 1,621,626.30 3.67 435.01 MWD+IFR-AK-CAZ-SC (4) 6,120.04 45.88 186.91 5,738.04 5,578.94 268.85 422.86 5,930,022.14 1,621,619.09 1.60 -369.13 MWD+IFR-AK-CAZ-SC (4) 6,215.81 47.85 189.14 5,803.52 5,644.42 199.66 413.08 5,929,952.98 1,621,609.14 2.67 -299.77 MWD+IFR-AK-CAZ-SC (4) 6,310.93 50.59 190.26 5,865.64 5,706.54 128.68 400.93 5,929,882.03 1,621,596.81 3.02 -228.06 MWD+IFR-AK-CAZ-SC (4) 6,405.93 52.94 191.11 5,924.43 5,765.33 55.36 387.09 5,929,808.76 1,621,582.78 2.57 -153.66 MWD+IFR-AK-CAZ-SC (4) 6,500.66 55.78 190.33 5,979.63 5,820.53 -20.28 372.78 5,929,733.17 1,621,568.28 3.07 -76.89 MWD+IFR-AK-CAZ-SC (4) 6,595.44 58.80 190.78 6,030.84 5,871.74 -98.67 358.17 5,929,654.82 1,621,553.47 3.21 2.61 MWD+IFR-AK-CAZ-SC (4) 6,690.21 60.69 191.24 6,078.59 5,919.49 -179.02 342.53 5,929,574.52 1,621,537.63 2.04 84.27 MWD+IFR-AK-CAZ-SC (4) 6,785.50 62.79 191.62 6,123.70 5,964.60 -261.28 325.90 5,929,492.31 1,621,520.79 2.23 168.03 MWD+IFR-AK-CAZ-SC (4) 6,879.60 65.85 192.52 6,164.47 6,005.37 -344.20 308.16 5,929,409.44 1,621,502.84 3.36 252.71 MWD+IFR-AK-CAZ-SC (4) 6,974.39 68.87 193.50 6,200.96 6,041.86 429.43 288.46 5,929,324.27 1,621,482.92 3.33 340.14 MWD+IFR-AK-CAZ-SC (4) 7,072.08 70.63 194.04 6,234.77 6,075.67 -518.44 266.64 5,929,235.33 1,621,460.88 1.87 431.76 MWD+IFR-AK-CAZ-SC (4) 7,165.22 72.78 194.69 6,264.01 6,104.91 -604.10 244.70 5,929,149.73 1,621,438.72 2.40 520.18 MWD+IFR-AK-CAZ-SC (4) 7,260.57 74.67 195.07 6,290.73 6,131.63 -692.55 221.19 5,929,061.34 1,621,415.00 2.02 611.71 MWD+IFR-AK-CAZ-SC (4) 7,355.40 77.20 194.53 6,313.77 6,154.67 -781.48 197.70 5,928,972.48 1,621,391.28 2.72 703.69 MWD+IFR-AK-CAZ-SC (4) 7,450.21 79.86 194.98 6,332.62 6,173.52 -871.33 174.04 5,928,882.71 1,621,367.39 2.84 796.59 MWD+IFR-AK-CAZ-SC (4) 7,544.25 81.63 195.83 6,347.75 6,188.65 -960.80 149.38 5,928,793.31 1,621,342.51 2.08 889.40 MWD+IFR-AK-CAZ-SC (4) 7,560.16 81.91 194.66 6,350.02 6,190.92 -975.99 145.24 5,928,778.13 1,621,338.33 7.49 905.15 MWD+IFR-AK-CAZ-SC (4) 7,620.00 84.07 194.52 6,357.33 6,198.23 -1,033.47 130.28 5,928,720.70 1,621,323.23 3.62 964.54 NOT an Actual Survey 7-6/8" x 9-7/8 by 11 7,659.93 85.51 194.42 6,360.95 6,201.85 -1,071.97 120.35 5,928,682.22 1,621,313.19 3.62 1,004.30 MWD+IFR-AK-CAZ-SC (5) 7,720.54 86.78 193.65 6,365.03 6,205.93 -1,130.64 105.68 5,928,623.60 1,621,298.38 2.45 1,064.76 MWD+IFR-AK-CAZ-SC (5) 7,814.02 87.59 193.09 6,369.62 6,210.52 -1,221.47 84.09 5,928,532.83 1,621,276.56 1.05 1,158.09 MWD+IFR-AK-CAZ-SC (5) 7,908.65 85.65 191.90 6,375.20 6,216.10 -1,313.70 63.66 5,928,440.67 1,621,255.89 2.40 1,252.46 MWD+IFR-AK-CAZ-SC (5) 9/20/2016 11:35:06AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Repoli Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 25-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N1 -S +E/ -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,003.37 88.05 193.10 6,380.40 6,221.30 -1,406.02 43.19 5,928,348.40 1,621,235.19 2.83 1,346.94 MWD+IFR-AK-CAZ-SC (5) 8,099.44 90.83 192.15 6,381.34 6,222.24 -1,499.75 22.19 5,928,254.73 1,621,213.96 3.06 1,442.91 MWD+IFR-AK-CAZ-SC (5) 8,192.83 92.63 192.76 6,378.52 6,219.42 -1,590.90 2.06 5,928,163.65 1,621,193.60 2.03 1,536.16 MWD+IFR-AK-CAZ-SC (5) 8,288.33 91.51 193.66 6,375.07 6,215.97 -1,683.81 -19.75 5,928,070.80 1,621,171.55 1.50 1,631.55 MWD+IFR-AK-CAZ-SC (5) 8,383.03 90.79 193.19 6,373.17 6,214.07 -1,775.90 -41.73 5,927,978.78 1,621,149.34 0.91 1,726.19 MWD+IFR-AK-CAZ-SC (5) 8,477.83 91.19 194.21 6,371.53 6,212.43 -1,867.99 -64.18 5,927,886.76 1,621,126.66 1.16 1,820.95 MWD+IFR-AK-CAZ-SC (5) 8,572.36 87.79 194.99 6,372.38 6,213.28 -1,959.45 -88.00 5,927,795.37 1,621,102.61 3.69 1,915.46 MWD+IFR-AK-CAZ-SC (5) 8,667.34 87.16 195.52 6,376.56 6,217.46 -2,050.99 -112.97 5,927,703.89 1,621,077.41 0.87 2,010.35 MWD+IFR-AK-CAZ-SC (5) 8,762.25 86.92 195.94 6,381.46 6,222.36 -2,142.23 -138.66 5,927,612.74 1,621,051.48 0.51 2,105.12 MWD+IFR-AK-CAZ-SC (5) 8,857.34 87.64 198.27 6,385.97 6,226.87 -2,233.00 -166.60 5,927,522.04 1,621,023.32 2.56 2,200.03 MWD+IFR-AK-CAZ-SC (5) 8,951.68 87.94 196.32 6,389.61 6,230.51 -2,323.01 -194.62 5,927,432.12 1,620,995.07 2.09 2,294.22 MWD+IFR-AK-CAZ-SC (5) 9,046.32 89.63 196.28 6,391.62 6,232.52 -2,413.82 -221.18 5,927,341.38 1,620,968.29 1.79 2,388.81 MWD+IFR-AK-CAZ-SC (5) 9,140.92 91.07 195.77 6,391.04 6,231.94 -2,504.74 -247.29 5,927,250.54 1,620,941.94 1.61 2,483.40 MWD+IFR-AK-CAZ-SC (5) 9,236.56 91.82 196.40 6,388.63 6,229.53 -2,596.60 -273.78 5,927,158.75 1,620,915.22 1.02 2,578.99 MWD+IFR-AK-CAZ-SC (5) 9,330.87 92.92 193.85 6,384.73 6,225.63 -2,687.56 -298.37 5,927,067.87 1,620,890.41 2.94 2,673.21 MWD+IFR-AK-CAZ-SC (5) 9,425.67 92.95 193.14 6,379.87 6,220.77 -2,779.62 -320.46 5,926,975.87 1,620,868.08 0.75 2,767.85 MWD+IFR-AK-CAZ-SC (5) 9,520.28 91.99 191.61 6,375.80 6,216.70 -2,871.94 -340.72 5,926,883.61 1,620,847.59 1.91 2,862.27 MWD+IFR-AK-CAZ-SC (5) 9,614.77 91.58 191.76 6,372.85 6,213.75 -2,964.43 -359.84 5,926,791.18 1,620,828.23 0.46 2,956.55 MWD+IFR-AK-CAZ-SC (5) 9,710.02 91.55 191.65 6,370.25 6,211.15 -3,057.66 -379.16 5,926,698.01 1,620,808.68 0.12 3,051.61 MWD+IFR-AK-CAZ-SC (5) 9,804.02 91.99 191.76 6,367.35 6,208.25 -3,149.66 -398.22 5,926,606.06 1,620,789.39 0.48 3,145.41 MWD+IFR-AK-CAZ-SC (5) 9,898.90 91.48 191.29 6,364.48 6,205.38 -3,242.59 -417.17 5,926,513.20 1,620,770.20 0.73 3,240.07 MWD+IFR-AK-CAZ-SC (5) 9,993.23 91.48 190.95 6,362.04 6,202.94 -3,335.12 -435.36 5,926,420.73 1,620,751.78 0.36 3,334.15 MWD+IFR-AK-CAZ-SC (5) 10,088.12 91.24 191.75 6,359.79 6,200.69 -3,428.12 -454.03 5,926,327.78 1,620,732.88 0.88 3,428.82 MWD+IFR-AK-CAZ-SC (5) 10,182.57 89.40 191.14 6,359.26 6,200.16 -3,520.69 -472.77 5,926,235.27 1,620,713.91 2.05 3,523.09 MWD+IFR-AK-CAZ-SC (5) 10,277.60 90.04 192.21 6,359.72 6,200.62 -3,613.75 -492.00 5,926,142.26 1,620,694.44 1.31 3,617.95 MWD+IFR-AK-CAZ-SC (5) 10,371.79 90.79 193.57 6,359.04 6,199.94 -3,705.56 -513.01 5,926,050.52 1,620,673.20 1.65 3,712.07 MWD+IFR-AK-CAZ-SC (5) 10,467.10 89.76 194.59 6,358.58 6,199.48 -3,798.01 -536.19 5,925,958.14 1,620,649.78 1.52 3,807.37 MWD+IFR-AK-CAZ-SC (5) 10,560.70 88.72 193.84 6,359.83 6,200.73 -3,888.73 -559.17 5,925,867.49 1,620,626.57 1.37 3,900.95 MWD+IFR-AK-CAZ-SC (5) 10,656.41 89.63 194.87 6,361.20 6,202.10 -3,981.44 -582.90 5,925,774.85 1,620,602.61 1.44 3,996.64 MWD+IFR-AK-CAZ-SC (5) 10,750.53 89.52 195.47 6,361.90 6,202.80 -4,072.28 -607.53 5,925,684.08 1,620,577.75 0.65 4,090.76 MWD+IFR-AK-CAZ-SC (5) 10,845.40 89.63 195.88 6,362.61 6,203.51 -4,163.62 -633.16 5,925,592.82 1,620,551.89 0.45 4,185.62 MWD+IFR-AK-CAZ-SC (5) 10,939.33 90.38 196.07 6,362.60 6,203.50 -4,253.92 -659.01 5,925,502.59 1,620,525.81 0.82 4,279.53 MWD+IFR-AK-CAZ-SC (5) 11,034.67 90.38 196.52 6,361.97 6,202.87 -4,345.43 -685.76 5,925,411.16 1,620,498.83 0.47 4,374.85 MWD+IFR-AK-CAZ-SC (5) 11,128.07 89.11 197.53 6,362.38 6,203.28 -4,434.73 -713.11 5,925,321.93 1,620,471.26 1.74 4,468.18 MWD+IFR-AK-CAZ-SC (5) 11,223.12 88.19 197.31 6,364.62 6,205.52 -4,525.39 -741.55 5,925,231.35 1,620,442.59 1.00 4,563.12 MWD+IFR-AK-CAZ-SC (5) 11,318.26 87.04 198.01 6,368.58 6,209.48 -4,615.97 -770.39 5,925,140.86 1,620,413.52 1.41 4,658.08 MWD+IFR-AK-CAZ-SC (5) 11,412.87 87.98 197.49 6,372.69 6,213.59 -4,705.99 -799.21 5,925,050.92 1,620,384.48 1.14 4,752.49 MWD+IFR-AK-CAZ-SC (5) 11,506.96 89.22 197.87 6,374.99 6,215.89 -4,795.61 -827.77 5,924,961.39 1,620,355.69 1.38 4,846.44 MWD+IFR-AK-CAZ-SC (5) 11,600.80 90.00 196.64 6,375.63 6,216.53 -4,885.22 -855.61 5,924,871.85 1,620,327.63 1.55 4,940.21 MWD+IFR-AK-CAZ-SC (5) 11,695.98 91.34 195.76 6,374.51 6,215.41 -4,976.61 -882.16 5,924,780.54 1,620,300.85 1.68 5,035.36 MWD+IFR-AK-CAZ-SC (5) 9/20/2016 11:35:06AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (D142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,790.89 92.03 194.87 6,371.72 6,212.62 -5,068.11 -907.22 5,924,689.11 1,620,275.56 1.19 5,130.22 MWD+IFR-AK-CAZ-SC (5) 11,886.13 91.89 194.86 6,368.47 6,209.37 -5,160.11 -931.63 5,924,597.19 1,620,250.91 0.15 5,225.41 MWD+IFR-AK-CAZ-SC (5) 11,981.33 91.14 195.00 6,365.95 6,206.85 -5,252.06 -956.15 5,924,505.31 1,620,226.16 0.80 5,320.57 MWD+IFR-AK-CAZ-SC (5) 12,076.19 90.55 194.91 6,364.55 6,205.45 -5,343.70 -980.63 5,924,413.74 1,620,201.45 0.63 5,415.42 MWD+IFR-AK-CAZ-SC (5) 12,170.11 90.62 194.78 6,363.59 6,204.49 -5,434.48 -1,004.69 5,924,323.03 1,620,177.16 0.16 5,509.33 MWD+IFR-AK-CAZ-SC (5) 12,264.91 88.84 194.93 6,364.04 6,204.94 -5,526.10 -1,028.99 5,924,231.48 1,620,152.63 1.88 5,604.13 MWD+IFR-AK-CAZ-SC (5) 12,360.29 86.31 197.84 6,368.07 6,208.97 -5,617.51 -1,055.87 5,924,140.15 1,620,125.52 4.04 5,699.38 MWD+IFR-AK-CAZ-SC (5) 12,455.37 86.75 197.03 6,373.83 6,214.73 -5,708.06 -1,084.30 5,924,049.68 1,620,096.86 0.97 5,794.20 MWD+IFR-AK-CAZ-SC (5) 12,549.05 86.61 196.28 6,379.25 6,220.15 -5,797.65 -1,111.11 5,923,960.16 1,620,069.83 0.81 5,887.68 MWD+IFR-AK-CAZ-SC (5) 12,643.85 86.88 196.76 6,384.64 6,225.54 -5,888.39 -1,138.02 5,923,869.50 1,620,042.69 0.58 5,982.29 MWD+IFR-AK-CAZ-SC (5) 12,739.28 87.67 195.70 6,389.17 6,230.07 -5,979.92 -1,164.66 5,923,778.06 1,620,015.82 1.38 6,077.59 MWD+IFR-AK-CAZ-SC (5) 12,834.87 88.32 195.31 6,392.52 6,233.42 -6,071.97 -1,190.20 5,923,686.08 1,619,990.05 0.79 6,173.12 MWD+IFR-AK-CAZ-SC (5) 12,929.92 88.52 192.86 6,395.14 6,236.04 -6,164.12 -1,213.32 5,923,593.99 1,619,966.70 2.59 6,268.11 MWD+IFR-AK-CAZ-SC (5) 13,024.14 90.05 192.49 6,396.32 6,237.22 -6,256.03 -1,233.99 5,923,502.14 1,619,945.79 1.67 6,362.25 MWD+IFR-AK-CAZ-SC (5) 13,117.94 89.70 192.08 6,396.52 6,237.42 -6,347.69 -1,253.95 5,923,410.55 1,619,925.60 0.57 6,455.94 MWD+IFR-AK-CAZ-SC (5) 13,212.28 89.90 191.25 6,396.85 6,237.75 -6,440.08 -1,273.02 5,923,318.22 1,619,906.30 0.90 6,550.12 MWD+IFR-AK-CAZ-SC (5) 13,307.28 90.86 190.77 6,396.22 6,237.12 -6,533.32 -1,291.17 5,923,225.03 1,619,887.92 1.13 6,644.88 MWD+IFR-AK-CAZ-SC (5) 13,402.84 90.66 190.96 6,394.95 6,235.85 -6,627.16 -1,309.18 5,923,131.24 1,619,869.67 0.29 6,740.19 MWD+IFR-AK-CAZ-SC (5) 13,497.52 89.72 192.49 6,394.64 6,235.54 -6,719.86 -1,328.42 5,923,038.60 1,619,850.20 1.90 6,834.71 MWD+IFR-AK-CAZ-SC (5) 13,592.34 90.14 192.19 6,394.75 6,235.65 -6,812.49 -1,348.68 5,922,946.03 1,619,829.70 0.54 6,929.43 MWD+IFR-AK-CAZ-SC (5) 13,688.98 88.98 191.98 6,395.50 6,236.40 -6,906.99 -1,368.91 5,922,851.60 1,619,809.23 1.22 7,025.94 MWD+IFR-AK-CAZ-SC (5) 13,782.05 87.28 192.72 6,398.53 6,239.43 -6,997.85 -1,388.81 5,922,760.80 1,619,789.10 1.99 7,118.85 MWD+IFR-AK-CAZ-SC (5) 13,877.26 86.75 192.82 6,403.49 6,244.39 -7,090.58 -1,409.82 5,922,668.13 1,619,767.85 0.57 7,213.86 MWD+IFR-AK-CAZ-SC (5) 13,973.14 89.74 193.09 6,406.43 6,247.33 -7,183.96 -1,431.31 5,922,574.81 1,619,746.14 3.13 7,309.62 MWD+IFR-AK-CAZ-SC (5) 14,067.15 90.59 193.71 6,406.16 6,247.06 -7,275.41 -1,453.09 5,922,483.43 1,619,724.12 1.12 7,403.60 MWD+IFR-AK-CAZ-SC (5) 14,161.38 89.85 192.83 6,405.79 6,246.69 -7,367.12 -1,474.72 5,922,391.78 1,619,702.26 1.22 7,497.78 MWD+IFR-AK-CAZ-SC (5) 14,257.29 90.69 193.02 6,405.34 6,246.24 -7,460.60 -1,496.17 5,922,298.37 1,619,680.57 0.90 7,593.63 MWD+IFR-AK-CAZ-SC (5) 14,352.28 91.14 193.36 6,403.83 6,244.73 -7,553.07 -1,517.85 5,922,205.96 1,619,658.66 0.59 7,688.56 MWD+IFR-AK-CAZ-SC (5) 14,447.26 91.58 193.53 6,401.57 6,242.47 -7,645.42 -1,539.92 5,922,113.67 1,619,636.35 0.50 7,783.47 MWD+IFR-AK-CAZ-SC (5) 14,541.68 92.85 193.04 6,397.92 6,238.82 -7,737.25 -1,561.60 5,922,021.92 1,619,614.44 1.44 7,877.78 MWD+IFR-AK-CAZ-SC (5) 14,636.48 92.64 194.98 6,393.38 6,234.28 -7,829.12 -1,584.53 5,921,930.11 1,619,591.29 2.06 7,972.45 MWD+IFR-AK-CAZ-SC (5) 14,731.94 92.95 193.55 6,388.73 6,229.63 -7,921.52 -1,608.02 5,921,837.78 1,619,567.56 1.53 8,067.79 MWD+IFR-AK-CAZ-SC (5) 14,826.68 92.61 193.62 6,384.13 6,225.03 -8,013.50 -1,630.25 5,921,745.86 1,619,545.10 0.37 8,162.39 MWD+IFR-AK-CAZ-SC (5) 14,921.26 91.15 192.70 6,381.03 6,221.93 -8,105.54 -1,651.77 5,921,653.89 1,619,523.35 1.82 8,256.86 MWD+IFR-AK-CAZ-SC (5) 15,016.01 91.79 194.04 6,378.60 6,219.50 -8,197.69 -1,673.67 5,921,561.80 1,619,501.22 1.57 8,351.54 MWD+IFR-AK-CAZ-SC (5) 15,110.55 91.96 196.90 6,375.50 6,216.40 -8,288.75 -1,698,87 5,921,470.82 1,619,475.79 3.03 8,446.02 MWD+IFR-AK-CAZ-SC (5) 15,206.22 92.00 195.97 6,372.20 6,213.10 -8,380.46 -1,725.92 5,921,379.19 1,619,448.50 0.97 8,541.60 MWD+IFR-AK-CAZ-SC (5) 15,300.84 90.11 195.03 6,370.46 6,211.36 -8,471.61 -1,751.20 5,921,288.11 1,619,422.99 2.23 8,636.20 MWD+IFR-AK-CAZ-SC (5) 15,375.00 89.27 195.26 6,370.86 6,211.76 -8,543.20 -1,770.58 5,921,216.58 1,619,403.44 1.17 8,710.35 NOT an Actual Survey 4 1/2" x 6-3/4 9/20/2016 11:35:06AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2S-06 Project: Kuparuk River Unit TVD Reference: 2S-06 actual @ 159.10usft (D142) Site: Kuparuk 2S Pad MD Reference: 2S-06 actual @ 159.10usft (13142) Well: 2S-06 North Reference: True Wellbore: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,395.58 89.04 195.33 6,371.16 6,212.06 -8,563.04 -1,776.01 5,921,196.75 1,619,397.96 1.17 8,730.93 MWD+IFR-AK-CAZ-SC (5) 15,489.89 87.53 195.78 6,373.98 6,214.88 -8,653.86 -1,801.29 5,921,106.01 1,619,372.45 1.67 8,825.19 MWD+IFR-AK-CAZ-SC (5) 15,585.60 85.06 196.96 6,380.17 6,221.07 -8,745.49 -1,828.20 5,921,014.46 1,619,345.30 2.86 8,920.66 MWD+IFR-AK-CAZ-SC (5) 15,679.44 82.22 197.26 6,390.56 6,231.46 -8,834.61 -1,855.64 5,920,925.41 1,619,317.65 3.04 9,013.85 MWD+IFR-AK-CAZ-SC (5) 15,774.24 84.51 196.42 6,401.51 6,242.41 -8,924.73 -1,882.91 5,920,835.37 1,619,290.14 2.57 9,107.96 MWD+IFR-AK-CAZ-SC (5) 15,868.49 85.51 196.39 6,409.71 6,250.61 -9,014.80 -1,909.43 5,920,745.38 1,619,263.40 1.06 9,201.83 MWD+IFR-AK-CAZ-SC (5) 15,963.28 86.71 196.18 6,416.14 6,257.04 -9,105.58 -1,935.95 5,920,654.68 1,619,236.65 1.29 9,296.37 MWD+IFR-AK-CAZ-SC (5) 16,058.46 87.12 196.38 6,421.26 6,262.16 -9,196.81 -1,962.59 5,920,563.53 1,619,209.78 0.48 9,391.39 MWD+IFR-AK-CAZ-SC (5) 16,153.67 86.47 196.08 6,426.59 6,267.49 -9,288.08 -1,989.16 5,920,472.33 1,619,182.98 0.75 9,486.43 MWD+IFR-AK-CAZ-SC (5) 16,249.50 86.44 194.57 6,432.51 6,273.41 -9,380.32 -2,014.44 5,920,380.16 1,619,157.47 1.57 9,582.07 MWD+IFR-AK-CAZ-SC (5) 16,343.48 86.85 194.45 6,438.01 6,278.91 -9,471.15 -2,037.95 5,920,289.40 1,619,133.73 0.45 9,675.89 MWD+IFR-AK-CAZ-SC (5) 16,435.09 87.78 195.14 6,442.30 6,283.20 -9,559.62 -2,061.31 5.920,201.00 1,619,110.14 1.26 9,767.39 MWD+IFR-AK-CAZ-SC (5) 16,532.66 87.40 194.87 6,446.41 6,287.31 -9,653.78 -2,086.55 5,920,106.91 1,619,084.67 0.48 9,864.88 MWD+IFR-AK-CAZ-SC (5) 16,627.31 87.36 194.72 6,450.73 6,291.63 -9,745.20 -2,110.70 5,920,015.57 1,619,060.29 0.16 9,959.43 MWD+IFR-AK-CAZ-SC (5) 16,722.09 87.63 194.37 6,454.88 6,295.78 -9,836.85 -2,134.48 5,919,923.98 1,619,036.28 0.47 10,054.11 MWD+IFR-AK-CAZ-SC (5) 16,817.05 89.52 192.84 6,457.24 6,298.14 -9,929.11 -2,156.80 5,919,831.79 1,619,013.72 2.56 10,149.01 MWD+IFR-AK-CAZ-SC (5) 16,912.69 90.86 192.69 6,456.92 6,297.82 -10,022.39 -2,177.94 5,919,738.58 1,618,992.35 1.41 10,244.57 MWD+IFR-AK-CAZ-SC (5) 17,008.25 90.93 192.85 6,455.43 6,296.33 -10,115.57 -2,199.06 5,919,645.46 1,618,971.00 0.18 10,340.05 MWD+IFR-AK-CAZ-SC (5) 17,102.51 90.72 191.32 6,454.07 6,294.97 -10,207,73 -2,218.79 5,919,553.36 1,618,951.03 1.64 10,434.18 MWD+IFR-AK-CAZ-SC (5) 17,197.82 90.99 193.29 6,452.65 6,293.55 -10,300.84 -2,239.10 5,919,460.32 1,618,930.49 2.09 10,529.37 MWD+IFR-AK-CAZ-SC (5) 17,292.46 92.79 195.45 6,449.53 6,290.43 -10,392.46 -2,262.57 5,919,368.76 1,618,906.79 2.97 10,623.94 MWD+IFR-AK-CAZ-SC (5) 17,386.12 94.34 191.64 6,443.70 6,284.60 -10,483.32 -2,284.46 5,919,277.97 1,618,884.67 4.38 10,717.37 MWD+IFR-AK-CAZ-SC (5) 17,476.93 94.43 192.68 6,436.76 6,277.66 -10,571.83 -2,303.53 5,919,189.52 1,618,865.37 1.15 10,807.80 MWD+IFR-AK-CAZ-SC (5) 17,569.03 94.60 192.39 6,429.51 6,270.41 -10,661.45 -2,323.46 5,919,099.95 1,618,845.22 0.36 10,899.53 MWD+IFR-AK-CAZ-SC (5) 17,661.49 94.57 191.97 6,422.12 6,263.02 -10,751.54 -2,342.90 5,919,009.92 1,618,825.55 0.45 10,991.58 MWD+IFR-AK-CAZ-SC (5) 17,752.49 94.47 192.22 6,414.95 6,255.85 -10,840.24 -2,361.91 5,918,921.28 1,618,806.31 0.30 11,082.18 MWD+IFR-AK-CAZ-SC (5) 17,842.86 93.50 192.40 6,408.67 6,249.57 -10,928.32 -2,381.13 5,918,833.26 1,618,786.87 1.09 11,172.23 MWD+IFR-AK-CAZ-SC (5) 17,933.76 93.57 194.45 6,403.06 6,243.96 -11,016.57 -2,402.20 5,918,745.08 1,618,765.59 2.25 11,262.92 MWD+IFR-AK-CAZ-SC (5) 17,998.00 93.57 194.45 6,399.06 6,239.96 -11,078.65 -2,418.19 5,918,683.04 1,618,749.43 0.00 11,327.03 PROJECTED to TD 9/20/2016 11.35:06AM Page 7 COMPASS 5000.1 Build 74 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. B Yes ❑ No I have checked to the best of my ability that the following data Is correct: 0 Surface Coordinates 0 Declination & Convergence ❑ GRS Survey Corrections Vincentm_�^�^l�•n. Digttally signed by Vlnrent Osam p Survey Tool Codes u SCMumberger, ^� � OSUI^ a,5=berger, 'email.vosara�slb.mm r -U5 SLB DE: Dat¢g1116.09.7O 13]9:15-03'00' Client Representative: Date: 20 -Sep -2016 AOGCC C►r FROM: Sandra D. Lemke, AT0704 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: 2S-06 (216-085-0) DATE: 09/12/2016 Kuparuk River Unit, Alaska 2S-06 l Halliburton Mud log data TRANSMITTAL 1 CD (.pdf images) &1 color prints each log.- 12" og: 12" MD Formation Evaluation log 2" MD Drilling Engineering log 2" MD Gas ration log TO: Makana Bender AOGCC 333 W. 71h Ave., Suite 100 Anchorage, Alaska 99501 Please promptly sign, scan and return electronically to Sandra. D. Lemke(a)Conocophillips.com CC: 2S-06 transmittal folder, production well files, eSearch y(G-cr-6� 2`r5�S� DATA LOGGED 9 /W2o16 10. K. BENDER ==., GIS -Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 THE STATE Adam Klem 'ALASKA GOVERNOR BILL WALKER Completions Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2S-06 Permit to Drill Number: 216-085 Sundry Number: 316-471 Dear Mr. Klem: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.alaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this day of September, 2016. RBDMS U v SEP 2 2 2016 RECEIVED STATE OF ALASKA SEP 15 201b ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 ' Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 . Stratigraphic Service El 216-085 , 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20747-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2S-06 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 025603, 025608 Kuparuk River Field/ Kuparuk River Oil Pool e 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 19,508' 6,440' est. 4,400 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface 2,616 10-3/4" 2,657' 2,550' Intermediate 7,580' 7-5/8" 7,621' 6,358' Production Liner 7894' 4-1/2" 15,373' 6,372' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See attached schematic See attached schematic 3.5" L-80 7503' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): No SSSV 7179' MD, 6,265' TVD 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 26 -Sep -16 OIL 0 . WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Adam Klem @ 907-263-4529 Email Adam.Klem@conocophillips.com Printed Name Adam Kle Title: Completions Engineer Signature Phone 907-263-4529 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: —2-) — ki7 I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4-ISF � �c5 Irl Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Ln Subsequent Form Required: 1 D APPROVED BY RBDMSv SEP 2 2 2016 Approved by: COMMISSIONER THE COMMISSION Dater-��' Submit Fbrm and Form 10-403 Revised 11/201 fZt(;1it1nA1lid for 12 months�rom the dateopprovalSme/in Duplicate 2S-06 ConocoPhillips Grassroots Horizontal A -Sand Producer Final Wellbore Schematic(wp13) ✓ r'CAMERON 4 -%'tree, top joint is 41/' 12.6# IBVA 16" Conductor to --120' 13.5" Surface Hole 3-1/V' x 1" KBMG GLM Surface Casing (-50' TVD below W Sak) 10-314!'45.5# L-80 Hydril 563 2,667' MD / 2,551' TVD (21' INC) 9-7/8" x 11" Intermediate Hole Tubing: 3-112" 9.3 # L-80 EUE 8RD-MOD GLMO SOV Weatherford Stage Collar: 5.1.00' MD 15k Stage TOC(5125' MD): Top of BermudalCairn formation) ' alta 23ir C16W 51dmg Slw-e J 3-%" x 7518", Premier Packer „ - 3-1V 2.75" D Nipple 4 7-5t8" x 4-54" Baker ZXP PaccedFlex Lock Liner Hanger TDA 7,998' MD 16,399' TVD k"' svwraue. un. Intermediate Casing Production Liner. 6-3/4" Production Hole 7-518" 29.7# L-80 Hyd563 Casing 4-112" 12.6# L-80 TXP 7,620' MD 16,358' TVD (850 INC) 15,375' MD 16,410' ND (890 INC) Section 1 -Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). ConocoPhillips Alaska, Inc. To: Operator and Owners (shown on Exhibit 2) Date: September 15, 2016 Re: Notice pursuant to 20 AAC 25.283 (1) 2S-06 Well Kuparuk River Unit, Alaska ADL 25603, KRU Tract 90, and ADL 25608, KRU Tract 95 Dear Sirs: Julie D. Little Staff Landman ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-360 Telephone: (907) 265-6158 Facsimile: (907) 265-1441 Julie. D.Little@conocophillips.com ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2S-06 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about September 15, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on lease ADL 25603, KRU Tract 90 and ADL 25608, KRU Tract 95: Surface Location (ADL 25603): 3043' FNL, 1408' FEL, Section 17, T10N, R08E, UM Target Location (ADL 25603): 4150' FNL, 1300' FEL, Section 17, T10N, R08E, UM Bottomhole Location (ADL 25608): 1980' FNL, 3469' FEL, Section 29, T1 ON, R08E, UM Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon request, CPAI will provide a complete copy of the Application. Please contact me if you require any additional information. Very truly yours, �-c c ,De� lie Little Staff Landman cc: Adam Klem Rebecca Swensen 2S-06 Hydraulic Fracturing Notice Lettr, September 15, 2016 Page 2 of 3 Exhibit 1 08Sep16 i ConocoPhillips 5 Alaska, Inc. 25-06 N 2S-14 I Kuparuk Lease Plat o 0.15 os 0.45 os A ' River Miles Unit ADL025590 2S -13L1 2S-11 ADL025589 1' is �+ 10 ADL390*0 I 25-04 2S-07 SOut+n Nliluv*ch 2S-05 Uni Y2 mile radius 17 2S-04PB1 from Well 2S -13P81 T' R8E F 10N R7E ADL025603 ADL025604 ADL380 1 2S-12PB1 20 2S-12 2S-03PB1 2S-01 2S-08 2S-10 29 2S-03 • Frac Points 02560 2S-06 Open Interval ADL025607 — 2S-06 Trajectory Well Within Trajectory Radius ❑ 1/2 Mi. Frac Point Radius ❑ 1/2 Mi. Trajectory Radius ------- ---------------- -- i ----------�_�_____------1. �+ Kuparuk PA ElBRPC Lease 32 33 gq ❑ CPAI Lease 2S-06 Hydraulic Fracturing Notice Lett. September 15, 2016 Page 3 of 3 Exhibit 2 Mineral Owners: Operators: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non -Operators BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. John Dittrich Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Dave White ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7t" Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director TO THE —ASKA OIL AND GAS CONSERVATION CO&.....SSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Julie D. Little Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 2S-06 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA M THIRD JUDICIAL DISTRICT Julie D. Little, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Julie D. Little, and I have personal knowledge of the matters set forth herein. 2. 1 am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAP') 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On or about September 15, 2016, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 15th day of September, 2016. Julie D. Little STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 15th day of September, 2016, by Julie D. Little. Notary Public, State of Alaska My Commission Expires: STATS OF ALASKA NOTARY PUBLIC REBECCA SWEN8EN Comn"sion V, 2020. Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2S-06 Landowners 08Sep16 i ConocoPhillips 6 Alaska, Inc. 2S-06 2S 14N .......... - Lease Plat 0 0.15 0.3 0.45 0.6 j Kuparuk River Miles Unit ±_ ADL025590 2S-1311 25-11 ADL025589 8 9 i0 L ADL390*0 2S-04 2S-07 Southern Miluv ° ch 2S-05 U'T I \1 2s-02 13 18' 16 15 2S-13PB1 2S -04P81 I ! / R8E l 1ON R7E 0 5603 ADL025604 ADL380 1 I / 2S-12PB1 / 2 19 20 21 / 2S-12 2S-03PB1 2S�01' 2S-08 2S-10 z2S-03 29 28 2?____ • Frac Points 02560 ; 2S-06 Open Interval ADL025607 — 2S-06 Trajectory -- Well Within Trajectory Radius ❑ 1/2 Mi. Frac Point Radius ! ❑ 1/2 Mi. Trajectory Radius �-------- ----- ----- ---------- �? Kuparuk PA 0 BRPC Lease i 32 33 34 ❑ CPA[ Lease Table 1: Wells within .5 miles API WELL NAME STATUS WELL -TYPE 501032072700 25-01 ACTIVE PROD 501032071000 25-02 ACTIVE INJ 501032072900 25-03 ACTIVE PROD 501032072970 2S-03PB1 PA EXPEND 501032072100 25-04 ACTIVE PROD 501032072170 2S-04PB1 PA EXPEND 501032073900 2S-05 ACTIVE PROD 501032071300 2S-07 ACTIVE PROD 501032072200 25-08 ACTIVE PROD 501032071700 2S-10 ACTIVE PROD 501032073200 25-11 ACTIVE PROD 501032074300 25-12 ACTIVE PROD 501032074370 2S-12PB1 PA EXPEND 501032072000 25-13 PROP SVC 501032072060 1 25-131-1 PROP SVC 501032072070 2S-13PB1 PA EXPEND 501032073300 25-14 ACTIVE PROD SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North Slope described by a %4 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field". SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. ✓ SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 8/21/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg Lead Deep Crete cement and 15.8 ppg tail cement. Took cement returns to surface. The plug bumped at 1,150 psi and the floats were checked and they held. The 7-5/8" casing cement report on 8/28/2016 shows that the job was pumped as designed, indicating competent cementing operations. The first stage was pumped with 15.8 ppg class G cement. Full returns were seen throughout the job. The plug was bumped and the floats were checked and they held. TOC was observed with logging tools at 5125' MD for the first stage cement job Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 8/23/2016 the 10 & 3/4" casing was pressure tested to 3500 psi. On 8/31/2016 the 7 & 5/8" casing was pressure tested to 3500 psi. The 7 5/8" casing will be pressure tested to 4,000psi post rig prior to frac AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 5,000 Annulus pressure during frac 3,600 Annulus PRV setpoint during frac 3,700 7 5/8" Annulus pressure test 4,000 3 1/2" Tubing pressure Test 5,000 Nitrogen PRV 7,100 Highest pump trip 6,900 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & %11 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Pressure Ratings Stimulation Surface Rig -Up Bleed! Tattle Tale Tank d vrzy N > 09 C U Ncrul dwnd Pop -Off Tank Frac Pump Frac Pump Frac Pump Frac Pump Frac Pump Frac Pump ,Tiede. L6mannortal inreymation reft-ted on fit isdrao ng are estmxtcJ MOMureme;nts Only. 10K Frac Tree 6.5 OTIS IIIIIIIIII ConocoPhillips Drill Site 2S- lOK Frac Tree ,CAMERON Wellhead with 10K Frac Tree 15 5 OTJS 4" 1002 1002 1 0,CKYJ 9 OR J(I /.19' op 0 Mix, [if TI.I,;qvf k ik,= t3,.U' Conor Phillips CAO DTIII Sle 75, PxKiuce.-� wl 1 UK 1 t ve IOT 10.010up 4-111,.)- 1U,UUUI x2* i 511 --L-16" — 1 U --V41 C'CAMERON SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Kuparuk A sand interval, is approximately 107' TVT at the heel, with the top of the Kuparuk A at -6,181' TVDSS (7,497' MD) and 100' TVT at the toe of the well, with the top Kuparuk A at -6,265' TVDSS. The Kuparuk A interval is composed of multiple packages of very fine grained, quartz rich sandstone, separated by laterally continuous shale interbeds. The estimated fracture pressure for the Kuparuk A is 13.1 ppg. The overlying confining zone has an overall thickness of 317' TVT (880' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at -5,856' TVDSS (6,566' MD). The estimated fracture pressure for the overlying confining layer is 16 ppg. The underlying confining zone consists of the Miluveach interval, a marine shale, approximately 500' thick. The estimated fracture pressure for the Miluveach is 15.5 ppg. The top of the Miluveach is located at approximately -6,280' TVDSS at the heel (the Miluveach interval was not penetrated in the 2S-06 wellbore). SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2S-04: The 7 & 5/8 casing cement pump report on 10/18/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, followed by 16 ppg tail cement. The plug bumped at 717 psi and the floats were checked and they held. 2S-04 PBI: 2S-04 PB1 was plugged and abandoned per state regulations on 10/12/2015. 2S-08: The 7 & 5/8 casing cement pump report on 11/15/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.1 ppg mud. The plug bumped at 1,400 psi and the floats were checked and they held. 2S-07: The 7 & 5/8 casing cement pump report on 8/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.3 ppg cement, displaced with 10.6 ppg mud. The plug bumped at 1,251 psi and the floats were checked and they held. 2S-10: The 7 & 5/8 casing cement pump report on 9/2/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 10.5 ppg mud. The plug bumped at 1,450 psi and the floats were checked and they held. 2S-06 Fracture Stimulation Area of Review WELL NAME STATUS Casing Size Top of A -sand Oil Top of A -Sand Top of Cement Top of Cement Top of Cement Reservoir Status Zonal Isolation Cement Operations Mechanical Integrity Pool (MD) Oil Pool (TVDSS) (MD) (TVDSS) Determined By Summary TOC 5,125' &Packer @ 7,179' 7-5/8" casing 2S-06 PROD 7-5/8" 7,497' 6,181' 5,125' 4,738 Sonic Log Frac sleeves ready to frac 738 sx 15.8ppg Class G pressure tested to V ✓ MD 3500 psi on 9/11/16 CBL TOC 6,010' & Packer @ Casing tested to 3500 2S-04 [NJ 7 & 5/8" 8,529' 6,228' 6,010' 4,875' Sonic Log Slotted liner open 458 sx class G for 30 mins on v 8,546' MD 10/22/15 2S-04PB1 PA 7 & 5/8" N/A N/A Plug @ 6,435' 5,196' Calculated PA Cement Plug @ 6,435' 123 bbls 15.8 ppg GasBLOK N/A 25-07 [NJ 7 & 5/8" 8,004' 6,311' TVD 4,900' 4,185' Sonic Log Slotted liner open TOC 4,900' & Packer @ 7,720' 377 sx GasBLOK, 155 sx Passing MITIA to MD GasBLOK 3000 psi on 9/5/15 25-10 INJ 7 & 5/8" 8,102' 6,264' 5,335' 4,800' Sonic Log Slotted liner open CBLTOC 5,335' & Packer @ 365 sx Class G, 130 sx Class G Passing MITIA to 8,085' MD 3500 psi on 9/19/15 SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are 13 mapped faults that transect the Kuparuk A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2S-06. The north -south trending faults around 2S-06 terminate between the HRZ and C-35 in lithology that consists of silts and shales in this area with an estimated fracture pressure of -16 ppg. Six sub -seismic faults intersect the 2S-06 wellbore. Sub -seismic faults #1 - #5 (see 2S-06 table) terminate within the confining layer. Fault #6 terminates near the C-35. The C-35 in this area consists of shales and siltstone lithologies with an estimated fracture pressure of -16ppg. By design, fault #6 is isolated from any frac points. Two of the 13 mapped faults intersect the 2S-08 wellbore. No losses were observed at any of the fault crossings during drilling of the 2S-08 or the 2S-06 lateral sections. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. 25-06 Faults MD (feet) SSTVD (feet) Throw in feet Fault #1 (A4/A4) 8,441 -6,220 4 (DTS) Fault #2 (A4/A4) 10,379 -6,200 5 (DTS) Fault #3 (A4/A4) 11,065 -6,200 4 (DTN) Fault #4 (A4/A4) 12,132 -6,205 6 (DTS) Fault #5 (A4/A4) 13,581 -6,235 4 (DTS) Fault #6 (A4/Kalubik) 15,424 -6,211 32 (DTS) 25-08 Faults MD (feet) SSTVD (feet) Throw in feet Fault #1 (A4/A4) 8612 6158 10 (DTS) Fault #2 (A4/A4) 10140 6132 10 (DTN) The effective fracture length is estimated to be 760' and 2S-06 is more than 800+' from mapped faults that do not transect the wellbore. All of the fractures will be longitudinal, running parallel to the 2S-06 wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. Plat 2: Fault Analysis 08Sepi6 . . ConocoPhllllps i Alaska, Inc. 2S-06 Fault Analysis Plat ' " I ,fN 0 0.15 0.3 0.45 0.6 �\ 1 ADL025590 Miles r v ADL390680 i e ADL025589 I2S_04 25-07 Southern I Miluveachl Kuparuk Unit River _-_--� Unit 17 2S-04PB1 ., 1E T10N WE ADL380051 ADL025603 I j T N E I 13 29 ADL025604 2508 25-10 • Frac Points — Faults Within Confining Zone 2S-06 Open Interval _: — 2S-06 Trajectory ADL025 ADL025607 — Well Within Frac Point Radius ❑ 1/2 Mi. Frac Point Radius ❑ 1/2 Mi. Trajectory Radius L3 Kuparuk PA 99 BRPC Lease ❑ CPAI Lease ------------- 72 -------------- ----------- 3----__--__–__– SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2S-06 was completed in 2016 as horizontal producer in the Kuparuk A sand formation. The well will be completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1 st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (A Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 20 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 21,582 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 500 bbl breakdown stage (35# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 25 BPM as quick as possible, pressure permitting. Increase annulus pressure to 3,600 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 5,000 psi. 2-5 35# H borG CUSTOMER LEASE FORMATION ConocoPhillips 25-06 Kuparuk A Sands 3.50 API SALES ORDEI DATE 50-103-20747 190 BFD (Ib/gol) BHST (°F) Max Pressure ( 165 HALLIBURTON 70.2199243 _ _ _ -150.151976 I 0:17:19 Liquid Additives 0.50 0.90 0.45 DryAdditives 0.15 Treatment Interval Stage Number Fluid Description Stage Description Proppant Description Prop Conc (ppg) Slurry Rate (bpm) Clean Volume (got) Clean Volume (bbl) Slurry Volume (bbl) Prop Total (Ibs) Stage Time (hh:mm:ss) Interval Time (hh:mm:ss) Lo -Surf 3000 Surfactant NO MO -67 Buffer (gpt) CL -22 UC Crosslinker (gpt) CL -31 LVT-200 Crosslinker n, Prote (gptJ f e NO WG -36 Gel 10170 BE -6 Biocide (ppt) Opti Flo -III Breaker (0120 OptlFlo-ll SP Breaker Breaker (ppt) (ppt) 0.25 1-1 35# H bor G Load Well 5 1000 24 24. 0:04:46 1:35:00 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 3-1 1-2 35# Hybor G Mini -Frac 0.25 25 25 21000 500 Soo 0:24:05 0:20:00 1:30:14 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 35# Hybor G 1-3 35# Linear Flush 25 7,770 185 185 0:38:45 0:07:24 1:10:14 1.00 0.45 35.00 0.15 35.00 0.15 2.00 0.25 ,o 1-4 Shut -In Shut -In 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 1:02:50 0.45 35.00 0.15 2.00 0.25 3-3 35# H borG Proppant Laden Fluid y e 1-5 35# HyborG Pad 100 mesh 0.25 25 25000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 ¢ Zxzo 25 35# Hybor G SSA -1 Silica Flour 0.035 0:08:40 0:25:59 1.00 0.50 875 0.45 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 � 0 1-6 35# Hybor G Pro ant Laden Fluid Wanli 20/40 1.00 25 5000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 7,000 1-7 35# Hybor G Proppant Laden Fluid Wanli 20/40 2.00 25 7500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 Y ' 1-8 35# Hybor G Pro ant Laden Fluid WanIi 20/40 3.00 25 8000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 602 1-9 35# Hybor G Proppant Laden Fluid Wank 20/40 3.50 25 8000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 875 1-10 35# Hybor G Proppant Laden Fluid Wanli 20/40 4.00 25 7000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 0:04:59 1-11 35# Hybor G 5 a er & DropBall 1.875" 0.90 0.45 25 630 15 15 4-3 0:00:36 0:00:36 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 u. 2-1 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 c a 0.50 35# Hybor G 0.45 SSA -1 Silica Flour 0.035 2.00 0.25 4-5 35# Hybor G 875 Wanli 20/40 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 sv v o 2-2 35# Hybor G Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 _ rn ¢ 7 2-3 35# HyborG Proppant Laden Fluid Wanli 20/40 2.00 25 7,500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 n 2-4 35# HyborG Pro pant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 2-5 35# H borG Proppant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 2-6 35# HyborG Proppant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 2-7 35# Hybor G Spacer & Drop Ball 1.938" 25 630 15 15 0:00:36 0:00:36 1.00 0.50 0.90 GAS 35.00 0.15 2.00 0.25 3-1 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 35# Hybor G SSA -1 Silica Flour 0.035 875 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 3-2 35# H bor G Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 3-3 35# H borG Proppant Laden Fluid Wanli 20/40 2.00 25 7,500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 3-4 35# Hybor G Proppant Laden Fluid WanIi 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 3-5 35# H borG Proppant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 3-6 35# Hybor G Pro ant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0:90 0.45 35.00 0.15 2.00 0.25 3-7 35# Hybor G Spacer & Drop Ball 2.000" 25 630 35 15 0:00:36 0:00:36 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 4-1 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 35# Hybor G SSA -1 Silica Flour 0.035 875 0:38A5 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 4-2 35# Hybor G Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 4-3 35# HyborG Proppant Laden Fluid Wanli 20/40 200 25 7,500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 4-4 35# Hybor G Proppant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59rl.w.:.11 0.50 0.90 0.45 35.00 0.15 2.00 0.25 4-5 35# Hybor G Proppant, Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:190.50 0.90 0.45 35.00 0.15 2.00 0.25 4-6 35# Hybor G Prop ant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:290.50 0.90 0.45 35.00 0.15 2.00 0.25 4-7 35# HyborG Spacer& Drop Ball 2.063" 25 630 15 15 0:00:36 0:00:360.50 0.90 0.45 35.00 0.15 2.00 0.25 5-1 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:08:140.50 0.90 0.45 35.00 0.15 2.00 0.25 35# Hybor G SSA -1 Silica Flour 0.035 875 0:44:090.50 0.90 0.45 .3 00 0.15 2.00 0.25 5-2 35# H borG Pro ant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59044:0900 0.50 0.90 0.45 35.00 0.15 2.00 0.25 x .;;5-3 35# Hybor G Proppant Laden Fluid Wanli _ 5-4 35# Hybor G Proppant Laden Fluid Wanli r n 2-535# H bor G Pro ant Laden Fluid Wanli 5-6 35#H borG Pr.pp.nt La den Fluid I Wanli 5-7 35# Linear Flush 167 150 0:08:50 0:22:43 1.00 0:07:53 0:13:53 1.00 0:06:00 0:06:00 1.00 0.45 1 1 35.00 1 0.15 1 2.00 1 0.25 1 1 ConocoPhillips - 2S-06 Planned Design 1 8-1 354 Hybor G CUSTOMER LEASE FORMATION Conoco Phillips 25-06 Kuparuk A Sands 0.25 API SALES ORDEI DATE 50-103-20747 595 BFD (Ib/gal) BHST (°F) Max Pressure( 165 N LISUATM ". 70.2199243 _ _ _ -150.151976 1:02:50 Liquid Additives 0.50 0.90 0.45 Dry Additives 0.15 Treatment Interval Stage Number Fluid Description Stage Description Proppant Description Prop Conc (ppg) Slurry Rate (bpm) Clean Volume (gal) Clean Volume (bbl) Slurry Volume (bbl) Prop Total (lbs) stage Time (hh:mm.ss) Interval Time (hh.mm:ss) Lo -Surf 300D Surfactant (9pt) MO -67 Buffer (9110 CL -22 UC Crosslinker (9110 CL -31 LVT-200 Crosslinker F-eProtec (9110 (9pt) WG -36 Gel (ppt) BE -6 Bloade (ppt) OptlFlo-III Breaker (PPI) OptlFlo-II SP Breaker Breaker (PPI) (ppt) 0.25 6-1 35# Hybor G Spacer & Drop Ball 2.125" Wanli 20/40 1.00 25 630 15 15 5,000 0:00:36 1:03:26 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 LL 6-2 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 ar c e Proppant Laden Fluid 35# Hybor G 3.00 SSA -1 Silica Flour 0.035 190 215 24,000 0:08:40 875 1.00 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 Proppant Laden Fluid 6-3 35# Hybor G Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 zx�„ 6-4 35# Hybor G Proppant Laden Fluid Wanli 20/40 2.00 25 7,500 1 179 194 1 1S,000 0:07:48 1 0:33:46 1.00 0.50 0.90 1 0.45 35.00 1 0.15 2.00 0.25 c o _ a 6-5 354 Hybor G Proppant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59V1.00 0 0.50 0.90 0.45 35.00 0.15 2.00 0.25 Y 6-6 35# HyborG Proppant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28 000 0:08:50 0:17:190 2.00 0.50. 0.90 0.45 35.00 0.15 2.00 0.25 6-7 35# HyborG Proppant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:290 0.25 0.50 0.90 0.45 35.00 0.15 2.00 0.25 119 6-8 35# HyborG Spacer & Drop Ball 2.188" 0:38:45 1.00 25 630 15 15 0.15 0:00:36 0:00:360 9-3 0.50 0.90 0.45 35.00 0.15 2.00 0.25 LL 7-1 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:500 35# Hybor G 0.50 0.90 0.45 35.00 0.15 2.00 0.25 24,000 0:08:40 35#H bore 1.00 SSA4 Silica Flour 0.035 0.45 35.00 0.15 2.00 875 9-5 0:38:450 Proppant Laden Fluid 0.50 0.90 0.45 35.00 0.15 2.00 0.25 w , vv'i w 7-2 35# HyborG Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 Wanli 20/40 0.50 0.90 0.45 35.00 0.15 2.00 0.25 y�ua 7-3 35# HyborG Pro ant Laden Fluid Wanli 20/40 2.00 25 7 500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 c 2 n a 7-4 35# Hybor G Proppant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 a 0 7-5 35# Hybor G Pro ant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 Y m 7-6 35# Hybor G Pro pant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 0.45 7-7 35# Hybor G Spacer & Drop Ball 2.250" 0.25 10-3 25 630 15 15 25 0:00:36 0:00:36 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 8-1 354 Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 35# Hybor G SSA -1 Silica. Flour 0.035 875 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 8-2 35# Hybor G Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 8-3 35# Hybor G Proppant Laden Fluid Wanli 20/40 2.00 25 7,500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 8-4 35# HyborG Proppant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 8-5 35# HyborG Proppant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 8-6 35# Hybor G Proppant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 8-7 35# HyborG Spacer & Drop Ball 2.313" 25 630 15 15 0:00:36 0:00:36 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 9-1 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 35# Hybor G SSA -1 Silica Flour 0.035 875 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 9-2 35# Hybor G Pro ant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 9-3 35# H bore Proppant, Laden Fluid Wanli 20/40 2.00 25 7,500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 9-4 35# Hybor G Pro pant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 9-5 35# Hybor G Proppant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 9-6 35# Hybor G Proppant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 9-7 35# Hybor G Spacer & Drop Ball 2.375" 25 630 15 15 0:00:36 0:00:36 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 10-1 35# HyborG Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:06:34 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 35# Hybor G SSA -1 Silica Flour 0.035 875 0:42:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 10-2 35# Hybor G Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:42:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 10-3 35# Hybor G Proppant Laden Fluid Wanli 20/40 2.00 25 7,500 179 194 15,000 0:07:48 0:37:30 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 10-4 35# Hybor G Proppant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:29:43 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 30-5 35# H borG Proppant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:21:03 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 0.25 Y �`O 10-635# HyborG Pro ant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:12:13 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 0.25 10-7 35# Linear Flush 25 4,547 1 108 108 0:04:20 0:04:20 1 1.00 1 35.00 0.15 2.00 0.25 1 0.5 COIIOCOPhillips - 2S-06 Planned Design 2 CUSTOMER Con -Phillips LEASE 25-06 API 50-103-20747 BFD (Ib/gal) HALLIBUR 70.2199243 SALES ORDEI BHST (°F) 165 _ -150.151976 Fluid Type Design Total (got) 35# Linear 21,802 35# Hybor G 877,190 Freeze Protect 840 899,832 21,425 22,960 1,499,750 15:28:36 FORMATION Kupamk A Sands CL -31 DATE 87,500 BE -6 Max Pressure ( OptiFlo-II SF (91, (gpm) Liquid Additives (gpm) Total (lbs) ppm PPm DryAdditives MO -67 CL-22UC Treatment Interval Stage Number Fluid Description Stage Description Proppant Description Prop Conc (ppg) Slurry Rate (bpm) Clean Volume (gal) Clean Volume (bbl) Slurry Volume (bbl) Prop Total (lbs) Stage Time (hh:mm:ss) Interval Time (hh:mm:ss) Lo-Surf300D Surfaaant (opt) MO -67 Buffer (opt) CL-22UC Grosslinker (opt) CL -31 LVF -200 Crosslinker eze Prote (gpt) re(gpt) WG -36 Gel (Ppt) BE -6 Blocide (ppt) OptiFlo-III Breaker (Apt) Opti Flo -ll Breaker (Apt) SP Breaker (ppt) 134.8 1 1,796.7 11-1 35# Hybor G Spacer & DropBall 2.438" 25 630 15 15 0:00:36 1:03:26 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 LL 11-2 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 'c 35# Hybor G SSA -1 Silica Flour 0.035 875 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 w 0 11-3 35# H borG Proppant Laden Fluid WanIi 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 A6 a 11-4 35# Hybor G Proppant Laden Fluid Wanli 20/40 2.00 25 7,500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 c ` m 11-5 35# H bor G Proppant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 _ 3 x @J vi 11-6 35#Hybor G Proppant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 11-7 35#H borG Proppant Laden Fluid Wanli 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 11-8 35# H bor G Spacer & Drop Ball 2.500" 25 630 15 15 0:00:36 0:00:36 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 LL 12-1 35# Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 '^ 35# Hybor G SSA -1 Silica Flour 0.035 875 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 12-2 35# HyborG Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 12-3 35# Hybor G Proppant Laden Fluid WanIi 20/40 2.00 25 7,500 .179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 x w c m m 12-4 35# Hybor G Proppant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 - o.� 12-5 35# Hybor G Proppant Laden Fluid WanIi 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 Y 12-6 35# Hybor G Proppant Laden Fluid WanIi 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 12-7 35# Hybor G Spacer & Drop Ball 2.563" 25 630 15 15 0:00:36 0:00:36 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 LL 13-1 354 Hybor G Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:02:50 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 35# H bore SSA -1 Silica Flour 0.035 875 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 c o 'a in c 13-2 35# Hybor G Proppant Laden Fluid Wanli 20/40 1.00 25 5,000 119 124 5,000 0:04:59 0:38:45 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 Z N 13-3 35# HyborG Proppant Laden Fluid Wanli 20/40 2.00 25 7,500 179 194 15,000 0:07:48 0:33:46 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 3 a w 134 35# Hybor G Proppant Laden Fluid Wanli 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:25:59 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 h13-5 35# HyborG Proppant Laden Fluid Wanli 20/40 3.50 25 8,000 190 219 28,000 0:08:50 0:17:19 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 Y 13-6 35#Hybor G Proppant: Laden fluid WanIi 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:08:29 1.00 0.50 0.90 0.45 35.00 0.15 2.00 0.25 13-7 35# HyborG Spacer & DropBall 2.625" 25 630 15 15 0:00:36 0:00:36 1.00 0.50 0.90 0.45 35.00 0.15 2.00 14-1 35# HyborG Pad 100 mesh 0.25 25 25,000 595 602 6,250 0:24:05 1:09:16F1011))0.50 0.90 0.45 35.00 0.15 2.00 LL 35# HyborG SSA -1 Silica Flour 0.035 875 0:45:110.50 0.90 0.45 35.00 0.15 2.00 _ 14-2 35# HyborG Pro pant Laden Fluid WanIi 20/40 1.00 25 5,000 119 124 S,D00 0:04:59 0:45:110.50 0.90 0.45 35.00 0.15 2.00 14-3 35# HyborG Proppant Laden Fluid WanIi 20/40 2.00 25 7,500 179 194 15,000 0:07:48 0:40:120.50 0.90 0.45 35.00 0.15 2.00 L0.25 14-4 35# Hybor G Proppant Laden Fluid WanIi 20/40 3.00 25 8,000 190 215 24,000 0:08:40 0:32:240.50 0.90 0.45 35.00 0.15 2.00 m„ 14-5 35# Hybor G Proc ppant Laden Fluid WanIi 20/40 350 25 8,000 190 219 28,000 0:08:50 0:23:450.50 0.90 0.45 35.00 0.15 2,00 14-6 35# HyborG Proppant Laden Fluid WanIi 20/40 4.00 25 7,000 167 195 28,000 0:07:53 0:14:550.50 0.90 0.45 35.00 0.15 2.00 14-735#LinearFlush 25 3,180 76 76 0:03:02 0:07:02 35.00 0.15 2.00 14-8 Freeze Protect Freeze Protect 5 840 20 20 0:04:00 0:04:00 1000.00 Fluid Type Design Total (got) 35# Linear 21,802 35# Hybor G 877,190 Freeze Protect 840 899,832 21,425 22,960 1,499,750 15:28:36 MO -67 S5A-1 silica Flour CL -31 100 mesh 87,500 BE -6 OptiFlo-III OptiFlo-II SF (91, (gpm) (9Pm) (gpm) Total (lbs) ppm PPm Lo-Surf300D MO -67 CL-22UC CL -31 Lrr-200 ALG -_36 BE -6 Opti Flo -III OptiFlo-II SP 1,400,000 0.5 1,050.0 (gal) (gal) (golf (gol) (gal) lbs lbs lbs lbs lbs 12,250 0.1 Initial Design Material Volumel 899.0 1 438.6 1 789.5 1 394.7 1 840.0 1 31,442.71 134.8 1 1,796.7 1 224.6 1 18.3 Proppant Type WanIi 20/40 MO -67 S5A-1 silica Flour CL -31 100 mesh 87,500 BE -6 OptiFlo-III OptiFlo-II SF COnocoPhIlllps - 25-06 Planned Design Lo-Surf300D MO -67 CL-22UC j CL -31 I LVT-200 WG -36 BE -6 OptiFlo-III OptiFlo-II SF (91, (gpm) (9Pm) (gpm) (gPm) ppm PPm PPm PPm PPm Max Additive Rate 1.1 0.5 0.9 0.5 1,050.0 36.8 0.2 2.1 03 0.5 Min Additive Rate 0.2 0.1 0.2 0.1 210.0 7.4 0.0 0.4 0.1 0.1 l • L,J ✓ Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 2016-09-10 State: Alaska County: Harrison Bay API Number: 6010320747 CONOCO PHILLIPS Operator Name: NORTH SLOPE EBUS Well Name and Number: 2S-06 Longitude: 0 Latitude: 0 Long/Lat Projection: Production Type: True Vertical Depth (TVD): 0 Total Water Volume (gal)*: 898,992 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Ingredient Mass Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Comments Number (CAS (% by mass)** HF Fluid (% by lbs #) mass)** Sea Water Operator Base Fluid NA NA 100.00`; 82.924330 7596458 Density = 8.450 BE -6 MICROBIOCIDE, CL -22 UC, CL -31 CROSSLINKER, LOSURF-300D, MO -67, OPTIFLO- II DELAYED Additive, Biocide, RELEASE Breaker, Crosslinker, BREAKER, Halliburton Gelling Agent, NA NA 0 NA OPTIFLO-III Microbiocide, Non-ionic DELAYED Surfactant, pH Control RELEASE Additive, Proppant BREAKER, SAND - COMMON WHITE - 100 MESH, SSA -2, 2500 LB SACK, SP BREAKER, WG -36 GELLING AGENT Silica Flour Halliburton Proppant NA NA 0 NA LVT-200 penreco Additive NA NA 0 NA Xinmi Wanli 20/40 Wanli Industry Proppant NA NA 0 NA Developmen t Co., Ltd 1,2,4 Tri methyl benzene 95-63-6 1.00`; 0.000740 68 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.000 0.00206% 189 Denise Tuck, Halliburton, 3000 Acrylate polymer Confidential 1.00% 0.00101% 93 N. Sam Houston Pkwy E., Houston, TX 77032,281- 871-6226 Ammonium persulfate 7727-54-0 100.00% 0.02207% 2022 Bentonite, benzyl(hydrogenated tallow alkyl) dimethylammonium 121888-68-4 5.00% 0.01716% 1573 stearate complex Borate salts Confidential 60.00% 0.06080% 5570 Corundum 1302-74-5 55.00% 6.40546% 770001 Crystalline silica, quartz 14808-60-7 100.00% 1.09512% 100325 Crystalline Silica, Quartz 14808-60-7 0.10% 0.00034% 32 Cured acrylic resin Confidential 30.00% 0.00662% 608 Ethanol 64-17-5 60.00% 0.04428% 4057 Guar gum 9000-30-0 100.00% 0.34324% 31443 Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02214% 2029 Hydrotreated Distillate, Light..C9-16 64742-47-8 100.00% 0.06336% 5805 Mullite 1302-93-8 45.00% 6.87720% 630001 Naphthalene 91-20-3 5.00% 0.00369% 339 Oxyalkylated phenolic resin Confidential 30.00% 0.02952% 2706 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 branched 5.00% 0.00369% 339 Potassium formate 590-29-4 60.00% 0.06080% 5570 Potassium hydroxide 1310-58-3 5.00% 0.00235% 216 Potassium metaborate 13709-94-9 60.00% 0.02823% 2586 Silica gel 112926-00-8 1.00% 0.00343% 315 Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00101% 93 Sodium chloride 7647-14-5 1.00% 0.00152% 140 Sodium glycollate 2836-32-0 1.00% 0.00101% 93 Sodium hydroxide 1310-73-2 30.00% 0.01530% 1402 Sodium persulfate 7775-27-1 100.00% 0.00021% 19 Sodium sulfate 7757-82-6 0.10% 0.00000% 1 Surfactant mixture Confidential 1.00% 0.00686% 630 Water 7732-18-5 100.00%1 0.10963% 110044 Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. �1s All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 2016-09-10 State: Alaska County: Harrison Bay API Number: 5010320747 CONOCO PHILLIPS Operator Name: NORTH SLOPE EBUS Well Name and Number: 2S-06 Longitude: 0 Latitude: 0 Long/Lat Projection: Production Type: True Vertical Depth (TVD): 0 Total Water Volume (gal)*: 898,992 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Ingredient Mass Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Comments Number (CAS (% by mass)** HF Fluid (% by lbs #) mass)** Sea Water Operator Base Fluid NA NA 100.00% 82.92433% 7596458 Density = 8.450 BE -6 MICROBIOCIDE, CL -22 UC, CL -31 CROSSLINKER, LOSURF-300D, MO -67, OPTIFLO- II DELAYED Additive, Biocide, RELEASE Breaker, Crosslinker, BREAKER, Halliburton Gelling Agent, NA NA 0 NA OPTIFLO-III Microbiocide, Non-ionic DELAYED Surfactant, pH Control RELEASE Additive, Proppant BREAKER, SAND - COMMON WHITE - 100 MESH, SSA -2, 2500 LB SACK, SP BREAKER, WG -36 GELLING AGENT Silica Flour Halliburton Proppant NA NA 0 NA LVT-200 penreco Additive NA NA 0 NA Xinmi Wanli 20/40 Wanli Industry Proppant NA NA 0 NA Developmen t Co Ltd 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00074% 68 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00% 0.00206% 189 Denise Tuck, Halliburton, 3000 Acrylate polymer Confidential 1.00% 0.00101% 93 N. Sam Houston Pkwy E., Houston, TX 77032,281- 871-6226 Ammonium persulfate 7727-54-0 100.00% 0.02207 % 2022 Bentonite, benzyl(hydrogenated tallow alkyl) dimethylammonium 121888-68-4 5.00% 0.01716% 1573 stearate complex Borate salts Confidential 60.00%1 0.06080% 5570 Corundum 1302-74-5 55.00% 8.40546% 770001 Crystalline silica, quartz 14808-60-7 100.00% 1.09512% 100325 Crystalline Silica, Quartz 14808-60-7 0.10% 0.00034% 32 Cured acrylic resin Confidential 30.00% 0.00662% 608 Ethanol 64-17-5 60.00% 0.04428% 4057 Guar gum 9000-30-0 100.00% 0.34324% 31443 Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02214% 2029 Hydrotreated Distillate, Light..C9-16 64742-47-8 100.00% 0.06336% 5805 Mullite 1302-93-8 45.00% 6.87720% 630001 Naphthalene 91-20-3 5.00% 0.00369% 339 Oxyalkylated phenolic resin Confidential 30.00% 0.02952% 2706 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 branched 5.00% 0.00369% 339 Potassium formate 590-29-4 60.00% 0.06080% 5570 Potassium hydroxide 1310-58-3 5.00% 0.00235% 216 Potassium metaborate 13709-94-9 60.00% 0.02823% 2586 Silica gel 112926-00-8 1.00% 0.00343% 315 Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00101% 93 Sodium chloride 7647-14-5 1.00% 0.00152% 140 Sodium glycollate 2836-32-0 1.00% 0.00101% 93 Sodium hydroxide 1310-73-2 30.00% 0.01530% 1402 Sodium persulfate 7775-27-1 100.00% 0.00021% 19 Sodium sulfate 7757-82-6 0.10% 0.00000% 1 Surfactant mixture Confidential 1.00% 0.00686% 630 Water 7732-18-5 100.00% 0.10963% 10044 Total Water Volume sources may include fresh water, produced water, and/or recycled water _ ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. �1s All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is submect to 29 CFR 1910.1200(i) and Appendix D. 2S-06 Kuparuk A Sand Multi-stage Frac Model Frac Design Stage 1-14 Stage a Elapsed Stage Fluid Clean Stage Curn, Clean Proppant Slurry Cum Slurry Cum Slurry.BBL Clean Fluid Time.mm:ss Time.mm:ss VoLGAL VoLGAL Conc.PPA Prcippant.LB Rate.BBLIM Rate,BBLIM 0:00 24:05 HyborG_35 =_225 -Vicon-. 5 25000.00 25000,00 White Frac 100 Mesh 0.25 6250,00 25.00 602,00 24.72 "2+05 4:58 HyborG_35=_225-Vicon-. 5 5000.00 30000.00 WANLI LITE 20140 1 1.00 11250.00 25.00 726.34 23.93 29:03 7:47 HyborG_35= 225 Vicon .5 7500.00 37500.00 WANLI LITE 20/40 2.00 26250.01 25.00 920.81 22,96 36:50 8:38 HyborG 35= 225 -Vicon -. 5 3000.00 45500.00 IWANLI LITE 20/40 3.00 50250,01 25.00 1136.71 22.06 45:28 8:48 HyborG 35= 225 - Vicon-, 5 8000.00 53500.00 FWANLI CITE 20/40 3.50 78250X1 25.00 1356.85 21.63 54:16 7:51 HyborG-35=-225Vicon-.5 7000.00 60500,00 IWANLI LITE 20*::] 4.00 106250.00 25.00 1553.19 21.22 1:02.08 6-40 5 22 5 -Vicon -. 5 HyborG -3 =- 7000,00 67500.00 EwANLI LITE 20/40 0.00 106250.00 25.00 1719,85 25.00 11:03:48 .... ..... .... .......... .................. . : .................. I I I I .......... I .......... ...... . ..... 67500.00 106250,00 1719.85 Totals (14 stages) 35# Hybor G 877,190 gal 35# Linear 28,406 gal 20/40 Wanli 1,400,000 lbs 100 mesh sand - 87,500 lbs Model Results 1-14 100,000 6310 6430 760 120 0.15 • Disclaimer Notice: — This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-06 (PTD No. 216-085; Sundry No. 316-471) Paragraph L Sub -Paragraph (a) Application for Sundry Approval (a)(1) Affidavit AOGCC (a)(2) Plat (a)((a)(2)(A) Well location a 2 B Each water well within X mile (a)(2)(C) Identify all well types within '2 mile (a)(3) Freshwater aquifers: geological name (a)(3) Freshwater aquifers: measured and true vertical depth (a)(4) Baseline water sampling plan (a)(5) Casing and cementing information (a)(6) Casing and cementing operation assessment (a)(6)(A) Casing cemented below lowermost freshwater aquifer and conforms to 20 AAC 25.030 (a)(6)( B) Each hydrocarbon zone is _ isolated (a)(7) Pressure test: information and pressure -test plans for casing and tubing installed in well Section Dated 9/15/2016. Provided with application. On 9/15/2016, operator sent Notice of Operations (Notice) to all owners, landowners, surface owners, and operators within one-half mile radius of proposed well trajectory. Provided as Exhibit 1 -Plat within application. TComplete? PKB PKB Legal description of well, (surface, target and bottomhole locations) provided in Notice dated 9/15/2016. PKB PKB None per DNR Water Estate Map (9/15/2016). Seventeen wells within % mile radius of KRU 25-06 well trajectory. Wells identified by name, well type and well PKB status. None: as per Aquifer Exemption Title 40 CFR 147.102(b)(3) The portions of aquifers on the North Slope described by a X miles area beyond and lying directly below the Kuparuk PKB River Unit oil and gas producing field. PKB NA NA PKB provided CDW provided CDW NA Per Aquifer Exemption Title 40 CFR 147.102(b)(3), no PKB freshwater aquifers present. Estimated TOC stage 1 is 5125 CDW 7 5/8" plan to test to 4000 psi. tubing plan to test to 5000 CDW psi prior to frac. Page 1 September 19, 2016 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-06 (PTD No. 216-085; Sundry No. 316-471) Paragraph Sub -Paragraph (a)(8) Pressure ratings and schematics: wellbore, wellhead, BOPS, treating head (a)(9)(A) Fracturing and confining zones: lithologic description for each zone (a)(9)(B) Geological name of each zone (a)(9)(C) and (a)(9)(D) Measured and true vertical depths (o)(9)(E) Fracture pressure for each zone Section Provided. 101(frac tree. Fracturing zone will be the Kuparuk A sand. It is -107' thick true vertical thickness. Upper confining zones are the Kalubik and HRZ mudstone with an overall thickness of 317'. Lower confining zone is the Miluveach shale -500' thick. Top Kuparuk A is 7,497' MD (6,181' TVDss). Top HRZ is 6,566' MD (5,856' TVDss). Top Miluveach is estimated at 6,280' TVDss. Note: Miluveach was not penetrated by wellbore. Kuparuk A sand est. fracture gradient is 13.1 ppg. Kalubik and HRZ est. fracture gradient is 16.0 ppg. Miluveach est. fracture gradient is 15.5 ppg (a)(10) Location, orientation, report on mechanical condition of each well (a)(11) Sufficient information to determine wells will not interfere with containment within % mile (a)(11) Faults and fractures, Location, nriantntinn 1(11) Faults and fractures, Sufficient Formation to determine no interference 'th containment within 'z mile provided provided Map of faults within AOR provided in application. There are 13 mapped faults that transect the Kuparuk A interval and enter the confining zone within % mile radius of the wellbore trajectory for 2S-06. Fault displacements range from 4 to 32'. Six faults intersect the 25-06 wellbore. Five faults terminate within the confining layer; whereas, one fault terminates near the C-35 geologic marker that lies above the HRZ. The C-35 in this area consists of shales and siltstone with an estimated fracture pressure of 16.00 ppg. Fracture gradients within the confining zone will not be exceeded and would therefore confine injected fluids to the pool. Complete? CDW PKB PKB - —I PKB CDW CDW PKB AOGCC Page 2 September 19, 2016 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-06 (PTD No. 216-085; Sundry No. 316-471) Paragraph Sub -Paragraph L- Section Complete? (b)Testing of casing or intermediate Fracture length is estimated to be 760'. Fractures will be longitudinal running parallel to 25-06 wellbore. Half - length height of fractures is 120 feet. ConocoPhillips mitigation plan should there be any evidence as to the likelihood of fracture wings intersecting a fault during the treatment is to terminate the fracturing operation. If this type of connection were to occur, the operator surmises that they would experience a much higher leak off rate than of that to the formation. (a)(12) Proposed program for fracturing provided CDW (a)(12)(A) Estimated volume 14 intervals, 21582 bbl CDW (a)(12)(8) Additives: names, purposes, provided spreadsheet. CDW concentrations _ (a)(12)(C) Chemical name and CAS number Provided or previously on file. Some marked proprietary. A CDW of each Sand Halliburton frac chemicals. (a)(12)(D) Inert substances, weight or CDW volume of each 1.5 million pound propant (a)(12)(E) Maximum treating pressure with CDW supporting info to determine Max wellhead pressure est. as 5000 psi, max of 7100 psi nitrogen PRV. appropriateness for program (a)(12)(F) Fractures — height, length, MD Stage 1-14 6310 to 6430 ft TVD, length 760 ft, height 120 and TVD to top, description of fracturing ft, 0.15 inch width is standard A Sand frac model. _model (a)(13) Proposed program for post- Disposal well fracturing well cleanup and fluid recovery j Tested >110% of max anticipated pressure�Test of IA 4000 psi plan, Max IA pressure = 3600 psi, PRV plan 3700 psi :BIZ/ CDW CDW AOGCC Page 3 September 19, 2016 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-06 (PTD No. 216-085; Sundry No. 316-471) Paragraph T Sub -Paragraph Section omplete? (c)(1) Packer >100'MD below TOC of TOC stated as 5125 ft MD for stage 1. premier packer est as (c) Fracturing string CDW production or intermediate casing 7179 ft MD, 6265 ft TVD Tubing test plan is 5000 psi. Max diff pressure is 5000- 3600 backpressure = 1400 psi. Line test stated as 9000 psi, press ure differential Tested >110% of max anticipated which is >110% of the exp. treating pressure states as 5000 CDW press psi. IA plan is to hold backpressure of3600 psi. _ (d) Pressure relief Line pressure <= test pressure, remotely Line test to 9000 psi ,pump trip at 6900 psi while nitrogen CDW valve controlled shut-in device I PRV set at 7100 psi. (e) Confinement (f) Surface casing pressures (g) Annulus pressure monitoring & Frac fluids confined to approved formations _ Monitored with gauge and pressure relief device 500 psi criteria (h) Sundry Report (g)(1) Notify AOGCC within 24 hours (g)(2) Corrective action or surveillance (g)(3) Sundry to AOGCC (i)(1) FracFocus Reporting (i)(2) AOGCC Reporting: printed & electronic (i) Reporting (j) Post frac water sampling plan (k) Confidential information (1) Variances Clearly marked and specific facts supporting nondisclosure Modifications of deadlines, requests for CDW CDW AOGCC Page 4 September 19, 2016 20 AAC 25.283 Hydraulic Fracturing Application — Checklist Well Name No. KRU 2S-06 (PTD No. 216-085; Sundry No. 316-471) - -- -- --- - _ - - - - - - Paragraph Sub -Paragraph Section Complete? J requested variances or waivers AOGCC Page 5 September 19, 2016 P 7D 2 /io -0 S-5, Loepp, Victoria T (DOA) From: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Sent: Thursday, September 08, 2016 4:06 PM To: Loepp, Victoria T (DOA) Subject: Sonic log - Cement Evaluation of 2S-06 Intermediate Casing Attachments: ConocoPhillips 2S-06 Top of Cement Analysis.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Here is the Sonic Log (Cement Evaluation) for 2S-06 Intermediate Casing job as discussed last week. Looking at the log, we are interpreting the Top of Cement to be at 5125' MD / 4921' TVD. The intermediate shoe was set at 7620' MD / 6358' TVD. Any questions or concerns let me know. Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) schlumhopgoIp *Techlog Processed Interpretation O Y O C O a "O Q O O to CN SonicScope • ofZ T CCCannnj 3 iS K AAmt$i8 -W co Casing m ca c 8 uCement JD �C6 g3z C 8 c C6 0 m Analysis N YAmplitude •O a Lft O N m R v O L R C N O ,C� "U .� X- N cv 1 — ca 4 �i c c.&�� O * A Mark of Schlumberger '�C (C6 N C o 8 Q c 0 0 COMPANY: ConocoPhillips Alaska LLC. o � '0 WELL: 25-06 N O LD: Kuparuk River Unit _ ` O C N m >+ STATE: Alaska o COUNTRY: USA M 2 0C6 Q C coo o CU ID c c N co c (> 8 "Q Z .� a16 o_ `O Sept. 1 2016 Se tem ber 7 2016 Dale Logged: Date Processed: p CD Q) N A��� L -o Suncce Location ; Longiiude:150° 9' 18.248"W Latitude: 70° 13' 10.625" N Na Co O P3 o C 0 s 53 co g A (D Elevations: KB: 159.1 ft DF: 159.1 GL: 120 ft = '- � _ C O � d LL 3Cj 2 ~ API Number: 50-103-20747-00-00 cc Of mus lk, ill'ifil.Rl:4illR91 n . D Schlumberger SonicScope Top of Cement Analysis Loepp, Victoria T (DOA) From: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Sent: Friday, August 26, 2016 9:47 AM To: Loepp, Victoria T (DOA) Subject: RE: Revision to the 2S-06 Revised(PTD 216-085): Add length to the lateral section of the wellbore. Follow Up Flag: Flag Status: Follow up Flagged Victoria, It is a—2870ft extension request to the existing permit. I re -did the 10-401 and got a directional plan heading your way first thing this morning. Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, August 26, 2016 9:35 AM To: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Cc: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: Revision to the 2S-06 Revised(PTD 216-085): Add length to the lateral section of the wellbore. How much length? From: Alexa, Kurt J [mailto:Kurt.J.Alexa@conocophillips.com] Sent: Thursday, August 25, 2016 6:44 PM To: Loepp, Victoria T (DOA) Cc: Bettis, Patricia K (DOA) Subject: Revision to the 2S-06 Revised(PTD 216-085): Add length to the lateral section of the wellbore. Victoria, We would like to extend the lateral of 2S-06 well again, this time to allow for a better understanding of the thickness of the A4 sand in the south of the original plan. We are currently on this well and drilling ahead in our intermediate hole section. I apologize for the short notice but it was just brought up to me yesterday. If you would like to discuss it, I will be more than happy to talk with you on the phone; otherwise, I will have the 10-401 revised and a new directional plan sent over for your review. If you have any questions, please do not hesitate to give me a call or send me an email. Thanks, Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, July 25, 2016 8:59 AM To: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Cc: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: 2S-06 Revised(PTD 216-085) Add Fracture Stimulation Kurt, I will add the fracture stimulation to the revised PTD. Thanx, Victoria From: Alexa, Kurt J [ma iIto: Kurt.J.Alexa0)conocophillips.com] Sent: Monday, July 25, 2016 8:45 AM To: Loepp, Victoria T (DOA) Subject: 2S-06 Re -Submittal Victoria, I had a couple questions regarding how the 2S-06 re -submittal works. The initial 25-06 permit approval and the re- submittal probably crossed paths in the mail room. The team decided to extend the lateral of 2S-06 by 500ft requiring a new directional plan which resulted in the re -submittal of the permit to drill for 2S-06. Will the API number and permit number for the well change because of the re -submittal or will it be the same as what was on the originally approved 2S- 06 permit to drill?(No change in API # or PTD #) In the event that we are ready to begin drilling prior to approval of the re -submittal, do we still have permission to drill to the originally permitted depth or does the re -submittal cancel the existing approved permit?(Need approved resubmitted PTD to drill) Also, I was told this morning that we need to include in the permit application that this well (2S-06) will be frac'd. Apologies for not having it in the submittal. Do I need to re -submit again or will this email be sufficient?(This email will suffice) If you have any questions, please don't hesitate to give me a call or shoot me an email. Thanks, Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) THE STATE 01ALASKA GOVERNOR BILL WALKER G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 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 2S-06 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-085 (Revised) Surface Location: 2236FSL, 1408' FEL, SEC. 17, TI ON, R8E, UM Bottomhole Location: 5239.45' FNL, 4311.28' FEL, SEC. 29, T10N, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated July 20, 2016 and July 26, 2016. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, CathyPFoerster Chair DATED this 3v day of August, 2016. � CEIVED STATE OF ALASKA AUG 2 6 204L :A OIL AND GAS CONSERVATION COMMI-DN PERMIT TO DRILL Ait , M. ,• 20 AAC 25.005 X11 S1 Ov� 4 Z-- Ia. -- 1a. Type of Work:1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp E]1 c. Specify if well is proposed for: Drill ❑- Lateral E] Stratigraphic Test ❑ Development - Oil ❑✓ Service - Winj ❑ Single Zone 21 Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2S-06 - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 19715' t TVD: 6426' ` Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 2236' FSL, 1408' FEL, Sec 17, T10N, R8E, UM ADL025603, ADL025608 Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4092.62' FNL, 1285.27' FEL, Sec17, T10N, R8E, UM 2677, 2681 8/19/2016 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 5239.45' FNL, 4311.28' FEL, Sec29, T10N, R8E, UM 5035 1,299.99' from ADL025604 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 159 15. Distance to Nearest Well Open Surface: x- 481,162.27' y- 5,930,004.80' Zone -4 GL Elevation above MSL (ft): 120 to Same Pool: 1,105.82'f/2S-10 16. Deviated wells: Kickoff depth: 425 feet - 3,,j 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: q 89,X5 degrees Downhole: 3650 ' Surface: 3013 . 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 80 39' 39' 120' 120' pre -driven, cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2839' 39' 39' 2779' 2661' 1020sx 11 ppg lead/300sx 15.8ppg tail 9.875" 7.625" 29.7# L-80 Hydril 563 8245' 39' 39' 7688' 6375' 690 sx 1st stg, 210 sx 2nd stg classG 6.75" 4.5" 1 12.6# L-80 TXP 9329' 7518' 6352' 16847' 6410' N/A- liner 3.5" 1 9.3# L-80 Hydril 563 8061' 39' 39' 7518' 6352' N/A - tubing 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Kurt Alexa @ 907-263-4933 Email KUrt.J.AIexa an.COP.com Printed Name G.L. Alvord Title Alaska Drilling Manager Signature A Phone 265-6120 Date 2 G Commission Use Only Permit to Drill (c���� API Number: Permit Approval See cover letter for other Number:2:kQ-o1 2 1 50- 103 - 267,/"7- GG -00 Date: -7- 20 - 2-01 Le I requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan gas hydrates, or gas contained in shales: Other: 00 P ��5 ya ��� n 5 Samples req'd: Yes Noz Mud log req'd: Yes❑ N4 res: Yes No❑( Directional svy req'd: Yes[ Nc❑ /1�n �- a56 v1 a ` /J�re- fir, �-fi t5 I` i� 6 ❑ Inclination-only Yes❑ Nry / Spacing exception req'd: Yes Nosvy req'd: (i 'C� C ✓t t t: Va / l 0 q t'-Gi ✓1 Post initial injection MIT req'd: Yes❑ NcE� thtrr tcll'at- c. 4bj IritCv12re- �-att`,Y+ 5(-/b vre'l -(3 Ao�tCC. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: --30 X13, 116 Form 10-401 (Revised 11/2015) OTRI r�i 1 iINAt onths from the date of approval (20 AAC 25.005(g)) M Submit Form and Attachments in Duplicate o 'QQpO 2S-06wp13 7Doao Plan Summary o_ x 9-7/8" by 11" 0 0 0 0 pr o 0 0 0 1 00 0 2000 4000 06000 8000 too(% 1120A 6140M m 16( Horizontal Departure 0 2500 5000 SURVEY PROGRAM 7th From Depth To Survey/Plan 39.00 2500 C >) 1750.00 2S-06wp13 (Rig: 2S-06) 750.00 2779.13 2S-06wp13 (Rig: 2S-06) 2779.13 4281.49 2S-06wp13 (Rig: 2S-06) 2779.13 7688.26 2S-06wp13 (Rig: 2S-06) 7688.26 7708.26 2S-06wp13 (Rig: 2S-06) 7688.26 D) ' 0 -s/s" x 7/e" y 1 1500 0 4500 9000 13500 18000 �OQpQ /4" x 13-1/2' Measured Depth j Geodetic Datum: North American Datum 1983 Depth Reference: Rig: Plan: 120+39 @ 159.00usft (Doyon142) Doyon142 x 9-7/8" by 11" 0 0 0 0 pr o 0 0 0 1 00 0 2000 4000 06000 8000 too(% 1120A 6140M m 16( Horizontal Departure 0 2500 5000 SURVEY PROGRAM 7th From Depth To Survey/Plan 39.00 750.00 2S-06wp13 (Rig: 2S-06) 750.00 1750.00 2S-06wp13 (Rig: 2S-06) 750.00 2779.13 2S-06wp13 (Rig: 2S-06) 2779.13 4281.49 2S-06wp13 (Rig: 2S-06) 2779.13 7688.26 2S-06wp13 (Rig: 2S-06) 7688.26 7708.26 2S-06wp13 (Rig: 2S-06) 7688.26 19715.53 2S-06wp13 (Rig: 2S-06) 7500 10000 Tool GYD-GC-SS MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC 12500 15000 Surface Location Pad Elevation: 120.00 270 0 CASING DETAILS TVD MD Name 2661.00 2779.13 10-3/4" x 13-1/2" 6375.00 7688.26 7-5/8" x 9-7/8" by 11" 6379.00 15200.00 4 1/2" x 6-3/4" SECTION DETAILS Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 425.00 0.00 0.00 425.00 0.00 0.00 0.00 0.00 0.00 3 600.06 2.63 0.00 600.00 4.01 0.00 1.50 0.00 -3.87 4 1380.92 22.15 0.00 1359.00 170.70 0.00 2.50 0.00 -164.89 5 1488.89 22.15 0.00 1459.00 211.41 0.00 0.00 0.00 -204.20 6 1847.71 21.32 29.27 1793.30 336.30 31.98 3.00 107.93 -333.12 7 3464.77 21.32 29.27 3299.73 849.09 319.34 0.00 0.00 -902.81 8 7688.26 85.00 194.33 6375.00 -1107.22 111.24 2.50 164.54 1040.70 2S -Salmon 1. Heel 050216 PB 9 7708.26 85.00 194.33 6376.74 -1126.53 106.31 0.00 0.00 1060.62 10 7995.55 90.75 194.34 6387.40 -1404.55 35.24 2.00 0.10 1347.57 11 9087.0590.75 194.34 6373.19 -2461.93 -235.16 0.00 0.00 2438.91 12 9099.76 91.00 194.34 6373.00 -2474.25 -238.31 2.00 -1.02 2451.62 2S-06 int 1 082416 KA 13 9143.97 91.88194.34 6371.89 -2517.07 -249.26 2.00 -0.32 2495.81 14 10005.92 91.88 194.34 6343.55 -3351.73 -462.55 0.00 0.00 3357.24 15 10100.12 90.00 194.33 6342.00 -3442.98 -485.87 2.00 -179.94 3451.42 2S-06 int 2 082416 KA 16 10122.21 89.56 194.33 6342.09 -3464.39 -491.34 2.00 -179.65 3473.51 17 11256.19 89.56 194.33 6350.83 -4563.05 -772.00 0.00 0.00 4607.38 1 8 11300.38 90.00 194.33 6351.00 -4605.86 -782.94 1.00 0.22 4651.56 2S-06 int 3 082416 KA 19 11300.69 90.00 194.34 6351.00 -4606.16 -783.02 1.00 90.00 4651.87 20 12299.43 90.00 194.34 6351.00 -5573.80 -1030.30 0.00 0.00 5650.54 21 12300.24 90.00 194.33 6351.00 -5574.59 -1030.50 1.00 -90.00 5651.35 2S-06 int 4 082416 KA 22 12390.20 89.10 194.32 6351.71 -5661.75 -1052.75 1.00 -179.58 5741.30 23 13291.18 89.10 194.32 6365.85 -6534.63 -1275.58 0.00 0.00 6642.11 24 13301.18 89.20 194.33 6366.00 -6544.32 -1278.05 1.00 5.48 6652.11 2S-06 int 5 082416 KA 25 13305.39 89.24 194.35 6366.06 -6548.40 -1279.10 1.00 22.62 6656.32 26 14317.22 89.24 194.35 6379.50 -7528.58 -1529.79 0.00 0.00 7667.99 27 14400.35 90.07 194.33 6380.00 -7609.12 -1550.37 1.00 -1.12 7751.11 2S-06 int 6 082416 KA 28 14400.93 90.07 194.32 6380.00 -7609.69 -1550.52 1.00 -74.34 7751.70 29 15200.67 90.07 194.32 6379.00 -8384.56 -1748.38 0.00 0.00 8551.37 30 15200.82 90.07 194.32 6379.00 -8384.71 -1748.42 3.00 -109.86 8551.53 2S-06 int 7 082416 KA 31 15369.82 85.00 194.32 6386.27 -8548.25 -1790.16 3.00 180.00 8720.30 32 15756.87 85.00194.32 6420.00 -8921.85 -1885.53 0.00 0.00 9105.86 33 15837.19 85.00 194.32 6427.00 -8999.37 -1905.32 0.00 0.00 9185.86 34 16637.19 93.00 194.32 6440.95 -9773.77 -2103.00 1.00 0.00 9985.03 35 16865.53 93.00194.32 6429.00 -9994.72 -2159.40 0.00 0.00 10213.05 36 16965.53 90.00 194.32 6426.38 -10091.56 -2184.12 3.00 180.00 10313.00 ling this ac novAe get at I have een in o9 of a risks, c ec ed that t e data is correct, ensured it's completeness, and all sur 39425 425 - 610 610 - 790 790 - 970 970 - 1150 1150 - 1340 1340 - 1520 1520 - 1700 1700 - 2330 2330 2950 2950 - 3580 3580 - 4200 4200 - 4830 4830 - 5450 5450 - 6080 6080 - 6700 6700 - 7970 7970 - 9240 9240 - 10511 10510 - 11781 11780 - 13041 13040 14311 14310 1558( 15580 - 16847 Magnetic Model: BGGM2016 r Magnetic Model Date: 22 -Aug -16 Magnetic Declination: 17.87° To convert a Magnetic Direction to a True Direction, Add 17.871 East �Rc.$ T-3 Sand Annotation KOP: Start 1.51/100' DLS, 0°TF, for 175.06' Start 2.57100' DI -S, 0°TF, for 780.86' Hold for 107.97' Start 31100' DLS, 107.931TF, for 358.82' Hold for 1617.06' Start 2.59100' DLS, 164.54°TF, for 4223.49' Hold for 20' Start 29100' DI -S, 01TF, for 242.71' Permit Pack K-15 Marker 1409.0 Base permafrost 1849.0 Top W Sak(W S 2544.0 Base W Sak 2944.0 C-80 4284.0 C-50 46 4C.400 5044.0' �5 Growler -AA J� A&Oa C-35 are assigned to the proper position and I approve the scan and collision avoidance plan asset out in the audit pack. I approve it as the basis for the final well r....:.....,_ ._...a._...a..o._.�...-._r..... .. u,.,._._........«..v a....,«.....,...,,.�_...-...............................................--------------- -----------.._------------ Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Erik Sterk 16:35, August 25 2016 Easting (3500 usft/in) 2M-33 M 15 L/2-04 2M -32L1 PB1 2M 08 2M-09 12S-14 2M -32L1 P62M-34 2 M-Wli-35 2,4%1 2S-11 2L-03 2S-04 2S-07 2S-05 Kuparuk 2S Pad 2S-02 L-314PB1 S+ S-06 2L-306PB1 2S -13P 1 4 C) - 06 2L-31 M 2L-308 c KR 21-10-8 2L-310 2L 2L-304 2S-12PB Z 1 2L-311 - S ar Tooth #1 L-30 2S-12 1 2 2L-316 2L-301 2S 03P61 2S-01 32 L-32 2L -317A 2L-320 2S-08 2L-32 2S 10 2L-33 Ln1309 2N-322 2S-03 2N-3 2 Prelim: Kuparuk-- rn_P_ad 2N 02 -322 B1 N-322 B2 Prelim: Kuparuk Cairn P 2L --- 2S-06wp13 2�(�3�4PB1 2N-310 Easting (3500 usft/in) 9L1 K-06 K-09 -08AP PB1 8APB1 -13 < 1 2K-13AL2 2K- 8 K- 4 K-19 2K-20 2K - 2K -28A K -21 A 2K-21 2K-22 0 22AL1 i h..22AL1 w CD 0 0 c w 2S-06wpl 3 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 10-3/4" x 13-1/2°------------ 000 0 00 ------ 2S -Salmon 1. Heel 050216 PB ------ 7-5/8" x 9-7/8" by 11 '` ------------ -2500 c M 0 N-5000 2S-06 int 7 082416 K 0 Z -7500- 7500 0 0 4 1/2" x 6-3/4" \- c/) -10000 - - 2S-06 X1 08251 -12500— 12500_-84 -1-64------- 2S_06w 2S-06 extend TD 082416 p r3 -12500 -10000 -7500 -5000 -2500 0 2500 5000 7500 10000 West( -)/East(+) (2500 usft/in) 2S-06wpl 3 Section View -2000- 200000° 0- 00 E 1000 U) D 0 2000-2000 N 1 O Q 10-3/4" x 13-1/ 3000 4 1/2" x 6-3/4" 0 2S-06 X1 08251 F 4000 4000 T 1 N C) 3� p4 0 0 0 0 0 o a 6000 �o& 0 ca ^ o rn 00 00 00 00 0 CN avo oxt gyp, rn ,- a� °`� aor � ,- �, / ' d o'nia5o 7-5/8" x 9-7/8" by a1 " ° 0 ° o 0 0 � 0 0; I o 0 0 0 - 0 0 0 0')I I I 8000 I I I I I 2S -Salmon 1. Heel 050216 PB I 2S-06 int 7 082416 K 2S-06 extend TD 082416 -2000 0 2000 4000 6000 8000 10000 12000 14000 Vertical Section at 195.00° (2000 usft/in) Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Rig: 2S-06 Rig: 2S-06 Plan: 2S-06wpl3 Standard Proposal Report 25 August, 2016 Permit Pack Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Rig: 2S-06 Wellbore: Rig: 2S-06 Design: 2S-06wp13 Comments apply to the line before it. Local Co-ordinate Reference: Well Rig: 2S-06 TVD Reference: Plan: 120+39 @ 159.O0usft (Doyon142) MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Latitude: 70° 13' 10.937 N From: Map Longitude: 150° 9' 13.991 W Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Rig: 2S-06 Well Position +N/ -S 0.00 usft Latitude: 70° 13' 10.625 N +E/ -W 0.00 usft Longitude: 150° 9' 18.248 W Position Uncertainty 0.00 usft Ground Level: 120.00 usft Wellbore Rig: 2S-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (') (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 2S-06wp13 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 39.00 0.00 0.00 195.00 8/25/2016 3:55:07PM Page 2 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 Depth Inclination Design: 2S-06wp13 System +N/ -S Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 39.00 0.00 0.00 39.00 -120.00 0.00 0.00 0.00 0.00 0.00 0.00 425.00 0.00 0.00 425.00 266.00 0.00 0.00 0.00 0.00 0.00 0.00 600.06 2.63 0.00 600.00 441.00 4.01 0.00 1.50 1.50 0.00 0.00 1,380.92 22.15 0.00 1,359.00 1,200.00 170.70 0.00 2.50 2.50 0.00 0.00 1,488.89 22.15 0.00 1,459.00 1,300.00 211.41 0.00 0.00 0.00 0.00 0.00 1,847.71 21.32 29.27 1,793.30 1,634.30 336.30 31.98 3.00 -0.23 8.16 107.93 3,464.77 21.32 29.27 3,299.73 3,140.73 849.09 319.34 0.00 0.00 0.00 0.00 7,688.26 85.00 194.33 6,375.00 6,216.00 -1,107.22 111.24 2.50 1.51 3.91 164.54 7,708.26 85.00 194.33 6,376.74 6,217.74 -1,126.53 106.31 0.00 0.00 0.00 0.00 7,995.55 90.75 194.34 6,387.40 6,228.40 -1,404.55 35.24 2.00 2.00 0.00 0.10 9,087.05 90.75 194.34 6,373.19 6,214.19 -2,461.93 -235.16 0.00 0.00 0.00 0.00 9,099.76 91.00 194.34 6,373.00 6,214.00 -2,474.25 -238.31 2.00 2.00 -0.04 -1.02 9,143.97 91.88 194.34 6,371.89 6,212.89 -2,517.07 -249.26 2.00 2.00 -0.01 -0.32 10,005.92 91.88 194.34 6,343.55 6,184.55 -3,351.73 -462.55 0.00 0.00 0.00 0.00 10,100.12 90.00 194.33 6,342.00 6,183.00 -3,442.98 -485.87 2.00 -2.00 0.00 -179.94 10,122.21 89.56 194.33 6,342.09 6,183.09 -3,464.39 -491.34 2.00 -2.00 -0.01 -179.65 11,256.19 89.56 194.33 6,350.83 6,191.83 -4,563.05 -772.00 0.00 0.00 0.00 0.00 11,300.38 90.00 194.33 6,351.00 6,192.00 -4,605.86 -782.94 1.00 1.00 0.00 0.22 11,300.69 90.00 194.34 6,351.00 6,192.00 -4,606.16 -783.02 1.00 0.00 1.00 90.00 12,299.43 90.00 194.34 6,351.00 6,192.00 -5,573.80 -1,030.30 0.00 0.00 0.00 0.00 12,300.24 90.00 194.33 6,351.00 6,192.00 -5,574.59 -1,030.50 1.00 0.00 -1.00 -90.00 12,390.20 89.10 194.32 6,351.71 6,192.71 -5,661.75 -1,052.75 1.00 -1.00 -0.01 -179.58 13,291.18 89.10 194.32 6,365.85 6,206.85 -6,534.63 -1,275.58 0.00 0.00 0.00 0.00 13,301.18 89.20 194.33 6,366.00 6,207.00 -6,544.32 -1,278.05 1.00 1.00 0.10 5.48 13,305.39 89.24 194.35 6,366.06 6,207.06 -6,548.40 -1,279.10 1.00 0.92 0.38 22.62 14,317.22 89.24 194.35 6,379.50 6,220.50 -7,528.58 -1,529.79 0.00 0.00 0.00 0.00 14,400.35 90.07 194.33 6,380.00 6,221.00 -7,609.12 -1,550.37 1.00 1.00 -0.02 -1.12 14,400.93 90.07 194.32 6,380.00 6,221.00 -7,609.69 -1,550.52 1.00 0.27 -0.96 -74.34 15,200.67 90.07 194.32 6,379.00 6,220.00 -8,384.56 -1,748.38 0.00 0.00 0.00 0.00 15,200.82 90.07 194.32 6,379.00 6,220.00 -8,384.71 -1,748.42 3.00 -1.02 -2.82 -109.86 15,369.82 85.00 194.32 6,386.27 6,227.27 -8,548.25 -1,790.16 3.00 -3.00 0.00 180.00 15,756.87 85.00 194.32 6,420.00 6,261.00 -8,921.85 -1,885.53 0.00 0.00 0.00 0.00 15,837.19 85.00 194.32 6,427.00 6,268.00 -8,999.37 -1,905.32 0.00 0.00 0.00 0.00 16,637.19 93.00 194.32 6,440.95 6,281.95 -9,773.77 -2,103.00 1.00 1.00 0.00 0.00 16,865.53 93.00 194.32 6,429.00 6,270.00 -9,994.72 -2,159.40 0.00 0.00 0.00 0.00 16,965.53 90.00 194.32 6,426.38 6,267.38 -10,091.56 -2,184.12 3.00 -3.00 0.00 180.00 19,715.53 90.00 194.32 6,426.38 6,267.38 -12,756.12 -2,864.30 0.00 0.00 0.00 0.00 8125/2016 3:55:07PM Page 3 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.00usft (Doyonl42) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 DLS Vert Section Design: 2S-06wp13 (usft) usft Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) -120.00 39.00 0.00 0.00 39.00 -120.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 41.00 0.00 0.00 0.00 0.00 289.00 0.00 0.00 289.00 130.00 0.00 0.00 0.00 0.00 top T-3 Sand 300.00 0.00 0.00 300.00 141.00 0.00 0.00 0.00 0.00 374.00 0.00 0.00 374.00 215.00 0.00 0.00 0.00 0.00 K-15 Marker 400.00 0.00 0.00 400.00 241.00 0.00 0.00 0.00 0.00 425.00 0.00 0.00 425.00 266.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' 500.00 1.12 0.00 500.00 341.00 0.74 0.00 1.50 -0.71 600.00 2.62 0.00 599.94 440.94 4.01 0.00 1.50 -3.87 600.06 2.63 0.00 600.00 441.00 4.01 0.00 1.50 -3.87 Start 2.5°/100' DLS, 0° TF, for 780.86' 700.00 5.12 0.00 699.70 540.70 10.76 0.00 2.50 -10.40 800.00 7.62 0.00 799.08 640.08 21.87 0.00 2.50 -21.12 900.00 10.12 0.00 897.87 738.87 37.29 0.00 2.50 -36.02 1,000.00 12.62 0.00 995.90 836.90 57.01 0.00 2.50 -55.07 1,100.00 15.12 0.00 1,092.97 933.97 80.99 0.00 2.50 -78.23 1,200.00 17.62 0.00 1,188.91 1,029.91 109.18 0.00 2.50 -105.46 1,300.00 20.12 0.00 1,283.53 1,124.53 141.53 0.00 2.50 -136.70 1,380.92 22.15 0.00 1,359.00 1,200.00 170.70 0.00 2.50 -164.89 Hold for 107.97' 1,400.00 22.15 0.00 1,376.67 1,217.67 177.90 0.00 0.00 -171.83 1,434.90 22.15 0.00 1,409.00 1,250.00 191.05 0.00 0.00 -184.54 Base permafrost (?) 1,488.89 22.15 0.00 1,459.00 1,300.00 211.41 0.00 0.00 -204.20 Start 3°/100' DLS, 107.93° TF, for 358.82' 1,500.00 22.05 0.85 1,469.30 1,310.30 215.59 0.03 3.00 -208.25 1,600.00 21.35 8.74 1,562.23 1,403.23 252.35 3.07 3.00 -244.55 1,700.00 21.03 17.00 1,655.49 1,496.49 287.51 11.09 3.00 -280.58 1,800.00 21.13 25.35 1,748.82 1,589.82 320.97 24.06 3.00 -316.26 1,847.71 21.32 29.27 1,793.30 1,634.30 336.30 31.98 3.00 -333.12 Hold for 1617.06' 1,900.00 21.32 29.27 1,842.01 1,683.01 352.88 41.27 0.00 -351.54 1,907.51 21.32 29.27 1,849.00 1,690.00 355.26 42.60 0.00 -354.19 Top W Sak (W Sak D) 2,000.00 21.32 29.27 1,935.17 1,776.17 384.60 59.04 0.00 -386.77 2,100.00 21.32 29.27 2,028.33 1,869.33 416.31 76.81 0.00 -422.00 2,200.00 21.32 29.27 2,121.49 1,962.49 448.02 94.58 0.00 -457.23 2,300.00 21.32 29.27 2,214.64 2,055.64 479.73 112.35 0.00 -492.46 2,400.00 21.32 29.27 2,307.80 2,148.80 511.44 130.12 0.00 -527.69 2,500.00 21.32 29.27 2,400.96 2,241.96 543.15 147.90 0.00 -562.92 2,600.00 21.32 29.27 2,494.12 2,335.12 574.86 165.67 0.00 -598.15 8/25/2016 3:55:07PM Page 4 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.O0usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 25-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 TVDss +N/ -S Design: 2S-06wp13 Vert Section (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (1 (1) (usft) usft (usft) (usft) 2,385.00 2,653.54 21.32 29.27 2,544.00 2,385.00 591.84 175.18 0.00 -617.01 Base W Sak 2,700.00 21.32 29.27 2,587.28 2,428.28 606.57 183.44 0.00 -633.38 2,779.13 21.32 29.27 2,661.00 2,502.00 631.67 197.50 0.00 -661.26 10-3/4" x 13-1/2" 2,800.00 21.32 29.27 2,680.44 2,521.44 638.28 201.21 0.00 -668.61 2,900.00 21.32 29.27 2,773.60 2,614.60 669.99 218.98 0.00 -703.84 3,000.00 21.32 29.27 2,866.76 2,707.76 701.71 236.75 0.00 -739.07 3,082.91 21.32 29.27 2,944.00 2,785.00 728.00 251.48 0.00 -768.28 C-80 3,100.00 21.32 29.27 2,959.92 2,800.92 733.42 254.52 0.00 -774.30 3,200.00 21.32 29.27 3,053.08 2,894.08 765.13 272.29 0.00 -809.53 3,300.00 21.32 29.27 3,146.23 2,987.23 796.84 290.06 0.00 -844.76 3,400.00 21.32 29.27 3,239.39 3,080.39 828.55 307.83 0.00 -879.99 3,464.77 21.32 29.27 3,299.73 3,140.73 849.09 319.34 0.00 -902.81 Start 2.5°/100' DLS, 164.54° TF, for 4223.49' 3,500.00 20.47 29.94 3,332.65 3,173.65 860.01 325.55 2.50 -914.97 3,600.00 18.08 32.17 3,427.04 3,268.04 888.30 342.54 2.50 -946.69 3,700.00 15.72 35.05 3,522.71 3,363.71 912.53 358.58 2.50 -974.25 3,800.00 13.42 38.90 3,619.49 3,460.49 932.66 373.65 2.50 -997.58 3,900.00 11.19 44.29 3,717.19 3,558.19 948.64 387.72 2.50 -1,016.66 4,000.00 9.11 52.19 3,815.63 3,656.63 960.44 400.75 2.50 -1,031.43 4,100.00 7.29 64.32 3,914.61 3,755.61 968.05 412.73 2.50 -1,041.88 4,200.00 5.99 82.92 4,013.94 3,854.94 971.44 423.63 2.50 -1,047.98 4,300.00 5.57 107.61 4,113.45 3,954.45 970.62 433.43 2.50 -1,049.72 4,400.00 6.21 131.36 4,212.94 4,053.94 965.58 442.11 2.50 -1,047.10 4,471.55 7.18 144.28 4,284.00 4,125.00 959.39 447.63 2.50 -1,042.55 C-50 4,500.00 7.65 148.42 4,312.22 4,153.22 956.33 449.66 2.50 -1,040.12 4,600.00 9.54 159.45 4,411.09 4,252.09 942.89 456.06 2.50 -1,028.80 4,700.00 11.66 166.69 4,509.38 4,350.38 925.29 461.29 2.50 -1,013.15 4,800.00 13.91 171.68 4,606.90 4,447.90 903.55 465.36 2.50 -993.21 4,838.29 14.79 173.19 4,644.00 4,485.00 894.15 466.61 2.50 -984.45 C-40 4,900.00 16.23 175.29 4,703.46 4,544.46 877.73 468.25 2.50 -969.02 5,000.00 18.59 178.00 4,798.87 4,639.87 847.87 469.95 2.50 -940.61 5,100.00 20.99 180.13 4,892.96 4,733.96 814.03 470.47 2.50 -908.05 5,101.11 21.01 180.15 4,894.00 4,735.00 813.63 470.47 2.50 -907.67 C-37 5,200.00 23.40 181.83 4,985.55 4,826.55 776.26 469.79 2.50 -871.40 5,264.08 24.96 182.75 5,044.00 4,885.00 750.04 468.74 2.50 -845.80 Growler -AA 5,300.00 25.83 183.23 5,076.45 4,917.45 734.65 467.93 2.50 -830.73 5,400.00 28.28 184.40 5,165.50 5,006.50 689.27 464.89 2.50 -786.11 5,500.00 30.73 185.40 5,252.53 5,093.53 640.21 460.67 2.50 -737.63 8/25/2016 3: 55 07P Page 5 COMPASS 5000.1 Build 74 Database: OAKEDM P2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Rig: 2S-06 Wellbore: Rig: 2S-06 Design: 2S-06wpl 3 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Standard Proposal Report Well Rig: 25-06 Plan: 120+39 @ 159.O0usft (Doyon142) Plan: 120+39 @ 159.00usft (Doyon142) True Minimum Curvature Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) V) (I (usft) usft (usft) (usft) 5,178.36 5,600.00 33.19 186.26 5,337.36 5,178.36 587.56 455.28 2.50 -685.38 5,700.00 35.65 187.02 5,419.85 5,260.85 531.43 448.73 2.50 -629.46 5,800.00 38.12 187.70 5,499.83 5,340.83 471.91 441.03 2.50 -569.98 5,900.00 40.59 188.30 5,577.15 5,418.15 409.13 432.20 2.50 -507.05 5,928.92 41.30 188.46 5,599.00 5,440.00 390.38 429.44 2.50 -488.22 Top Cairn 6,000.00 43.06 188.84 5,651.67 5,492.67 343.19 422.25 2.50 -440.79 6,044.66 44.17 189.07 5,684.00 5,525.00 312.77 417.46 2.50 -410.16 Top Bermuda 6,100.00 45.54 189.34 5,723.24 5,564.24 274.24 411.21 2.50 -371.32 6,137.09 46.45 189.52 5,749.00 5,590.00 247.92 406.84 2.50 -344.77 Base Bermuda 6,188.50 47.73 189.75 5,784.00 5,625.00 210.80 400.54 2.50 -307.29 C-35 6,200.00 48.01 189.80 5,791.72 5,632.72 202.39 399.09 2.50 -298.79 6,300.00 50.49 190.22 5,856.98 5,697.98 127.79 385.92 2.50 -223.32 6,400.00 52.97 190.61 5,918.91 5,759.91 50.58 371.72 2.50 -145.07 6,500.00 55.46 190.98 5,977.38 5,818.38 -29.10 356.52 2.50 -64.17 6,600.00 57.94 191.33 6,032.28 5,873.28 -111.09 340.35 2.50 19.22 6,698.97 60.40 191.65 6,083.00 5,924.00 -194.36 323.42 2.50 104.03 Top HRZ (K-2 mkr) 6,700.00 60.42 191.66 6,083.51 5,924.51 -195.24 323.24 2.50 104.93 6,800.00 62.91 191.97 6,130.97 5,971.97 -281.39 305.22 2.50 192.80 6,898.65 65.36 192.26 6,174.00 6,015.00 -368.17 286.59 2.50 281.45 Upper Kalubik (base HRZ) 6,900.00 65.39 192.27 6,174.56 6,015.56 -369.37 286.33 2.50 282.68 7,000.00 67.88 192.56 6,214.22 6,055.22 -459.02 266.59 2.50 374.38 7,100.00 70.37 192.83 6,249.85 6,090.85 -550.16 246.06 2.50 467.73 7,143.26 71.44 192.95 6,264.00 6,105.00 -590.01 236.94 2.50 508.58 Lower Kalubik (K-1 mkr) 7,200.00 72.85 193.10 6,281.39 6,122.39 -642.63 224.77 2.50 562.56 7,300.00 75.34 193.36 6,308.79 6,149.79 -736.24 202.75 2.50 658.68 7,400.00 77.83 193.62 6,331.99 6,172.99 -830.82 180.06 2.50 755.91 7,460.66 79.34 193.77 6,344.00 6,185.00 -888.58 165.98 2.50 815.35 Kuparuk C (Top C4) 7,500.00 80.32 193.87 6,350.95 6,191.95 -926.18 156.73 2.50 854.06 7,551.20 81.59 194.00 6,359.00 6,200.00 -975.26 144.55 2.50 904.62 A5 7,600.00 82.80 194.12 6,365.62 6,206.62 -1,022.16 132.81 2.50 952.96 7,628.32 83.51 194.19 6,369.00 6,210.00 -1,049.43 125.93 2.50 981.07 A4 7,688.26 85.00 194.33 6,375.00 6,216.00 -1,107.22 111.24 2.50 1,040.70 Hold for 20'- 7-5/8" x 9-7/8" by 11" 7,700.00 85.00 194.33 6,376.02 6,217.02 -1,118.55 108.35 0.00 1,052.40 8/25/2016 3:55:07PM Page 6 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 TVDss +Nl-S Design: 2S-06wpl 3 Vert Section (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +Nl-S +El -W DLS Vert Section (usft) (I (I (usft) usft (usft) (usft) 6,217.74 7,708.26 85.00 194.33 6,376.74 6,217.74 -1,126.53 106.31 0.00 1,060.62 Start 2*1100' DLS, 0' TF, for 242.71' 7,800.00 86.83 194.34 6,383.27 6,224.27 -1,215.18 83.65 2.00 1,152.12 7,900.00 88.83 194.34 6,387.05 6,228.05 -1,311.99 58.90 2.00 1,252.04 7,950.97 89.85 194.34 6,387.64 6,228.64 -1,361.37 46.28 2.00 1,303.00 Hold for 8396.63' 7,995.55 90.75 194.34 6,387.40 6,228.40 -1,404.55 35.24 2.00 1,347.57 8,000.00 90.75 194.34 6,387.34 6,228.34 -1,408.87 34.13 0.00 1,352.03 8,100.00 90.75 194.34 6,386.04 6,227.04 -1,505.74 9.36 0.00 1,452.01 8,200.00 90.75 194.34 6,384.74 6,225.74 -1,602.62 -15.41 0.00 1,552.00 8,300.00 90.75 194.34 6,383.44 6,224.44 -1,699.49 -40.19 0.00 1,651.98 8,400.00 90.75 194.34 6,382.14 6,223.14 -1,796.36 -64.96 0.00 1,751.97 8,500.00 90.75 194.34 6,380.84 6,221.84 -1,893.24 -89.73 0.00 1,851.95 8,600.00 90.75 194.34 6,379.53 6,220.53 -1,990.11 -114.51 0.00 1,951.94 8,700.00 90.75 194.34 6,378.23 6,219.23 -2,086.99 -139.28 0.00 2,051.92 8,800.00 90.75 194.34 6,376.93 6,217.93 -2,183.86 -164.05 0.00 2,151.91 8,900.00 90.75 194.34 6,375.63 6,216.63 -2,280.73 -188.83 0.00 2,251.89 9,000.00 90.75 194.34 6,374.33 6,215.33 -2,377.61 -213.60 0.00 2,351.88 9,087.05 90.75 194.34 6,373.19 6,214.19 -2,461.93 -235.16 0.00 2,438.91 9,099.76 91.00 194.34 6,373.00 6,214.00 -2,474.25 -238.31 2.00 2,451.62 9,100.00 91.00 194.34 6,373.00 6,214.00 -2,474.48 -238.37 0.00 2,451.86 9,143.97 91.88 194.34 6,371.89 6,212.89 -2,517.07 -249.26 2.01 2,495.81 9,200.00 91.88 194.34 6,370.05 6,211.05 -2,571.32 -263.12 0.00 2,551.81 9,300.00 91.88 194.34 6,366.76 6,207.76 -2,668.16 -287.87 0.00 2,651.75 9,400.00 91.88 194.34 6,363.47 6,204.47 -2,764.99 -312.61 0.00 2,751.69 9,500.00 91.88 194.34 6,360.18 6,201.18 -2,861.83 -337.36 0.00 2,851.63 9,600.00 91.88 194.34 6,356.89 6,197.89 -2,958.66 -362.10 0.00 2,951.57 9,700.00 91.88 194.34 6,353.61 6,194.61 -3,055.50 -386.85 0.00 3,051.51 9,800.00 91.88 194.34 6,350.32 6,191.32 -3,152.33 -411.60 0.00 3,151.45 9,900.00 91.88 194.34 6,347.03 6,188.03 -3,249.16 -436.34 0.00 3,251.38 10,000.00 91.88 194.34 6,343.74 6,184.74 -3,346.00 -461.09 0.00 3,351.32 10,005.92 91.88 194.34 6,343.55 6,184.55 -3,351.73 -462.55 0.00 3,357.24 10,100.00 90.00 194.33 6,342.00 6,183.00 -3,442.86 -485.84 2.00 3,451.30 10,100.12 90.00 194.33 6,342.00 6,183.00 -3,442.98 -485.87 2.00 3,451.42 10,122.21 89.56 194.33 6,342.09 6,183.09 -3,464.39 -491.34 2.00 3,473.51 10,200.00 89.56 194.33 6,342.69 6,183.69 -3,539.75 -510.59 0.00 3,551.29 10,300.00 89.56 194.33 6,343.46 6,184.46 -3,636.64 -535.34 0.00 3,651.28 10,400.00 89.56 194.33 6,344.23 6,185.23 -3,733.52 -560.09 0.00 3,751.27 10,500.00 89.56 194.33 6,345.00 6,186.00 -3,830.41 -584.84 0.00 3,851.26 10,600.00 89.56 194.33 6,345.77 6,186.77 -3,927.29 -609.59 0.00 3,951.25 10,700.00 89.56 194.33 6,346.54 6,187.54 -4,024.18 -634.34 0.00 4,051.24 10,800.00 89,56 194.33 6,347.31 6,188.31 -4,121.06 -659.09 0.00 4,151.23 10,900.00 89.56 194.33 6,348.08 6,189.08 -4,217.95 -683.84 0.00 4,251.22 11,000.00 89.56 194.33 6,348.85 6,189.85 -4,314.84 -708.60 0.00 4,351.21 11,100.00 89.56 194.33 6,349.63 6,190.63 -4,411.72 -733.35 0.00 4,451.20 8/25/2016 3.55:07PM Page 7 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Plan: 120+39 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 TVDss +N/ -S Design: 2S-06wp13 Vert Section (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (^) (I (usft) usft (usft) (usft) 6,191.40 11,200.00 89.56 194.33 6,350.40 6,191.40 -4,508.61 -758.10 0.00 4,551.19 11,256.19 89.56 194.33 6,350.83 6,191.83 -4,563.05 -772.00 0.00 4,607.38 11,300.00 90.00 194.33 6,351.00 6,192.00 -4,605.49 -782.85 1.00 4,651.18 11,300.38 90.00 194.33 6,351.00 6,192.00 -4,605.86 -782.94 1.00 4,651.56 11,300.69 90.00 194.34 6,351.00 6,192.00 -4,606.16 -783.02 1.00 4,651.87 11,400.00 90.00 194.34 6,351.00 6,192.00 -4,702.38 -807.61 0.00 4,751.17 11,500.00 90.00 194.34 6,351.00 6,192.00 -4,799.27 -832.37 0.00 4,851.17 11,600.00 90.00 194.34 6,351.00 6,192.00 -4,896.15 -857.12 0.00 4,951.16 11,700.00 90.00 194.34 6,351.00 6,192.00 -4,993.04 -881.88 0.00 5,051.15 11,800.00 90.00 194.34 6,351.00 6,192.00 -5,089.93 -906.64 0.00 5,151.15 11,900.00 90.00 194.34 6,351.00 6,192.00 -5,186.81 -931.40 0.00 5,251.14 12,000.00 90.00 194.34 6,351.00 6,192.00 -5,283.70 -956.16 0.00 5,351.13 12,100.00 90.00 194.34 6,351.00 6,192.00 -5,380.58 -980.92 0.00 5,451.13 12,200.00 90.00 194.34 6,351.00 6,192.00 -5,477.47 -1,005.68 0.00 5,551.12 12,299.43 90.00 194.34 6,351.00 6,192.00 -5,573.80 -1,030.30 0.00 5,650.54 12,300.00 90.00 194.33 6,351.00 6,192.00 -5,574.36 -1,030.44 1.00 5,651.11 12,300.24 90.00 194.33 6,351.00 6,192.00 -5,574.59 -1,030.50 1.00 5,651.35 12,390.20 89.10 194.32 6,351.71 6,192.71 -5,661.75 -1,052.75 1.00 5,741.30 12,400.00 89.10 194.32 6,351.86 6,192.86 -5,671.24 -1,055.18 0.00 5,751.10 12,500.00 89.10 194.32 6,353.43 6,194.43 -5,768.12 -1,079.91 0.00 5,851.08 12,600.00 89.10 194.32 6,355.00 6,196.00 -5,865.01 -1,104.64 0.00 5,951.06 12,700.00 89.10 194.32 6,356.57 6,197.57 -5,961.89 -1,129.37 0.00 6,051.04 12,800.00 89.10 194.32 6,358.14 6,199.14 -6,058.77 -1,154.10 0.00 6,151.02 12,900.00 89.10 194.32 6,359.71 6,200.71 -6,155.65 -1,178.84 0.00 6,251.00 13,000.00 89.10 194.32 6,361.28 6,202.28 -6,252.53 -1,203.57 0.00 6,350.98 13,100.00 89.10 194.32 6,362.85 6,203.85 -6,349.41 -1,228.30 0.00 6,450.97 13,200.00 89.10 194.32 6,364.42 6,205.42 -6,446.29 -1,253.03 0.00 6,550.95 13,291.18 89.10 194.32 6,365.85 6,206.85 -6,534.63 -1,275.58 0.00 6,642.11 13,300.00 89.19 194.33 6,365.98 6,206.98 -6,543.17 -1,277.76 1.00 6,650.93 13,301.18 89.20 194.33 6,366.00 6,207.00 -6,544.32 -1,278.05 1.00 6,652.11 13,305.39 89.24 194.35 6,366.06 6,207.06 -6,548.40 -1,279.10 1.00 6,656.32 13,400.00 89.24 194.35 6,367.31 6,208.31 -6,640.04 -1,302.54 0.00 6,750.91 13,500.00 89.24 194.35 6,368.64 6,209.64 -6,736.92 -1,327.31 0.00 6,850.90 13,600.00 89.24 194.35 6,369.97 6,210.97 -6,833.79 -1,352.09 0.00 6,950.88 13,700.00 89.24 194.35 6,371.30 6,212.30 -6,930.66 -1,376.86 0.00 7,050.87 13,800.00 89.24 194.35 6,372.63 6,213.63 -7,027.54 -1,401.64 0.00 7,150.85 13,900.00 89.24 194.35 6,373.96 6,214.96 -7,124.41 -1,426.42 0.00 7,250.83 14,000.00 89.24 194.35 6,375.28 6,216.28 -7,221.28 -1,451.19 0.00 7,350.82 14,100.00 89.24 194.35 6,376.61 6,217.61 -7,318.16 -1,475.97 0.00 7,450.80 14,200.00 89.24 194.35 6,377.94 6,218.94 -7,415.03 -1,500.74 0.00 7,550.79 14,300.00 89.24 194.35 6,379.27 6,220.27 -7,511.90 -1,525.52 0.00 7,650.77 14,317.22 89.24 194.35 6,379.50 6,220.50 -7,528.58 -1,529.79 0.00 7,667.99 14,400.00 90.07 194.33 6,380.00 6,221.00 -7,608.78 -1,550.28 1.00 7,750.76 14,400.35 90.07 194.33 6,380.00 6,221.00 -7,609.12 -1,550.37 1.00 7,751.11 14,400.93 90.07 194.32 6,380.00 6,221.00 -7,609.69 -1,550.52 1.00 7,751.70 8/25/2016 3:55:07PM Page 8 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 TVDss +N/ -S Design: 2S-06wpl3 Vert Section (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (^) (I (usft) usft (usft) (usft) 6,220.88 14,500.00 90.07 194.32 6,379.88 6,220.88 -7,705.67 -1,575.03 0.00 7,850.76 14,600.00 90.07 194.32 6,379.75 6,220.75 -7,802.56 -1,599.77 0.00 7,950.75 14,700.00 90.07 194.32 6,379.63 6,220.63 -7,899.46 -1,624.51 0.00 8,050.74 14,800.00 90.07 194.32 6,379.50 6,220.50 -7,996.35 -1,649.25 0.00 8,150.74 14,900.00 90.07 194.32 6,379.38 6,220.38 -8,093.24 -1,673.99 0.00 8,250.73 15,000.00 90.07 194.32 6,379.25 6,220.25 -8,190.13 -1,698.73 0.00 8,350.72 15,100.00 90.07 194.32 6,379.13 6,220.13 -8,287.02 -1,723.47 0.00 8,450.71 15,200.00 90.07 194.32 6,379.00 6,220.00 -8,383.91 -1,748.21 0.00 8,550.71 41/2" x 63/4" 15,200.67 90.07 194.32 6,379.00 6,220.00 -8,384.56 -1,748.38 0.00 8,551.37 15,200.82 90.07 194.32 6,379.00 6,220.00 -8,384.71 -1,748.42 3.00 8,551.53 15,300.00 87.09 194.32 6,381.45 6,222.45 -8,480.76 -1,772.94 3.00 8,650.66 15,369.82 85.00 194.32 6,386.27 6,227.27 -8,548.25 -1,790.16 3.00 8,720.30 15,400.00 85.00 194.32 6,388.90 6,229.90 -8,577.38 -1,797.60 0.00 8,750.37 15,500.00 85.00 194.32 6,397.61 6,238.61 -8,673.90 -1,822.24 0.00 8,849.98 15,600.00 85.00 194.32 6,406.33 6,247.33 -8,770.43 -1,846.88 0.00 8,949.59 15,700.00 85.00 194.32 6,415.04 6,256.04 -8,866.95 -1,871.52 0.00 9,049.20 15,756.87 85.00 194.32 6,420.00 6,261.00 -8,921.85 -1,885.53 0.00 9,105.86 15,800.00 85.00 194.32 6,423.76 6,264.76 -8,963.48 -1,896.16 0.00 9,148.82 15,837.19 85.00 194.32 6,427.00 6,268.00 -8,999.37 -1,905.32 0.00 9,185.86 15,900.00 85.63 194.32 6,432.13 6,273.13 -9,060.03 -1,920.81 1.00 9,248.46 16,000.00 86.63 194.32 6,438.88 6,279.88 -9,156.70 -1,945.48 1.00 9,348.22 16,100.00 87.63 194.32 6,443.89 6,284.89 -9,253.47 -1,970.18 1.00 9,448.09 16,200.00 88.63 194.32 6,447.16 6,288.16 -9,350.31 -1,994.91 1.00 9,548.03 16,300.00 89.63 194.32 6,448.68 6,289.68 -9,447.19 -2,019.64 1.00 9,648.01 16,347.60 90.10 194.32 6,448.79 6,289.79 -9,493.31 -2,031.41 1.00 9,695.60 Adjust TF to 0", for 600' 16,400.00 90.63 194.32 6,448.46 6,289.46 -9,544.08 -2,044.37 1.00 9,748.00 16,500.00 91.63 194.32 6,446.49 6,287.49 -9,640.95 -2,069.10 1.00 9,847.97 16,600.00 92.63 194.32 6,442.78 6,283.78 -9,737.78 -2,093.81 1.00 9,947.89 16,637.19 93.00 194.32 6,440.95 6,281.95 -9,773.77 -2,103.00 1.00 9,985.03 16,700.00 93.00 194.32 6,437.66 6,278.66 -9,834.55 -2,118.52 0.00 10,047.75 16,800.00 93.00 194.32 6,432.43 6,273.43 -9,931.31 -2,143.22 0.00 10,147.61 16,847.60 93.00 194.32 6,429.94 6,270.94 -9,977.36 -2,154.97 0.00 10,195.14 TD: 16847.6' MD, 6410.27' TVD 16,865.53 93.00 194.32 6,429.00 6,270.00 -9,994.72 -2,159.40 0.00 10,213.05 16,900.00 91.97 194.32 6,427.51 6,268.51 -10,028.08 -2,167.92 3.00 10,247.48 16,965.53 90.00 194.32 6,426.38 6,267.38 -10,091.56 -2,184.12 3.00 10,313.00 17,000.00 90.00 194.32 6,426.38 6,267.38 -10,124.96 -2,192.65 0.00 10,347.46 17,100.00 90.00 194.32 6,426.38 6,267.38 -10,221.85 -2,217.38 0.00 10,447.45 17,200.00 90.00 194.32 6,426.38 6,267.38 -10,318.75 -2,242.12 0.00 10,547.45 17,300.00 90.00 194.32 6,426.38 6,267.38 -10,415.64 -2,266.85 0.00 10,647.44 17,400.00 90.00 194.32 6,426.38 6,267.38 -10,512.53 -2,291.58 0.00 10,747.43 17,500.00 90.00 194.32 6,426.38 6,267.38 -10,609.43 -2,316.32 0.00 10,847.43 17,600.00 90.00 194.32 6,426.38 6,267.38 -10,706.32 -2,341.05 0.00 10,947.42 8/25/2016 3:55:07PM Page 9 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 25-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159,00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 TVDss +N/ -S Design: 2S-06wp13 Vert Section (usft) Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) 6,267.38 17,700.00 90.00 194.32 6,426.38 6,267.38 -10,803.21 -2,365.79 0.00 11,047.41 17,800.00 90.00 194.32 6,426.38 6,267.38 -10,900.10 -2,390.52 0.00 11,147.40 17,900.00 90.00 194.32 6,426.38 6,267.38 -10,997.00 -2,415.25 0.00 11,247.40 18,000.00 90.00 194.32 6,426.38 6,267.38 -11,093.89 -2,439.99 0.00 11,347.39 18,100.00 90.00 194.32 6,426.38 6,267.38 -11,190.78 -2,464.72 0.00 11,447.38 18,200.00 90.00 194.32 6,426.38 6,267.38 -11,287.68 -2,489.45 0.00 11,547.38 18,300.00 90.00 194.32 6,426.38 6,267.38 -11,384.57 -2,514.19 0.00 11,647.37 18,400.00 90.00 194.32 6,426.38 6,267.38 -11,481.46 -2,538.92 0.00 11,747.36 18,500.00 90.00 194.32 6,426.38 6,267.38 -11,578.35 -2,563.65 0.00 11,847.35 18,600.00 90.00 194.32 6,426.38 6,267.38 -11,675.25 -2,588.39 0.00 11,947.35 18,700.00 90.00 194.32 6,426.38 6,267.38 -11,772.14 -2,613.12 0.00 12,047.34 18,800.00 90.00 194.32 6,426.38 6,267.38 -11,869.03 -2,637.86 0.00 12,147.33 18,900.00 90.00 194.32 6,426.38 6,267.38 -11,965.93 -2,662.59 0.00 12,247.33 19,000.00 90.00 194.32 6,426.38 6,267.38 -12,062.82 -2,687.32 0.00 12,347.32 19,100.00 90.00 194.32 6,426.38 6,267.38 -12,159.71 -2,712.06 0.00 12,447.31 19,200.00 90.00 194.32 6,426.38 6,267.38 -12,256.61 -2,736.79 0.00 12,547.31 19,300.00 90.00 194.32 6,426.38 6,267.38 -12,353.50 -2,761.52 0.00 12,647.30 19,400.00 90.00 194.32 6,426.38 6,267.38 -12,450.39 -2,786.26 0.00 12,747.29 19,500.00 90.00 194.32 6,426.38 6,267.38 -12,547.28 -2,810.99 0.00 12,847.28 19,600.00 90.00 194.32 6,426.38 6,267.38 -12,644.18 -2,835.73 0.00 12,947.28 19,700.00 90.00 194.32 6,426.38 6,267.38 -12,741.07 -2,860.46 0.00 13,047.27 19,715.53 90.00 194.32 6,426.38 6,267.38 -12,756.12 -2,864.30 0.00 13,062.80 8/25/2016 3:55:07PM Page 10 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 plan misses target center by 18.24usft at 16850.44usft MD (6429.79 TVD, -9980.11 N, -2155.67 E) Design: 2S-06wp13 2S -Nurse 2 -Toe 0.00 0.00 6,269.00 4,199.60 5,479.68 Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E1 -W Shape V) (1) (usft) (usft) (usft) 2S -Salmon 1.Heel 032515 VO 0.00 0.00 6,329.00 -1,262.29 -180.45 plan misses target center by 251.06usft at 7910.48usft MD (6387.25 TVD, -1322.14 N, 56.31 E) Circle (radius 100.00) 2S -Salmon 1. Heel 050216 PB 0.00 0.00 6,375.00 -1,107.22 111.24 plan hits target center - Circle (radius 100.00) 2S-06 int 11 082416 KA 0.00 0.00 6,448.00 -9,980.91 -2,156.39 plan misses target center by 18.24usft at 16850.44usft MD (6429.79 TVD, -9980.11 N, -2155.67 E) Circle (radius 100.00) 2S -Nurse 2 -Toe 0.00 0.00 6,269.00 4,199.60 5,479.68 plan misses target center by 6200.62usft at 5101.11 usft M D (4894.00 TVD, 813.63 N, 470.47 E) Circle (radius 100.00) 2S-06 int 1 082416 KA 0.00 0.00 6,373.00 -2,474.25 -238.31 plan hits target center Circle (radius 100.00) 2S -Salmon 1. Heel 041916 PB 0.00 0.00 6,329.00 -1,107.22 111.24 plan misses target center by 45.82usft at 7683.65usft MD (6374.59 TVD, -1102.78 N, 112.38 E) Circle (radius 100.00) 2S-06 int 3 082416 KA 0.00 0.00 6,351.00 -4,605.86 -782.94 plan hits target center Circle (radius 100.00) 2S-06 int 10 082416 KA 0.00 0.00 6,425.00 -9,450.51 -2,020.73 plan misses target center by 23.70usft at 16303.43usft MD (6448.70 TVD, -9450.51 N, -2020.48 E) Circle (radius 100.00) 2S-06 int 7 082416 KA 0.00 0.00 6,379.00 -8,384.71 -1,748.42 - plan hits target center - Circle (radius 100.00) 2S-06 int 8 082416 KA 0.00 0.00 6,398.00 -8,578.85 -1,797.93 plan misses target center by 8.94usft at 15402.29usft MD (6389.10 TVD, -8579.59 N, -1798.17 E) Circle (radius 100.00) 2S -Salmon 2. Toe 050216 PB 0.00 0.00 6,409.00 -9,496.54 -2,032.61 - plan misses target center by 39.79usft at 16351.28usft MD (6448.79 TVD, -9496.88 N, -2032.32 E) - Circle (radius 100.00) 2S -Salmon 2. Toe 041916 PB 0.00 0.00 6,409.00 -9,098.29 -1,950.62 - plan misses target center by 32.69usft at 15942.79usft MD (6435.23 TVD, -9101.38 N, -1931.36 E) - Circle (radius 100.00) 2S -Salmon 2. Toe 050216 PB -Circle 0.00 0.00 6,409.00 -9,496.54 -2,032.61 plan misses target center by 39.79usft at 16351.28usft MD (6448.79 TVD, -9496.88 N, -2032.32 E) - Circle (radius 1,320.00) 2S -Salmon 1. Heel 050216 PB -Circle 0.00 0.00 6,375.00 -1,107.22 111.24 - plan hits target center - Circle (radius 1,320.00) 2S-06 extend TD 082416 KA 0.00 0.00 6,459.00 -12,742.24 -2,960.44 plan misses target center by 102.47usft at 19715.53usft MD (6426.38 TVD, -12756.12 N, -2864.30 E) - Circle (radius 100.00) 2S -Nurse 1.Heel_Cirlce 0.00 0.00 6,355.00 -1,604.15 3,955.48 plan misses target center by 3852.06usft at 7298.98usft MD (6308.53 TVD, -735.28 N, 202.98 E) Circle (radius 1,320.00) 2S-06 int 9 082416 KA 0.00 0.00 6,419.00 -8,869.07 -1,872.20 - plan misses target center by 3.75usft at 15702.56usft MD (6415.27 TVD -8869.42 N -1872.15 E) 8/25/2016 3:55:07PM Page 11 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.O0usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 Design: 2S-06wp13 0.00 6,351.00 - Circle (radius 100.00) Measured Vertical Casing Hole 2S-06 int 5 082416 KA 0.00 0.00 6,366.00 -6,544.32 -1,278.05 plan hits target center 2,661.00 10-3/4" x 13-1/2" 10-3/4 13-1/2 7,688.26 6,375.00 7-5/8" x 9-7/8" by 11" 7-5/8 11 Circle (radius 100.00) 6,379.00 4 1/2" x 6-3/4" 4-1/2 6-3/4 2S-06 int4 082416 KA 0.00 0.00 6,351.00 -5,574.59 -1,030.50 plan hits target center Circle (radius 100.00) 2S-06 int 2 082416 KA 0.00 0.00 6,342.00 -3,442.98 -485.87 plan hits target center Circle (radius 100.00) 2S-06 X1 082516 0.00 0.00 6,420.00 -9,043.92 -1,916.95 plan misses target center by 10.81 usft at 15882.50usft MD (6430.77 TVD, -9043.13 N, -1916.49 E) Point 2S-06 int 6 082416 KA 0.00 0.00 6,380.00 -7,609.12 -1,550.37 plan hits target center Circle (radius 100.00) 2S-06 int 12 082416 KA 0.00 0.00 6,459.00 -10,129.02 -2,194.02 plan misses target center by 32.62usft at 17004.27usft MD (6426.38 TVD, -10129.10 N, -2193.71 E) Circle (radius 100.00) 2S -Salmon 2. Toe 032715 VO 0.00 0.00 6,409.00 -9,000.67 -2,212.74 plan misses target center by 298.52usft at 15913.10usft MD (6433.11 TVD, -9072.68 N, -1924.04 E) Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 2,779.13 2,661.00 10-3/4" x 13-1/2" 10-3/4 13-1/2 7,688.26 6,375.00 7-5/8" x 9-7/8" by 11" 7-5/8 11 15,200.00 6,379.00 4 1/2" x 6-3/4" 4-1/2 6-3/4 8/25/2016 3:55:07PM Page 12 COMPASS 5000.1 Build 74 Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2S-06 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad North Reference: True Well: Rig: 2S-06 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2S-06 6,174.00 Upper Kalubik (base HRZ) Design: 2S-06wp13 A4 374.00 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology 3,082.91 2,944.00 C-80 1,907.51 1,849.00 Top W Sak (W Sak D) 1,434.90 1,409.00 Base permafrost (?) 6,898.65 6,174.00 Upper Kalubik (base HRZ) 7,628.32 6,369.00 A4 374.00 374.00 K-15 Marker 6,137.09 5,749.00 Base Bermuda 6,044.66 5,684.00 Top Bermuda 5,101.11 4,894.00 C-37 289.00 289.00 top T-3 Sand 5,264.08 5,044.00 Growler -AA 4,838.29 4,644.00 C-40 4,471.55 4,284.00 C-50 6,698.97 6,083.00 Top HRZ (K-2 mkr) 6,188.50 5,784.00 C-35 7,551.20 6,359.00 A5 7,460.66 6,344.00 Kuparuk C (Top C4) 7,143.26 6,264.00 Lower Kalubik (K-1 mkr) 2,653.54 2,544.00 Base W Sak 5,928.92 5,599.00 Top Cairn Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 425.00 425.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' 600.06 600.00 4.01 0.00 Start 2.5°/100' DLS, 0° TF, for 780.86' 1,380.92 1,359.00 170.70 0.00 Hold for 107.97' 1,488.89 1,459.00 211.41 0.00 Start 3°/100' DLS, 107.93° TF, for 358.82' 1,847.71 1,793.30 336.30 31.98 Hold for 1617.06' 3,464.77 3,299.73 849.09 319.34 Start 2.5°/100' DLS, 164.54° TF, for 4223.49' 7,688.26 6,375.00 -1,107.22 111.24 Hold for 20' 7,708.26 6,376.74 -1,126.53 106.31 Start 2°/100' DLS, 0° TF, for 242.71' 7,950.97 6,387.64 -1,361.37 46.28 Hold for 8396.63' 16,347.60 6,424.78 -9,493.63 -2,031.74 Adjust TF to 0°, for 500' 16,847.60 6,450.09 -9,977.41 -2,155.30 TD: 16847.6' MD, 6410.27' TVD 8/25/2016 3: 55 07P Page 13 COMPASS 5000. 1 Build 74 AC Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Rig: 2S-06 Rig: 2S-06 50103xxxxx00 2S-06wp13 Clearance Summary Anticollision Report 25 August, 2016 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Rig: 2S-06 - Rig: 2S-06 - 2S-06wp13 Well Coordinates: 5,929,754.39 N, 1,621,195.59 E (70° 13' 10.63" N, 150° 09,118.26" W) Datum Height: Plan: 120+39 @ 159.00usft (Doyon142) Scan Range: 0.00 to 19,715.53 usft. Measured Depth. Scan Radius is 2,167.65 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Rig: 2S-06 - 2S-06wpl3 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Rig: 2S-06 - Rig: 2S-06 - 2S-06wp13 Scan Range: 0.00 to 19,715.63 usft. Measured Depth. Scan Radius is 2,167.65 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad 2S-01 - 2S-01 - 25-01 349.36 147.26 349.36 141.05 350.00 23.715 Centre Distance Pass - Major Risk 2S-01 - 2S-01 - 2S-01 399.35 147.54 399.35 140.50 400.00 20.957 Clearance Factor Pass - Major Risk 2S-02 - 2S-02 - 2S-02 261.50 119.37 261.50 112.53 250.00 17.448 Centre Distance Pass - Major Risk 2S-02 - 2S-02 - 2S-02 361.46 119.99 361.46 111.74 350.00 14.539 Clearance Factor Pass - Major Risk 2S-03 - 2S-03 - 2S-03 324.31 87.82 324.31 82.06 325.00 15.237 Centre Distance Pass - Major Risk 2S-03 - 2S-03 - 2S-03 424.19 88.60 424.19 81.11 425.00 11.827 Clearance Factor Pass - Major Risk 2S-03 - 2S-03PB1 - 2S-03PB1 324.31 87.82 324.31 82.06 325.00 15.237 Centre Distance Pass - Major Risk 2S-03 - 2S-03PB1 - 2S-03PB1 424.19 88.60 424.19 81.11 425.00 11.827 Clearance Factor Pass - Major Risk 2S-04 - 2S-04 - 2S-04 761.11 52.71 761.11 40.28 750.00 4.239 Centre Distance Pass - Major Risk 2S-04 - 2S-04 - 2S-04 785.68 52.83 785.68 40.06 775.00 4.137 Clearance Factor Pass - Major Risk 2S-04 - 2S-04PB1 - 2S-04PB1 761.11 52.71 761.11 40.28 750.00 4.239 Centre Distance Pass - Major Risk 2S-04 - 2S-04PB1 - 2S-04PB1 785.68 52.83 785.68 40.06 775.00 4.137 Clearance Factor Pass - Major Risk 2S-05 - 2S-05 - 2S-05 561.46 26.77 561.46 17.32 550.00 2.833 Centre Distance Pass - Major Risk 2S-05 - 2S-05 - 25-05 611.26 27.05 611.26 16.80 600.00 2.639 Clearance Factor Pass - Major Risk 2S-07 - 2S-07 - 2S-07 39.00 29.52 39.00 28.30 27.50 24.010 Centre Distance Pass - Major Risk 2S-07 - 2S-07 - 2S-07 486.35 31.30 486.35 16.90 475.00 2.173 Clearance Factor Pass - Major Risk 2S-08 - 2S-08 - 2S-08 286.49 58.66 286.49 53.60 275.00 11.598 Centre Distance Pass - Major Risk 2S-08 - 2S-08 - 2S-08 361.46 59.26 361.46 52.95 350.00 9.389 Clearance Factor Pass - Major Risk 2S-10 - 2S-10 - 2S-10 585.37 115.80 585.37 105.92 575.00 11.721 Centre Distance Pass - Major Risk 2S-10 - 2S-10 - 2S-10 830.81 116.65 830.81 103.39 825.00 8.798 Clearance Factor Pass - Major Risk 2S-11 - 2S-11 - 2S-11 399.29 148.68 399.29 141.69 400.00 21.254 Centre Distance Pass - Major Risk 2S-11 - 2S-11 -2S-11 473.65 149.45 473.65 141.19 475.00 18.084 Clearance Factor Pass - Major Risk 2S-12 - 2S-12 - 2S-12 39.00 179.98 39.00 178.97 27.50 178.037 Centre Distance Pass - Major Risk 2S-12 - 2S-12 - 2S-12 584.92 182.57 584.92 172.72 575.00 18.543 Clearance Factor Pass - Major Risk 2S-12 - 2S-12PB1 - 2S-12PB1 39.00 179.98 39.00 178.97 27.50 178.037 Centre Distance Pass - Major Risk 2S-12 - 2S-12PB1 - 2S-12PB1 584.92 182.57 584.92 172.72 575.00 18.543 Clearance Factor Pass - Major Risk 2S-14 - 2S-14 - 2S-14 324.89 239.26 324.89 233.58 325.00 42.102 Centre Distance Pass - Major Risk 2S-14 - 2S-14 - 2S-14 449.41 240.13 449.41 232.36 450.00 30.927 Clearance Factor Pass - Major Risk 25 August, 2016 - 15:12 Page 2 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Rig: 2S-06 - 2S-06wpl3 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Rig: 25-06 - Rig: 2S-06 - 2S-06wp13 Scan Range: 0.00 to 19,715.53 usft. Measured Depth. Scan Radius is 2,167.65 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Plan: 2S-09 - Plan: 2S-09 - 2S-09wp08.1 350.00 90.03 350.00 83.81 350.00 14.482 Centre Distance Pass - Major Risk Plan: 2S-09 - Plan: 2S-09 - 2S-09wp08.1 7,093.48 165.77 7,093.48 63.04 7,225.00 1.614 Clearance Factor Pass - Major Risk Plan: 2S-315 - Plan: 2S-315 - 2S-315wp02 400.00 210.25 400.00 203.16 400.00 29.656 Centre Distance Pass - Major Risk Plan: 2S-315 - Plan: 2S-315 - 2S-315wp02 449.71 210.58 449.71 202.68 450.00 26.661 Clearance Factor Pass - Major Risk Rig: 2S-06 - Rig: 2S-06 - Rig: 2S-06 - Rig: 2S-06 - Rig: 2S-06 - Rig: 2S-06 - Non -Pad Shark Tooth #1 - Shark Tooth #1 - Shark Tooth #1 10,454.63 1,003.25 10,454.63 885.15 6,325.00 8.495 Clearance Factor Pass - Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 750.00 2S-06wp13 GYD-GC-SS 750.00 1,750.00 2S-06wp13 MWD 750.00 2,779.13 2S-06wp13 MWD+IFR-AK-CAZ-SC 2,779.13 4,281.49 2S-06wp13 MWD 2,779.13 7,688.26 2S-06wp13 MWD+IFR-AK-CAZ-SC 7,688.26 7,708.26 2S-06wp13 MWD 7,688.26 19,715.53 2S-06wp13 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 25 August, 2016 - 15:12 Page 3 of 5 COMPASS Ladder View 16:21, August 25 201 2 S- 0 6w p 1 3 The Reference Well is the X-axis. along rror Ellipses are the Sum of the Reference and Offset Well Errors. N v3ai mm m na a n o q N N N o N N 300— 00 d) d) i � I 150' - -- --- - — — — U I 0 Equlvelant Magnetic Distance U -4 I¢ 0 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire well:Measured Depth 39.00 To 19715.53 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 750.00 2S-06wp13 (Rig: 2S-06) GYD-GC-SS 2661.00 2779.13 10-3/4" x 13-1/2" 750.00 1750.00 2S-06wp13 (Rig: 2S-06) MWD 6375.00 7688.26 7-5/8" x 9-7/8" by 11" 750.00 2779.13 2S-06wp13 (Rig: 2S-06) MWD+IFR-AK-CAZ-SC 6379.00 15200.00 4 1/2" x 6-3/4" 2779.13 4281.49 2S-06wp13 (Rig: 2S-06) MWD 2779.13 7688.26 2S-06wp13 (Rig: 2S-06) MWD+IFR-AK-CAZ-SC 7688.26 7708.26 2S-06wp13 (Rig: 2S-06) MWD 7688.26 19715.53 2S-06wp13 (Rig: 2S-06) MWD+IFR-AK-CAZ-SC Q N m a qhq N Y (h t%1 ✓q! N N N 60 co U) Q 30 - — -- -- ---- - -- -- ---- U o � U 0 z7- 0 250 500 750 1000 1250 1500 Partial Measured Depth N Inc Ali TVD +N/ -S +E/ -W Dleg TFace Target 39.1 .00 0.00 39.00 0.00 0.00 0.00 0.00 2S-06wp13 425.00 0.00 0.00 425.00 0.00 0.00 0.00 0.00 O.uO 425 ---- 610 600.06 2.63 0.00 600.00 4.01 0.00 1.50 0.00 -3.87 39.00 To 19715.53 1380.92 1488.89 22.15 22.15 0.00 0.00 1359.00 1459.0 0 170.70 211.41 0.00 0.00 2.50 0 .00 0.00 0.00 -164.89 -204.20 610 790 1847.71 21.32 29.27 1793.30 336.30 31.98 3.00 107.93 -333.12 3464.77 21.32 29.27 3299.73 849.09 319.34 0.00 0.00 -902.81 790 970 7688.26 85.00 194.33 6375.00 -1107.22 111.24 2.50 164.54 1040.70 2S -Salmon 1. Heel 050216 P8 16.08. AuauS1 25 2016 7708.26 85.00 194.33 6376.74 -1126.53 106.31 0.00 0.00 1060.62 970 1150 7995.55 90-75 194.34 6387.40 -1404.55 35.24 2.00 0.10 1347.57 9087.05 90.75 194.34 6373.19 -2461.93 -235-16 0.00 0.00 2438.91 1150 1340 SURVEY PROGRAM 9099.76 91.00 194.34 6373.00 -2474.25 -238.31 2.00 -1.02 2451.62 2S-06 int 1 082416 KA 9143.97 91.88 194.34 6371.89 -2517.07 -249.26 2.00 -0.32 2495.81 pN Rrom oepm go su Wp- 1., 3s oa 756.60 2S-0 pt3(Rig: 2-) Gro- C- 10005.92 91.88 194.34 6343.55 -3351.73 -462.55 0.00 0.00 3357.24 1340 1520 750-17w.00 2-O Pv 3 (Rig: 21.) mw. 10100.12 90.00 194.33 6342.00 -3442.98 -485.87 2.00 -179.94 3451.42 2S-06 int 2 082416 KA 71- 2;'13 2"-0 ,,13 (Rig: 2506) Mwo.1rm-Ax-caz-sc 27A.13 25-0fiwpl](Rig:25-06) MWO 10722.21 89.56 194.33 6342.09 -3464.39 -491.34 2.00 -179.65 3473.51 ---- 1520" 1700 4201A9 29]9.13 760026 2S-0fiwp13(Ri9: 28 d6) MW -M -A -M-w 11256.19 89.56 194.33 6350.83 -4563.05 -772.00 0.00 0.00 4607.38 76�.z6 -26 'S-pt3 (Rig: 28-06) MWD 7fi0026 19715.53 2"",,13 (Rig: 2-6) MwG 1 -Ax-cat-9c 11300.38 90.00 194.33 6351.00 -4605.86 -782.94 1.00 0.22 4651.56 2S-06 int 3 082416 KA 1700 2330 11300.69 90.00 194.34 6351.00 -4606.16 -783.02 1.00 90.00 4651.87 12299.43 90.00 194.34 6351.00 -5573.80 -1030.30 0.00 0.00 5650.54 CASING DETAILS 72300.24 90.00 194.33 6351.00 -5574.59 -1030.50 1.00 -90.00 5651.35 2S-06 int 4 082416 KA 2330 2950 12390.20 89.10 194.32 6351.71 -5661.75 -1052.75 1.00 -179.58 5741.30 TVD MD Name Size 13291.18 89.10 194.32 6365.85 -6534.63 -1275.58 0.00 0.00 6642.11 2950 3580 2661.00 2779.13 10-3/4" x 13-1/2" 10-3/4 13301.18 89.20 194.33 6366.00 -6544.32 -1278.05 1.00 5.48 6652.11 2S-06 int 5 082416 KA 6375.00 7688.2'i/8" x 9-7/8" by 11" 7-5/8 13305.39 89.24 194.35 6366.06 -6548.40 -1279.10 1.00 22.62 6656.32 6379.00 15200.00 41/2"x6-3/4" 4-1/2 14317.22 89.24 194.35 6379.50 -7528.58 -1529.79 0.00 0.00 7667.99 3580 4200 14400.35 90.07 194.33 6380.00 -7609.12 -1550.37 1.00 -1.12 7751.11 2S-06 int 6 082416 KA 14400.93 90.07 194.32 6380.00 -7609.69 -1550.52 1.00 -74.34 7751.70 4200 4830 15200.67 90.07 194.32 6379.00 -8384.56 -1748.38 0.00 0.00 8551.37 15200.82 90.07 194.32 6379.00 -8384.71 -1748.42 3.00 -109.86 8551.53 2S-06 int 7 082416 KA 4830 5450 15369.82 85.00 194.32 6386.27 -8548.25 -1790.16 3.00 180.00 8720.30 15756.87 85.00 194.32 6420.00 -8921.85 -1885.53 0.00 0.00 9105.86 15837.19 85.00 194.32 6427.00 -8999.37 -1905.32 0.00 0.00 9185.86 5450 6080 16637.19 93.00 194.32 6440.95 -9773.77 -2103.00 1.00 0.00 9985.03 16865.53 93.00 194.32 6429.00 -9994.72 -2159.40 0.00 0.00 10213.05 6080 6700 16965.53 90.00 194.32 6426.38 -10091.56 -2184.12 3.00 180.00 10313.00 19715.53 90.00 194.32 6426.38 -12756.12 -2864.30 0.00 0.00 13062.80 6700 7970 -30/330 210 30 7970 9240 195 9240 __._._. 10510 180 10510 11780 165 11780 -- 13040 2s-o9wpo6.1 13040 14310 150 14310 15580 13 7 -60/300 12 60 15580 16848 10 90 . 7 81 503P61 60 R7 S-06 2060 3 -90/270 90 3 98 4 S -12P61 60 2572 63 75 1 2S -315.p02 90 ' 10 zs-ot 25-08 12 9 -120/240 120 13 o � - 2502 107 -150/2 0 150 zs-10 -180//f 2505 2 507 i 2S -04P61 2504 it z6s :6 p ,s z6 zs $ x 4 PaR p�wa,V. 9 zso>. zs pae,, zs mae, Vp -f- zs m. 2so,. zsp,w �1F :s,:. zs,z. xs,xvp i- aa2 zsa,s, Aa�zsa�s. xsa swum va 16:06, August 25 201 AC wells ONLY (NOT a Spider) Prelim: Kuparuk Easting (3000 usft/in) Easting (3000 usft/in) 7 Pool Report 11 17:05, August 25 2016 X W 0 -3000 0 0 0 Co -6000 0 z F 0 -9000 I-12000 2S-06wp13 Quarter Mile View -15000 -12000 -9000 -6000 -3000 0 3000 6000 9000 West( -)/East(+) (3000 usft/in) WELLBORE TARGET DETAILS (MAP COORDINATES) Name TVD Shape 25-06 int 2 082416 KA 6342.00 Circle (Radius: 100.00) 25-06 int 3 082416 KA 6351.00 Circle (Radius: 100.00) 2S-06 int 4 082416 KA 6351.00 Circle (Radius: 100.00) 25-06 int 5 082416 KA 6366.00 Circle (Radius: 100.00) 2S-06 int 1 082416 KA 6373.00 Circle (Radius: 100.00) - a monT. ee uc e a s: 25-06 int7 082416 KA 6379.00 Circle (Rwadius: 100.00) 2S -06m 6 082416 KA 6380.00 Circle (Radius: 100.00) 25-06 int 8 082416 KA 6398.00 Circle (Radius: 100.00) 2S -Salmon 2. Toe 050216 PB 6409.00 Circle (Radius: 100.00) 2S-06 int 9 082416 KA 6419.00 Circle (Radius: 100.00) -15000 -12000 -9000 -6000 -3000 0 3000 6000 9000 West( -)/East(+) (3000 usft/in) C� 0 2S-06wp10 Surface Location CPAI Coordinate Convener' tt '- O' �AINr lltl� From: _ _ _ _ To: Datum: NApg3 + Region: alaska Datum: JNAD27 ►' Region: alaska C Latitude/Longitude Decimal Degrees Latitude/Longitude Decimal Degrees y I t ' UTM Zone: �� South t"' UTM Zone::True i4 South State Plane Zone: 14 + Units: us-ft + ri State Plane Zone: 4 + Units: us Fk + t Legal Description (NAD27 only) C-- Legal Description (NAD27 only) Starting Coordinates: - Ending Coordinates: -- - - X: 1621195.59 X: 481162.271120299 Y: 15929754.39 Y: 5930004.80121475 ........................................ .................. € Transform Quit Help 2S-06wp10 Surface Casing CPAI Coordinate Converter:11 From: To: - -- Datum: rrNAD83 + Region: (alaska + Datum: N4D27 Region: alaska + a i Latitude/Longitude Decimal Degrees r Latitude/Longitude IDecimal Degrees >t"'' UTM Zone: — F South r UTM Zone: ITrue F South t: State Plane Zone: 4 + Units: us-ft + r. State Plane Zone: q + Units: us ft +' f Legal Description (NAD27 only) t" Legal Description (NAD27 only) Starting Coordinates: oordinates:----------- Ending Coordinates:------------- X: X: 11621394.68 X: 1481361.374615991 Y: 5930385.49 Y: 16930635.88476797 ........................................................... Transform Quit Help 2S-06w 10 Intermediate Casing CPAI Coordinate Convert: From: To: Datum: f , 83 - Region: jalaska Datum: NAD27 - Region: alaska i r Latitude/Longitude Decimal Degrees r' Latitude/Longitude IDecimalDegrees 's t' UTM Zone: r j`" South UTM Zone: True South t State Plane Zone: Ij Units: us-ft , Skate Plane Zone:14 Units: Fus_ft t"' Legal Description (NAD27 only) f" Legal Description (NAD27 only) f Starting Coordinates: — - Ending Coordinates: — -- K: 11621304 X: I 481270.667327537 Y: 15628647 Y: 15928897.43351369 ............ . Transform Quit Help 2S-06w 10 Production Horizon �} CPAI Coordinate Conve From: Datum: Region: To: __._..._. -- Datum: Region: INAD83 alaska �� NAD27 alaska w' d Latitude/Longitude Decimal Degrees Latitude/Longitude Decimal Degrees i r UTM Zone: "�- }� South UTM Zone: True f- South r: State Plane Zone: '� Units: us ft State Plane Zone: 4 _.� Units: us ft i Legal Description (NAD27 only) P r_" Legal Description (NAD27 only) Starting Coordinates: --- -- - Ending Coordinates: - - - - -- - - ---- X: 11621318.84 X: 1481285.508498438 Y: 15928704.76 Y: 15928955.19206039 ... Transform Quit Help 2S-06wp13 TD CPAI Coordinate Con -venter., 0 From: To: Datum:NAD83 Region: l Datum: N—AD-27—:DRegion: -1k—a--:-] Latitude/Longitude Decimal DegreesIDecimal Degrees Latitude/Longitude C- UTM Zone: F- South UTM Zone: rTrue r South State Plane Zone: 14Units: Jus -ft State Plane Zone: 14 Units: lus-ft —j Legal Description (NAD27 only) i i a Legal Description (NAD 27 only) Starting Coordinates: Ending Coordinates: ------ - - - X: 1618299.1 X: I 478265.516696775 Y: 15917006.88 Y* 5917257.60027711 Transform € Quit Help 2S-06wp10 Surface Location [� CPAI Coordinate Converter;IN From: - - - - - To: - ---- -- -- _ _ _ Datum: INAD83 Region: alaska J Datum: NAD27 Region: alaska + C- Latitude/Lon itude I---i al 9 .Decimal Degrees + �" Latitude/Longitude itude I�uJ—���� 9 Decimal Degrees r UTM Zone: South r UTM Zone: True F South C« Stake Plane Zone: 4 Units: State Plane Zone: 4 Units: us Ft + i Legal Description (NAD27 only) Starting Coordinates: - - Legal Description - X: 11621195.59 Township: 010 N Range: 008 E Y: 15929754.39 Meridian: JU I Section:117 FNL 13043.2293 IFEL 11408.0056 ........................................................... Transform Quit Help 2S-06wp10 Surface Casing f CPAI Coordinate Convert^ From: _ To: ._ Datum: NAD83 'I Region: alaska Datum: NAD27 + Region: alaska + Latitude/Longitude Decimal Degrees �� Latitude/Longitude Decimal Degrees UTM Zone: — F South UTM Zone: True i South t+` State Plane Zone:4 Units: us-fk +: _jjus-ft f- State Plane Zone: 4 Units: + d Legal Legal Description (NAD27 only) Starting Coordinates: - - - - - Legal Description -- -- X: 11621394.68 Township: 010 N + Range: 008 E Y: 15930385.49 Meridian: JU Section:17 FNL + 2411.5809 FEL 11208.9729 ...................................... .................Transform................., Quit Help 2S-06w 10 Intermediate Casing ®•. CPA9 Coordinate Converter From: To: Datum: NAD83 + Region: alaska Datum: NAD27 - Region: jalaska f" Latitude/Longitude Decimal Degrees i �r' Latitude/Longitude IDecimal Degrees —� C' UTM Zone:— r South r UTM Zone: ITrue y South State Plane Zone:q Units: us ft r State Plane Zone: q + Units: jus.ft + l" k_..--. f e=;iF:±r:•r, i?J,�.C�;' on:_ 1 c: Legal Description (NAD27 only) Starting Coordinates: - - - Legal Description X: 1101304 Township: 010 N + Range: 008 E + Y: 5928647 Meridian: ILI Section:' 17 - FNL 14150.4272 FEL 1300.1419 ........................................................... .Transform Quit Help 2S-06wp10 Production Horizon �- CPA3 Coordinate Converter From: _ _ To: - Datum: INAD63 + Region: alaska -,-] Datum: INAD27 ,, Region: jalaska C Latitude/Longitude IDecimal Degrees Latitude/Longitude IDecimal Degrees i UTM Zone: f- r South r UTM Zone: True r South Stake Plane Zone: q + Units: us-ft +' i State Plane Zone: q + Units: us-ft Le, •sl Cie>+ r�,tic+n Irl. L�=? c,r,I}) (i Legal Description (NAD27 only) Starting Coordinates: --------- Legal Description X: 11621318.84 Township: 010 FN--,-] Range: 008 E + Y: 15928704.76 Meridian: U + Section::77 FNL + 4092.6272 FEL 1285.2654 ... Transform Quit Help 2S-06wp13 TD CPAI Coordinate Converter �_ F --I From: _ _. _ To: _ Datum: Region: NAD83 9 alaska Datum: Region: NAD27 +� �alaska Latitude/Longitude IDecimal Degrees �" Latitude/Longitude Decimal Degrees i UTA4 Zone: - South i ' UTM Zone: True f-• South r:' State Plane Zone:Units: us ft r State Plane Zone: True Units: fu,.ft Legal Description (NAD27 only) Coordinates: ----------- Legal Description - - - - - - FStarting X: 11618299.1 Township:010 N ] Range: 008 E Y: 15917556.89 Meridian: I U Section29 i FNL 1, 15239.4521 FEL 4311.2826 Transform Quit Help As -built 1 5/28/1 SZ I JAH I I Created Drawing Per K140173ACS 1 2 11/14/1 SZ MEH I I Add Well 13 per K150013ACS NOTES, n Kw 19 Oo 17 10 ' 15 14 �A 3 7 ! 116 — 0 14 1. BASIS OF LOCATION AND ELEVATION IS DS2S 19 20 21 22 u 9 s MONUMENTATION PER LOUNSBURY & ASSOC. ►' 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 39 29 28 27 p ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES- �' ; ;, 6s' imv ARE NAD 27. • G�31 3. ELEVATIONS ARE B.P.M.S.L PN T1 ON 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED ---Ace SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, 9 10 11 7 C 9 10 UMIAT MERIDIAN. 3 If! / 4 U IB t7 IB 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS 16 15 L15-28, L15-29, L15-32, L15-35, 11-13-2015R07ECT 22 I23 - FIELD BOOK L15-75. 4 9 21 P 24 19 20 21 22 - LOCATION o 25 --- 29 ,9 ., 6. ALL DISTANCES SHOWN ARE TRUE. r 27 Z 127 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR 13.32 3! 34 3R i 32 3Jt_1 VICINITY MAP N i NTS LEGEND O AS -BUILT CONDUCTOR LOCATION • EXISTING CONDUCTOR LOCATIONS 17 16 20 , 21 GRAPHIC SCALE 0 100 200 400 LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. 1 inch = 200 ft. SREYORS ENGINEERS PLANNERS AREA: 2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 1 CEA-D2SX-6219D24 1 1 of 2 2 REVI DATE IBYICK JAPPI DESCRIPTION IREVI DAIS IBY ICK IAPPI DESCRIPTION 1 5/28/1 SZ I JAH I I Created Drawing Per K140173ACS 1 2 11/14/1 SZ I MEH I Add Well 13 Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN ' ' Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. O.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150' 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150° 09' 08.804" 2224' 1467' 111.1' 120.0- 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 155V 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 190.0- 13 5,929,948.70 480,898.09 70' 13' 11.187" 150° 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' * CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. �•• ♦ SURVEYOR'S CERTIFICATE 4b '49 .........••••• •� •• ••, / LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY �/ .. ....................................../ ' JEREMIAH F. CORNELL�� �r �'. ': DONE BY ME OR UNDER MY DIRECT SUPERVISION AND • . „ r THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER 13, 2015. %14• ,1j �►� to RY ALOUNSB & assoc�r► s, INC. SURVEYORS ENGINEERS PLANNERS AREA: 2S MODULE: XXXX UNIT: D2 ConocoPhilli s DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE N0. LK6219d24 5/2 15 DRAWING NO. 1 CEA-D2SX-6219D24 PART: 1 2 of 2 REV: 2 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, July 25, 2016 8:59 AM To: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Cc: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: 2S-06 Revised(PTD 216-085) Add Fracture Stimulation Kurt, I will add the fracture stimulation to the revised PTD. Thanx, Victoria From: Alexa, Kurt J [maiIto: Kurt.J.Alexa0)conocophill ips.com] Sent: Monday, July 25, 2016 8:45 AM To: Loepp, Victoria T (DOA) Subject: 2S-06 Re -Submittal Victoria, I had a couple questions regarding how the 2S-06 re -submittal works. The initial 2S-06 permit approval and the re- submittal probably crossed paths in the mail room. The team decided to extend the lateral of 2S-06 by 500ft requiring a new directional plan which resulted in the re -submittal of the permit to drill for 2S-06. Will the API number and permit number for the well change because of the re -submittal or will it be the same as what was on the originally approved 2S- 06 permit to drill?(No change in API # or PTD #) In the event that we are ready to begin drilling prior to approval of the re -submittal, do we still have permission to drill to the originally permitted depth or does the re -submittal cancel the existing approved permit?(Need approved resubmitted PTD to drill) Also, I was told this morning that we need to include in the permit application that this well (25-06) will be frac'd. Apologies for not having it in the submittal. Do I need to re -submit again or will this email be sufficient?(This email will suffice) If you have any questions, please don't hesitate to give me a call or shoot me an email. Thanks, Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 (Office) (907) 787-9637 ( Cell ) TRANSMITTAL LETTER CHECKLIST WELL NAME: K 1k lac, PTD: Q 16 - ut Development Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: Z"J&f POOL: t 6T t)d&F Ot I 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' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of 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 Public Well Name: KUPARUK RIV UNIT 2S-06_ Program DEV_ Well bore seg ❑ PTD#:2160850 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / 1 -OIL GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025603, Surf Loc & Top Prod Interv; ADL0025608, TD. 3 Unique well name and number Yes KRU 2S-06 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed 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 wellbore 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 8/26/2016 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile 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 Yes 80' conductor provided Engineering 19 Surface casing protects all known USDWs Yes 2779' MD 20 CMT vol adequate to circulate on conductor & surf csg Yes 128% excess 21 CMT vol adequate to tie-in long string to surf csg No 22 CMT will cover all known productive horizons No Productive interval will be completed with uncemented 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 a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations Yes Diverter meets regulations Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 3650 psig(11.0 ppg EMW); will drill w/ 9.3-11.5 ppg EMW VTL 8/29/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 3013 psig; will test BOPs to 3500 psig 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 1-12S gas probable Yes H2S 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 1-12S measures required. Geology 36 Data presented on potential overpressure zones Yes Max potential reservoir pressure is 11.0 ppg EMW; will be drilled using 9.3 to 11.5 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA PKB 8/26/2016 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development well to be drilled. Geologic Engineering Public Revised application to deepen well to 16847'&change intermediate TOC VTL 7/22/16: Revision 2 - deepen well to 19715'MD. VTL Commissioner: Date: Comm' sioner: Date Commissioner Date 8/29/16 DTS CPF Regg, James B (DOA) P7-6 74('0eScs From: Rig 142 <rigl42@doyondrilling.com> 2efC CI ZA Sent: Tuesday, August 23, 2016 6:23 AM To: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Regg, James B (DOA) Cc: Doyon 142 Company Man Subject: Doyon 142 BOP test 8-22-16 Attachments: 2S-06 BOP Test.xlsx; 2S-06 BOP test chart 8-22-16.pdf, 2S-06 BOP test seq. 8-22-16.pdf Steve Dambacher Rig 142 Toolpusher Email: rigl42@doyondrilling.com Rig office (907)670-6002 Cell, (907)398-4270 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report��� �"� �l Submit to: iim.regg aaalaska.gov AOGCC.I nspectors@alaska.gov phoebe.brooks(o)alaska.gov Contractor: Doyon Rig No.: 142 DATE: 8/22/16 Rig Rep.: S.Dambacher/F.Carlo Rig Phone: 670-6002 Operator: CPAI Op. Phone: 670-6001 Rep.: M.Shotenski/A.Lundale E -Mail rig 142(a.doyondrilling .com Well Name: KRU 2S-06 PTD # 2160850 Sundry # Operation: Test: Test Pressure (psi): Drilling: Initial: Rams: X X 250/3500 Workover: Weekly: Annular: Explor.: Bi -Weekly: 250/3500 - Valves: 250/3500 - MASP: 3013 - MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly I P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type I P nding Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer I 13-5/8"x5000psi P Pit Level Indicators P P #1 Rams 1 3 1/2"X6" P Flow Indicator P P #2 Rams 1 Blind P Meth Gas Detector P P #3 Rams 1 3 1/2"X6" P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3-1/8"x5000psi P Inside Reel valves 0 NA HCR Valves 2 3-1/8"x5000psi P Kill Line Valves 3 3-1/8"x5000psi P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi) 3000 P - CHOKE MANIFOLD: Pressure After Closure (psi) 1800 P _ Quantity Test Result 200 psi Attained (sec) 6 P No. Valves 14 P Full Pressure Attained (sec) 44 P Manual Chokes I P Blind Switch Covers: All stations Yes Hydraulic Chokes I P Nitgn. Bottles # & psi (Avg.): 6ea @ 2633 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 3.5 ' Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: Tested annular, rams #1 & #3 w/ 5" testjoint. Tested lea 4 1/2" if FOSV & Dart valve.Both primary and remote BOP controls functioned tested. Accumulator draw down test performed with 2ea air pumps and 2ea electric triplex pumps. Both the audio and visual alarms for Gas & PVT's tested. AOGCC Inspection 24 hr Notice Yes Date/Time 8/21/16 @ 02:28 Waived By Bob Noble Test Start Date/Time: 8/22/16 @ 19:00 hrs (date) (time) Witness Test Finish Date/Time: 8/22/16 @ 22:30hrs A-44-aclt"� `►3c,1 Pi`�5 +— ct o,, i3oPc- ; NSA ��;,•�„�� Form 10-424 (Revised 11/2015) 2S-06 BOP Test.xlsx . .... ...... .... �,,,_ �-,�.—�Z�� ..;-_`"'�...:-� :��.. s`'`ue (.Ioq tij Z- Kc"L Ftt DOYON RIG 142 BOP TEST 250 LOW/ 3500 HIGH CPA] WELL # 2S-06 8-22-16 WITH 5" TEST JT: TEST 1: CLOSE ANNULAR, 1,12,13,14, 4" KILL LINE ON MUD MANIFOLD, 4 % IF DART VALVE TEST 2: CLOSE TOP RAMS, 9,11, MEZZ KILL LINE, 4 %Z IF FOSV OPEN: ANNULAR, FLOOR KILL LINE, 12 TEST 3: CLOSE 8,10, LEAVE 9 CLOSED, HCR KILL OPEN: 11, MEZZ KILL TEST 4: CLOSE 6,7 OPEN: 8,10, LEAVE 9 CLOSED, LEAVE HCR KILL CLOSED TEST 5: CLOSE SUPER CHOKE AND MAN OPPERATED CHOKE OPEN: 9,7 LEAVE 6 CLOSED TEST 6: CLOSE 25, MAN KILL OPEN: SUPER CHOKE, MAN OPERATED CHOKE, HCR KILL TEST 7: HCR CHOKE, UPPER IBOP OPEN: 1 TEST 8 : MANUAL CHOKE, LOWER IBOP OPEN HCR CHOKE, OPEN UPPER IBOP TEST 9: CLOSE LOWER PIPE RAMS OPEN UPPER PIPE RAMS OPEN RAMS, LEAVE MAN CHOKE VALVE CLOSED AND PERFORM KOOMEY DRAW DOWN TEST. LEAVE HCR CHOKE CLOSED AFTER DRAWDOWN TEST. OPEN MAN CHOKE REMOVE TOP TEST FITTING AND MOVE TO #1 CHOKE VALVE, REMOVE TEST JT. TEST 10: CLOSE: BLINDS, 3,4,6, OPEN: 1,2, 5 & HCR CHOKE TIDE STATE OPAL GOVERNOR BILL WALKER G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 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 2S-06 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-085 (Revised) Surface Location: 2236' FSL, 1408' FEL, SEC. 17, TION, R8E, UM Bottomhole Location: 2464.17' FNL, 3594.91' FEL, SEC. 29, TION, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated July 20, 2016. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, a ie T. Seamount, Jr. Commissioner DATED this 4cday of July, 2016. STATE OF ALASKA AL: A OIL AND GAS CONSERVATION COMM[. ON PERMIT TO DRILL 20 AAC 25.005 Uit,3ED 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑� ' Lateral ❑ 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 Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2S-06 - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16847' TVD: 6410' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 2236' FSL, 1408' FEL, Sec 17, T10N, R8E, UM ADL025603, ADL025608 Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4092.62' FNL, 1285.27' FEL, Sec17, TION, R8E, UM 2677, 2681 8/10/2016 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 2464.17' FNL, 3594.91' FEL, Sec29, T10N, R8E, UM 5035 1,299.99' from ADL025604 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 159 - 15. Distance to Nearest Well Open Surface: x- 481,162.27' y- 5,930,004.80' Zone -4 GL Elevation above MSL (ft): 120 to Same Pool: 1,105.82'f/2S-10 16. Deviated wells: Kickoff depth: 425 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) D Maximum Hole Angle: 89.95 degrees Downhole: 3650 - Surface: 3013 Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks 18. Casing Program: Specifications Hole Casing Weight Grade I Coupling Lengthd7518'6352' TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 80 39' 120' 120' pre -driven, cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2839' 39' 2779' 2661' 1020sx 11 ppg lead/300sx 15.8ppg tail 9.875" 7.625" 29.7# L-80 Hydril 563 8245' 39' 7688' 6375' 6 sx 1 st stg, 210 sx 2nd stg classG 6.75" 4.5" 12.6# L-80 TXP 9329' 16847' 6410' 3$' V -t, N/A- liner 3.5" 9.3# L-80 Hydril 563 8061' 39' 7518' 6352' N/A - tubing 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production 20 16 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft):GGy 6„ 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Kurt Alexa @ 907-263-4933 Email Kurt.J.Alexa(d)COP.com Printed Name G.L. Alvord Title Alaska Drilling Manager Signature { 0A Phone 265-6120 Date 7(2-v I Z, f Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: " Q 50- 3' a0 C)0 -Ob Date: rl ' 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: 15 Other: Bp p f C5 f tc 356)'D f25 _ Samples req'd: Yes ❑ No Mud log req'd: Yes❑ NcQ► /-I h vt v l a r pre V" -r) fCVJ� r-Sf f 0 Z 5 U d�� S t H�S measures: Yes [� No ❑ Directional svy req'd: YeW No❑ Spacing exception req'd: Yes ❑ No� Inclination -only svy req'd: Yes❑ NW Post initial injection MIT req'd: Yes❑ No®' APPROVED BY Date: Approved by: COMMISSIONER THE COMMISSION (rTL 7/22-/1 F/Ab 712.1 /S. Submit Form and Form 10-401 (Revised 11/2015) fyift Ia�1 �or 4 J:ths from th�� a ofppproval (20 AAC 25.005(g)) Attachments in Duplicate --1 / Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 263-4933 Email: Kurt.J.Alexa(-conocophillips.com July 19, 2016 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 2S-06 Saved: 19 -Jul -16 ConocoPhillips Re: Revised Application for Permit to Drill Well 2S-06, A Kuparuk A4 Sand Producer Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots producer well from the 2S pad. The expected spud date for this well is August 10th, 2016. It is planned to use rig Doyon 142. 25-06 is planned to be a horizontal well in the Kuparuk A4 sand. The surface section will be drilled with 13-1/2" bit and run 10-3/4" casing to +/-2,779' MD / 2,661' TVD. The intermediate section will be drilled with 9-7/8" x 11" bit/Under Reamer and run 7-5/8" casing to 7,688'MD / 6,375'TVD. The production hole will be drilled with 6-3/4" and run 4-1/2" slotted liner to +/- 16,847'MD / 6,410'TVD. The upper completion wil be run with 3-1/2" tubing. Well w4 b< {i�w G f L �—C V�� rYJ vl of 1r- q. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kurt Alexa at 263-4933 (Kurt.J.Alexa@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Kurt Alexa Drilling Engineer Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Monday, July 25, 2016 8:59 AM To: 'Alexa, Kurt J' Cc: Bettis, Patricia K (DOA) Subject: RE: 2S-06 Revised(PTD 216-085) Add Fracture Stimulation Kurt, I will add the fracture stimulation to the revised PTD. Thanx, Victoria From: Alexa, KurtJ fmaiIto: Kurt.J.Alexa@conocophilIips.com] Sent: Monday, July 25, 2016 8:45 AM To: Loepp, Victoria T (DOA) Subject: 2S-06 Re -Submittal Victoria, I had a couple questions regarding how the 2S-06 re -submittal works. The initial 2S-06 permit approval and the re- submittal probably crossed paths in the mail room. The team decided to extend the lateral of 2S-06 by 500ft requiring a new directional plan which resulted in the re -submittal of the permit to drill for 2S-06. Will the API number and permit number for the well change because of the re -submittal or will it be the same as what was on the originally approved 2S- 06 permit to drill?(No change in API # or PTD #) In the event that we are ready to begin drilling prior to approval of the re -submittal, do we still have permission to drill to the originally permitted depth or does the re -submittal cancel the existing approved permit?(Need approved resubmitted PTD to drill) Also, I was told this morning that we need to include in the permit application that this well (2S-06) will be frac'd. Apologies for not having it in the submittal. Do I need to re -submit again or will this email be sufficient?(This email will suffice) If you have any questions, please don't hesitate to give me a call or shoot me an email. Thanks, Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) Application for Permit to Dill Document DriHinlag Kuparuk Well 2S-06 Conocomlli Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 25-06 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat ident fi-ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective_formation and at total depth; Location at Surface 3043.23' FNL, 1408.01' FEL, Sec 17, TION, R008E, UM NGS Coordinates Northings: 5,930,004.80' Eastings: 481,162.27' IRKB Elevation 159AMSL Pad Elevation 120' AMSL Location at surface Casing 2411.58' FNL, 1208.57 FEL, Sec 17, TION, R008E, UM NGS Coordinates Northings: 5,930, 635.88' Eastings: 481,361.37' Measured Depth, RKB: 2,779' Total Vertical Depth, RKB: 2,661' Total Vertical Depth, SS: 2,502' Location at intremediate Casing 4150.43' FNL, 1300.14 FEL, Sec 17, TION, ROME, UM NGS Coordinates Northings: 5,928,897.43' Eastings: 481,270.67' Measured Depth, RKB: 7,688' Total Vertical Depth, RKB: 6,375' Total Vertical Depth, SS: 6,216' Location at Top of Productive Interval Ku aruk C4 Sand 4092.63' FNL, 1285.27' FEL, Sec 17, T1ON, ROME, UM NGS Coordinates Northings: 5,928,955.19' Eastings: 481,285.51' Measured Depth, RKB: 7,628' Total Vertical Depth, RKB: 6,369' Total Vertical Depth, SS: 6,210' Location at Total Depth 2464.17' FNL, 3594.91' FEL, Sec 29, TION, R008E, UM NGS Coordinates Northings: 5,920,030.58' Eastings: 478,980.46' Measured Depth, RKB: 16,847' Total Vertical Depth, RKB: 6,410' Total Vertical Depth, SS: 6,251' and (D) other information required by 20 AAC 25.050(b): Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated. the application for a Permit to Drill (Forst 10-401) must (1) inchide a plat, drawn to a suitable scale, showing the path of the proposed wellbore. including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered criteria used to determine it, and maximum potential surface pressure based on a methane gradient.- The radient.The maximum potential surfac ur (MPSP) while drilling 2S-06 is calculated using an estimated maximum reservoir pressure Vf 35650 p 0 ppg (6369' RKB TVD), based on eastern2S development wells), a gas gradient of 0.10 the esti ed depth of the Kuparuk A4 sand at 6,369' TVD (WP09): A Sand Estimated. BHP = 3,650 ps A Sand estimated depth (WP08) = 6,369' TV Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 637 psi ( ,369' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 3,M psi (3,6/0 — 637psi) (B) data on potential gas zones; The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; See attached 2S-06 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrio� tests, as required under 20 AAC 25.03060.- A 5.0300: A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed Casing and Cement Program Casing and CementingPro ram Csg/Tbg OD Hole Siz'� weight Grade Conn. Length Top MDITVD Btm MD/TVD Cement Program (in) (2,779 — 2,279') X 0.3634 ft3/ft X 1.50 (50% excess) = 272.6 ft3 (Ib7ft) (80') X 0.5313 ft3/ft X 1.0 (0% excess) = 42.5 ft3 Rathole + 3bbls cmt on top of plug (ft) (ft) (ft) 16 24 62.5 H-40 Welded 78 Surf 120/ 120 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,701 Surf 2,779 / 2,661 1,020 sx DeepCRETE Lead 11.0 ppg, 300 sx Class G Tail Slurry 15.8 ppg Stage 1: 690 sx Class G at 15.8 ppg w/ 9-7/8 Hydril TOC at 6,045' MD 7-5/8 X 29.7 L-80 563 7,653 Surf 71688 / 6,375 Stage 2: 205 sx Class G at 15.8 ppg w/ 11 TOC at 4,600' MD 4 1/2 6-3/4 12.6 L-80 TXP 8,809 7,534 / 6,353 16,348/ 6,409 Uncemented Liner with Frac Sleeves 10-3/4" Surface casing run to 2,878' MD / 2,581' TVD Cement from 2,779' MD to 2,279'(500' of tail) with 15.8 ppg Class G, and from 2,279' to surface with 11 ppg DeepCrete. Assume 200% excess annular volume in permafrost and 50% excess below the permafrost (1440' MD), zero excess in 16" conductor. Lead slurry from 2,282' MD to surface with Arctic Lite Crete @ 11 ppg Conductor (120'— 39') X 0.5967 ft3/ft X 1.0 (0% excess) = 48.4 ft3 Permafrost to Conductor (1,435'— 120') X 0.3634 ft3/ft X 3.0 (200% excess) = 1,433.6 ft3 Top of Tail to Permafrost (2,279'— 1,435') X 0.3634 ft3/ft X 1.5 (50% excess) = 460.1 ft3 Total Volume = 48.4 + 1,433.6 + 460.1 = 1,942 ft3=> 1,016sx of 11 ppg DeepCrete @ 1.91 ft3/sk Tail slurry from 2,782' MD to 2,282' MD with 15.8 ppg Class G Shoe to Top of Tail (2,779 — 2,279') X 0.3634 ft3/ft X 1.50 (50% excess) = 272.6 ft3 Shoe Joint (80') X 0.5313 ft3/ft X 1.0 (0% excess) = 42.5 ft3 Rathole + 3bbls cmt on top of plug (10') X 0.6568 ft3/ft X 1.5 (50% excess) +16.8 ft3 = 26.7 ft3 Total Volume = 272.6 + 42.5 + 26.7= 316 ft3 => 298 sx of 15.8 ppg Class G @ 1.17 ft3/sk 7-5/8" Intermediate casing run to 7,688' MD / 6,375' TVD 1" stage slurry designed to be at the top of Bermuda/base Cairn Formation at 6,045' MD / 5,684' TVD. Top of 2nd stage slurry is designed to be at 4,601' MD, which is 500' MD above the C-37 top at 5,101' MD / 4,735' TVD. Assume 40% excess annular volume. 11' Stage slurry from 7,688' MD to 5,929' MD with 15.8ppg Class G + additives Shoe to Top of Cement (7,688 — 5,929') X 0.3425 ft3/ft X 1.40 (40% excess) = 843.4 ft3 Shoe Joint (80') X 0.2483 ft3/ft X 1.0 (0% excess) = 19.9 ft3 Total Volume = 843.4 + 19.9 = 863.3 ft3 => 738 sx of 15.8 ppg Class G @ 1.17 ft3/sk LSND (WBM) 2"d Stage slurry from 5,101' MD to 4,601 MD with 15.8ppg Class G + additives Stage Collar to Top of Cement (5,101 — 4,601) X 0.3425 ft3/ft X 1.40 (40% excess) = 239.8 ft3 Total Volume = 239.8 ft3 => 205sx of 15.8 ppg Class G @ 1.17 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) an application, for a Permit to Drill must be accompanied by each of the folloiring items. except for all item ah•eadr on file frith the commission and identified in the application. (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference attached diverter schematic for Doyon 142 on 2S pad slot 6. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) In application Jor a Permit to Drill nasi he accompanied bY each of the following items. except for as item alreacly on file frith the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,• Mud Program Summary Surface 13-1/2" Hole 10-3/4" Casing Intermediate 9-7/8" x 11 " Hole 7-5/8" Casing Production 6-3/4" Hole 4-1/2" Liner Mud System Spud (WBM) LSND (WBM) FloPro (WBM Density 9.3-10 9.6-10.5 10.3-11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10-12 5 - 8 10 minute Gel 30-50 10-18 5-12 API Filtrate NC < 6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. 2. Spud and directionally drill 13.5" hole to casing point at +/- 2,779' MD / 2,661' TVD as per directional plan (wp9). Survey with MWD, Gamma, Resistivity, Gyro -While -Drilling. 3. Run and cement 10-3/4", 45.5#, L80, Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job (post rig.) 4. In the event cement returns are not seen at surface, perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi (annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8" PDC bit and directional drilling assembly, with MWD/LWD (Gamma, Resistivity, Neu, Dens). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg, maximum of 16 ppg EMW leak off, recording results. 8. Open 11" Under Reamer and directionally drill to the top of the HRZ 9. Install RCD bearing at this time for use of MPD if necessary. 10. Directionally drill to intermediate TD of 7,688' MD / 6,375' TVD, wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean, minimum of 3 bottoms up. 11. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 12. Lay down intermediate BHA and rack back 5" DP 13. Run 7-5/8", 29.7# L80, Hydril 563 casing from surface to TD at 7688' MD. 14. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 5929' MD (top of Cairn formation), top of second stage to be 4,601' MD (500' above C37). 15. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel to freeze protect. 16. Lay down 5" DP. 17. PU 4" DP, 6-3/4" bit, RSS, and MWD/LWD assembly (Gamma, resistivity, Periscope, and neutron density) 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg, maximum of 14.5 ppg EMW leak off, recording results. 20. Swap mud over to 10.3 ppg F1oPro mud system. 21. Directionally drill 6-3/4" hole geosteering through the Kuparuk A4 sand to TD 16,348' MD as per directional plan (wp9). 22. Circulate hole clean and POOH. 23. Lay down production BHA. 24. PU and run 4-1/2", 12.6# liner. The top of liner will be placed at 7,518' MD, allowing for 150' of overlap in the 7-5/8" casing. 25. Set liner hanger. Slackoff and set liner top packer. 26. Monitor well for flow for 15 minutes 27. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes, chart results. 28. Flow check well for 30 minutes and POOH 29. Run 3-1/2" upper completion. 30. Nipple down BOPE, nipple up tree and test. 31. Freeze protect well with diesel and install BPV. 32. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary 2S-06wpl 0[Salmon]6.811 Plan Summary tap 3 Sand Top Bermuda Top Cairn Growler -AA > 5 15 Marker Base jBermudli C-35 - Kuparuk C (Top C4) 5 \ a`a ase permafrost (?)C{40107 W �A4 Upperkalubik (base HRZ) ,/ \ ' - Base W Sak f� _ - - _ _ - Top HRZ (K-2 mkr) A5 o ToW Sak (W Sak D) p I i Lower Kalubik (K-1 mkr) ..I ... i C-80 ` ` - 0 7-5/8" x 9-7/8" by 11 0 0 10-3/4" x 13-1/2' 4000 8000 12000 16000 Measured Depth o Geodetic Datum: North American Datum 1983 0° 10.314" x 13-1/2' Depth Reference: Plan: 120+39 @ 159.00usft (Doyon142) 0 Rig: Doyon142 Nbt� •. 1000 r' 4 1/2" x 6-3/4' ' o 0�� roan m r r� 0 1500 3000 4500 6000 7500 9000 10500 12000 T Horizontal Departure Magnetic Model Date: 22 -Aug -16 16 6D ��\\ 300 To convert a Magnetic Direction to a True Direction, Add 17.87° East T-3 Sand 30- Cj 0 0 ° �, S -D5 � 270 art 2.5°/100' DLS, 0° TF, for 780.86' dd for 107.97' 2S. 7 .. .... _ ID 1409.0 rid for 1617.06' art 2.5°1100' DLS, 164.54° TF, for 4223.49' 5=oe . 0 1849.0 0 2500 5000 7500 10000 12500 15000 240 iId for 8396.63' SURVEY PROGRAM just TF to 0°, for 500' Surface Location Depth From Depth To Survey/Plan Tool 39.00 750.00 2S-0 10Salmon] PIan:2S-06 GYD-GC-SS pad Elevation: 120.00 zsoawogry.r 750.00 1750.00 2S-06wp10 Salmon] PIan:2S-06; MWD 750.00 2779.13 2S-06wp10 Salmon] Plan: 2S-08yVD+IFR-AK-CAZ-SC 2779.13 4281.49 2S -06w)10 [Salmon] (Plan: 2S-06) MWD CASING DETAILS 2779.13 7688.26 2S -06w)10 [Salmon] (Plan: 2S-0®yVD+IFR-AK-CAZ-SC 7588.26 9188.26 2S -06w)10 [Salmon] (Plan: 2S-06) MWD TVD MD Name 7688.26 16847.60 2S-06wp10 [Salmon] (Plan: 2S-06yVD+IFR-AK-CAZ-SC 2661.00 2779.13 10-3/4" x 13-1/2" - 6375.00 7688.26 7-5/8" x 9-718" by 11" 6410.27 16847.60 4 1/2" x 6-3/4" SECTION DETAILS Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 425.00 0.00 0.00 425.00 0.00 0.00 0.00 0.00 0.00 3 600.06 2.63 0.00 600.00 4.01 0.00 1.50 0.00 -3.87 4 1380.92 22.15 0.00 1359.00 170.70 0.00 2.50 0.00 -164.89 5 1488.89 22.15 0.00 1459.00 211.41 0.00 0.00 0.00 -204.20 6 1847.71 21.32 29.27 1793.30 336.30 31.98 3.00 107.93 -333.12 7 3464.77 21.32 29.27 3299.73 849.09 319.34 0.00 0.00 -902.81 8 7688.26 85.00 194.33 6375.00 -1107.22 111.24 2.50 164.54 1040.70 2S -Salmon 1. Heel 050216 PB -85.00 9 7708.26 194.33 6376.74 -1126.53 106.31 0.00 0.00 1060.62 10 7950.97 89.85 194.33 6387.64 -1361.37 46.30 2.00 0.00 1303.00 11 16347.60 89.85 194.33 6409.00 -9496.54 -2032.61 0.00 0.00 9699.04 2S -Salmon 2. Toe 050216 PB 12 16847.60 89.85 194.33 6410.27 -9980.97 -2156.41 0.00 0.00 10199.00 0 39 - 425 425 - 610 610 - 790 790 - 970 970 - 1150 1150 - 1340 1340 - 1520 1520 - 1700 1700 - 2330 2330 2950 2950 - 3580 3580 - 4200 4200 - 4830 4830 - 5450 5450 - 6080 6080 - 6700 6700 - 7970 7970 - 9240 9240 - 1051C 10510 - 1178C 11780 - 1304C 13040 1431C iao 1112 r2Z-_6El zsoa 14310 1558C 15580 - 1684E T Magnetic Model: BGGM2016 Magnetic Model Date: 22 -Aug -16 Magnetic Declination: 17.870 To convert a Magnetic Direction to a True Direction, Add 17.87° East T-3 Sand notation )P: Start 1.5°/100' DLS, 0° TF, for 175.06' K-15 Marker art 2.5°/100' DLS, 0° TF, for 780.86' dd for 107.97' art 3°1100' DLS, 107.93° TF, for 358.82' 1409.0 rid for 1617.06' art 2.5°1100' DLS, 164.54° TF, for 4223.49' Base permafrost (? rid for 20' 1849.0 art 2°/100' DLS, 0° TF, for 242.71' iId for 8396.63' Top W Sak (W Sak just TF to 0°, for 500' t: 16847.6' MD, 8410.27' TVD 2544.0 Base W Sak 2944.0 C-80 4284.0 C-50 4644.0 - yyC44-40 485044:27 S��Groppwleaar�a--rA'A � @'' C-35 signing this I acknowledge that 1 have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position and I approve the scan and Ilision avoidance Ian as set out in the audit ack. I a rove it as the basis for the final well Ian and wellsite drawin s. I also adcnowled a that unless notified otherwise all tar ets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Erik Stark 6:03, July 18 20161Easting (3500 usft/in) K 152M-332 -04 -32L1PB1 A2M-34 2M-08 2M-09 M-321-1PB2 A-jL11 2M-35 2$4%1 2S-11 - 2K- 21--03 2S-04 r 2S-07 / 2S-05 � Kuparuk 2S Pad , 2S-02 ' L-314PB1 Al- 4 N 2L-306PBI 2S-13P 1 3 o ig: -14 0 2L-31 - 06 a� c 2L-308 c KR 21-10-8 021- _ 2L-310 Z2L-304 21--311 2S-12P6 - S ar Tooth #1 L-30 2S-12 L 1 r 1 2 2L-316 2L-301 2S- 313131 2S-01 -32 L-32 2L-317A 2L-320 2S-08 2L-32 2S-10 2L-33 L21.4309 2N-322 2S-03 219*W5A 2N-3 2 2S-06wp10 [Salmon] 2N 02 2 311 �,-311 N-322PB2 - rei�rr�: Kliparl�k Ca[rr� �d 2L-328 2�t �3$4PB1 Prelim: Kuparuk Cairn Fuad 2N-310 Easting (3500 usft/in) ?K-13 2K-13AL2 2K-091-1-0 Y2K -29 _2K-28APE 4A 9 2K-28AL1 2K-20 -28AL1 -21 A 2 K-21 iD L 3 2S-06wp10 [Salmon] Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 10-3/4" x 13-1/2'_'__-_ 05000 00 0 00 -2000 7-5/8" x 9-7/8" by 11" _ .-. 2S- Salmon 1. Heel 050216 P c 0 0 40000 c—'4-4000- 0 Z =-6000- -1 0 -8000 2S -Salmon 2. Toe 050216 P -10000 4 1/2" x 6-3/4"- 41 - - ---- S-06wp10 [Salmon] 0 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 West( -)/East(+) (2000 usft/in) 2S-06wp10 [Salmon] Section View -1500— top T-3 Sand K-15 Marker "Base permafrost (?) 0— Top Sak (W Sak D) .,'Base W Sak 'law" C-80 . ... .. ... .. ... .. ... .. ... ... c 1500 C-50 C-37 0 C) LO 0, C-40' Growler-AA � ------------- - --------------- --------------- --------------------- 3000 U 0 0 0 Top Cairn Top Bermuda 10-3/4" -FU x 13-1/ base Berrf�uda Top HRZ (K-2 mkr) 4 40DO Upper Kalubik (base HRZ) 4500-- -------------- I I - --------------0 -1,5 Q�O- ---------- --A5 Kuparuk C (Top C4) A4 -cj C5 CD C) OD -CF- 6000— 0 0 N C) CO 'IT LO W (0 Qa 0- - E cu C-35 CO Lower Kalubik (K-1 mkr) 4 1/2" x 6-3/4" 7500- 7-5/8" x 9-7/8" by 11 (0 9 -1500 0 1500 3000 4500 6000 7500 9000 10500J Vertical Section at 195.00' (1500 usft/in) Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-06 Plan: 2S-06 Plan: 2S-06wp10 [Salmon] Report 18 July, 2016 Permit Pack Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp10 [Salmon] Schlumberger Date 7/18/2016 Report Local Co-ordinate Reference: Well Plan: 2S-06 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan: 25-06 Well Position +N/ -S 0.00 usft Northing: usft Latitude: +E/ -W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan: 2S-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 2S-06wp10 [Salmon] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 195.00 Survey Tool Program Date 7/18/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 750.00 2S-06wplo [Salmon] (Plan: 2S-06) GYD-GC-SS Gyrodata gyro single shots 750.00 1,750.00 2S-06wpl0 [Salmon] (Plan: 2S-06) MWD MWD - Standard 750.00 2,779.13 2S-06wp10 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,779.13 4,281.49 2S-06wp10 [Salmon] (Plan: 2S-06) MWD MWD - Standard 2,779.13 7,688.26 2S-06wp10 [Salmon] (Plan: 25-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,688.26 9,188.26 2S-06wp10 [Salmon] (Plan: 2S-06) MWD MWD - Standard 7,688.26 16,847.60 2S-06wpl0 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 39.00 0.00 0.00 39.00 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.00 0.00 0.00 0.04 200.00 0.00 0.00 200.00 41.00 0.00 0.00 0.19 289.00 0.00 0.00 289.00 130.00 0.00 0.00 0.33 top T-3 Sand 300.00 0.00 0.00 300.00 141.00 0.00 0.00 0.33 7/1812016 3:12:49PM Page 2 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyonl42) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon -142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp10 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 374.00 0.00 0.00 374.00 215.00 0.00 0.00 0.48 K-15 Marker 400.00 0.00 0.00 400.00 241.00 0.00 0.00 0.48 425.00 0.00 0.00 425.00 266.00 0.00 0.00 0.51 KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' 500.00 1.12 0.00 500.00 341.00 1.50 0.00 0.62 600.00 2.62 0.00 599.94 440.94 1.50 0.00 0.77 600.06 2.63 0.00 600.00 441.00 1.50 0.00 0,77 Start 2.5°/100' DLS, 0° TF, for 780.86' 700.00 5.12 0.00 699.70 540.70 2.50 0.00 0.92 800.00 7.62 0.00 799.08 640.08 2.50 0.00 1.00 900.00 10.12 0.00 897.87 738.87 2.50 0.00 1.05 1,000.00 12.62 0.00 995.90 836.90 2.50 0.00 1.19 1,100.00 15.12 0.00 1,092.97 933.97 2.50 0.00 1.42 1,200.00 17.62 0.00 1,188.91 1,029.91 2.50 0.00 1.75 1,300.00 20.12 0.00 1,283.53 1,124.53 2.50 0.00 2.16 1,380.92 22.15 0.00 1,359.00 1,200.00 2.50 0.00 2.55 Hold for 107.97' 1,400.00 22.15 0.00 1,376.67 1,217.67 0.00 0.00 2.65 1,434.90 22.15 0.00 1,409.00 1,250.00 0.00 0.00 3.11 Base permafrost (?) 1,488.89 22.15 0.00 1,459.00 1,300.00 0.00 0.00 3.11 Start 3°/100' DLS, 107.93° TF, for 358.82' 1,500.00 22.05 0.85 1,469.30 1,310.30 3.00 107.93 3.16 1,600.00 21.35 8.74 1,562.23 1,403.23 3.00 107.14 3.49 1,700.00 21.03 17.00 1,655.49 1,496.49 3.00 99.80 3.80 1,800.00 21.13 25.35 1,748.82 1,589.82 3.00 92.10 1.91 1,847.71 21.32 29.27 1,793.30 1,634.30 3.00 84.31 1.96 Hold for 1617.06' 1,900.00 21.32 29.27 1,842.01 1,683.01 0.00 0.00 2.04 1,907.51 21.32 29.27 1,849.00 1,690.00 0.00 0.00 2.22 Top W Sak (W Sak D) 2,000.00 21.32 29.27 1,935.17 1,776.17 0.00 0.00 2.22 2,100.00 21.32 29.27 2,028.33 1,869.33 0.00 0.00 2.41 2,200.00 21.32 29.27 2,121.49 1,962.49 0.00 0.00 2.60 2,300.00 21.32 29.27 2,214.64 2,055.64 0.00 0.00 2.80 2,400.00 21.32 29.27 2,307.80 2,148.80 0.00 0.00 3.00 2,500.00 21.32 29.27 2,400.96 2,241.96 0.00 0.00 3.20 2,600.00 21.32 29.27 2,494.12 2,335.12 0.00 0.00 3.40 2,653.54 21.32 29.27 2,544.00 2,385.00 0.00 0.00 3.61 Base W Sak 2,700.00 21.32 29.27 2,587.28 2,428.28 0.00 0.00 3.61 2,779.13 21.32 29.27 2,661.00 2,502.00 0.00 0.00 3.84 10-3/4" x 13-1/2" 2,800.00 21.32 29.27 2,680.44 2,521.44 0.00 0.00 3.84 7/18/2016 3:12:49PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 25-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wpl0 [Salmon) Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 2,900.00 21.32 29.27 2,773.60 2,614.60 0.00 0.00 4.13 3,000.00 21.32 29.27 2,866.76 2,707.76 0.00 0.00 4.47 3,082.91 21.32 29.27 2,944.00 2,785.00 0.00 0.00 4.84 C-80 3,100.00 21.32 29.27 2,959.92 2,800.92 0.00 0.00 4.84 3,200.00 21.32 2927 3,053.08 2,894.08 0.00 0.00 5.24 3,300.00 21.32 29.27 3,146.23 2,987.23 0.00 0.00 5.67 3,400.00 21.32 29.27 3,239.39 3,080.39 0.00 0.00 6.11 3,464.77 21.32 29.27 3,299.73 3,140.73 0.00 0.00 6.40 Start 2.5°/100' DLS, 164.54° TF, for 4223.49' 3,500.00 20.47 29.94 3,332.65 3,173.65 2.50 164.54 6.53 3,600.00 18.08 32.17 3,427.04 3,268.04 2.50 163.92 6.78 3,700.00 15.72 35.05 3,522.71 3,363.71 2.50 161.81 7.01 3,800.00 13.42 38.90 3,619.49 3,460.49 2.50 159.05 7.17 3,900.00 11.19 44.29 3,717.19 3,558.19 2.50 155.32 7.23 4,000.00 9.11 52.19 3,815.63 3,656.63 2.50 150.06 7.10 4,100.00 7.29 64.32 3,914.61 3,755.61 2.50 142.28 6.57 4,200.00 5.99 82.92 4,013.94 3,854.94 2.50 130.27 5.30 4,300.00 5.57 107.61 4,113.45 3,954.45 2.50 111.79 3.05 4,400.00 6.21 131.36 4,212.94 4,053.94 2.50 87.23 3.31 4,471.55 7.18 144.28 4,284.00 4,125.00 2.50 63.60 3.86 C-50 4,500.00 7.65 148.42 4,312.22 4,15322 2.50 50.77 3.86 4,600.00 9.54 159.45 4,411.09 4,252.09 2.50 46.66 4.25 4,700.00 11.66 166.69 4,509.38 4,350.38 2.50 35.75 4.50 4,800.00 13.91 171.68 4,606.90 4,447.90 2.50 28.63 4.66 4,838.29 14.79 173.19 4,644.00 4,485.00 2.50 23.77 4.77 C-40 4,900.00 16.23 175.29 4,703.46 4,544.46 2.50 22.30 4.77 5,000.00 18.59 178.00 4,798.87 4,639.87 2.50 20.28 4.86 5,100.00 20.99 180.13 4,892.96 4,733.96 2.50 17.69 4.93 5,101.11 21.01 180.15 4,894.00 4,735.00 2.50 15.69 5.00 C-37 5,200.00 23.40 181.83 4,985.55 4,826.55 2.50 15.67 5.00 5,264.08 24.96 182.75 5,044.00 4,885.00 2.50 14.12 5.07 Growler -AA 5,300.00 25.83 183.23 5,076.45 4,917.45 2.50 13.27 5.07 5,400.00 28.28 184.40 5,165.50 5,006.50 2.50 12.84 5.15 5,500.00 30.73 185.40 5,252.53 5,093.53 2.50 11.80 5.25 5,600.00 33.19 186.26 5,337.36 5,178.36 2.50 10.93 5.35 5,700.00 35.65 187.02 5,419.85 5,260.85 2.50 10.19 5.48 5,800.00 38.12 187.70 5,499.83 5,340.83 2.50 9.57 5.63 5,900.00 40.59 188.30 5,577.15 5,418.15 2.50 9.03 5.80 5,928.92 41.30 188.46 5,599.00 5,440.00 2.50 8.56 5.99 Top Cairn 7/18/2016 3:12:49PM Page 4 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp10 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 6,000.00 43.06 188.84 5,651.67 5,492.67 2.50 8.44 5.99 6,044.66 44.17 189.07 5,684.00 5,525.00 2.50 8.16 6.21 Top Bermuda 6,100.00 45.54 189.34 5,723.24 5,564.24 2.50 7.99 6.21 6,137.09 46.45 189.52 5,749.00 5,590.00 2.50 7.80 6.45 Base Bermuda 6,188.50 47.73 189.75 5,784.00 5,625.00 2.50 7.68 6.45 C-35 6,200.00 48.01 189.80 5,791.72 5,632.72 2.50 7.52 6.45 6,300.00 50.49 190.22 5,856.98 5,697.98 2.50 7.49 6.73 6,400.00 52.97 190.61 5,918.91 5,759.91 2.50 7.21 7.02 6,500.00 55.46 190.98 5,977.38 5,818.38 2.50 6.97 7.34 6,600.00 57.94 191.33 6,032.28 5,873.28 2.50 6.75 7.69 6,698.97 60.40 191.65 6,083.00 5,924.00 2.50 6.56 8.05 Top HRZ (K-2 mkr) 6,700.00 60.42 191.66 6,083.51 5,924.51 2.50 6.40 8.05 6,800.00 62.91 191.97 6,130.97 5,971.97 2.50 6.40 8.44 6,898.65 65.36 192.26 6,174.00 6,015.00 2.50 6.25 8.84 Upper Kalubik (base HRZ) 6,900.00 65.39 192.27 6,174.56 6,015.56 2.50 6.12 8.84 7,000.00 67.88 192.56 6,214.22 6,055.22 2.50 6.12 9.27 7,100.00 70.37 192.83 6,249.85 6,090.85 2.50 6.00 9.71 7,143.26 71.44 192.95 6,264.00 6,105.00 2.50 5.90 10.16 Lower Kalubik (K-1 mkr) 7,200.00 72.85 193.10 6,281.39 6,122.39 2.50 5.86 10.16 7,300.00 75.34 193.36 6,308.79 6,149.79 2.50 5.82 10.63 7,400.00 77.83 193.62 6,331.99 6,172.99 2.50 5.75 11.10 7,460.66 79.34 193.77 6,344.00 6,185.00 2.50 5.69 11.59 Kuparuk C (Top C4) 7,500.00 80.32 193.87 6,350.95 6,191.95 2.50 5.66 11.59 7,551.20 81.59 194.00 6,359.00 6,200.00 2.50 5.64 12.09 A5 7,600.00 82.80 194.12 6,365.62 6,206.62 2.50 5.62 12.09 7,628.32 83.51 194.19 6,369.00 6,210.00 2.50 5.60 12.46 A4 7,688.26 85.00 194.33 6,375.00 6,216.00 2.50 5.59 12.46 Hold for 20'- 7-5/8" x 9-7/8" by 11" 7,700.00 85.00 194.33 6,376.02 6,217.02 0.00 5.58 12.51 7,708.26 85.00 194.33 6,376.74 6,217.74 0.00 0.00 12.54 Start 2°/100' DLS, 0° TF, for 242.71' 7,800.00 86.83 194.33 6,383.27 6,224.27 2.00 0.00 12.99 7,900.00 88.83 194.33 6,387.05 6,228.05 2.00 0.00 13.61 7,950.97 89.85 194.33 6,387.64 6,228.64 2.00 0.00 13.98 Hold for 8396.63' 8,000.00 89.85 194.33 6,387.76 6,228.76 0.00 0.00 14.36 8,100.00 89.85 194.33 6,388.01 6,229.01 0.00 D.00 15.21 7/18/2016 3:12:49PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 25-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyonl42) Well: Plan: 25-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wpl0 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 8,200.00 89.85 194.33 6,388.27 6,229.27 0.00 0.00 16.16 8,300.00 89.85 194.33 6,388.52 6,229.52 0.00 0.00 17.17 8,400.00 89.85 194.33 6,388.78 6,229.78 0.00 0.00 18.25 8,500.00 89.85 194.33 6,389.03 6,230.03 0.00 0.00 19.38 8,600.00 89.85 194.33 6,389.29 6,230.29 0.00 0.00 20.55 8,700.00 89.85 194.33 6,389.54 6,230.54 0.00 0.00 21.76 8,800.00 89.85 194.33 6,389.80 6,230.80 0.00 0.00 23.00 8,900.00 89.85 194.33 6,390.05 6,231.05 0.00 0.00 24.26 9,000.00 89.85 194.33 6,390.30 6,231.30 0.00 0.00 25.55 9,100.00 89.85 194.33 6,390.56 6,231.56 0.00 0.00 26.85 9,200.00 89.85 194.33 6,390.81 6,231.81 0.00 0.00 16.37 9,300.00 89.85 194.33 6,391.07 6,232.07 0.00 0.00 16.76 9,400.00 89.85 194.33 6,391.32 6,232.32 0.00 0.00 17.17 9,500.00 89.85 194.33 6,391.58 6,232.58 0.00 0.00 17.58 9,600.00 89.85 194.33 6,391.83 6,232.83 0.00 0.00 18.00 9,700.00 89.85 194.33 6,392.09 6,233.09 0.00 0.00 18.43 9,800.00 89.85 194.33 6,392.34 6,233.34 0.00 0.00 18.87 9,900.00 89.85 194.33 6,392.59 6,233.59 0.00 0.00 19.32 10,000.00 89.85 194.33 6,392.85 6,233.85 0.00 0.00 19.77 10,100.00 89.85 194.33 6,393.10 6,234.10 0.00 0.00 20.23 10,200.00 89.85 194.33 6,393.36 6,234.36 0.00 0.00 20.69 10,300.00 89.85 194.33 6,393.61 6,234.61 0.00 0.00 21.16 10,400.00 89.85 194.33 6,393.87 6,234.87 0.00 0.00 21.64 10,500.00 89.85 194.33 6,394.12 6,235.12 0.00 0.00 22.12 10,600.00 89.85 194.33 6,394.38 6,235.38 0.00 0.00 22.60 10,700.00 89.85 194.33 6,394.63 6,235.63 0.00 0.00 23.09 10,800.00 89.85 194.33 6,394.88 6,235.88 0.00 0.00 23.59 10,900.00 89.85 194.33 6,395.14 6,236.14 0.00 0.00 24.08 11,000.00 89.85 194.33 6,395.39 6,236.39 0.00 0.00 24.58 11,100.00 89.85 194.33 6,395.65 6,236.65 0.00 0.00 25.09 11,200.00 89.85 194.33 6,395.90 6,236.90 0.00 0.00 25.59 11,300.00 89.85 194.33 6,396.16 6,237.16 0.00 0.00 26.10 11,400.00 89.85 194.33 6,396.41 6,237.41 0.00 0.00 26.62 11,500.00 89.85 194.33 6,396.67 6,237.67 0.00 0.00 27.13 11,600.00 89.85 194.33 6,396.92 6,237.92 0.00 0.00 27.65 11,700.00 89.85 194.33 6,397.17 6,238.17 0.00 0.00 28.17 11,800.00 89.85 194.33 6,397.43 6,238.43 0.00 0.00 28.69 11,900.00 89.85 194.33 6,397.68 6,238.68 0.00 0.00 29.22 12,000.00 89.85 194.33 6,397.94 6,238.94 0.00 0.00 29.74 12,100.00 89.85 194.33 6,398.19 6,239.19 0.00 0.00 30.27 12,200.00 89.85 194.33 6,398.45 6,239.45 0.00 0.00 30.80 12,300.00 89.85 194.33 6,398.70 6,239.70 0.00 0.00 31.33 12,400.00 89.85 194.33 6,398.96 6,239.96 0.00 0.00 31.86 12,500.00 89.85 194.33 6,399.21 6,240.21 0.00 0.00 32.40 7/98/2016 3:12.,49PM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 25-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp10 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) 12,600.00 89.85 194.33 6,399.46 6,240.46 0.00 0.00 32.93 12,700.00 89.85 194.33 6,399.72 6,240.72 0.00 0.00 33.47 12,800.00 89.85 194.33 6,399.97 6,240.97 0.00 0.00 34.01 12,900.00 89.85 194.33 6,400.23 6,241.23 0.00 0.00 34.55 13,000.00 89.85 194.33 6,400.48 6,241.48 0.00 0.00 35.09 13,100.00 89.85 194.33 6,400.74 6,241.74 0.00 0.00 35.63 13,200.00 89.85 194.33 6,400.99 6,241.99 0.00 0.00 36.18 13,300.00 89.85 194.33 6,401.25 6,242.25 0.00 0.00 36.72 13,400.00 89.85 194.33 6,401.50 6,242.50 0.00 0.00 37.27 13,500.00 89.85 194.33 6,401.75 6,242.75 0.00 0.00 37.81 13,600.00 89.85 194.33 6,402.01 6,243.01 0.00 0.00 38.36 13,700.00 89.85 194.33 6,402.26 6,243.26 0.00 0.00 38.91 13,800.00 89.85 194.33 6,402.52 6,243.52 0.00 0.00 39.46 13,900.00 89.85 194.33 6,402.77 6,243.77 0.00 0.00 40.01 14,000.00 89.85 194.33 6,403.03 6,244.03 0.00 0.00 40.56 14,100.00 89.85 194.33 6,403.28 6,244.28 0.00 0.00 41.11 14,200.00 89.85 194.33 6,403.54 6,244.54 0.00 0.00 41.66 14,300.00 89.85 194.33 6,403.79 6,244.79 0.00 0.00 42.22 14,400.00 89.85 194.33 6,404.04 6,245.04 0.00 0.00 42.77 14,500.00 89.85 194.33 6,404.30 6,245.30 0.00 0.00 43.32 14,600.00 89.85 194.33 6,404.55 6,245.55 0.00 0.00 43.88 14,700.00 89.85 194.33 6,404.81 6,245.81 0.00 0.00 44.43 14,800.00 89.85 194.33 6,405.06 6,246.06 0.00 0.00 44.99 14,900.00 89.85 194.33 6,405.32 6,246.32 0.00 0.00 45.54 15,000.00 89.85 194.33 6,405.57 6,246.57 0.00 0.00 46.10 15,100.00 89.85 194.33 6,405.83 6,246.83 0.00 0.00 46.66 15,200.00 89.85 194.33 6,406.08 6,247.08 0.00 0.00 47.22 15,300.00 89.85 194.33 6,406.33 6,247.33 0.00 0.00 47.78 15,400.00 89.85 194.33 6,406.59 6,247.59 0.00 0.00 48.33 15,500.00 89.85 194.33 6,406.84 6,247.84 0.00 0.00 48.89 15,600.00 89.85 194.33 6,407.10 6,248.10 0.00 0.00 49.45 15,700.00 89.85 194.33 6,407.35 6,248.35 0.00 0.00 50.01 15,800.00 89.85 194.33 6,407.61 6,248.61 0.00 0.00 50.57 15,900.00 89.85 194.33. 6,407.86 6,248.86 0.00 0.00 51.13 16,000.00 89.85 194.33 6,408.12 6,249.12 0.00 0.00 51.69 16,100.00 89.85 194.33 6,408.37 6,249.37 0.00 0.00 52.26 16,200.00 89.85 194.33 6,408.62 6,249.62 0.00 0.00 52.82 16,300.00 89.85 194.33 6,408.88 6,249.88 0.00 0.00 53.38 16,347.60 89.85 194.33 6,409.00 6,250.00 0.00 0.00 53.65 Adjust TF to 0°, for 500' 16,400.00 89.85 194.33 6,409.13 6,250.13 0.00 0.00 53.94 16,500.00 89.85 194.33 6,409.39 6,250.39 0.00 0.00 54.51 16,600.00 89.85 194.33 6,409.64 6,250.64 0.00 0.00 55.07 16,700.00 89.85 194.33 6,409.90 6,250.90 0.00 0.00 55.63 16,800.00 89.85 194.33 6,410.15 6,251.15 0.00 0.00 56.20 7/18/2015 3:12:49PM Page 7 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp10 [Salmon] Schlumberger Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2S-06 Plan: 120+39 @ 159.00usft (Doyon142) Plan: 120+39 @ 159.00usft (Doyonl42) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TPace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 16,847.60 89.85 194.33 6,410.27 6,251.27 0.00 0.00 56.46 TD: 16847.6' MD, 6410.27' TVD 7/18/2016 3:12:49PM Page 8 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp10 [Salmon] Schlumberger Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2S-06 Plan: 120+39 @ 159.00usft (Doyon142) Plan: 120+39 @ 159.00usft (Doyon142) True Minimum Curvature OAKEDMP2 Casing Points Vertical Dip Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (11) 2,779.13 2,661.00 10-3/4" x 13-1/2" 10-3/4 13-1/2 16,847.60 6,410.27 4 1/2" x 6-3/4" 4-1/2 6-3/4 7,688.26 6,375.00 7-5/8" x 9-7/8" by 11" 7-5/8 11 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 289.00 289.00 top T-3 Sand 7,460.66 6,344.00 Kuparuk C (Top C4) 5,264.08 5,044.00 Growler -AA 3,082.91 2,944.00 C-80 1,434.90 1,409.00 Base permafrost (?) 6,698.97 6,083.00 Top HRZ (K-2 mkr) 5,101.11 4,894.00 C-37 4,471.55 4,284.00 C-50 6,044.66 5,684.00 Top Bermuda 2,653.54 2,544.00 Base W Sak 4,838.29 4,644.00 C-40 1,907.51 1,849.00 Top W Sak (W Sak D) 374.00 374.00 K-15 Marker 6,137.09 5,749.00 Base Bermuda 7,628.32 6,369.00 A4 6,188.50 5,784.00 C-35 7,143.26 6,264.00 Lower Kalubik (K-1 mkr) 5,928.92 5,599.00 Top Cairn 6,898.65 6,174.00 Upper Kalubik (base HRZ) 7,551.20 6,359.00 A5 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 425.00 425.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' 600.06 600.00 4.01 0.00 Start 2.5°/100' DLS, 0° TF, for 780.86' 1,380.92 1,359.00 170.70 0.00 Hold for 107.97' 1,488.89 1,459.00 211.41 0.00 Start 3°/100' DLS, 107.93° TF, for 358.82' 1,847.71 1,793.30 336.30 31.98 Hold for 1617.06' 3,464.77 3,299.73 849.09 319.34 Start 2.5°/100' DLS, 164.54° TF, for 4223.49' 7,688.26 6,375.00 -1,107.22 111.24 Hold for 20' 7,708.26 6,376.74 -1,126.53 106.31 Start 2°/100' DLS, 0° TF, for 242.71' 7,950.97 6,387.64 -1,361.37 46.30 Hold for 8396.63' 16,347.60 6,409.00 -9,496.54 -2,032.61 Adjust TF to 0°, for 500' 16,847.60 6,410.27 -9,980.97 -2,156.41 TD: 16847.6' MD, 6410.27' TVD Checked By: Approved By: Date: 7/98/2016 3:12:49PM Page 9 COMPASS 5000.1 Build 74 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-06 Plan: 2S-06 50103xxxxx00 2S-06wp10 [Salmon] Clearance Summary Anticollision Report 18 July, 2016 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-06 - Plan: 2S-06 - 2S-06wp10 [Salmon] Well Coordinates: Datum Height: Plan: 120+39 @ 159.00usft (Doyon142) Scan Range: 0.00 to 16,847.60 usft. Measured Depth. Scan Radius is 1,880.86 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-06 - 2S-06wp10 [Salmon] Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-06 - Plan: 2S-06 - 2S-06wp10 [Salmon] Scan Range: 0.00 to 16,847.60 usft. Measured Depth. Scan Radius is 1,880.86 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad 25-01 - 25-01 - 25-01 2S-01 - 2S-01 - 2S-01 2S-02 - 2S-02 - 2S-02 2S-02 - 2S-02 - 2S-02 2S-03 - 2S-03 - 2S-03 2S-03 - 2S-03 - 2S-03 2S-03 - 2S-03PB1 - 2S-03PB1 2S-03 - 2S-03PB1 - 2S-03PB1 2S-04 - 2S-04 - 2S-04 2S-04 - 25-04 - 2S-04 2S-04 - 2S-04PB1 - 2S-04PB1 2S-04 - 2S-04PB1 - 2S-04PB1 2S-05 - 2S-05 - 25-05 2S-05 - 2S-05 - 2S-05 2S-07 - 25-07 - 2S-07 2S-07 - 2S-07 - 25-07 2S-08 - 2S-08 - 2S-08 2S-08 - 25-08 - 2S-08 2S-10 - 2S-10 - 25-10 2S-10 - 2S-10 - 2S-10 2S-11 - 2S-11 - 2S-11 2S-11 - 25-11 - 2S-11 2S-12 - 2S-12 - 2S-12 2S-12 - 2S-12 - 2S-12 2S-12 - 2S-12PB1 - 2S-12PB1 2S-12 - 2S-12PB1 - 2S-12PB1 2S-12- 2S-12PB1 - 2S-12wp10.1 [Bull] 2S-12 - 2S-12PB1 - 2S-12wp10.1 [Bull] 349.36 147.26 349.36 141.05 350.00 23.715 Centre Distance Pass - Major Risk 399.35 147.54 399.35 140.50 400.00 20.957 Clearance Factor Pass - Major Risk 261.50 119.37 261.50 112.53 250.00 17.448 Centre Distance Pass - Major Risk 361.46 119.99 361.46 111.74 350.00 14.539 Clearance Factor Pass - Major Risk 324.31 87.82 324.31 82.06 325.00 15.237 Centre Distance Pass - Major Risk 424.19 88.60 424.19 81.11 425.00 11.827 Clearance Factor Pass - Major Risk 324.31 87.82 324.31 82.06 325.00 15.237 Centre Distance Pass - Major Risk 424.19 88.60 424.19 81.11 425.OD 11.827 Clearance Factor Pass - Major Risk 761.11 52.71 761.11 40.28 750.00 4.239 Centre Distance Pass - Major Risk 785.68 52.83 785.68 40.06 775.00 4.137 Clearance Factor Pass - Major Risk 761.11 52.71 761.11 40.28 750.00 4.239 Centre Distance Pass - Major Risk 785.68 52.83 785.68 40.06 775.00 4.137 Clearance Factor Pass - Major Risk 561.46 26.77 561.46 17.32 550.00 2.833 Centre Distance Pass - Major Risk 611.26 27.05 611.26 16.80 600.00 2.639 Clearance Factor Pass - Major Risk 39.00 29.52 39.00 28.30 27.50 24.010 Centre Distance Pass - Major Risk 486.35 31.30 486.35 16.90 475.00 2.173 Clearance Factor Pass - Major Risk 286.49 58.66 286.49 53.60 275.00 11.598 Centre Distance Pass - Major Risk 361.46 59.26 361.46 52.95 350.00 9.389 Clearance Factor Pass - Major Risk 585.37 115.80 585.37 105.92 575.00 11.721 Centre Distance Pass - Major Risk 830.81 116.65 830.81 103.39 825.00 8.798 Clearance Factor Pass - Major Risk 399.29 148.68 399.29 141.69 40D.00 21.254 Centre Distance Pass - Major Risk 473.65 149.45 473.65 141.19 475.00 18.084 Clearance Factor Pass - Major Risk 39.00 179.98 39.00 178.97 27.50 178.037 Centre Distance Pass - Major Risk 584.92 182.57 584.92 172.72 575.00 18.543 Clearance Factor Pass - Major Risk 39.00 179.98 39.00 178.97 27.50 178.037 Centre Distance Pass - Major Risk 584.92 182.57 584.92 172.72 575.00 18.543 Clearance Factor Pass - Major Risk 411.50 179.98 411.50 172.82 400.00 25.122 Centre Distance Pass - Major Risk 634.09 181.38 634.09 170.39 625.00 16.503 Clearance Factor Pass - Major Risk 18 July, 2016 - 15:09 Page 2 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-06 - 2S-O6wp1O [Salmon] To (usft) (usft) 39.00 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 2S-06wpl0 [Salmon] 750.00 1,750.00 2S-06wpl0 [Salmon] 750.00 2,779.13 2S-06wp10 [Salmon] Reference Design: Kuparuk 2S Pad - Plan: 2S-06 - Plan: 2S-06 - 2S-06wp10 [Salmon] 4,281.49 2S-06wp10 [Salmon] 2,779.13 7,688.26 2S-06wp10 [Salmon] 7,688.26 9,188.26 Scan Range: 0.00 to 16,847.60 usft. Measured Depth. 7,688.26 16,847.60 2S-06wp10 [Salmon] Scan Radius is 1,880.86 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Plan: 25-09 - Plan: 2S-09 - 2S-09wp08(Tiger] 350.00 90.03 350.OD 83.81 350.00 14.482 Centre Distance Pass - Major Risk Plan: 2S-09 - Plan: 2S-09 - 2S-09wp08[Tiger] 7,093.48 165.77 7,093.48 63.04 7,225.00 1.614 Clearance Factor Pass - Major Risk Plan: 2S-315 - Plan: 2S-315 - 2S-315wp02 400.00 210.25 400.OD 203.16 400.00 29.656 Centre Distance Pass - Major Risk Plan: 2S-315 - Plan: 25-315 - 2S-315wp02 449.71 210.58 449.71 202.68 450.00 26.661 Clearance Factor Pass - Major Risk Rig: 25-14 - Rig: 2S-14 - Rig: 2S-14 324.89 239.26 324.89 233.58 325.00 42.102 Centre Distance Pass - Major Risk Rig: 2S-14 - Rig: 2S-14 - Rig: 2S-14 449.41 240.13 449.41 232.36 450.00 30.927 Clearance Factor Pass - Major Risk Rig: 2S-14 - Rig: 2S-14 - 2S-14wpl0.1 [Whale] 300.00 240.12 3DO.DD 234.77 300.00 44.944 Centre Distance Pass - Major Risk Rig: 2S-14 - Rig: 2S-14 - 2S-14wpl0.1 [Whale) 399.99 240.81 399.99 233.88 400.00 34.732 Clearance Factor Pass - Major Risk Non -Pad Shark Tooth #1 - Shark Tooth #1 - Shark Tooth #1 10,452.76 1,003.12 10,452.76 863.55 6,375.00 8.390 Clearance Factor Pass - Major Risk SuiyeV fool program From To (usft) (usft) 39.00 750.00 2S-06wpl0 [Salmon] 750.00 1,750.00 2S-06wpl0 [Salmon] 750.00 2,779.13 2S-06wp10 [Salmon] 2,779.13 4,281.49 2S-06wp10 [Salmon] 2,779.13 7,688.26 2S-06wp10 [Salmon] 7,688.26 9,188.26 2S-06wp10 [Salmon] 7,688.26 16,847.60 2S-06wp10 [Salmon] Survey/Plan Survey Tool GYD-GC-SS MWD M W D+I FR-AK-CAZ-SC MWD M W D+I F R-AK-CAZ-SC MWD M W D+I F R-AK-CAZ-SC 18 July, 2016 - 15:09 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-06 - 2S-06wp10 [Salmon] Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 18 July, 2016 - 15:09 Page 4 of 6 COMPASS Ladder View 15:20, July 18 2016 C 2S-06wp10 [Salmon] The ReferenceWell is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors t n G a o a 0 o c n n r r 300 I J s= 02 , a a� a� 150— 50 (D N (D U Equivalent Magnetic Distance 0 i 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire well:Measured Depth 39.00 To 16847.60 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 750.00 2S-06wp10 [Salmon] (Plan: 2S-06)GYD-GC-SS 2661.OE779.13 10-3/4" x 13-1/2" 750.00 1750.00 2S-06wp10 [Salmon] (Plan: 2S-06)MWD 6375.01B88725/8" x 9-7/8" by 11" 750.00 2779.13 2S-06wp10 [Salmon] (Plan: 2S-06)MWD+IFR-AK-CAZ-SC 6410:B847.60 4 1/2" x 6-3/4" 2779.13 4281.49 2S-06wp10 [Salmon] (Plan: 2S-06)MWD 2779.13 7688.26 2S-06wp10 [Salmon] (Plan: 2S-06)MWD+IFR-AK-CAZ-SC 7688.26 9188.26 2S-06wp10 [Salmon] (Plan: 2S-06)MWD 7688.2616847.60 2S-06wp10 [Salmon] (Plan: 2S-06)MWD+IFR-AK-CAZ-SC m a oq q N 4f 41 N N 60— 0 .2 'O 30- 0 0 � I I 0 f 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth 2S-06wp10 [Salmon] MD Inc Azi TVD Dleg TFace Target 1150 -"- 39.00 0.00 0.00 39.00 0.00 0.00 2330 39.00 To 16847.60 425.00 0.00 0.00 425.00 0.00 0.00 4830 4830 600.06 2.63 0.00 600.00 1.50 0.00 7970 7970 -- 380.92 22.15 0.00 1359.00 2.50 0.00 - 13040 15.19,July Is2016 488.89 22.15 0.00 1459.00 0.00 0.00 897.71 21.32 29.27 1793.30 3.00 107.93 CASING DETAILS 464.77 21.32 29.27 3299.73 0.00 0.00 688.26 85.00 194.33 6375.00 2.50 164.54 2S -Salmon 1. Heel 050216 P TVD MD Name 708.26 85.00 194.33 6376.74 0.00 0.00 2661.00 2779.13 10-3/4" x 13-1/2" 950.97 89.85 194.33 6387.69 2.00 0.00 6375.00 7688.28-5/8" x 9-7/e" 6- 347.60 89.85 194.33 6409.00 0.00 0.00 2S -Salmon 2. Toe 050216 PB 6910.27 16897.60 4 1/2" x 6-3/4/41 1 847.60 89.65 194.33 6410.27 0.00 0.00 °� Y.66 1750. o 25 66' o ;5a a - , (2Im: =5� 55 956.00 1156.60 25-66rp16 [sazmn] IPlm: 253x61 956.66 2119,13 25 6x 16 [sal 1 (aYm: 25fegrIFx-Art-CAL-6c 2]]9.13 1 1.49 25-66rp16 [sales] (elm: 2S 2)99.13 1666.26 26:6O.p 9 [Salina] (elm: 253.6yIP2-AC-CAz-sc ,666.26 9166.26 25-96VIO [Sala] (91m: 2536q >666.26 16649.60 25-06vp10 [Sala] (Plae: 2596e7tI6R-A6-as-sc -60/300 -90/270 2S-12PB ; Ji i 2S-12 2S.12wp10:1 2S-31 Swp02, 2S-08 120 / 240 425 ---- -- 610 610"--"- 790 790 970 970 1150 1150 -"- _ 1340 1340 1520 1520 1700 1700 2330 2330 2950 2950 3580 3580 4200 4200 -"--- 4830 4830 5450 5450 6080 6080 -- 6700 6700 _-- 7970 7970 -- 9240 9240 10510 10510 11780 11780 - 13040 13040 14310 14310 15580 15580 --- 16848 �,\�-'Ae•�4 ; , �i:s- b �'� 3 G�j`® l'da •MhI`'y ►bb. �i in 14'••II --7 1\ �`� <�x • a o��� �• l � v ^. ]I '0!I Z"1 �•"`«�,� ,w3e�V.bizi ...�vorra n ® 16x" .s 1 ]d� ••••• �I say ® ►®� ,� ii b 02 -En q1 � � .y�• '�iy!�� ii�if` .•E, 1 1 MM July 18 201 0 0 0 M upar k 2 0 z Easting (3000 usftlin) Easting (3000 usftfin) 2 AC Flipbook Casing Details Survey Program ND MD Name ?375.00 688.23 "-9-"x1by1, 0375.00 7688.26 7-518" x 9918° by 1A' Depth From gg.00 750.00 Depth To Survey/Plan 750.00 zS-o6wpio[Salmon](Plan:z5-o6) 1750.00 ZS-06wp1a [Salmon] (Plan: 2S-o6) Tool GYD-GC-55 MWD 2S-o6wplo [Salmon] 39 425 6410.27 16847.60 41/2"z6-3/4" 75a.00 2779.13 2S-o6wplo(Salmon](Plan: 4281.49 2S-06wpto[Salmon](Plan:zS-o6) 2S-o6) MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC 2 4 5 610 V 3 9.0 0 TO 110 O.0 0 2779.13 7688.26 7688.26 2S-06w [Salmon] 9188.26 2S-o6wplo[Salmon](P (Plan: z5-o6) [an : 2S-o6) MWD 7688.26 16847.6o zS-o6wplo [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC 610 790 M D Azi 0/360 790 970 39.00 0.00 go 2S-03PB1 970 1150 425.00 0.00 -30/33 0 I 600.06 0.00 „"' 1150 1340 1380.92 0.002S-03 1340 1520 1488.89 0.00 60 1520-._._._. 1700 1847.71 29.27 _6o/300 = I �I10 1700 2330 3464.77 29.27 7688.26 194.33 '' 2330 2950 7708.26 194.33 30 -' � `'� = 2950 3580 7950.97 194.33 16347.60 194.33 _- 3580 4200 16847.60 194.33 - 0 / 27P, a;> r .� '�, 90 4200 4830 4830 5450 ..---- -. - 5450 6 080 0 30 8 6080 6 0 7 0 6700 7970 -120/240 - 120 7970 9240 6o 9240 -10510 2S-04PB1 10510 11780 -150/210 _ -5-0- 11780 13040 go 25-04 13040 14310 -18o/18 25-05 14310 15580 15580 16848 15:251 July 18 2016 Casing Details Survey Program ND MD Name 2661.o0 -7798 ".9-°x8y11" 6375.00 7688.z6 7-516" x 9-718" by 14, Depth From 39.00 750.00 Depth To SurveylPlan 750.00 2S-06wplo [Salmon] (Plan: z5 -o6) 1750.00 2S-o6wp10 [Salmon] (Plan: 2S-06) Tool GVD-GC-SS MWD C 2S-o6wpio [Salmon] 39 l 2 425 641 o.z7 16847Go 41/z" x 6-3/4" 750.00 2779.13 2779.13 25-o6wpl0 [Salmon] (Plan: zS-06) 4281.49 zS-06wplo [Salmon] (Plan: zS-o6) MWD+IFR-AK-CAZ-SC MWD 4 5 G 1 o 17 110 0. o o To 7000-00 277913 7686.26 7688.26 ZS-o6wplo [Salmon] (Plan: zS 06) 9188.26 z5-o6wplo [Salmon]( PIan:2S-o6) MWD+IFR-AK-CAZ SC MWD 7688.26 16847.60 2S.o6wplo [Salmon] (plan: 2S.o6) MWD+IFR-AK-CAZ-SC 610 790 M D Azi 0/360 790 970 39.00 0.00 9 0 970 1150 425.00 0.00 0 / 3 33 " 0 600.o6 0.o0 _ 1150 1340 1380.92 0.00 1340 1520 1488.89 0.00 6o _....- -1700 1520 1847.71 29.27 -60 / 300 -� " ;' - 60 1700 2330 3464.77 29.27 , 7688.26 194.33 2330 2950 7708.26 194.33 302950 3580 7950.97 194.33 16347.60 1 94 .33 _- -. 3580 4200 16847.6o 194.330 4200 4830 / 2�0 90 4830 5450 5450 6080 30 6o8o 6700 6700 7970 -120/240 =` _. 120 7970 9240 6o - 9240 ------ -10510 10510 11780 11780 13040 -150/210 150 go 13040 14310 -18o/18o 14310 15580 15580 16848 15:281 July 18 m6l Casing Details Survey Program 2S-o6wplo [Salmon] ND MD z661.00 -1779.8 6375.00 7688.-16 Name 10 -3/4"x13 -1/z" 7-5/8" x 9718" 3- /2" Depth From Depth To Survey/Plan 39-oo 750.00 2S-o6wplo [Salmon] (Plan: 2S -o6) 750.00 1750.00 2S-06wplo [Salmon] (Plan: 2S -o6) Tool 6YD-GC-SS MWD 39 2 425 6410.27 16847.60 41/2" x 6-3/4" 750.0o 1779.13 2779.13 4281.49 2S-o6wplo [Salmon] (PIan:2S-o6) 2S-o6wplo[Salmon](Plan: 2S -o6) MWD+IFR-AK-CAZ-SC MWD 2 4 5 G10 U 7 0 0 O.O o To7500.00 O O.O o -1779.13 7688.26 7688.26 9188.-16 2S-o6wplo [Salmon] (PIan:2S-o6) zS-o6wpm [Salmon] (Plan: z5-ob) MWD+IFR-AK-CAZ-SC MWD 7688.26 1684760 25-06wplo [Salmon](Plan: 25-06) MWD+IFR-AK-CAZ-SC 610 790 M D Azi 01360 790 970 39.00 0.00 9 0 970 1150 425.00 0.00 -30/33 _ o 600.o6 o.00 1150 1340 1380.92 0.00 `, ; , ,, 1340 1520 148 8.8 9 0.00 6o ___.___.. 1520 � 1700 1847.71 29.27 6o/300 _.. 1700 2330 3464.77 29.27 .-6o 7688.26 194.33 2330 2950 77o8.26 194.33 3 0 -' , - \ ' 2950 3580 7950.97 194.33 16347.6o 194.33 3580 4200 16847.6o 194.33/ 4200 4830 0 70 90 4830 5450 _ 545o __ 6080 30 o8o 670 6700 7970 -120/240 �' _,.. ,;; . 120 7970 9240 6o 9240 10510 10510 11780 1178o 13040 -150/210 150 go 13040 14310 -18o/18o 14310 15580 15580 16848 15.29, July 18 2016 _ 1 25-o6wpto [s�aonJ 7 p ®A • O O �O G Q �/. ` O 7 ■L/■ V v / V Casing Details TVD MD Name 266 0o z779a3 0-3/4"xg-111" G375.00 7688.26 7-5/8" x 9-7/8" by tt" 6410.27 16847.6o 41/z x 6-314" Depth From 39.00 790.00 750.00 2779.13 2779.13 7688.26 7688.26 Survey Program Depth To Survey/Plan 750.00 z5-o6wpt0[Salmon](Plan: z5 -o6) 1750.00 zS-o6wpto [Salmon] (Plan: 2S-06) 2779.13 2S-o6wpto [Salmon] (Plan: 2S -o6) 4281.49 2S-o6wpto [Salmon] (Plan: 2S -o6) 7688.26 25-06w 10 [Salmon] (Plan: 2S o6) 9188.26 2S-o6wpto [Salmon] (Plan: 25-06) 16847.60 2S-06wpto[Salmon](Plan: 2S-06) Tool CVD -GC -SS MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC 39 425 610 425 G 1 o V -`--M-D-- Azi - 0/36o 790 790 970 39.00 0.00 9 0 970 1150 425.00 0.00 -30/33 0 600.o6 o.00 1150 1340 1380.92 0.00 ,- 1340 1520 1488.89 o.00 6o _- -- 1520 1700 1847.71 29.27 60/300 - 60 1700 2330 3464.77 29.27 7688.26 194.33 - 2330 2950 7708.26 194.33 3 0 ,' 2950 3580 7950.97 194.33 16347.60 194.33 !,-..... 3580 4200 16847.6o 194.330 4200 4830 / 2�0 90 4830 5450 5450 608o - 30 608o 6700 6700 7970 -120/ 240 120 7970 9240 60 9240 ----------------- 10510 10510 1178o 11780 13040 -150/210 _ - 150 go 13040 14310 -18o/180 14310 1558o 1558o 16848 15:291, Jury 18 2016 Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-06 Plan: 2S-06 Plan: 2S-06wp10 [Salmon] Report - Errors 18 July, 2016 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wpl0 [Salmon] Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 2S-06 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) MD Reference: Plan: 120+39 @ 159.00usft (Doyonl42) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan: 2S-06 Well Position +N/ -S usft Northing: usft Latitude: +E/ -W usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan: 2S-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength C) l°) (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 2S-06wp10 [Salmon] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 39.00 0.00 0.00 195.00 Survey Tool Program Date 7/18/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 750.00 2S-06wp10 [Salmon] (Plan: 2S-06) GYD-GC-SS Gyrodata gyro single shots 750.00 1,750.00 2S-06wp10 [Salmon] (Plan: 2S-06) MWD MWD - Standard 750.00 2,779.13 2S-06wp10 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,779.13 4,281.49 2S-06wp10 [Salmon] (Plan: 25-06) MWD MWD - Standard 2,779.13 7,688.26 2S-06wp10 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,688.26 9,188.26 2S-06wp10 [Salmon] (Plan: 2S-06) MWD MWD - Standard 7,688.26 16,847.60 2S-06wp10 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error LaL Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 39.00 0.00 0.00 0.00 -120.00 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -59.00 1.15 0.04 0.04 200.00 1.15 0.00 0.00 41.00 1.15 0.19 0.19 289.00 1.15 0.00 0.00 130.00 1.15 0.33 0.33 top T-3 Sand 300.00 1.15 0.00 0.00 141.00 1.15 0.33 0.33 7/18/2016 3:13:01PM Page 2 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyonl42) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp10 [Salmon) Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) V) V) (usft) (usft) (usft) (usft) 374.00 1.15 0.00 0.00 215.00 1.15 0.48 0.48 K-15 Marker 400.00 1.15 0.00 0.00 241.00 1.15 0.48 0.48 425.00 1.15 0.00 0.00 266.00 1.15 0.51 0.51 KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' 500.00 1.15 1.12 90.00 341.00 1.15 0.62 0.62 600.00 1.15 2.62 90.00 440.94 1.15 0.77 0.77 600.06 1.15 2.63 90.00 441.00 1.15 0.77 0.77 Start 2.5°/100' DLS, 0° TF, for 780.86' 700.00 1.16 5.12 90.00 540.70 1.15 0.92 0.91 800.00 1.16 7.62 91.12 640.08 1.15 1.00 0.98 900.00 1.17 10.12 178.96 738.87 1.15 1.05 1.00 1,000.00 1.18 12.62 179.28 836.90 1.14 1.19 1.02 1,100.00 1.19 15.12 179.40 933.97 1.14 1.42 1.07 1,200.00 1.21 17.62 179.48 1,029.91 1.14 1.75 1.13 1,300.00 1.22 20.12 179.53 1,124.53 1.13 2.16 1.21 1,380.92 1.24 22.15 179.56 1,200.00 1.13 2.55 1.29 Hold for 107.97' 1,400.00 1.24 22.15 179.57 1,217.67 1.13 2.65 1.31 1,434.90 1.25 22.15 179.59 1,250.00 1.15 3.11 1.42 Base permafrost (?) 1,488.89 1.25 22.15 179.59 1,300.00 1.15 3.11 1.42 Start 3°/100' DLS, 107.93° TF, for 358.82' 1,500.00 1.25 22.05 179.60 1,310.30 1.15 3.16 1.44 1,600.00 1.26 21.35 0.21 1,403.23 1.18 3.49 1.62 1,700.00 1.30 21.03 1.64 1,496.49 1.21 3.80 1.90 1,800.00 1.28 21.13 0.03 1,589.82 1.20 1.91 1.61 1,847.71 1.29 21.32 1.28 1,634.30 1.20 1.96 1.67 Hold for 1617.06' 1,900.00 1.29 21.32 3.19 1,683.01 1.21 2.04 1.72 1,907.51 1.30 21.32 6.67 1,690.00 1.24 2.22 1.82 Top W Sak (W Sak D) 2,000.00 1.30 21.32 6.67 1,776.17 1.24 2.22 1.82 2,100.00 1.31 21.32 9.44 1,869.33 1.26 2.41 1.92 2,200.00 1.32 21.32 11.69 1,962.49 1.29 2.60 2.02 2,300.00 1.33 21.32 13.53 2,055.64 1.31 2.80 2.13 2,400.00 1.34 21.32 15.07 2,148.80 1.34 3.00 2.24 2,500.00 1.35 21.32 16.36 2,241.96 1.37 3.20 2.34 2,600.00 1.36 21.32 17.47 2,335.12 1.40 3.40 2.46 2,653.54 1.37 21.32 18.42 2,385.00 1.44 3.61 2.57 Base W Sak 2,700.00 1.37 21.32 18.42 2,428.28 1.44 3.61 2.57 2,779.13 1.38 21.32 19.31 2,502.00 1.45 3.84 2.63 10-3/4" x 13-1/2" 2,800.00 1.38 21.32 19.31 2,521.44 1.45 3.84 2.63 7/18/2016 3:13:01PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 25-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp10 [Salmon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) V) V) (usft) (usft) (usft) (usft) 2,900.00 1.39 21.32 20.46 2,614.60 1.46 4.13 2.64 3,000.00 1.41 21.32 21.54 2,707.76 1.48 4.47 2.66 3,082.91 1.42 21.32 22.47 2,785.00 1.50 4.84 2.69 C-80 3,100.00 1.42 21.32 22.47 2,800.92 1.50 4.84 2.69 3,200.00 1.43 21.32 23.26 2,894.08 1.52 5.24 2.74 3,300.00 1.44 21.32 23.92 2,987.23 1.54 5.67 2.79 3,400.00 1.45 21.32 24.48 3,080.39 1.56 6.11 2.85 3,464.77 1.46 21.32 24.79 3,140.73 1.58 6.40 2.90 Start 2.6°i100' DLS, 164.64° TF, for 4223.49' 3,500.00 1.46 20.47 24.89 3,173.65 1.59 6.53 2.93 3,600.00 1.48 18.08 25.10 3,268.04 1.63 6.78 3.05 3,700.00 1.51 15.72 25.41 3,363.71 1.66 7.01 3.20 3,800.00 1.55 13.42 25.81 3,460.49 1.69 7.17 3.42 3,900.00 1.60 11.19 26.29 3,558.19 1.72 7.23 3.78 4,000.00 1.67 9.11 26.83 3,656.63 1.74 7.10 4.37 4,100.00 1.75 7.29 27.44 3,755.61 1.76 6.57 5.36 4,200.00 1.84 5.99 28.12 3,854.94 1.78 5.30 6.75 4,300.00 1.80 5.57 23.38 3,954.45 1.74 3.05 4.95 4,400.00 1.88 6.21 23.67 4,053.94 1.76 3.31 4.83 4,471.55 1.96 7.18 23.95 4,125.00 1.77 3.86 4.45 C-60 4,500.00 1.96 7.65 23.95 4,153.22 1.77 3.86 4.45 4,600.00 2.05 9.54 24.19 4,252.09 1.78 4.25 4.11 4,700.00 2.14 11.66 24.39 4,350.38 1.79 4.50 3.88 4,800.00 2.23 13.91 24.51 4,447.90 1.79 4.66 3.71 4,838.29 2.33 14.79 24.52 4,485.00 1.80 4.77 3.60 C-40 4,900.00 2.33 16.23 24.52 4,544.46 1.80 4.77 3.60 5,000.00 2.43 18.59 24.40 4,639.87 1.80 4.86 3.51 5,100.00 2.53 20.99 24.09 4,733.96 1.81 4.93 3.45 5,101.11 2.63 21.01 23.56 4,735.00 1.82 5.00 3.40 C37 5,200.00 2.63 23.40 23.56 4,826.55 1.82 5.00 3.40 5,264.08 2.73 24.96 22.77 4,885.00 1.82 5.07 3.35 Growler -AA 5,300.00 2.73 25.83 22.77 4,917.45 1.82 5.07 3.35 5,400.00 2.83 28.28 21.69 5,006.50 1.83 5.15 3.31 5,500.00 2.93 30.73 20.32 5,093.53 1.85 5.25 3.28 5,600.00 3.04 33.19 18.68 5,178.36 1.86 5.35 3.25 5,700.00 3.14 35.65 16.87 5,260.85 1.88 5.48 3.23 5,800.00 3.24 38.12 14.99 5,340.83 1.91 5.63 3.21 5,900.00 3.34 40.59 13.17 5,418.15 1.94 5.80 3.19 5,928.92 3.43 41.30 11.52 5,440.00 1.98 5.99 3.18 Top Cairn 7/1812016 3:13:01PM Page 4 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wpl0 [Salmon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 6,000.00 3.43 43.06 11.52 5,492.67 1.98 5.99 3.18 6,044.66 3.53 44.17 10.10 5,525.00 2.02 6.21 3.18 Top Bermuda 6,100.00 3.53 45.54 10.10 5,564.24 2.02 6.21 3.18 6,137.09 3.62 46.45 8.94 5,590.00 2.08 6.45 3.18 Base Bermuda 6,188.50 3.62 47.73 8.94 5,625.00 2.08 6.45 3.18 C-35 6,200.00 3.62 48.01 8.94 5,632.72 2.08 6.45 3.18 6,300.00 3.72 50.49 8.05 5,697.98 2.14 6.73 3.18 6,400.00 3.81 52.97 7.39 5,759.91 2.21 7.02 3.19 6,500.00 3.90 55.46 6.94 5,818.38 2.28 7.34 3.21 6,600.00 3.98 57.94 6.65 5,873.28 2.37 7.69 3.23 6,698.97 4.07 60.40 6.49 5,924.00 2.47 8.05 3.26 Top HRZ (K-2 mkr) 6,700.00 4.07 60.42 6.49 5,924.51 2.47 8.05 3.26 6,800.00 4.15 62.91 6.43 5,971.97 2.57 8.44 3.30 6,898.65 4.23 65.36 6.45 6,015.00 2.68 8.84 3.34 Upper Kalubik (base HRZ) 6,900.00 4.23 65.39 6.45 6,015.56 2.68 8.84 3.34 7,000.00 4.31 67.88 6.54 6,055.22 2.80 9.27 3.39 7,100.00 4.39 70.37 6.66 6,090.85 2.92 9.71 3.45 7,143.26 4.47 71.44 6.82 6,105.00 3.05 10.16 3.51 Lower Kaiubik (K-1 mkr) 7,200.00 4.47 72.85 6.82 6,122.39 3.05 10.16 3.51 7,300.00 4.54 75.34 7.00 6,149.79 3.19 10.63 3.58 7,400.00 4.62 77.83 7.19 6,172.99 3.33 11.10 3.65 7,460.66 4.69 79.34 7.40 6,185.00 3.48 11.59 3.73 Kuparuk C (Top C4) 7,500.00 4.69 80.32 7.40 6,191.95 3.48 11.59 3.73 7,551.20 4.76 81.59 7.61 6,200.00 3.62 12.09 3.81 AS 7,600.00 4.76 82.80 7.61 6,206.62 3.62 12.09 3.81 7,628.32 5.35 83.51 7.22 6,210.00 3.63 12.46 3.81 A4 7,688.26 5.35 85.00 7.22 6,216.00 3.63 12.46 3.81 Hold for 20'- 7-5/8" x 9-718" by 11" 7,700.00 5.35 85.00 7.21 6,217.02 3.63 12.51 3.81 7,708.26 5.35 85.00 7.20 6,217.74 3.63 12.54 3.81 Start 2°/100' DLS, 0° TF, for 242.71' 7,800.00 5.41 86.83 7.24 6,224.27 3.67 12.99 3.78 7,900.00 5.46 88.83 7.45 6,228.05 3.74 13.61 3.78 7,950.97 5.49 89.85 7.61 6,228.64 3.79 13.98 3.80 Hold for 8396.63' 8,000.00 5.50 89.85 7.79 6,228.76 3.85 14.36 3.85 8,100.00 5.50 89.85 8.18 6,229.01 3.99 15.21 3.99 7/18/2016 3:13:01PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.O0usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp10 [Salmon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 8,200.00 5.51 89.85 8.59 6,229.27 4.15 16.16 4.16 8,300.00 5.52 89.85 9.00 6,229.52 4.34 17.17 4.35 8,400.00 5.53 89.85 9.39 6,229.78 4.56 18.25 4.56 8,500.00 5.54 89.85 9.75 6,230.03 4.79 19.38 4.79 8,600.00 5.55 89.85 10.08 6,230.29 5.04 20.55 5.04 8,700.00 5.55 89.85 10.37 6,230.54 5.30 21.76 5.30 8,800.00 5.56 89.85 10.64 6,230.80 5.57 23.00 5.57 8,900.00 5.57 89.85 10.88 6,231.05 5.86 24.26 5.86 9,000.00 5.58 89.85 11.10 6,231.30 6.15 25.55 6.15 9,100.00 5.59 89.85 11.30 6,231.56 6.45 26.85 6.45 9,200.00 5.60 89.85 9.07 6,231.81 4.57 16.37 4.57 9,300.00 5.61 89.85 9.24 6,232.07 4.68 16.76 4.68 9,400.00 5.62 89.85 9.41 6,232.32 4.80 17.17 4.80 9,500.00 5.63 89.85 9.57 6,232.58 4.92 17.58 4.92 9,600.00 5.64 89.85 9.73 6,232.83 5.04 18.00 5.04 9,700.00 5.65 89.85 9.88 6,233.09 5.16 18.43 5.17 9,800.00 5.66 89.85 10.02 6,233.34 5.29 18.87 5.30 9,900.00 5.67 89.85 10.16 6,233.59 5.43 19.32 5.43 10,000.00 5.68 89.85 10.30. 6,233.85 5.56 19.77 5.56 10,100.00 5.69 89.85 10.43 6,234.10 5.70 20.23 5.70 10,200.00 5.70 89.85 10.55 6,234.36 5.84 20.69 5.84 10,300.00 5.71 89.85 10.67 6,234.61 5.98 21.16 5.98 10,400.00 5.72 89.85 10.78 6,234.87 6.12 21.64 6.13 10,500.00 5.73 89.85 10.89 6,235.12 6.27 22.12 6.27 10,600.00 5.74 89.85 10.99 6,235.38 6.42 22.60 6.42 10,700.00 5.75 89.85 11.09 6,235.63 6.56 23.09 6.57 10,800.00 5.76 89.85 11.18 6,235.88 6.71 23.59 6.72 10,900.00 5.77 89.85 11.27 6,236.14 6.87 24.08 6.87 11,000.00 5.78 89.85 11.36 6,236.39 7.02 24.58 7.02 11,100.00 5.79 89.85 11.44 6,236.65 7.17 25.09 7.18 11,200.00 5.80 89.85 11.52 6,236.90 7.33 25.59 7.33 11,300.00 5.81 89.85 11.60 6,237.16 7.48 26.10 7.49 11,400.00 5.82 89.85 11.67 6,237.41 7.64 26.62 7.64 11,500.00 5.84 89.85 11.74 6,237.67 7.80 27.13 7.80 11,600.00 5.85 89.85 11.80 6,237.92 7.96 27.65 7.96 11,700.00 5.86 89.85 11.87 6,238.17 8.12 28.17 8.12 11,800.00 5.87 89.85 11.93 6,238.43 8.28 28.69 8.28 11,900.00 5.88 89.85 11.99 6,238.68 8.44 29.22 8.44 12,000.00 5.89 89.85 12.04 6,238.94 8.60 29.74 8.61 12,100.00 5.90 89.85 12.10 6,239.19 8.77 30.27 8.77 12,200.00 5.91 89.85 12.15 6,239.45 8.93 30.80 8.93 12,300.00 5.93 89.85 12.20 6,239.70 9.09 31.33 9.10 12,400.00 5.94 89.85 12.24 6,239.96 9.26 31.86 9.26 12,500.00 5.95 89.85 12.29 6,240.21 9.42 32.40 9.43 7/18/2015 3:13.01PM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 25-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp10 [Salmon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) V) V) (usft) (usft) (usft) (usft) 12,600.00 5.96 89.85 12.34 6,240.46 9.59 32.93 9.59 12,700.00 5.97 89.85 12.38 6,240.72 9.76 33.47 9.76 12,800.00 5.99 89.85 12.42 6,240.97 9.92 34.01 9.93 12,900.00 6.00 89.85 12.46 6,241.23 10.09 34.55 10.09 13,000.00 6.01 89.85 12.50 6,241.48 10.26 35.09 10.26 13,100.00 6.02 89.85 12.53 6,241.74 10.43 35.63 10.43 13,200.00 6.04 89.85 12.57 6,241.99 10.59 36.18 10.60 13,300.00 6.05 89.85 12.60 6,242.25 10.76 36.72 10.76 13,400.00 6.06 89.85 12.64 6,242.50 10.93 37.27 10.93 13,500.00 6.07 89.85 12.67 6,242.75 11.10 37.81 11.10 13,600.00 6.09 89.85 12.70 6,243.01 11.27 38.36 11.27 13,700.00 6.10 89.85 12.73 6,243.26 11.44 38.91 11.44 13,800.00 6.11 89.85 12.76 6,243.52 11.61 39.46 11.61 13,900.00 6.12 89.85 12.79 6,243.77 11.78 40.01 11.78 14,000.00 6.14 89.85 12.81 6,244.03 11.95 40.56 11.95 14,100.00 6.15 89.85 12.84 6,244.28 12.12 41.11 12.12 14,200.00 6.16 89.85 12.86 6,244.54 12.29 41.66 12.30 14,300.00 6.18 89.85 12.89 6,244.79 12.47 42.22 12.47 14,400.00 6.19 89.85 12.91 6,245.04 12.64 42.77 12.64 14,500.00 6.20 89.85 12.94 6,245.30 - 12.81 43.32 12.81 14,600.00 6.22 89.85 12.96 6,245.55 12.98 43.88 12.98 14,700.00 6.23 89.85 12.98 6,245.81 13.15 44.43 13.15 14,800.00 6.24 89.85 13.00 6,246.06 13.33 44.99 13.33 14,900.00 6.26 89.85 13.02 6,246.32 13.50 45.54 13.50 15,000.00 6.27 89.85 13.04 6,246.57 13.67 46.10 13.67 15,100.00 6.28 89.85 13.06 6,246.83 13.84 46.66 13.84 15,200.00 6.30 89.85 13.08 6,247.08 14.02 47.22 14.02 15,300.00 6.31 89.85 13.10 6,247.33 14.19 47.78 14.19 15,400.00 6.32 89.85 13.12 6,247.59 14.36 48.33 14.36 15,500.00 6.34 89.85 13.14 6,247.84 14.54 48.89 14.54 15,600.00 6.35 89.85 13.15 6,248.10 14.71 49.45 14.71 15,700.00 6.37 89.85 13.17 6,248.35 14.88 50.01 14.89 15,800.00 6.38 89.85 13.19 6,248.61 15.06 50.57 15.06 15,900.00 6.39 89.85 13.20 6,248.86 15.23 51.13 15.23 16,000.00 6.41 89.85 13.22 6,249.12 15.41 51.69 15.41 16,100.00 6.42 89.85 13.23 6,249.37 15.58 52.26 15.58 16,200.00 6.44 89.85 13.25 6,249.62 15.75 52.82 15.76 16,300.00 6.45 89.85 13.26 6,249.88 15.93 53.38 15.93 16,347.60 6.46 89.85 13.27 6,250.00 16.01 53.65 16.01 Adjust TF to 0°, for 500' 16,400.00 6.47 89.85 13.27 6,250.13 16.10 53.94 16.11 16,500.00 6.48 89.85 13.29 6,250.39 16.28 54.51 16.28 16,600.00 6.49 89.85 13.30 6,250.64 16.45 55.07 16.45 16,700.00 6.51 89.85 13.31 6,250.90 16.63 55.63 16.63 16,800.00 6.52 89.85 13.33 6,251.15 16.80 56.20 16.80 7/18/2016 3:13:01PM Page 7 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp10 [Salmon] Schlumberger Report - Errors Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2S-06 Plan: 120+39 @ 159.00usft (Doyon142) Plan: 120+39 @ 159.00usft (Doyon142) True Minimum Curvature OAKEDM P2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 16,847.60 6.53 89.85 13.33 6,251.27 16.89 56.46 16.89 TD: 16847.6' MD, 6410.27' TVD 711812016 3:13:01PM Page 8 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp10 [Salmon] Schlumberger Report - Errors Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 25-06 Plan: 120+39 @ 159.00usft (Doyon142) Plan: 120+39 @ 159.00usft (Doyon142) True Minimum Curvature OAKEDMP2 Casing Points Measured Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (11) 2,779.13 2,661.00 10-3/4" x 13-1/2" 10-3/4 13-1/2 16,847.60 6,410.27 4 1/2" x 6-3/4" 4-1/2 6-3/4 7,688.26 6,375.00 7-5/8" x 9-7/8" by 11" 7-5/8 11 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 289.00 289.00 top T-3 Sand 7,460.66 6,344.00 Kuparuk C (Top C4) 5,264.08 5,044.00 Growler -AA 3,082.91 2,944.00 C-80 1,434.90 1,409.00 Base permafrost(?) 6,698.97 6,083.00 Top HRZ (K-2 mkr) 5,101.11 4,894.00 C-37 4,471.55 4,284.00 C-50 6,044.66 5,684.00 Top Bermuda 2,653.54 2,544.00 Base W Sak 4,838.29 4,644.00 C-40 1,907.51 1,849.00 Top W Sak (W Sak D) 374.00 374.00 K-15 Marker 6,137.09 5,749.00 Base Bermuda 7,628.32 6,369.00 A4 6,188.50 5,784.00 C-35 7,143.26 6,264.00 Lower Kalubik (K-1 mkr) 5,928.92 5,599.00 Top Cairn 6,898.65 6,174.00 Upper Kalubik (base HRZ) 7,551.20 6,359.00 A5 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 425.00 425.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' 600.06 600.00 4.01 0.00 Start 2.5°/100' DLS, 0° TF, for 780.86' 1,380.92 1,359.00 170.70 0.00 Hold for 107.97' 1,488.89 1,459.00 211.41 0.00 Start 3°/100' DLS, 107.93° TF, for 358.82' 1,847.71 1,793.30 336.30 31.98 Hold for 1617.06' 3,464.77 3,299.73 849.09 319.34 Start 2.5°/100' DLS, 164.54° TF, for 4223.49' 7,688.26 6,375.00 -1,107.22 111.24 Hold for 20' 7,708.26 6,376.74 -1,126.53 106.31 Start 2°/100' DLS, 0° TF, for 242.71' 7,950.97 6,387.64 -1,361.37 46.30 Hold for 8396.63' 16,347.60 6,409.00 -9,496.54 -2,032.61 Adjust TF to 0°, for 500' 16,847.60 6,410.27 -9,980.97 -2,156.41 TD: 16847.6' MD, 6410.27' TVD Checked By: Approved By: Date: 7/18/2016 3:13:01PM Page 9 COMPASS 5000.1 Build 74 Pool Report WELLBORE TARGET DETAILS (MAP COORDINATES) 15:48, July 182018 2S-06wp10 [Salmon] Name TVD Shape 100 00) 2S-Salmon 1. Heel 050216 PB 6375.00 Circle (Radius: 100.00) 2SS Irnon 2. Toe 050216 PB 6409.00 Circle (Radius: 100.00) Quarter Mile View 2S-Salmon I. Toe 05021 6 PB_Circle 6375.00 Circle (Radius: 1320.00) 25-Sednon 2. Toe 050216 PB_Clrcle 6409.00 Circle (Radius: 1320.00) 6000 3000 '�'^• V/ 0 O O O M -3000 O Z I 4- X000 -9000 ?`1.Oq ( 23.0;28-08 ,i 2 Os I I j I i i I 25.02 � S.p I N — i 2S•12Pg 1' r 2S•1? Sh�rk T °th #� I � -2S ss.o1 03p81 2S.10 2S'03 I 2s.0 6 K'p10 -12000 -9000 -6000 -3000 0 3000 6000 9000 12000 !Sa mo 15:49,Ju1y182016 2S-06wp10 [Salmon] WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name 2&Salmon 1. Heel 050216 PB TVD 6375.00 Circle (Radius: Shape 100.00) 2S-Selmon 2. Toe 050216 PB 6409.00 Circle (Radius: 100.00) Quarter Mile View 2S-Salmon 2'Salmon 1, Hee1050218 P8 Circle 2. Toe 050216 PB Circle 6375.00 Circle (Redlus: 6409.00 CRcle (Radius: 1320.00) 1320.00) IIII - 2S- ?S.0 4 2S 0? S'OS 28-o2 0 — -- - - - -- -- -- -04PS I � I t�N i I 2000 -- t ___ _ -- --- t--- I f CD 4000 ------------ --- -- ----- 2S-12Pi - - -_ ---.. --.._.................-................-............_.........._ ........_.........._.._. - -, _ -- -- - _. _....;_ _ - ----I i' � � S ark Too I h #1 I 25-12 i O ! z 6000 _ I -- -- 0 2S-03P i 2S-01 1 -8 p000 _ ._. ----.._/---__.-- __. -- ...... .... ...._..... ... --........ ...... ....... ..__.- ..... -- - -_. __-T_ , - --- -- - --- I S•06 j ! I f 2S_10 I 1 -10000 - C ---� -- I I. 25-03 _ 2Si o6WP10 lSa/moo I -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 L� ------------------ ----------------------- -------------- -------------- ------------ ' --``` .............. ------------- ----------------- - -------------- I I 2S-06wt)10 Surface Location I M CPAI Datum: INAD83 _Mj Region: F—fas7a f- Latitude/Longitude Decimal Degrees r UTM Zone:f— r South r- State Plane Zone: 14Units: V lus-ft (- Legal Description (NAD27 only) i -Starting Coordinates: X: J1621195.59 Y: 1592975439 2S-06wp10 Surface Casing 1�, CPAI Coordinate Conve Datum: NAp83 Region: alaska Latitude/Longitude Decimal Degrees r UTM Zone: f— South ('W State Plane Zone: 14 �.] Units: ju;'fi D,,: r Legal Description (NAD27 only) Starting Coordinates: ----------------- X: 1621394.68 Y: 5930385.49 ------ Datum: Region: 1;la—s_ka r Latitude/LongitudeiDegrees b� rlmi -, T. UTM UTM Zone: True I— South 3*7 Skate Plane Zone: 14 Units: lus-ft W1 r Legal Description (NAD27 only) Ending Coordinates: — X: 4817 62.2717 Y: I E936654.80121475 .... Transform Quit Help ................. . ... .......... ............. *'*"* ........... - To: Datum: NAD27 Region: a- i -a s—k a - r Latitude/Longitude 1Decimal _Degrees r UTM Zone: True r South % State Plane Zone: 14 Units: us fk r Legal Description (NAD27 only) Ending Coordinates: X: 481361374615991 g Y: f 6930_E_5._88476797 Quit Help ..... . ........... ..... ....................... ........... Transform ............... . ..................... _, 2S-06w 10 Intermediate Casing I CPAI Coordinate Cones From: _--_ _____. - To: Datum:NAD83 ,. Region: alaska Datum: NAD27 Region: alaska t om' LakitudefLon Latitude/Longitude 9 Decimal Degrees TLatitude/LongitudeDecimal � g De reel i UTM Zane:" South i C UTM Zone: True r South i I f+ Units: Plane Zone: q f Zone: Units: us ft t Legal Description (NAD27 only) i C Legal Description (NAD27 only) ,--Starting Coordinates:----— --- - X: 1621304 r- Ending Coordinates: X: 481270.667327537 4j `f: 5928647 5928897.43351369 ....................................................... Transform Quit Help 2S-06w 10 Production Horizon fj, CPAI Coordinate Conv From: - To: Datum: Region: Datum: NA627 Region: jalaska f" Latitude/Longitude Decimal Degrees � - Latitude/Longitude IDecimal Degrees c" UTM Zone: F_ r- South r UTM Zone: True I"- South 0- State Plane Zone: ! 4 Units: us-ft 0- State Plane Zone: 4 Units: us ft t` Legal Description (NAD27 only) ir. Legal Description (NAD27 only) 3 Starting Coordinates: - -- -- —------- Ending Coordinates: -- —_ X: 1621318.84 I X' 481285.508498438 ii Y: 1592876T76 I Y: I 5928955.19206039 .............. Transform Quit Help 2S-06wp10 TD CPAI Coordinate Converter From: Datum: Region: alaska Latitude/Longitude 16eZZI Degrees U T M Zone: South State Plane Zone: Units: C Legal Description (NAD27 only) - To: Datum: Region: fa`j-a;k-a-----,j -- Latitude/Longitude 1Decimal Degrees f- UTM Zone: [True r South t -o State Plane Zone: 4 Units: us ft r Legal Description (NAD27 only) .Starting Coordinates:-------- Ending Coordinates: X: F97961, F-68" X: 1 4789�675 711�56 YE = 5919779.93— - Y: 1 59250738Bi1 191 .... Transform u Help ...... I 2S-06wD10 Surface Location I CPAI Coordinate Converter Datum: paDS3 Region: alaska i- Latitude/Longitude Decimal Degrees C UTM Zone: 1- South State Plane Zone: 4 Units: us ft i�' L�:r-tal D�scii.;tior-+ (P1 `.tj�` it;{iri IF Starting Coordinates: - ---- -- I X: 1621195.59 Y: 5929754.39 2S-06wp10 Surface Casi -To: — _ — - --- - -- Datum: NAp27 w Region: alaska �, r LatitudelLongitudeDecimal Degrees r UTM Zone: True r South State Plane Zone:4 T Units: us -ft t+ Legal Description (NAD27 only) �cyovcouiNnn I Township: 010 N , Range: 008 ; E I I Meridian: U Section] 1 FNL !FEE' FEL 1408.0059 ................................................ _....... , Transform Quit Help f M CPAI Coordinate Corr>erter `1- =1 I Ij k, E, ",J Datum:gD$3 Region: 'alaska i" Latitude/Lon itude 9 Decimal Degrees a r UTM Zone: ` South #� State Plane Zone: 4 T Units: us -ft ;, _�—,lel Description (IAD27 rjrtltE) Starting Coordinates: ------ ---- ------------- X: 11621T9416 Y: 1593036E49 To: Datum NA627 - Region: alaska r Latitude/Longitude, 16 e—,iZl Degrees • UTM Zone: True r South • State Plane Zone: 4 Units: us -ft r Legal Description (NAD27 only) Legal Description Township: 010 N .,. Range: f0 -o8 E -U - -' 17 - Meridian: Section:. :.FNL 7: .2411.5809 FEL T JU661726 -Transform Quit Help 2S -06w 10 Intermediate Casing �. CPA] Coo,Tdinata Converter From: -- — To:— - --; Datum: Region: 'alaska + 'NAD27 -_ -- -a � Datum: Region: alask+ f C Latitude/Longitude Decimal Degrees + Latitude/Longitude Decimal Degrees +i g {j If "UTM Zane: SouthUTM Zone: True r South i :+ State Plane Zone: 4 + Units: us fk + r Stake Plane Zone: 4 + Units: us Z- Legal Drse-i tion PIA1127 oniv! is Legal Description (NAD27 only) s, Starting Coordinates: - ---- —~ --- — - Legal Description ---- — X:- 1621304 --- - - Township: 010 N + Range: 00$ E 1 r Y: 592$647 Meridian: U Section: j7 e f_—_ FNL 4150.4272 FEL + 1300.1419 ... _ Transform Quit Help 2S-06wp10 Production Horizon �. CPA` Coo:Tdinate Conv From _----- — -- ------ To: — --- --- — Datum: NAD$3 +, alaska+Re ion: Datum FNA—D2 Region: alaska +' } Latitude/Longitude Decimal Degrees + 1 i Latitude/Longitude Decimal Degrees + f UTM Zone:,r South f' UTM Zone. True South rf State Plane Zane: d Units: us-fk r State Plane Zone: 4 Units: us fk + L egai Descri tion (INA - os-, y) t: Legal Description (NAD27 only) Starting Coordinates:--- -Legal Description ----- X: 162131$.$4 Township: 010 - MN,.' Range: ! 00$ E + Y: 592$704.76 j Meridian:U + Section 17 FNL + 4092.6272 IFE wl ji2E2Ej i Transform -� Quik Help 2S-06wp10 TD CPAit Coordinate Con c-rter rom: -- ----- Datum: NApg3 Region: alaska r Latitude/Longitude :Decimal Degrees C UTM Zone: j� South 0' State Plane Zone: 14 Units: ju,.ft w i— 'Legal i escription f?,IAD 7 Ott Lv) Starting Coordinates:— X: oordinates: X: 1619013.9$ Y: 5919779.93 i Datum: NAD27 ..... + Region: alaska r Latitude/Longitude IDecimal Degrees f— UTM Zone: True )— South i� State Plane Zone: 14 1 Units: us -ft W r% Legal Description (NAD27 only) Legal Description— — ---- — Township:010 FN --,-1 008 E �, Meridian: Section:29 FNL 2464.1741 13594.9134 ......... ransfor.......m........... .•.••••._..._ TQuit Hel p As -built REVI DATE IBYICKIAPPI DESCRIPTION I REV DATE 1BYI CK 1APPI DESCRIPTION 1 5/28/1 SZ I JAH I I Created Drawing Per K140173ACS 2 11/14/1 SZ MEH Add Well 13 per K150013ACS NOTES: 3 W w 18 ] 8 5 4 a ff6 n W �A — RS 14� , 1. BASIS OF LOCATION AND ELEVATION IS DS2S 19 23 21 22 23 19 20 ,` `u MONUMENTATION PER LOUNSBURY & ASSOC. — ti_ ► CPF2 39 22 2a 2: j 2s 2s 3o x9 / <a <] 2. COORDINATES SHOWN ARE ALASKA STATE PLANE,DOQy ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES — �' pg�y{ 05 2F ARE NAD 27. 31 Sf r 4 36 34 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, UMIAT MERIDIAN. 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS L15-28, L15-29, L15-32, L15-35, 11-13-2015 FIELD BOOK L15-75. 6. ALL DISTANCES SHOWN ARE TRUE. 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR 13. N i QGr_� 't- ti^ DS2fi TION pP`�N 4 3 2•r ! 1 K K 6 5 M1 3 P 3 ,a Sm 14I n s n ,s is zz .4 19 20 2f I I 23 � 24 f9 i0 2, 22 PROJECT LOCATION 31 32 3: Y .5 xy 31 32 I 33 34 VICINITY MAP NTS LEGEND O AS—BUILT CONDUCTOR LOCATION • EXISTING CONDUCTOR LOCATIONS GRAPHIC SCALE i 17 16 20 , 21 0 100 200 400 LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. 1 inch = 200 ft. S� YORS ENGINEERS PLANNERS AREA: 2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD ALE NO. LK62 9d24 5 28 15 DRAWING No. CEA-D2SX-6219D24 PART: 1 OF 2 REV: 2 REV L DATE I BY CK APP DESCRIPTION REV DATE BY CK AAP DESCRIPTION 1 5/28/15 SZ I JAH I lCreated Drawing Per K140173ACS 2 11/14/15 SZ I MEH I Add Well 13 Per IC150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, T. 10 N., R. 8 E., UMIAT MERIDIAN Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. O.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 1200 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70-13' 11.873" 150° 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70-13- 11.806" 150' 09' 06.242" 2243' 1378' 111.8' 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150° 09' 08.804" 2224' 1467' 111.1' 120.0' 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 1200 10 5,929,979.72 481,044.13 70' 13' 11.496" 150° 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' IIS 11.436" 150° 09' 11.362" 2205' 1555 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,948.70 480,898.09 70' 13' 11.187" 150' 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 12186'116431 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 12192'1161,v 110.6' 120.0' CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. AV CD,pp SURVEYOR'S CERTIFICATE y g . •':. 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND • •••••• ••• ••••• : •� LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY .. . ........... ......................... . . �` ' tai DONE BY ME F. CORNEL� OR UNDER MY DIRECT SUPERVISION AND %JEREMIAH THAT ALL DIMENSIONS AND OTHER DETAILS ♦® LS -12663 ARE CORRECT ,: AS OF NOVEMBER 13, 2015. URYASSOINC. *��LOUNSB EYORS F1CtNEERS RUNNERS AREA: 2S MODULE: XXXX UNIT: D2 e® Cn4t®Pholl'ps DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CARD FILE NO. LK6219d24 5/28/15 DRAWING NO. CEA-D2SX-6219D24 PART: 2 of 2 REV: 1 2 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Monday, July 25, 2016 8:59 AM To: 'Alexa, Kurt J' Cc: Bettis, Patricia K (DOA) Subject: RE: 2S-06 Revised(PTD 216-085) Add Fracture Stimulation Kurt, I will add the fracture stimulation to the revised PTD. Thanx, Victoria From: Alexa, Kurt J[mailto:Kurt.J.Alexa@conocophillips.com] Sent: Monday, July 25, 2016 8:45 AM To: Loepp, Victoria T (DOA) Subject: 2S-06 Re -Submittal Victoria, I had a couple questions regarding how the 2S-06 re -submittal works. The initial 2S-06 permit approval and the re- submittal probably crossed paths in the mail room. The team decided to extend the lateral of 2S-06 by 500ft requiring a new directional plan which resulted in the re -submittal of the permit to drill for 2S-06. Will the API number and permit number for the well change because of the re -submittal or will it be the same as what was on the originally approved 2S- 06 permit to drill?(No change in API # or PTD #) In the event that we are ready to begin drilling prior to approval of the re -submittal, do we still have permission to drill to the originally permitted depth or does the re -submittal cancel the existing approved permit?(Need approved resubmitted PTD to drill) Also, I was told this morning that we need to include in the permit application that this well (2S-06) will be frac'd. Apologies for not having it in the submittal. Do I need to re -submit again or will this email be sufficient? (Th is email will suffice) If you have any questions, please don't hesitate to give me a call or shoot me an email. Thanks, Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) TRANSMITTAL LETTER CHECKLIST WELL NAME: XR LA., PTD: Z 6 —Og s Development _ Service _ Exploratory Stratigraphic Test Non -Conventional FIELD: POOL: 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' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of 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, t/ 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 2S-06 Program DEV Well bore seg ❑ PTD#:2160850 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / 1-01_L GeoArea 890 _ Unit 11160 On/Off Shore On Annular Disposal n Administration 17 Nonconven. gas conforms to AS31,05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 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 7/21/2016 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile 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 Yes Engineering 19 Surface casing protects all known USDWs Yes 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie-in long string to surf csg No 22 CMT will cover all known productive horizons No 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes 25 if a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 7/22/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of 1-12S gas probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA PKB 7/21/2016 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only) NA ADL0025603, Surf Loc & Top Prod Interv; ADL0025608, TD. KRU 2S-06 KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432D.. CO 432D contains no spacing restrictions with respect to drilling unit boundaries. CO 432D has no interwell spacing restrictions. Wellbore will be more than 500' from an external property line where ownership or landownership changes. 80' conductor provided 2779' MD 128% excess Productive interval will be completed with uncemented slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Diverter meets regulations Max formation pressure is 3650 psig(11.0 ppg EMW); will drill w/ 9.3-11.5 ppg EMW MPSP is 3013 psig; will test BOPS to 3500 psig 1-12S measures required H2S measures required. Max potential reservoir pressure is 11.0 ppg EMW; will be drilled using 9.3 to 11.5 ppg mud. Onshore development well to be drilled. Geologic Engineering Public Revised application to deepen well to 16,847'8,change intermediate TOC VTL 7/22/16 Date: Date Date Commissioner: Commissioner: Commissio r 1 DTS CPF �� ` THE STATE ®fl LASKA GOVERNOR BILL WALKER G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commissi®n 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 2S-06 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-085 Surface Location: 2236' FSL, 1408' FEL, SEC. 17, TI ON, R8E, UM Bottomhole Location: 1979.73' FNL, 3469.64' FEL, SEC. 29, T10N, R8E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this Gv day of July, 2016. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 7 2016 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp 1 c. Specify if well is proposed for: Drill Lateral ❑ Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone e Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q • Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2S-06 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16,348, TVD: • 6,409 Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 2236' FSL, 1408' FEL, Sec 17, T1 ON, R8E, UM ADL025603, ADL025608 Kuparuk River Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4092.62' FNL, 1285.27' FEL, Sec17, T10N, R8E, UM 2677, 2681 8/13/2016 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1979.73' FNL, 3469.64' FEL, Sec29, T10N, R8E, UM 5035. 1,299.99' from ADL025604 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 159 15. Distance to Nearest Well Open Surface: x- 481,162.27' y- 5,930,004.80' Zone -4 • GL Elevation above MSL (ft): 120 to Same Pool: 1,105.82'f/2S-10 16. Deviated wells: Kickoff depth: 425 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.95 degrees Downhole: 3650 , Surface: 3013 . 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 80 39' 39' 120' 120' pre -driven, cement to surface 13.5" 10.75" 45.5# L-80 Hydril 563 2839' 39' 39' 2779' 2661' 1020sx 11ppg lead/300sx 15.8ppg tail 9.875" 7.625" 29.7# L-80 Hydril 563 8245' 39' 39' 7688' 6375' 690 sx 1st stg, 210 sx 2nd stg classG 6.75" 4.5" 12.6# L-80 TXP 8407' 7518' 6352' 16348' 6409' 1N/A- liner 3.5" 1 9.3# 1 L-80 Hydril 563 8061' 39' 39' 7518' 6352' 1 N/A - tubing 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): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Kurt Alexa @ 907-263-4933 Email KUrt.J.Alexa CO ..com Printed Name G.L. Alvord Title Alaska Drilling Manager �. �1-t (2�(G Signature - Phone 265-6120 Date Commission Use Only Permit to Drill _ API Number: Permit Approval See cover letter for other Number: - S 50- 03 - Q - - v0 Date: O requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed urethan gas hydrates, O or gas contained in shales: Pr Other: 13Qp res tp 35 a 5/1G/ f0 tCi t5 Z UDn ! les req'd: Yes No[o Mud log req'd: YeN4Y V � /'Ahf, vl A /- p�'G t/ en 2 easures: Yes No❑ Directional svy req'd: Yes Nc.�❑.�//// Spacing exception req'd: Yes ❑ No ff Inclination -only svy req'd: Ye� N Post initial injection MIT req'd: Yes -]N APPROVED BY 7.V Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and 0 RIG (fid AOL's Thpermit va1i888 for 24 months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 263-4933 Email: Kurt.J.Alexa(aD-conocophillips.com June 27, 2016 Application for Permit to Drill, Well 2S-06 Saved: 27 -Jun -16 Con o+coPhi IIi ps 333 West 71 Avenue, Suite 100 JUN 2 7 2010 Anchorage, Alaska 99501 Re: Application for Permit to Drill Well 25-06, A Kuparuk A4 Sand Producer OGCC Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots producer well from the 2S pad. The expected spud date for this well is August 101', 2016. It is planned to use rig Doyon 142. ✓ 2S-06 is planned to be a horizontal well in the Kuparuk A4 sand. The surface section will be drilled with 13-1/2" bit and run 10-3/4" casing to +/-2,779' MD / 2,661' TVD. The intermediate section will be drilled with 9-7/8" x 11" bit/Under Reamer and run 7-5/8" casing to 7,688'MD / 6,375'TVD. The production hole will be drilled with 6-3/4" and run 4-1/2" slotted liner to +/- 16,348'MD / 6,409'TVD. The upper completion will be run with 3-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kurt Alexa at 263-4933 (Kurt.J.Alexa eonocophillips.com) or Chip Alvord at 265-6120. Sincerely, Kurt Alexa Drilling Engineer F71-1 Application for Permit to Dill Document Drilling el &Wells Kuparuk Well 2S-06 Con coPhillios Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 25-06 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat ident fi,tng the property and the property's owners and showing (A)the coordinates of the proposed location of the ivell at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the ivell at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3043.23' FNL, 1408.01' FEL, Sec 17, TION, ROME, UM NGS Coordinates Northings: 5,930,004.80' Eastings: 481,162.27' IRKB Elevation 159AMSL Pad Elevation I 120' AMSL Location at surface Casing 2411.58' FNL, 1208.57 FEL, Sec 17, TION, ROME, UM NGS Coordinates Northings: 5,930,635.88'Eastings: 481,361.37' Measured Depth, RKB: 2,779' Total Vertical Depth, RKB: 2,661' Total Vertical Depth, SS: 2,502' Location at intremediate Casing 4150.43' FNL, 1300.14 FEL, Sec 17, TION, ROME, UM NGS Coordinates Northings: 5,928,897.43' Eastings: 481,270.67' Measured Depth, RKB: 7,688' Total Vertical Depth, RKB: 6,375' Total Vertical Depth, SS: 6,216' Location at Top of Productive Interval Ku aruk C4 Sand 4092.63' FNL, 1285.27' FEL, Sec 17, TION, R008E, UM NGS Coordinates Northings: 5,928,955.19' Eastings: 481,285.51' Measured Depth, RKB: 7,628' Total Vertical Depth, RKB: 6,369' Total Vertical Depth, SS: 6,210' Location at Total Depth 1979.73' FNL, 3469.64' FEL, Sec 29, T10N, ROME, UM NGS Coordinates Northings: 5,920,514.64' Eastings: 479,105.49' Measured Depth, RKB: 16,348' Total Vertical Depth, RKB: 6,409' Total Vertical Depth, SS: 6,250' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) 1/a a r// is to be intentionally, deviated, the application for a Permit to Drill (Form 10-401) must (l) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore. including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed ivellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records. and show that each named operator has been faurnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035. 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)f4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may: be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 2S-06 is calculated using an estimated maximum reservoir pressure of 3,650 psi (11.0 ppg (6369' RKB TVD), based on eastern 2S development wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A4 sand at 6,369' TVD (WP09): A Sand Estimated. BHP = 3,650 psi A Sand estimated depth (WP08) = 6,369' TVD Gas Gradient = 0.10 psi/ft Hydrostatic of full gas column = 637 psi MPSP = BHP — gas column = 3,013 psi as per 20 AAC 25.005 (e)(4)(A) (6,369' TVD * 0.10 psi/ft) (3,670 psi — 637psi) (B) data on potential gas =ones; The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and =ones that have a propensity for differential sticking; See attached 2S-06 Drilling Hazards Summary Requirements of 20 AAC 25.005 fc)(5) An application for a Permit to Drill must he accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting forination integrity tests. as required tinder 20 AAC 25.0300: A procedure is on file with the commission for performing LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed Casing and Cement Program Casing and Cementing Program CsglTbg OD Hole iz Weight Grade Conn. Length Top MD/TVD Btm MD7TVD Cement Program (in) (in16 (Ib/ft) (80') X 0.5313 ft3/ft X 1.0 (0% excess) = 42.5 ft3 Rathole + 3bbls curt on top of plug (ft) (ft) (h) 24 62.5 H-40 Welded 78 Surf 120/120 Existing Hydril Cement to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,701 Surf 2,779 / 2,661 1,020 sx DeepCRETE Lead 11.0 ppg, 300 sx Class G Tail Slurry 15.8 ppg Stage 1: 690 sx Class G at 15.8 ppg w/ 9-7/8 Hydril TOC at 6,827 MD 7-5/8 X 29.7 L-80 563 7,653 Surf 71688 / 6,375 Stage 2: 205 sx Class G at 15.8 ppg w/ 11 TOC at 5,282 MD 41/2 6-3/4 12.6 L-80 TXP 8,809 7,534 / 6,353 16,348/ 6,409 Uncemented Liner with Frac Sleeves 10-3/4" Surface casing run to 2,878' MD / 2,581' TVD Cement from 2,779' MD to 2,279'(500' of tail) with 15.8 ppg Class G, and from 2,279' to surface with I 1 ppg DeepCrete. Assume 200% excess annular volume in permafrost and 50% excess below the permafrost (1440' MD), zero excess in 16" conductor. Lead slurry from 2,282' MD to surface with Arctic Lite Crete @ 11 ppg Conductor (120'— 39') X 0.5967 ft3/ft X 1.0 (0% excess) = 48.4 ft3 Permafrost to Conductor (1,435'— 120') X 0.3634 ft3/ft X 3.0 (200% excess) = 1,433.6 ft3 Top of Tail to Permafrost (2,279'— 1,435') X 0.3634 ft3/ft X 1.5 (50% excess) = 460.1 ft3 Total Volume = 48.4 + 1,433.6 + 460.1 = 1,942 ft3 => 1,016sx of 11 ppg DeepCrete @ 1.91 ft3 /sk Tail slurry from 2,782' MD to 2,282' MD with 15.8 ppg Class G Shoe to Top of Tail (2,779 — 2,279') X 0.3634 ft3/ft X 1.50 (50% excess) = 272.6 ft3 Shoe Joint (80') X 0.5313 ft3/ft X 1.0 (0% excess) = 42.5 ft3 Rathole + 3bbls curt on top of plug (10') X 0.6568 ft3/ft X 1.5 (50% excess) +16.8 ft3 = 26.7 ft3 Total Volume = 272.6 + 42.5 + 26.7= 316 ft3 => 298 sx of 15.8 ppg Class G @ 1.17 ft3/sk 7-5/8" Intermediate casing run to 7,688' MD / 6,375' TVD 1 st stage slurry designed to be at the top of Bermuda/base Cairn Formation at 6,045' MD / 5,684' TVD. Top of 2nd stage slurry is designed to be at 4,601' MD, which is 500' MD above the C-37 top at 5,101' MD / 4,735' TVD. Assume 40% excess annular volume. V Stage slurry from 7,688' MD to 6,045' MD with 15.8ppg Class G + additives Shoe to Top of Cement (7,688 — 6,045') X 0.3425 ft3/ft X 1.40 (40% excess) = 787.8 ft3 Shoe Joint (80') X 0.2483 ft3/ft X 1.0 (o% excess) = 19.9 ft3 Total Volume = 787.2 + 19.9 = 798.1 ft3 => 690 sx of 15.8 ppg Class G @ 1.17 ft3/sk LSND (WBM) 2"d Stage slurry from 5,782' MD to 5,282' MD with 15.8ppg Class G + additives Stage Collar to Top of Cement (5,101 — 4,601) X 0.3425 ft3/ft X 1.40 (40% excess) = 239.8 ft3 Total Volume = 239.8 ft3 => 205sx of 15.8 ppg Class G @ 1.17 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference attached diverter schematic for Doyon 142 on 2S pad slot 6. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An applicotion for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,• Mud Program Summary Surface 13-1/2" Hole 10-3/4" Casing Intermediate 9-7/8" x 11 " Hole 7-5/8" Casing Production 6-3/4" Hole 4-112" Liner Mud System Spud (WBM) LSND (WBM) FloPro (WBM Density 9.3-10 9.6-10.5 10.3-11.5 PV 30-50 10-20 10-20 YP 40-80 16-24 16-24 Funnel Viscosity 200-300 N/A N/A Initial Gel 30-50 10-12 5 - 8 10 minute Gel 30-50 10-18 5-12 API Filtrate NC < 6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 pH 9.0-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application fora Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to attachment for proposed well schematic 1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. 2. Spud and directionally drill 13.5" hole to casing point at +/- 2,779' MD / 2,661' TVD as per directional plan (wp9). Survey with MWD, Gamma, Resistivity, Gyro -While -Drilling. ✓ 3. Run and cement 10-3/4", 45.54, L80, Hyd-563 casing to surface. Displace cement with mud. Evacuate top 2 feet of cement from annulus for sealant job (post rig.) 4. In the event cement returns are not seen at surface, perform a top job. Notify AOGCC if this occurs. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's to 3500 psi (annular preventer to 2500 psi) high and 250 psi low. Notify AOGCC 24 hrs before test. 6. PU 9-7/8" PDC bit and directional drilling assembly, with MWD/LVD (Gamma, Resistivity). RIH and clean out to 100' above shoe. Test surface casing to 3500 psi for 30 minutes. 7. Drill out shoe track and 20' of new hole. Perform leak off test to a minimum of 12.5 ppg, maximum of 16 ppg EMW leak off, recording results. 8. Open 11" Under Reamer and directionally drill to the top of the HRZ 9. Install RCD bearing at this time for use of MPD if necessary. 10. Directionally drill to intermediate TD of 7,688' MD / 6,375' TVD, wellsite geologist will call intermediate TD. Circulate and rotate at maximum rates until shakers are clean, minimum of 3 bottoms up. 11. POOH on elevators. Closely monitor drag and address any problem areas by dropping below and circulating/rotating to clean up. 12. Lay down intermediate BHA and rack back 5" DP 13. Run 7-5/8", 29.7# L80, Hydril 563 casing from surface to TD at 7688' MD. 14. Pump two stage cement job as per Schlumberger proposal. Top of first stage to be 5928' MD (top of Bermuda formation), top of second stage to be 4,601' MD (500' above C37). 15. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel to freeze protect. 16. Lay down 5" DP. 17. PU 4" DP, 6-3/4" bit, RSS, and MWD/LWD assembly (Gamma, resistivity, Periscope, and neutron density) i 18. RIH and clean out cement to 100' above shoe. Test intermediate casing to 3500 psi for 30 minutes. 19. Drill out shoe track and 20' of new hole. Perform formation integrity test to minimum of 12.5 ppg, maximum of 14.5 ppg EMW leak off, recording results. 20. Swap mud over to 10.3 ppg F1oPro mud system. 21. Directionally drill 6-3/4" hole geosteering through the Kuparuk A4 sand to TD 16,348' MD as per directional plan (wp9). 22. Circulate hole clean and POOH. 23. Lay down production BHA. 24. PU and run 4-1/2", 12.6# liner. The top of liner will be placed at 7,518' MD, allowing for 150' of overlap in the 7-5/8" casing. 25. Set liner hanger. Slackoff and set liner top packer. 26. Monitor well for flow for 15 minutes 27. Displace to clear brine. PT liner to 3,000 psi at surface for 30 minutes, chart results. 28. Flow check well for 30 minutes and POOH 29. Run 3-1/2" upper completion. 30. Nipple down BOPE, nipple up tree and test. 31. Freeze protect well with diesel and install BPV. 32. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the folloiving items. except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori_ation under 20 AAC 15.080 for an annular disposal operation in the well.: Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Well Schematic Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary 2S-06 Grassroots Horizontal A -Sand Producer Proposed Wellbore Schematic(wp09) CAMERON 4-%" tree, top joint is 4-1/2" 12.6# IBTM 16" Conductor to - 120' S-%2" X'I" KtiMU ULM Surface Casing (-50' TVD below W Sak) 10-3/4" 45.5# L-80 Hydril 563 2,779' MD / 2,661' TVD (21- INC) Tubina: 3-1/2" 9.3 # L-80 EUE 8RD-MOD GLM w/ SOV s Conocophillips Last Edited: Alexa 6-22-16 13.5" Surface Hole West Sak Sand: T 1,908' MD/1,849' TVD B 2,653' MD/2,544' TVD 9-7/8" x 11" Intermediate Hole 2nd Stage TOC = 500' MD above C-37 Formation at 4,600' MD/4,411' TVD Weatherford Stage Collar: 5,100' MD - C-37,5,101MD14,894'TVD 1" Stage TOC: Top of Bermuda/Cairn formation) Growler (Iceberg): 5,264' MD 15,044' TVD --Baker 2.812" CMU Sliding Sleeve Cairn : 5,929' MD 15,599' TVD 3-%" x 7-5/8", Premier Packer Bermuda: 6,045' MD / 5,684' TVD .� 3-1/2" 2.75" D Nipple HRZ: 6,699' MD /6,083' TVD Kalubik: 6,899' MD 16,174' TVD SLB DHG 6" x 4-'/." Swell Packer Ku aruk C: 9 667' MD / 6 330' TVD Kuparuk A4: 7,628' MD 16,369' TVD -11.0 ppg se�----- shoe 7-5/8" x 4-1/2" Baker ZXP Packer/Flex Lock Liner Hanger v""d "P- TD:16,348' MD / 6,409' TVD Intermediate Casina Production Liner: 6-3/4" Production Hole 7-5/8" 29.7# L-80 Hyd563 Casing 4-1/2" 12.6# L-80 UP 7,688' MD / 6,375' TVD (85° INC) 16,348' MD / 6,409' TVD (85° INC) DDI 2S-06wpO9 [Salmon] 6.670 Plan Summary C-50 C-40 Top Cairn Top HRZ (K-2 mkr) Kuparuk C (Top C4) a 5to -3 Sand �\ � i , - 5 51 I \ Marker �Lower Kalubik (K-1 mkr) 0) Ba - _ - se permafrost(?)�1� a _ co CM Sak Alt - _ _ _ _ - . Upper Kalubik (base HRZ) n p o it I Top W al (W Sak D) C 0 I �Y 7-5/8" x 9-7/8" by 11 0 0 4000 8000 12000 16000 Measured Depth Depth Reference: Plan: 120+39 @ 159.00usft (Doyon142) Rig: Doyon142 b000 75/8" x 9-7/8" by 11 O m6 F4-1 /2" x 6-3/4' O O Q p 1 0 0 0 0 0 0 0 0 0 0 o W 0 0 o q o ........:.... SURVEY PROGRAM 610 - 790 -. 0 1500 3000 4500 6000 7500 9000 10500 12000 zs-o4 _ Horizontal Departure Depth From O m6 270 0 2500 5000 7500 10000 12500 15000 240 425 ` 610 ........:.... SURVEY PROGRAM 610 - 790 -. -----;-..; 790 - 970 9970 zs-o4 _ Depth From Depth To \...\ 2S-04PB1 ._ _.... 6 39.00 750.00 2S-06wp09 [Salmon] (Plan: 2S-06) GYD-GC-SS pad Elevation: 120.00 750.00 1750.00 2S-06wp09 [Salmon]Plan: 2S-06) 2S-07 750.00 2779.13 2S-06wp09 [Salmon] Plan: 2S-(MYVD+IFR-AK-CAZ-SC 5-08 I 2779.13 270 0 2500 5000 7500 10000 12500 15000 240 425 ` 610 ........:.... SURVEY PROGRAM 610 - 790 -. -----;-..; 790 - 970 9970 - 1150 Surface Location Depth From Depth To Survey/Plan Tool 6 39.00 750.00 2S-06wp09 [Salmon] (Plan: 2S-06) GYD-GC-SS pad Elevation: 120.00 750.00 1750.00 2S-06wp09 [Salmon]Plan: 2S-06) MWD 750.00 2779.13 2S-06wp09 [Salmon] Plan: 2S-(MYVD+IFR-AK-CAZ-SC 4150 '--4760 2779.13 4281.49 2S-06wp09 [Salmon] (Plan: 2S-06) MWD CASING DETAILS 2779.13 7688.26 2S-06wp09 [Salmon] (Plan: 2S-0®yVD+IFR-AK-CAZ-SC 6 6600 - 7820 7688.26 9183.74 2S-06wp09 [Salmon] (Plan: 2S-06) MWD TVD MD Name 7688.26 16347.60 2S-06wp09[Salmon] (Plan: 2S-0®yVD+IFR-AK-CAZ-SC 10260 - 1148( 2661.00 2779.13 10-3/4" x 13-1/2" - - 50 11480 - 1269( 7'- 2s-asa1 6375.00 7688.26 7-5/8" x 9-7/8" by 11" 180 13910 1513( 6409.00 16347.60 4 1/2" x 6-3/4" 15130 - 1634E T SECTION DETAILS Sec MD Inc Azi TVD +N/ -S -E/-W Dleg TFace VSect Target 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 425.00 0.00 0.00 425.00 0.00 0.00 0.00 0.00 0.00 3 600.06 2.63 0.00 600.00 4.01 0.00 1.50 0.00 -3.87 4 1380.92 22'150,00 1359.00 170.70 0.00 2.50 0.00 -164.89 5 1488.89 22.15 0.00 1459.00 211.41 0.00 0.00 0.00 -204.20 6 1847.71 21.32 29.27 1793.30 336.30 31.98 3.00 107.93 -333.12 7 3464.77 21.32 29.27 3299.73 849.09 319.34 0.00 0.00 -902.81 8 7688.26 85.00 194.33 6375.00 -1107.22 111.24 2.50 164.54 1040.70 2S -Salmon 1. Heel 050216 PB 9 7708.26 85.00 194.33 6376.74 -1126.53 106.31 0.00 0.00 1060.62 10 7950.97 89.85 194.33 6387.64 -1361.37 46.30 2.00 0.00 1303.00 11 16347.60 89.85 194.33 6409.00 -9496.54 -2032.61 0.00 0.00 9699.04 2S -Salmon 2. Toe 050216 PB Permit Pack C-80 4284.0 C-50 4644.0 yyC66-44q0 5044-U7 Growler -AA I; ik%q@a C-35 signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position and I approve the scan and Ilision avoidance plan as set out in the audit Pack. I approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Erik Stark 39425 0 425 ` 610 ........:.... 12 30 610 - 790 -. -----;-..; 790 - 970 9970 - 1150 1150 - 1340 60 1340 - 1520 6 1520 -- 1700 2s-03aBi 1700 - 2310 2310 2930 2s.o2 2930 - 3540 90 3540 - 4150 �s 4150 '--4760 4760 - 5370 5370 - 5990 5990 - 6600 6 6600 - 7820 120 7820 - 9040 ;, nm - ----- 9040 - 1026( 10260 - 1148( - - 50 11480 - 1269( 7'- 2s-asa1 12690 1391( 180 13910 1513( 15130 - 1634E T Magnetic Model: BGGM2016 Magnetic Model Date: 22 -Aug -16 Magnetic Declination: 17.87' To convert a Magnetic Direction to a True Direction, Atld 17.870 East 3�jc$ T-3 Sand Annotation KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' K-15 Marker Start 2.5°/100' DLS, 0° TF, for 780.86' Hold for 107.97' Start 3-/100' DLS, 107.93' TF, for 358.82' 1409.0 Hold for 1617.06' Start 2.5°/100' DLS, 164.54° TF, for 4223.49' Base permafrost (? Hold for 20' 1849.0 Start 2'/100' DLS, 0° TF, for 242.71' Hold for 8396.63' Top W Sak (W Sak TD: 16347.6' MD, 6409' TVD 2544.0 Base W Sak 2944.0 C-80 4284.0 C-50 4644.0 yyC66-44q0 5044-U7 Growler -AA I; ik%q@a C-35 signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position and I approve the scan and Ilision avoidance plan as set out in the audit Pack. I approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Erik Stark 11, June 21 201 2L-03 c w N 0 0 0 v c L-314PB1 2L-306PB1 1= 0 Z 2L-3 2 2N-322 2L-310 �- 2L-311 2L Easting (4000 usft/in) 0 L -30 L 2M-17 \- 2M -22\(2H-14 \—I 2H-10 2H-01 \\- 2H-( 2 9 2M-02 M_p 2 0 2M-1 2K-04 2K-03 -1 20 2K-0 2 -0 L1-01 t> pr�02 2 -Ti�K-5 10 wl 1MAK 15 _rwp10 2M-33 2M-32L1PB1 04 M-08 2M-09 -0 Kuparuk 2K Pad 2N 4L1 Ll 2S-14wp10.1 [W 21e� 34 2M -32L1 PB noon 2 gMLJ2Qi 2M-35 2M- 8AL2_wp04 -13 -1 21 - 2K. 71T11L1 2S-11 - L K-13AL2 2S-09wp07 [Tiger] 2M-08A_wp05 2S-04 2S-07 H 2S-05 - 2K-19 2K- Kuparuk 2S Pad K-21 1 2S-0 2 21 2S-13 fig: 2S - MATI13MO • E-11 2L-316wp06.`Zo 2 03PB1 2S-01 2L-31 (/ 2S-3 5wp02 22L -3202S -12w C�${ftII] 2L-3 2S-10����slYfh L2Q�09 2N-301 (wp03) 2S-03 2wp05 2S-06wp09 [Salm n] Prelim: Kuparuk Cairn Pad2 �2L-328 w Prelim: KuparuK (;airn Faa 2L-328 Easting (4000 usft/in) 21- 1 2 K 5P 2 -22 2K-24 c 0 2K-24AL2 01 0 _ y -22AL1-0 Ec K-22AL1 2K-24AL2_ 401 Cookiecutt�r wp05 wp01 L Sigxillw 05 Lantern wp04 Gulper wp04.1 2S-06wpO9 [Salmon] Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 2000- 10-3/4" x 13-1/2'L ------ p5000 0 00 7-5/8" x 9-7/8" by 112'- - -2000 2S -Salmon 1. Heel 050216 P 0 0 0 _74000- 0 z -6000 0 U) -8000 4 1/2" x 6-3/4"- _10000— 06wppg 2S -Salmon 2. Toe 050216 P !Sa/,�on1 -10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 West( -)/East(+) (2000 usft/in) 2S-06wpO9 [Salmon] Section View -1500 0 Base permafrost (?) ---.._.__. . k ( ) -0. Top'1N Sa W S k a D 1pfl� "Base W Sak c 1500 --- --- '--- - ., ---------------------------- Cn O, LO T , - , I C-50 -10-3/4" x 13-1/ Op C-40 - - Q a) r-) r3owler-AA 4x00 , > 4500---- - a)-" --- ���p�---- - ,- - -- - - - -- - r' --------------------- .._ - _.._ ..... _........_ _. _. - CD J 6000 Nt LO COc0 ._I .. 1. a m a m a u s a m ss m ss m m v m ss a m a m a a m a m a/ -- _ ...1 - a I i 1 � -- ss - - a ss a �' m a - a 7-5/8" x 9-7/8" by 11" 4 1/2" x 6-3/4" CO M 0 7500 3 0 0 -1500 0 1500 3000 4500 6000 7500 9000 1 L9 0 Vertical Section at 195.00° (1500 usft/in) Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-06 Plan: 2S-06 Plan: 2S-06wp09 [Salmon] 4=1 21 June, 2016 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp09 [Salmon] Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan: 2S-06 Well Position +N/ -S 0.00 usft Northing: usft Latitude: +E/ -W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan: 2S-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 2S-06wp09 [Salmon] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 195.00 Survey Tool Program Date 6/21/2016 Schlumberger Comments apply t Report To Local Co-ordinate Reference: Well Plan: 2S-06 TVD Reference: Plan: 120+39 @ 159.00usft (Doyonl42) MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan: 2S-06 Well Position +N/ -S 0.00 usft Northing: usft Latitude: +E/ -W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan: 2S-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 2S-06wp09 [Salmon] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 195.00 Survey Tool Program Date 6/21/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 750.00 2S-06wp09 [Salmon] (Plan: 25-06) GYD-GC-SS Gyrodata gyro single shots 750.00 1,750.00 2S-06wp09 [Salmon] (Plan: 2S-06) MWD MWD - Standard 750.00 2,779.13 2S-06wp09 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,779.13 4,281.49 2S-06wp09 [Salmon] (Plan: 2S-06) MWD MWD - Standard 2,779.13 7,688.26 2S-06wp09 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,688.26 9,183.74 2S-06wp09 [Salmon] (Plan: 2S-06) MWD MWD - Standard 7,688.26 16,347.60 2S-06wp09 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (I (°) (usft) (usft) (°/100usft) (°) (usft) 39.00 0.00 0.00 39.00 -120.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 -59.00 0.00 0.00 0.04 200.00 0.00 0.00 200.00 41.00 0.00 0.00 0.19 289.00 0.00 0.00 289.00 130.00 0.00 0.00 0.33 top T-3 Sand 300.00 0.00 0.00 300.00 141.00 0.00 0.00 0.33 6/21/2016 2:49:53PM Page 2 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyonl42) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon 142) Well: Plan: 25-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 374.00 0.00 0.00 374.00 215.00 0.00 0.00 048 K-15 Marker 400.00 0.00 0.00 400.00 241.00 0.00 0.00 0.48 425.00 0.00 0.00 425.00 266.00 0.00 0.00 0.51 KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' 500.00 1.12 0.00 500.00 341.00 1.50 0.00 0.62 600.00 2.62 0.00 599.94 440.94 1.50 0.00 0.77 600.06 2.63 0.00 600.00 441.00 1.50 0.00 0.77 Start 2.5"/100' DLS, 0° TF, for 780.86' 700.00 5.12 0.00 699.70 540.70 2.50 0.00 0.92 800.00 7.62 0.00 799.08 640.08 2.50 0.00 1.00 900.00 10.12 0.00 897.87 738.87 2.50 0.00 1.05 1,000.00 12.62 0.00 995.90 836.90 2.50 0.00 1.19 1,100.00 15.12 0.00 1,092.97 933.97 2.50 0.00 1.42 1,200.00 17.62 0.00 1,188.91 1,029.91 2.50 0.00 1.75 1,300.00 20.12 0.00 1,283.53 1,124.53 2.50 0.00 2.16 1,380.92 22.15 0.00 1,359.00 1,200.00 2.50 0.00 2.55 Hold for 107.97' 1,400.00 22.15 0.00 1,376.67 1,217.67 0.00 0.00 2.65 1,434.90 22.15 0.00 1,409.00 1,250.00 0.00 0.00 3.11 Base permafrost (?) 1,488.89 22.15 0.00 1,459.00 1,300.00 0.00 0.00 3.11 Start 3°/100' DLS, 107.93° TF, for 358.82' 1,500.00 22.05 0.85 1,469.30 1,310.30 3.00 107.93 3.16 1,600.00 21.35 8.74 1,562.23 1,403.23 3.00 107.14 3.49 1,700.00 21.03 17.00 1,655.49 1,496.49 3.00 99.80 3.80 1,800.00 21.13 25.35 1,748.82 1,589.82 3.00 92.10 1.91 1,847.71 21.32 29.27 1,793.30 1,634.30 3.00 84.31 1.96 Hold for 1617.06' 1,900.00 21.32 29.27 1,842.01 1,683.01 0.00 0.00 2.04 1,907.51 21.32 29.27 1,849.00 1,690.00 0.00 0.00 2.22 Top W Salk (W Salk D) 2,000.00 21.32 29.27 1,935.17 1,776.17 0.00 0.00 2.22 2,100.00 21.32 29.27 2,028.33 1,869.33 0.00 0.00 2.41 2,200.00 21.32 29.27 2,121.49 1,962.49 0.00 0.00 2.60 2,300.00 21.32 29.27 2,214.64 2,055.64 0.00 0.00 2.80 2,400.00 21.32 29.27 2,307.80 2,148.80 0.00 0.00 3.00 2,500.00 21.32 29.27 2,400.96 2,241.96 0.00 0.00 3.20 2,600.00 21.32 29.27 2,494.12 2,335.12 0.00 0.00 3.40 2,653.54 21.32 29.27 2,544.00 2,385.00 0.00 0.00 3.61 Base W Salk 2,700.00 21.32 29.27 2,587.28 2,428.28 0.00 0.00 3.61 2,779.13 21.32 29.27 2,661.00 2,502.00 0.00 0.00 3.84 10-3/4" x 13-1/2" 2,800.00 21.32 29.27 2,680.44 2,521.44 0.00 0.00 3.84 6/21/2016 2:49:53PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 2,900.00 21.32 29.27 2,773.60 2,614.60 0.00 0.00 4.13 3,000.00 21.32 29.27 2,866.76 2,707.76 0.00 0.00 4.47 3,082.91 21.32 29.27 2,944.00 2,785.00 0.00 0.00 4.84 C-80 3,100.00 21.32 29.27 2,959.92 2,800.92 0.00 0.00 4.84 3,200.00 21.32 29.27 3,053.08 2,894.08 0.00 0.00 5.24 3,300.00 21.32 29.27 3,146.23 2,987.23 0.00 0.00 5.67 3,400.00 21.32 29.27 3,239.39 3,080.39 0.00 0.00 6.11 3,464.77 21.32 29.27 3,299.73 3,140.73 0.00 0.00 6.40 Start 2.6°1100- DLS, 164.64° TF, for 4223.49' 3,500.00 20.47 29.94 3,332.65 3,173.65 2.50 164.54 6.53 3,600.00 18.08 32.17 3,427.04 3,268.04 2.50 163.92 6.78 3,700.00 15.72 35.05 3,522.71 3,363.71 2.50 161.81 7.01 3,800.00 13.42 38.90 3,619.49 3,460.49 2.50 159.05 7.17 3,900.00 11.19 44.29 3,717.19 3,558.19 2.50 155.32 7.23 4,000.00 9.11 52.19 3,815.63 3,656.63 2.50 150.06 7.10 4,100.00 7.29 64.32 3,914.61 3,755.61 2.50 142.28 6.57 4,200.00 5.99 82.92 4,013.94 3,854.94 2.50 130.27 5.30 4,300.00 5.57 107.61 4,113.45 3,954.45 2.50 111.79 3.05 4,400.00 6.21 131.36 4,212.94 4,053.94 2.50 87.23 3.31 4,471.55 7.18 144.28 4,284.00 4,125.00 2.50 63.60 3.86 C-60 4,500.00 7.65 148.42 4,312.22 4,153.22 2.50 50.77 3.86 4,600.00 9.54 159.45 4,411.09 4,252.09 2.50 46.66 4.25 4,700.00 11.66 166.69 4,509.38 4,350.38 2.50 35.75 4.50 4,800.00 13.91 171.68 4,606.90 4,447.90 2.50 28.63 4.66 4,838.29 14.79 173.19 4,644.00 4,485.00 2.50 23.77 4.77 C-40 4,900.00 16.23 175.29 4,703.46 4,544.46 2.50 22.30 4.77 5,000.00 18.59 178.00 4,798.87 4,639.87 2.50 20.28 4.86 5,100.00 20.99 180.13 4,892.96 4,733.96 2.50 17.69 4.93 5,101.11 21.01 180.15 4,894.00 4,735.00 2.50 15.69 5.00 C-37 5,200.00 23.40 181.83 4,985.55 4,826.55 2.50 15.67 5.00 5,264.08 24.96 182.75 5,044.00 4,885.00 2.50 14.12 5.07 Growler -AA 5,300.00 25.83 183.23 5,076.45 4,917.45 2.50 13.27 5.07 5,400.00 28.28 184.40 5,165.50 5,006.50 2.50 12.84 5.15 5,500.00 30.73 185.40 5,252.53 5,093.53 2.50 11.80 5.25 5,600.00 33.19 186.26 5,337.36 5,178.36 2.50 10.93 5.35 5,700.00 35.65 187.02 5,419.85 5,260.85 2.50 10.19 5.48 5,800.00 38.12 187.70 5,499.83 5,340.83 2.50 9.57 5.63 5,900.00 40.59 188.30 5,577.15 5,418.15 2.50 9.03 5.80 5,928.92 41.30 188.46 5,599.00 5,440.00 2.50 8.56 5.99 Top Cairn 6121/2016 2:49:53PM Page 4 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.O0usft (Doyonl42) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 25-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (1) V) (usft) (usft) (°1100usft) (1) (usft) 6,000.00 43.06 188.84 5,651.67 5,492.67 2.50 8.44 5.99 6,044.66 44.17 189.07 5,684.00 5,525.00 2.50 8.16 6.21 Top Bermuda 6,100.00 45.54 189.34 5,723.24 5,564.24 2.50 7.99 6.21 6,137.09 46.45 189.52 5,749.00 5,590.00 2.50 7.80 6.45 Base Bermuda 6,188.50 47.73 189.75 5,784.00 5,625.00 2.50 7.68 6.45 C-35 6,200.00 48.01 189.80 5,791.72 5,632.72 2.50 7.52 6.45 6,300.00 50.49 190.22 5,856.98 5,697.98 2.50 7.49 6.73 6,400.00 52.97 190.61 5,918.91 5,759.91 2.50 7.21 7.02 6,500.00 55.46 190.98 5,977.38 5,818.38 2.50 6.97 7.34 6,600.00 57.94 191.33 6,032.28 5,873.28 2.50 6.75 7.69 6,698.97 60.40 191.65 6,083.00 5,924.00 2.50 6.56 8.05 Top HRZ (K-2 mkr) 6,700.00 60.42 191.66 6,083.51 5,924.51 2.50 6.40 8.05 6,800.00 62.91 191.97 6,130.97 5,971.97 2.50 6.40 8.44 6,898.65 65.36 192.26 6,174.00 6,015.00 2.50 6.25 8.84 Upper Kalubik (base HRZ) 6,900.00 65.39 192.27 6,174.56 6,015.56 2.50 6.12 8.84 7,000.00 67.88 192.56 6,214.22 6,055.22 2.50 6.12 9.27 7,100.00 70.37 192.83 6,249.85 6,090.85 2.50 6.00 9.71 7,143.26 71.44 192.95 6,264.00 6,105.00 2.50 5.90 10.16 Lower Kalubik (K-1 mkr) 7,200.00 72.85 193.10 6,281.39 6,122.39 2.50 5.86 10.16 7,300.00 75.34 193.36 6,308.79 6,149.79 2.50 5.82 10.63 7,400.00 77.83 193.62 6,331.99 6,172.99 2.50 5.75 11.10 7,460.66 79.34 193.77 6,344.00 6,185.00 2.50 5.69 11.59 Kuparuk C (Top C4) 7,500.00 80.32 193.87 6,350.95 6,191.95 2.50 5.66 11.59 7,551.20 81.59 194.00 6,359.00 6,200.00 2.50 5.64 12.09 A5 7,600.00 82.80 194.12 6,365.62 6,206.62 2.50 5.62 12.09 7,628.32 83.51 194.19 6,369.00 6,210.00 2.50 5.60 12.46 A4 7,688.26 85.00 194.33 6,375.00 6,216.00 2.50 5.59 12.46 Hold for 20'- 7-5/8" x 9-7/8" by 11" 7,700.00 85.00 194.33 6,376.02 6,217.02 0.00 5.58 12.51 7,708.26 85.00 194.33 6,376.74 6,217.74 0.00 0.00 12.54 Start 2°/100' DLS, 0" TF, for 242.71' 7,800.00 86.83 194.33 6,383.27 6,224.27 2.00 0.00 12.99 7,900.00 88.83 194.33 6,387.05 6,228.05 2.00 0.00 13.61 7,950.97 89.85 194.33 6,387.64 6,228.64 2.00 0.00 13.98 Hold for 8396.63' 8,000.00 89.85 194.33 6,387.76 6,228.76 0.00 0.00 14.36 8,100.00 89.85 194.33 6,388.01 6,229.01 0.00 0.00 15.21 6/21/2016 2:49:53PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 25-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyonl42) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (') (°) (usft) (usft) (°/100usft) (°) (usft) 8,200.00 89.85 194.33 6,388.27 6,229.27 0.00 0.00 16.16 8,300.00 89.85 194.33 6,388.52 6,229.52 0.00 0.00 17.17 8,400.00 89.85 194.33 6,388.78 6,229.78 0.00 0.00 18.25 8,500.00 89.85 194.33 6,389.03 6,230.03 0.00 0.00 19.38 8,600.00 89.85 194.33 6,389.29 6,230.29 0.00 0.00 20.55 8,700.00 89.85 194.33 6,389.54 6,230.54 0.00 0.00 21.76 8,800.00 89.85 194.33 6,389.80 6,230.80 0.00 0.00 23.00 8,900.00 89.85 194.33 6,390.05 6,231.05 0.00 0.00 24.26 9,000.00 89.85 194.33 6,390.30 6,231.30 0.00 0.00 25.55 9,100.00 89.85 194.33 6,390.56 6,231.56 0.00 0.00 26.85 9,200.00 89.85 194.33 6,390.81 6,231.81 0.00 0.00 16.37 9,300.00 89.85 194.33 6,391.07 6,232.07 0.00 0.00 16.76 9,400.00 89.85 194.33 6,391.32 6,232.32 0.00 0.00 17.17 9,500.00 89.85 194.33 6,391.58 6,232.58 0.00 0.00 17.58 9,600.00 89.85 194.33 6,391.83 6,232.83 0.00 0.00 18.00 9,700.00 89.85 194.33 6,392.09 6,233.09 0.00 0.00 18.43 9,800.00 89.85 194.33 6,392.34 6,233.34 0.00 0.00 18.87 9,900.00 89.85 194.33 6,392.59 6,233.59 0.00 0.00 19.32 10,000.00 89.85 194.33 6,392.85 6,233.85 0.00 0.00 19.77 10,100.00 89.85 194.33 6,393.10 6,234.10 0.00 0.00 20.23 10,200.00 89.85 194.33 6,393.36 6,234.36 0.00 0.00 20.69 10,300.00 89.85 194.33 6,393.61 6,234.61 0.00 0.00 21.16 10,400.00 89.85 194.33 6,393.87 6,234.87 0.00 0.00 21.64 10,500.00 89.85 194.33 6,394.12 6,235.12 0.00 0.00 22.12 10,600.00 89.85 194.33 6,394.38 6,235.38 0.00 0.00 22.60 10,700.00 89.85 194.33 6,394.63 6,235.63 0.00 0.00 23.09 10,800.00 89.85 194.33 6,394.88 6,235.88 0.00 0.00 23.59 10,900.00 89.85 194.33 6,395.14 6,236.14 0.00 0.00 24.08 11,000.00 89.85 194.33 6,395.39 6,236.39 0.00 0.00 24.58 11,100.00 89.85 194.33 6,395.65 6,236.65 0.00 0.00 25.09 11,200.00 89.85 194.33 6,395.90 6,236.90 0.00 0.00 25.59 11,300.00 89.85 194.33 6,396.16 6,237.16 0.00 0.00 26.10 11,400.00 89.85 194.33 6,396.41 6,237.41 0.00 0.00 26.62 11,500.00 89.85 194.33 6,396.67 6,237.67 0.00 0.00 27.13 11,600.00 89.85 194.33 6,396.92 6,237.92 0.00 0.00 27.65 11,700.00 89.85 194.33 6,397.17 6,238.17 0.00 0.00 28.17 11,800.00 89.85 194.33 6,397.43 6,238.43 0.00 0.00 28.69 11,900.00 89.85 194.33 6,397.68 6,238.68 0.00 0.00 29.22 12,000.00 89.85 194.33 6,397.94 6,238.94 0.00 0.00 29.74 12,100.00 89.85 194.33 6,398.19 6,239.19 0.00 0.00 30.27 12,200.00 89.85 194.33 6,398.45 6,239.45 0.00 0.00 30.80 12,300.00 89.85 194.33 6,398.70 6,239.70 0.00 0.00 31.33 12,400.00 89.85 194.33 6,398.96 6,239.96 0.00 0.00 31.86 12,500.00 89.85 194.33 6,399.21 6,240.21 0.00 0.00 32.40 6/21/2016 2:49:53PM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 [Salmon] Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) 12,600.00 89.85 194.33 6,399.46 6,240.46 0.00 0.00 32.93 12,700.00 89.85 194.33 6,399.72 6,240.72 0,00 0.00 33.47 12,800.00 89.85 194.33 6,399.97 6,240.97 0.00 0.00 34.01 12,900.00 89.85 194.33 6,400.23 6,241.23 0.00 0.00 34.55 13,000.00 89.85 194.33 6,400.48 6,241.48 0.00 0.00 35.09 13,100.00 89.85 194.33 6,400.74 6,241.74 0.00 0.00 35.63 13,200.00 89.85 194.33 6,400.99 6,241.99 0.00 0.00 36.18 13,300.00 89.85 194.33 6,401.25 6,242.25 0.00 0.00 36.72 13,400.00 89.85 194.33 6,401.50 6,242.50 0.00 0.00 37.27 13,500.00 89.85 194.33 6,401.75 6,242.75 0.00 0.00 37.81 13,600.00 89.85 194.33 6,402.01 6,243.01 0.00 0.00 38.36 13,700.00 89.85 194.33 6,402.26 6,243.26 0.00 0.00 38.91 13,800.00 89.85 194.33 6,402.52 6,243.52 0.00 0.00 39.46 13,900.00 89.85 194.33 6,402.77 6,243.77 0.00 0.00 40.01 14,000.00 89.85 194.33 6,403.03 6,244.03 0.00 0.00 40.56 14,100.00 89.85 194.33 6,403.28 6,244.28 0.00 0.00 41.11 14,200.00 89.85 194.33 6,403.54 6,244.54 0.00 0.00 41.66 14,300.00 89.85 194.33 6,403.79 6,244.79 0.00 0.00 42.22 14,400.00 89.85 194.33 6,404.04 6,245.04 0.00 0.00 42.77 14,500.00 89.85 194.33 6,404.30 6,245.30 0.00 0.00 43.32 14,600.00 89.85 194.33 6,404.55 6,245.55 0.00 0.00 43.88 14,700.00 89.85 194.33 6,404.81 6,245.81 0.00 0.00 44.43 14,800.00 89.85 194.33 6,405.06 6,246.06 0.00 0.00 44.99 14,900.00 89.85 194.33 6,405.32 6,246.32 0.00 0.00 45.54 15,000.00 89.85 194.33 6,405.57 6,246.57 0.00 0.00 46.10 15,100.00 89.85 194.33 6,405.83 6,246.83 0.00 0.00 46.66 15,200.00 89.85 194.33 6,406.08 6,247.08 0.00 0.00 47.22 15,300.00 89.85 194.33 6,406.33 6,247.33 0.00 0.00 47.78 15,400.00 89.85 194.33 6,406.59 6,247.59 0.00 0.00 48.33 15,500.00 89.85 194.33 6,406.84 6,247.84 0.00 0.00 48.89 15,600.00 89.85 194.33 6,407.10 6,248.10 0.00 0.00 49.45 15,700.00 89.85 194.33 6,407.35 6,248.35 0.00 0.00 50.01 15,800.00 89.85 194.33 6,407.61 6,248.61 0.00 0.00 50.57 15,900.00 89.85 194.33 6,407.86 6,248.86 0.00 0.00 51.13 16,000.00 89.85 194.33 6,408.12 6,249.12 0.00 0.00 51.69 16,100.00 89.85 194.33 6,408.37 6,249.37 0.00 0.00 52.26 16,200.00 89.85 194.33 6,408.62 6,249.62 0.00 0.00 52.82 16,300.00 89.85 194.33 6,408.88 6,249.88 0.00 0.00 53.38 16,347.60 89.85 194.33 6,409.00 6,250.00 0.00 0.00 53.65 TD: 16347.6' MD, 6409' TVD 6/21/2016 2:49:53PM Page 7 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp09 [Salmon] Casing Points Formations Plan Annotations Schlumberger Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Measured Vertical Depth Depth (usft) (usft) Name 7,688.26 6,375.00 7-5/8" x 9-7/8" by 11" 16,347.60 6,409.00 4 1/2" x 6-3/4" 2,779.13 2,661.00 10-3/4" x 13-1/2" Measured Vertical Depth Depth Depth (usft) (usft) (usft) Name 7,628.32 6,369.00 A4 6,898.65 6,174.00 Upper Kalubik (base HRZ) 1,907.51 1,849.00 Top W Sak (W Sak D) 6,044.66 5,684.00 Top Bermuda 6,698.97 6,083.00 Top HRZ (K-2 mkr) 2,653.54 2,544.00 Base W Sak 3,082.91 2,944.00 C-80 7,460.66 6,344.00 Kuparuk C (Top C4) 1,434.90 1,409.00 Base permafrost (?) 5,264.08 5,044.00 Growler -AA 289.00 289.00 top T-3 Sand 7,143.26 6,264.00 Lower Kalubik (K-1 mkr) 6,188.50 5,784.00 C-35 4,471.55 4,284.00 C-50 5,928.92 5,599.00 Top Cairn 6,137.09 5,749.00 Base Bermuda 374.00 374.00 K-15 Marker 7,551.20 6,359.00 A5 5,101.11 4,894.00 C-37 4,838.29 4,644.00 C-40 Measured Vertical Depth Depth (usft) (usft) 425.00 425.00 600.06 600.00 1,380.92 1,359.00 1,488.89 1,459.00 1,847.71 1,793.30 3,464.77 3,299.73 7,688.26 6,375.00 7,708.26 6,376.74 7,950.97 6,387.64 16,347.60 6,409.00 Lithology Well Plan: 2S-06 Plan: 120+39 @ 159.00usft (Doyon142) Plan: 120+39 @ 159.00usft (Doyon142) True Minimum Curvature OAKEDMP2 Casing Hole Diameter Diameter 7-5/8 11 4-1/2 6-3/4 10-3/4 13-1/2 Local Coordinates +N/ -S +E/ -W (usft) (usft) Comment 0.00 0.00 KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' 4.01 0.00 Start 2.5°/100' DLS, 0° TF, for 780.86' 170.70 0.00 Hold for 107.97' 211.41 0.00 Start 3°/100' DLS, 107.93° TF, for 358.82' 336.30 31.98 Hold for 1617.06' 849.09 319.34 Start 2.5°/100' DLS, 164.54° TF, for 4223.49' -1,107.22 111.24 Hold for 20' -1,126.53 106.31 Start 2°/100' DLS, 0° TF, for 242.71' -1,361.37 46.30 Hold for 8396.63' -9,496.54 -2,032.61 TD: 16347.6' MD, 6409' TVD Checked By: Approved By: Date: 6/21/2016 2 49:53PM Page 8 COMPASS 5000.1 Build 74 AC Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-06 Plan: 2S-06 50103xxxxx00 2S-06wp09 [Salmon] Clearance Summary Anticollision Report 21 June, 2016 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-06 - Plan: 2S-06 - 2S-06wp09 [Salmon] Well Coordinates: Datum Height: Plan: 120+39 @ 159.00usft (Doyon142) Scan Range: 0.00 to 16,347.60 usft. Measured Depth. Scan Radius is 1,830.86 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Conocoftillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-06 - 2S-06wpO9 [Salmon] Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2S Pad - Plan: 2S-06 - Plan: 2S-06 - 2S-06wp09 [Salmon] Scan Range: 0.00 to 16,347.60 usft. Measured Depth. Scan Radius is 1,830.86 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2S Pad 2S-01 - 2S-01 - 2S-01 2S-01 - 2S-01 - 2S-01 2S-02 - 2S-02 - 2S-02 2S-02 - 2S-02 - 2S-02 2S-03 - 2S-03 - 2S-03 2S-03 - 2S-03 - 2S-03 2S-03 - 2S-03PB1 - 2S-03PB1 2S-03 - 2S-03PB1 - 2S-03PB1 2S-04 - 2S-04 - 2S-04 2S-04 - 2S-04 - 2S-04 2S-04 - 2S-04PB1 - 2S-04PB1 2S-04 - 2S-04PB1 - 2S-04PB1 2S-05 - 2S-05 - 2S-05 2S-05 - 2S-05 - 2S-05 2S-07 - 2S-07 - 2S-07 25-07 - 2S-07 - 2S-07 2S-08 - 2S-08 - 2S-08 2S-08 - 2S-08 - 2S-08 25-10 - 2S-10 - 2S-10 2S-10 - 2S-10 - 2S-10 2S-11 - 2S-11 - 2S-11 2S-11 - 2S-11 - 2S-11 Plan: 2S-09 - Plan: 2S-09 - 2S-09wp07 [Tiger] Plan: 2S-09 - Plan: 2S-09 - 2S-09wp07 [Tiger] Plan: 2S-14 - Plan: 2S-14 - 2S-14wp10.1 [Whale] Plan: 2S-14 - Plan: 2S-14 - 2S-14wp10.1 [Whale] Plan: 25-315 - Plan: 2S-315 - 2S-315wp02 Plan: 2S-315 - Plan: 2S-315 - 2S-315wp02 349.36 147.26 349.36 141.05 350.00 23.715 Centre Distance Pass - Major Risk 399.35 147.54 399.35 140.50 400.00 20.957 Clearance Factor Pass - Major Risk 261.50 119.37 261.50 112.53 250.00 17.448 Centre Distance Pass - Major Risk 361.46 119.99 361.46 111.74 350.00 14.539 Clearance Factor Pass - Major Risk 324.31 87.82 324.31 82.06 325.00 15.237 Centre Distance Pass - Major Risk 424.19 88.60 424.19 81.11 425.00 11.827 Clearance Factor Pass - Major Risk 324.31 87.82 324.31 82.06 325.00 15.237 Centre Distance Pass - Major Risk 424.19 88.60 424.19 81.11 425.00 11.827 Clearance Factor Pass - Major Risk 761.11 52.71 761.11 40.28 750.00 4.239 Centre Distance Pass - Major Risk 785.68 52.83 785.68 40.06 775.00 4.137 Clearance Factor Pass - Major Risk 761.11 52.71 761.11 40.28 750.00 4.239 Centre Distance Pass - Major Risk 785.68 52.83 785.68 40.06 775.00 4.137 Clearance Factor Pass - Major Risk 561.46 26.77 561.46 17.32 550.00 2.833 Centre Distance Pass - Major Risk 611.26 27.05 611.26 16.80 600.00 2.639 Clearance Factor Pass - Major Risk 39.00 29.52 39.00 28.30 27.50 24.010 Centre Distance Pass - Major Risk 486.35 31.30 486.35 16.90 475.00 2.173 Clearance Factor Pass - Major Risk 286.49 58.66 286.49 53.60 275.00 11.598 Centre Distance Pass - Major Risk 361.46 59.26 361.46 52.95 350.00 9.389 Clearance Factor Pass - Major Risk 585.37 115.80 585.37 105.92 575.00 11.721 Centre Distance Pass - Major Risk 830.81 116.65 830.81 103.39 825.00 8.798 Clearance Factor Pass - Major Risk 399.29 148.68 399.29 141.69 400.00 21.254 Centre Distance Pass - Major Risk 473.65 149.45 473.65 141.19 475.00 18.084 Clearance Factor Pass - Major Risk 425.00 90.03 425.00 82.50 425.00 11.961 Centre Distance Pass - Major Risk 7,032.03 180.26 7,032.03 80.66 7,275.00 1.810 Clearance Factor Pass - Major Risk 300.00 240.12 300.00 234.77 300.00 44.944 Centre Distance Pass - Major Risk 399.99 240.81 399.99 233.88 400.00 34.732 Clearance Factor Pass - Major Risk 400.00 210.25 400.00 203.16 400.00 29.656 Centre Distance Pass - Major Risk 449.71 210.58 449.71 202.68 450.00 26.661 Clearance Factor Pass - Major Risk 21 June, 2016 - 14.'49 Page 2 of 6 COMPASS Anticollision Report for Plan: 2S-06 - 2S-06wpO9 [Salmon] Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) @Measured Clearance Reference Design: Kuparuk 2S Pad - Plan: 2S-06 - Plan: 2S-06 - 2S-06wp09 [Salmon] Separation Depth Scan Range: 0.00 to 16,347.60 usft. Measured Depth. Minimum Separation Warning (usft) Scan Radius is 1,830.86 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 1,750.00 Measured Minimum @Measured Site Name Depth Distance Depth Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) Plan: 2S -Basking - Plan: 2S -Basking - 2S -Basking wp0 411.50 198.60 411.50 Plan: 2S -Basking - Plan: 2S -Basking - 2S -Basking wp0 608.92 199.75 608.92 Plan: 2S -Frilled - Plan: 2S -Frilled - 2S -Frilled wp01 1,481.76 287.53 1,481.76 Plan: 2S -Frilled - Plan: 2S -Frilled - 2S -Frilled wp01 1,504.62 287.59 1,504.62 Rig: 2S-12 - Rig: 2S-12 - Rig: 2S-12 39.00 179.98 39.00 Rig: 2S-12 - Rig: 2S-12 - Rig: 2S-12 584.92 182.57 584.92 Rig: 2S-12 - Rig: 2S-12 - 2S-12wp10.1 [Bull] 411.50 179.98 411.50 Rig: 2S-12 - Rig: 2S-12 - 2S-12wp10.1 [Bull] 634.09 181.38 634.09 Non -Pad Clearance Factor Pass - Major Risk Shark Tooth #1 - Shark Tooth #1 - Shark Tooth #1 10,452.76 1,003.12 10,452.76 Survey tool program ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Ellipse @Measured Clearance Summary Based on (usft) Separation Depth Factor Minimum Separation Warning (usft) usft 750.00 1,750.00 2S-06wp09 [Salmon] 191.33 400.00 27.320 Centre Distance Pass - Major Risk 189.02 600.00 18.617 Clearance Factor Pass - Major Risk 261.51 1,525.00 11.051 Centre Distance Pass - Major Risk 261.23 1,550.00 10.909 Clearance Factor Pass - Major Risk 178.97 27.50 178.037 Centre Distance Pass - Major Risk 172.72 575.00 18.543 Clearance Factor Pass - Major Risk 172.82 400.00 25.122 Centre Distance Pass - Major Risk 170.39 625.00 16.503 Clearance Factor Pass - Major Risk 883.39 6,375.00 8.378 Clearance Factor Pass - Major Risk From To Survey/Plan Survey Tool (usft) (usft) 39.00 750.00 2S-06wp09 [Salmon] GYD-GC-SS 750.00 1,750.00 2S-06wp09 [Salmon] MWD 750.00 2,779.13 2S-06wp09 [Salmon] MWD+IFR-AK-CAZ-SC 2,779.13 4,281.49 2S-06wp09 [Salmon] MWD 2,779.13 7,688.26 2S-06wp09 [Salmon] MWD+IFR-AK-CAZ-SC 7,688.26 9,183.74 2S-06wp09 [Salmon] MWD 7,688.26 16,347.60 2S-06wp09 [Salmon] MWD+IFR-AK-CAZ-SC 21 June, 2016 - 14:49 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2S-06 - 2S-06wp09 [Salmon] Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 21 June, 2016 - 14:49 Page 4 of 6 COMPASS Ladder View 19:29, June 21 2016 C 2S-06wp09 [Salmon] The Reference is the Well along X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors n m 3 n m o a o 0 ,M�'� N 300 — - ---— ---- - C U 150 ---f V 1 I I I!} I C Eguivelant Magnetic Distance U I I 1 0 0 2500 5000 7500 10000 12500 15000 Displayed interval could be less than entire well:Measured Depth 39.00 To 16347.60 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 750.00 2S-06wp09 [Salmon] (Plan: 2S-06)GYD-GC-SS 2661.CU79.13 10-3/4" x 13-1/2" 750.00 1750.00 2S-06wp09 [Salmon] (Plan: 2S-06)MWD 6375.0x1688726/8" x 9-7/8" by 11" 750.00 2779.13 2S-06wp09 [Salmon] (Plan: 2S-06)MWD+IFR-AK-CAZ-SC 6409.847.60 4 1/2" x 6-3/4" 2779.13 4281.49 2S-06wp09 [Salmon] (Plan: 2S-06)MWD 2779.13 7688.26 2S-06wp09 [Salmon] (Plan: 2S-06)MWD+IFR-AK-CAZ-SC 7688.26 9183.74 2S-06wp09 [Salmon] (Plan: 2S-06)MWD 7688.2616347.60 2S-06wp09 [Salmon] (Plan: 2S-06)MWD+IFR-AK-CAZ-SC A G Q N N N y N 60—,t f I 1 � o , i I f Q 30— C) o a� I c U 0 I � 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth 0 4:32, June 21 201 W� S (NOT a Spidery Easting (3000 usft/in) Prelim: Kuparuk Cairn Pad2'-" Easting (3000 usft/in) 3 AC Flipbook Casing Details Survey Program TVD MD 2661.00 688.26 637500 7688.26 Name 0914°x1by11 7-5/8" x q-7/8" by n" Depth From 39.00 750.00 Depth To Survey/Plan 750.00 2S-o6wpo9 175079.13 2S-o6wpo9 [Salmon] [Salmon] (Plan: 2S -o6) (Plan: 2S -o6) Tool GYD-GC-SS MWD 2S-o6wpog [Salmon] 39 425 640900 16347.60 41/2" x 6-3/4" 750.00 2779.8 25-o6wpo9 [Salmon] (Plan: z5 -o6) MWD+IFR-AK-CAI-SC 39.00 TO 1100.00 2779.13 277913 7688.26 4281,49 2S-o6wpo9 688.26 25-06wp09[Salmon](Plan: 918374 2S-o6wpo9 [Salmon] [Salmon] (Plan: ZS -o6) 25-06) (Plan: zS-o6) MWD MWD+IFR-AK-CAZ-SC MWD -"""-""""""` 425 G 1 O V 7688.26 16347.60 2S-o6wpo9 [Salmon]( Plane zS-o6) MWD 610 790 M D Azi 0/36o 790 970 39.00 0.00 9 'ID 970 1150 425.00 0.00 -30 / 33 0 600.06 0.00 2S -03P61 1150 1340 1380.92 0.001 1340 1520 1488.89 0.006 0 2S-03 _. _ ______ 1520 1700 1847.71 29.27 6o/300 61p 1700 2310 3464.77 29.27 7688.26 194.3325-08 " 2310 2930 7708.26 194.33 3 0 �, 2930 3540 7950.97 194.33 _ 16347.60 194.33 3540 4150 4150 ------ 4760 -0 2 0 % - 904760 5370 5370 5990 30 5990 6600 6600 7820 -120/240 120 7820 9040 60 9040 10260 10260 11480 -150/210 `t- ------ 2S -04P61 11480 12690 9 0 25-04 12690 13910 25-0] -18o/18 25-05 13910 15130 15130 16348 14:39, .June 21 2016 2 S -o 6w p o g [Salmon] 11 O O. o o To 16347.6o Casing Details ND MD Name z661.00 2119-13 ID -3/4"9-7/ x 13-111" 637500 7688.26 7-518" x 9-718" by n" 640900 16347.60 41/2"x6-314" Depth From 30.00 790.00 750.00 27798 277913 7688.26 7688.26 Survey Program Depth To Survey/Plan 750.00 zS-06wpo9 [Salmon] (Plan: zS-06) 1750.00 z5-o6wpo9 [Salmon] (Plan: 2S-06) 2779.13 2S-o6wpo9[Salmon,(Plan: 2S -o6) 428149 2S-o6wpo9[Salmon](Pan: z5 -o6) 7688.76 2S-o6wpo9 [Salmon] (Plan: 2S 06) 9183.79 25-06wpo9 [Salmon] (Plan: zS-o6) 16347.60 zS-06wpo9 [Salmon] (Plan: 2S-06) Tool 6YD-6C-SS MWD MWD'IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC 39 425 610 425 U 610 MD Azi 0/36o 790 790 970 39.00 0.00 go 970 1150 425.00 0.00 -30/33 0 600.06 0.00 1150 1340 1380.92 0.00 1340 1520 1488.89 0.00 60 - --- -- 1520 1700 1847.71 29.27 -60 / 300 6o 1700 2310 3464.77 29.27 7688.26 194.33 2310 2930 7708.26 194.33 30 2930 3540 7950.97 194.33 16347.60 194.33 3540 4150 415 0 - ------ 476 0 - 0/270 go 4760 5370 5370 _^- 5990 30 5990 6600 6600 7820 -120/240 120 7820 9040 6o 9040 10260 10260 11480 11480 12690 -150/210 150 go 12690 13910 -18o/18o 13910 15130 15130 16348 14:40, June 21 2016 Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2S Pad Plan: 2S-06 Plan: 2S-06 Plan: 2S-06wp09 [Salmon] Report - Errors 21 June, 2016 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp09 [Salmon] Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 2S-06 TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OA KE D M P2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2S Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.14 ° Well Plan: 2S-06 Well Position +N/ -S 0.00 usft Northing: usft Latitude: +E/ -W 0.00 usft Easting: usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 120.00 usft Wellbore Plan: 2S-06 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BGGM2016 8/22/2016 17.87 80.84 57,534 Design 2S-06wp09 [Salmon] Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 195.00 Survey Tool Program Date 6/21/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 750.00 2S-06wp09 [Salmon] (Plan: 2S-06) GYD-GC-SS Gyrodata gyro single shots 750.00 1,750.00 2S-06wp09 [Salmon] (Plan: 2S-06) MWD MWD - Standard 750.00 2,779.13 2S-06wp09 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,779.13 4,281.49 2S-06wp09 [Salmon] (Plan: 25-06) MWD MWD - Standard 2,779.13 7,688.26 2S-06wp09 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,688.26 9,183.74 2S-06wp09 [Salmon] (Plan: 2S-06) MWD MWD - Standard 7,688.26 16,347.60 2S-06wp09 [Salmon] (Plan: 2S-06) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 39.00 0.00 0.00 0.00 -120.00 0.00 0.00 0.00 100.00 1.15 0.00 0.00 -59.00 1.15 0.04 0.04 200.00 1.15 0.00 0.00 41.00 1.15 0.19 0.19 289.00 1.15 0.00 0.00 130.00 1.15 0.33 0.33 top T-3 Sand 300.00 1.15 0.00 0.00 141.00 1.15 0.33 0.33 6/21/2016 2:50.05PM Page 2 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 [Salmon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) V) C) (usft) (usft) (usft) (usft) 374.00 1.15 0.00 0.00 215.00 1.15 0.48 0.48 K-15 Marker 400.00 1.15 0.00 0.00 241.00 1.15 0.48 0.48 425.00 1.15 0.00 0.00 266.00 1.15 0.51 0.51 KOP: Start 1.5°/100' DLS, 0` TF, for 175.06' 500.00 1.15 1.12 90.00 341.00 1.15 0.62 0.62 600.00 1.15 2.62 90.00 440.94 1.15 0.77 0.77 600.06 1.15 2.63 90.00 441.00 1.15 0.77 0.77 Start 2.5°/100' DLS, 0° TF, for 780.86' 700.00 1.16 5.12 90.00 540.70 1.15 0.92 0.91 800.00 1.16 7.62 91.12 640.08 1.15 1.00 0.98 900.00 1.17 10.12 178.96 738.87 1.15 1.05 1.00 1,000.00 1.18 12.62 179.28 836.90 1.14 1.19 1.02 1,100.00 1.19 15.12 179.40 933.97 1.14 1.42 1.07 1,200.00 1.21 17.62 179.48 1,029.91 1.14 1.75 1.13 1,300.00 1.22 20.12 179.53 1,124.53 1.13 2.16 1.21 1,380.92 1.24 22.15 179.56 1,200.00 1.13 2.55 1.29 Hold for 107.97' 1,400.00 1.24 22.15 179.57 1,217.67 1.13 2.65 1.31 1,434.90 1.25 22.15 179.59 1,250.00 1.15 3.11 1.42 Base permafrost (?) 1,488.89 1.25 22.15 179.59 1,300.00 1.15 3.11 1.42 Start 3°/100' DLS, 107.93° TF, for 358.82' 1,500.00 1.25 22.05 179.60 1,310.30 1.15 3.16 1.44 1,600.00 1.26 21.35 0.21 1,403.23 1.18 3.49 1.62 1,700.00 1.30 21.03 1.64 1,496.49 1.21 3.80 1.90 1,800.00 1.28 21.13 0.03 1,589.82 1.20 1.91 1.61 1,847.71 1.29 21.32 1.28 1,634.30 1.20 1.96 1.67 Hold for 1617.06' 1,900.00 1.29 21.32 3.19 1,683.01 1.21 2.04 1.72 1,907.51 1.30 21.32 6.67 1,690.00 1.24 2.22 1.82 Top W Salk (W Salk D) 2,000.00 1.30 21.32 6.67 1,776.17 1.24 2.22 1.82 2,100.00 1.31 21.32 9.44 1,869.33 1.26 2.41 1.92 2,200.00 1.32 21.32 11.69 1,962.49 1.29 2.60 2.02 2,300.00 1.33 21.32 13.53 2,055.64 1.31 2.80 2.13 2,400.00 1.34 21.32 15.07 2,148.80 1.34 3.00 2.24 2,500.00 1.35 21.32 16.36 2,241.96 1.37 3.20 2.34 2,600.00 1.36 21.32 17.47 2,335.12 1.40 3.40 2.46 2,653.54 1.37 21.32 18.42 2,385.00 1.44 3.61 2.57 Base W Salk 2,700.00 1.37 21.32 18.42 2,428.28 1.44 3.61 2.57 2,779.13 1.38 21.32 19.31 2,502.00 1.45 3.84 2.63 10-3/4" x 13-1/2" 2,800.00 1.38 21.32 19.31 2,521.44 1.45 3.84 2.63 6/21/2016 2:50.05PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 [Salmon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Herz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 2,900.00 1.39 21.32 20.46 2,614.60 1.46 4.13 2.64 3,000.00 1.41 21.32 21.54 2,707.76 1.48 4.47 2.66 3,082.91 1.42 21.32 22.47 2,785.00 1.50 4.84 2.69 C-80 3,100.00 1.42 21.32 22.47 2,800.92 1.50 4.84 2.69 3,200.00 1.43 21.32 23.26 2,894.08 1.52 5.24 2.74 3,300.00 1.44 21.32 23.92 2,987.23 1.54 5.67 2.79 3,400.00 1.45 21.32 24.48 3,080.39 1.56 6.11 2.85 3,464.77 1.46 21.32 24.79 3,140.73 1.58 6.40 2.90 Start 2.5°/100' DLS, 164.540 TF, for 4223.49' 3,500.00 1.46 20.47 24.89 3,173.65 1.59 6.53 2.93 3,600.00 1.48 18.08 25.10 3,268.04 1.63 6.78 3.05 3,700.00 1.51 15.72 25.41 3,363.71 1.66 7.01 3.20 3,800.00 1.55 13.42 25.81 3,460.49 1.69 7.17 3.42 3,900.00 1.60 11.19 26.29 3,558.19 1.72 7.23 3.78 4,000.00 1.67 9.11 26.83 3,656.63 1.74 7.10 4.37 4,100.00 1.75 7.29 27.44 3,755.61 1.76 6.57 5.36 4,200.00 1.84 5.99 28.12 3,854.94 1.78 5.30 6.75 4,300.00 1.80 5.57 23.38 3,954.45 1.74 3.05 4.95 4,400.00 1.88 6.21 23.67 4,053.94 1.76 3.31 4.83 4,471.55 1.96 7.18 23.95 4,125.00 1.77 3.86 4.45 C-50 4,500.00 1.96 7.65 23.95 4,153.22 1.77 3.86 4.45 4,600.00 2.05 9.54 24.19 4,252.09 1.78 4.25 4.11 4,700.00 2.14 11.66 24.39 4,350.38 1.79 4.50 3.88 4,800.00 2.23 13.91 24.51 4,447.90 1.79 4.66 3.71 4,838.29 2.33 14.79 24.52 4,485.00 1.80 4.77 3.60 C-40 4,900.00 2.33 16.23 24.52 4,544.46 1.80 4.77 3.60 5,000.00 2.43 18.59 24.40 4,639.87 1.80 4.86 3.51 5,100.00 2.53 20.99 24.09 4,733.96 1.81 4.93 3.45 5,101.11 2.63 21.01 23.56 4,735.00 1.82 5.00 3.40 C-37 5,200.00 2.63 23.40 23.56 4,826.55 1.82 5.00 3.40 5,264.08 2.73 24.96 22.77 4,885.00 1.82 5.07 3.35 Growler -AA 5,300.00 2.73 25.83 22.77 4,917.45 1.82 5.07 3.35 5,400.00 2.83 28.28 21.69 5,006.50 1.83 5.15 3.31 5,500.00 2.93 30.73 20.32 5,093.53 1.85 5.25 3.28 5,600.00 3.04 33.19 18.68 5,178.36 1.86 5.35 3.25 5,700.00 3.14 35.65 16.87 5,260.85 1.88 5.48 3.23 5,800.00 3.24 38.12 14.99 5,340.83 1.91 5.63 3.21 5,900.00 3.34 40.59 13.17 5,418.15 1.94 5.80 3.19 5,928.92 3.43 41.30 11.52 5,440.00 1.98 5.99 3.18 Top Cairn 6/21/2016 2:50:05PM Page 4 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 (Salmon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) V) (1) (usft) (usft) (usft) (usft) 6,000.00 3.43 43.06 11.52 5,492.67 1.98 5.99 3.18 6,044.66 3.53 44.17 10.10 5,525.00 2.02 6.21 3.18 Top Bermuda 6,100.00 3.53 45.54 10.10 5,564.24 2.02 6.21 3.18 6,137.09 3.62 46.45 8.94 5,590.00 2.08 6.45 3.18 Base Bermuda 6,188.50 3.62 47.73 8.94 5,625.00 2.08 6.45 3.18 C-35 6,200.00 3.62 48.01 8.94 5,632.72 2.08 6.45 3.18 6,300.00 3.72 50.49 8.05 5,697.98 2.14 6.73 3.18 6,400.00 3.81 52.97 7.39 5,759.91 2.21 7.02 3.19 6,500.00 3.90 55.46 6.94 5,818.38 2.28 7.34 3.21 6,600.00 3.98 57.94 6.65 5,873.28 2.37 7.69 3.23 6,698.97 4.07 60.40 6.49 5,924.00 2.47 8.05 3.26 Top HRZ (K-2 mkr) 6,700.00 4.07 60.42 6.49 5,924.51 2.47 8.05 3.26 6,800.00 4.15 62.91 6.43 5,971.97 2.57 8.44 3.30 6,898.65 4.23 65.36 6.45 6,015.00 2.68 8.84 3.34 Upper Kalubik (base HRZ) 6,900.00 4.23 65.39 6.45 6,015.56 2.68 8.84 3.34 7,000.00 4.31 67.88 6.54 6,055.22 2.80 9.27 3.39 7,100.00 4.39 70.37 6.66 6,090.85 2.92 9.71 3.45 7,143.26 4.47 71.44 6.82 6,105.00 3.05 10.16 3.51 Lower Kalubik (K-1 mkr) 7,200.00 4.47 72.85 6.82 6,122.39 3.05 10.16 3.51 7,300.00 4.54 75.34 7.00 6,149.79 3.19 10.63 3.58 7,400.00 4.62 77.83 7.19 6,172.99 3.33 11.10 3.65 7,460.66 4.69 79.34 7.40 6,185.00 3.48 11.59 3.73 Kuparuk C (Top C4) 7,500.00 4.69 80.32 7.40 6,191.95 3.48 11.59 3.73 7,551.20 4.76 81.59 7.61 6,200.00 3.62 12.09 3.81 A5 7,600.00 4.76 82.80 7.61 6,206.62 3.62 12.09 3.81 7,628.32 5.35 83.51 7.22 6,210.00 3.63 12.46 3.81 A4 7,688.26 5.35 85.00 7.22 6,216.00 3.63 12.46 3.81 Hold for 20'- 7-5/8" x 9-7/8" by 11" 7,700.00 5.35 85.00 7.21 6,217.02 3.63 12.51 3.81 7,708.26 5.35 85.00 7.20 6,217.74 3.63 12.54 3.81 Start 2"/100' DLS, 0° TF, for 242.71' 7,800.00 5.41 86.83 7.24 6,224.27 3.67 12.99 3.78 7,900.00 5.46 88.83 7.45 6,228.05 3.74 13.61 3.78 7,950.97 5.49 89.85 7.61 6,228.64 3.79 13.98 3.80 Hold for 8396.63' 8,000.00 5.50 89.85 7.79 6,228.76 3.85 14.36 3.85 8,100.00 5.50 89.85 8.18 6,229.01 3.99 15.21 3.99 6/21/2016 2.50:05PM Page 5 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp09 [Salmon] Planned Survey MD (usft) 8,200.00 8,300.00 8,400.00 8,500.00 8,600.00 8,700.00 8,800.00 8,900.00 9,000.00 9,100.00 9,200.00 9,300.00 9,400.00 9,500.00 9,600.00 9,700.00 9,800.00 9,900.00 10,000.00 10,100.00 10,200.00 10,300.00 10,400.00 10,500.00 10,600.00 10,700.00 10, 800.00 10,900.00 11,000.00 11,100.00 11,200.00 11,300.00 11,400.00 11,500.00 11,600.00 11,700.00 11, 800.00 11, 900.00 12,000.00 12,100.00 12,200.00 12,300.00 12,400.00 12,500.00 Schlumberger Report - Errors Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2S-06 Plan: 120+39 @ 159.00usft (Doyon142) Plan: 120+39 @ 159.00usft (Doyon142) True Minimum Curvature OAKEDMP2 MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error (usft) (") (°) (usft) (usft) (usft) 5.51 89.85 8.59 6,229.27 4.15 16.16 5.52 89.85 9.00 6,229.52 4.34 17.17 5.53 89.85 9.39 6,229.78 4.56 18.25 5.54 89.85 9.75 6,230.03 4.79 19.38 5.55 89.85 10.08 6,230.29 5.04 20.55 5.55 89.85 10.37 6,230.54 5.30 21.76 5.56 89.85 10.64 6,230.80 5.57 23.00 5.57 89.85 10.88 6,231.05 5.86 24.26 5.58 89.85 11.10 6,231.30 6.15 25.55 5.59 89.85 11.30 6,231.56 6.45 26.85 5.60 89.85 9.07 6,231.81 4.57 16.37 5.61 89.85 9.24 6,232.07 4.68 16.76 5.62 89.85 9.41 6,232.32 4.80 17.17 5.63 89.85 9.57 6,232.58 4.92 17.58 5.64 89.85 9.73 6,232.83 5.04 18.00 5.65 89.85 9.88 6,233.09 5.16 18.43 5.66 89.85 10.02 6,233.34 5.29 18.87 5.67 89.85 10.16 6,233.59 5.43 19.32 5.68 89.85 10.30 6,233.85 5.56 19.77 5.69 89.85 10.43 6,234.10 5.70 20.23 5.70 89.85 10.55 6,234.36 5.84 20.69 5.71 89.85 10.67 6,234.61 5.98 21.16 5.72 89.85 10.78 6,234.87 6.12 21.64 5.73 89.85 10.89 6,235.12 6.27 22.12 5.74 89.85 10.99 6,235.38 6.42 22.60 5.75 89.85 11.09 6,235.63 6.56 23.09 5.76 89.85 11.18 6,235.88 6.71 23.59 5.77 89.85 11.27 6,236.14 6.87 24.08 5.78 89.85 11.36 6,236.39 7.02 24.58 5.79 89.85 11.44 6,236.65 7.17 25.09 5.80 89.85 11.52 6,236.90 7.33 25.59 5.81 89.85 11.60 6,237.16 7.48 26.10 5.82 89.85 11.67 6,237.41 7.64 26.62 5.84 89.85 11.74 6,237.67 7.80 27.13 5.85 89.85 11.80 6,237.92 7.96 27.65 5.86 89.85 11.87 6,238.17 8.12 28.17 5.87 89.85 11.93 6,238.43 8.28 28.69 5.88 89.85 11.99 6,238.68 8.44 29.22 5.89 89.85 12.04 6,238.94 8.60 29.74 5.90 89.85 12.10 6,239.19 8.77 30.27 5.91 89.85 12.15 6,239.45 8.93 30.80 5.93 89.85 12.20 6,239.70 9.09 31.33 5.94 89.85 12.24 6,239.96 9.26 31.86 5.95 89.85 12.29 6,240.21 9.42 32.40 Horz. Error (usft) 4.16 4.35 4.56 4.79 5.04 5.30 5.57 5.86 6.15 6.45 4.57 4.68 4.80 4.92 5.04 5.17 5.30 5.43 5.56 5.70 5.84 5.98 6.13 6.27 6.42 6.57 6.72 6.87 7.02 7.18 7.33 7.49 7.64 7.80 7.96 8.12 8.28 8.44 8.61 8.77 8.93 9.10 9.26 9.43 6/21/2016 2:50:05PM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2S-06 Project: Kuparuk River Unit TVD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Site: Kuparuk 2S Pad MD Reference: Plan: 120+39 @ 159.00usft (Doyon142) Well: Plan: 2S-06 North Reference: True Wellbore: Plan: 2S-06 Survey Calculation Method: Minimum Curvature Design: 2S-06wp09 [Salmon] Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 12,600.00 5.96 89.85 12.34 6,240.46 9.59 32.93 9.59 12,700.00 5.97 89.85 12.38 6,240.72 9.76 33.47 9.76 12,800.00 5.99 89.85 12.42 6,240.97 9.92 34.01 9.93 12,900.00 6.00 89.85 12.46 6,241.23 10.09 34.55 10.09 13,000.00 6.01 89.85 12.50 6,241.48 10.26 35.09 10.26 13,100.00 6.02 89.85 12.53 6,241.74 10.43 35.63 10.43 13,200.00 6.04 89.85 12.57 6,241.99 10.59 36.18 10.60 13,300.00 6.05 89.85 12.60 6,242.25 10.76 36.72 10.76 13,400.00 6.06 89.85 12.64 6,242.50 10.93 37.27 10.93 13,500.00 6.07 89.85 12.67 6,242.75 11.10 37.81 11.10 13,600.00 6.09 89.85 12.70 6,243.01 11.27 38.36 11.27 13,700.00 6.10 89.85 12.73 6,243.26 11.44 38.91 11.44 13,800.00 6.11 89.85 12.76 6,243.52 11.61 39.46 11.61 13,900.00 6.12 89.85 12.79 6,243.77 11.78 40.01 11.78 14,000.00 6.14 89.85 12.81 6,244.03 11.95 40.56 11.95 14,100.00 6.15 89.85 12.84 6,244.28 12.12 41.11 12.12 14,200.00 6.16 89.85 12.86 6,244.54 12.29 41.66 12.30 14,300.00 6.18 89.85 12.89 6,244.79 12.47 42.22 12.47 14,400.00 6.19 89.85 12.91 6,245.04 12.64 42.77 12.64 14,500.00 6.20 89.85 12.94 6,245.30 12.81 43.32 12.81 14,600.00 6.22 89.85 12.96 6,245.55 12.98 43.88 12.98 14,700.00 6.23 89.85 12.98 6,245.81 13.15 44.43 13.15 14,800.00 6.24 89.85 13.00 6,246.06 13.33 44.99 13.33 14,900.00 6.26 89.85 13.02 6,246.32 13.50 45.54 13.50 15,000.00 6.27 89.85 13.04 6,246.57 13.67 46.10 13.67 15,100.00 6.28 89.85 13.06 6,246.83 13.84 46.66 13.84 15,200.00 6.30 89.85 13.08 6,247.08 14.02 47.22 14.02 15,300.00 6.31 89.85 13.10 6,247.33 14.19 47.78 14.19 15,400.00 6.32 89.85 13.12 6,247.59 14.36 48.33 14.36 15,500.00 6.34 89.85 13.14 6,247.84 14.54 48.89 14.54 15,600.00 6.35 89.85 13.15 6,248.10 14.71 49.45 14.71 15,700.00 6.37 89.85 13.17 6,248.35 14.88 50.01 14.89 15,800.00 6.38 89.85 13.19 6,248.61 15.06 50.57 15.06 15,900.00 6.39 89.85 13.20 6,248.86 15.23 51.13 15.23 16,000.00 6.41 89.85 13.22 6,249.12 15.41 51.69 15.41 16,100.00 6.42 89.85 13.23 6,249.37 15.58 52.26 15.58 16,200.00 6.44 89.85 13.25 6,249.62 15.75 52.82 15.76 16,300.00 6.45 89.85 13.26 6,249.88 15.93 53.38 15.93 16,347.60 6.46 89.85 13.27 6,250.00 16.01 53.65 16.01 TD: 16347.6' MD, 6409' TVD 6/21/2016 2.50.05PM Page 7 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2S Pad Well: Plan: 2S-06 Wellbore: Plan: 2S-06 Design: 2S-06wp09 [Salmon] Casing Points Formations Schlumberger Report - Errors Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2S-06 Plan: 120+39 @ 159.00usft (Doyon142) Plan: 120+39 @ 159.00usft (Doyon142) True Minimum Curvature OAKEDMP2 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name Name Lithology 7,688.26 6,375.00 7-5/8" x 9-7/8" by 11" 7-5/8 11 16,347.60 6,409.00 4 1/2" x 6-3/4" 4-1/2 6-3/4 2,779.13 2,661.00 10-3/4" x 13-1/2" 10-3/4 13-1/2 Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 7,628.32 6,369.00 A4 6,898.65 6,174.00 Upper Kalubik (base HRZ) 1,907.51 1,849.00 Top W Sak (W Sak D) 6,044.66 5,684.00 Top Bermuda 6,698.97 6,083.00 Top HRZ (K-2 mkr) 2,653.54 2,544.00 Base W Sak 3,082.91 2,944.00 C-80 7,460.66 6,344.00 Kuparuk C (Top C4) 1,434.90 1,409.00 Base permafrost (?) 5,264.08 5,044.00 Growler -AA 289.00 289.00 top T-3 Sand 7,143.26 6,264.00 Lower Kalubik (K-1 mkr) 6,188.50 5,784.00 C-35 4,471.55 4,284.00 C-50 5,928.92 5,599.00 Top Cairn 6,137.09 5,749.00 Base Bermuda 374.00 374.00 K-15 Marker 7,551.20 6,359.00 A5 5,101.11 4,894.00 C-37 4,838.29 4,644.00 C-40 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) 425.00 425.00 0.00 0.00 600.06 600.00 4.01 0.00 1,380.92 1,359.00 170.70 0.00 1,488.89 1,459.00 211.41 0.00 1,847.71 1,793.30 336.30 31.98 3,464.77 3,299.73 849.09 319.34 7,688.26 6,375.00 -1,107.22 111.24 7,708.26 6,376.74 -1,126.53 106.31 7,950.97 6,387.64 -1,361.37 46.30 16,347.60 6,409.00 -9,496.54 -2,032.61 Comment KOP: Start 1.5°/100' DLS, 0° TF, for 175.06' Start 2.5°/100' DLS, 0° TF, for 780.86' Hold for 107.97' Start 3°/100' DLS, 107.93° TF, for 358.82' Hold for 1617.06' Start 2.5°/100' DLS, 164.54° TF, for 4223.49' Hold for 20' Start 2°/100' DLS, 0° TF, for 242.71' Hold for 8396.63' TD: 16347.6' MD, 6409' TVD Checked By: Approved By: Date: 6/21/2016 2.50:05PM Page 8 COMPASS 5000.1 Build 74 Pool Report 15:03, June 212016 2S 06wp09 [Salmon] WELLBORE TARGET DETAILS (MAP CO-ORDINATES) Name TVD Shape 2S-Salmon i. Heel 050216 PB 6375.00 Circle (Radius: 100.00) 2S-Salmon 2. Toe 050216 PB 6409.00 Circle (Radius: 100.00) Quarter Mile View 2S Salmon 1. Heel 050216 PB Circle 6375.00 Circle (Radius: 1320.00) 2S-Salmon 2. Toe050216 PEI Circle 6409.00 Circle (Radius: 1320.00) 6000 - - ?5.04 25.0 2S OS 3000 - 2S-02 0 -? - - - - - O S.0 B O M :93000- - -- - — _ 0 Z I I Sha r Tooth � 1 X6000 - - - - - - -_ 2S-03Pa, 2S-01 2&08 2s-10 -9000 -_ ` 2S-03 2S 06wpo9 lSa mon -9000 -6000 -3000 0 3000 6000 9000 12000 15000 16:04, June 212016 2S-06wp09 [Salmon] Quarter Mile View N -2000 U) o-4000 0 0 N 0-6000 Z E u)-8000 -10000 Name TVD Shape 2S -Salmon 1. Heel 050216 PB 6375.00 Circle (Radius: 100.00) 2S -Salmon 2. Toe 050216 PB 6409.00 Circle (Radius: 100.00) 2S -Salmon 1. Heel 050216 PB_Circle 6375.00 Circle (Radius: 1320.00) 2S -Salmon 2. Toe 050216 PE_Cimle 6409.00 Circle (Radius: 1320.00) -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 I ------------------- ------------ ------------ -------------- - .. ........... ........ ...... ---------- ----------- ............ 2S-06wp09 Surface Location CPAI Coordinate Convert er a ' From: f To: _ - Datum: NAD83 - Region: alaska , Datum: INAD27 Region: alaska Latitude/Longitude Decimal Degrees 6 C' Latitude?Longitude IDecimal Degrees r UTM Zone: r- South p I r UTM Zone: True C- South State Plane Zone: 1 Units: us-ft - 1' Co' State Plane Zone: 4 Units: us fk r" Legal Description (NAD27 only) ? Legal Description (NAD27 only) Starting Coordinates: - -- - -- Ending Coordinates: - X: 11621195.59 X: f 481162.271120299 YX6929754.39 Y: 5930004.80121475 6 ,....... € Transform Quit Help 2S-06wp09 Surface Casing CPAI Coordinate Converter From: i To: Datum: NAD83 Region: alaska Datum: INAD27 Region: alaska C- Latitude?Longitude IDecimalDegrees t"' Latitude}Longitude Decimal Degrees C' UTM Zone:- South r UTM Zone: ,True f- South t State Plane Zone: 4 .' Units: us-ft r: State Plane Zone: 4 t Units: us-ft C" Legal Description (NAD27 only) i r Legal Description (NAD27 only) Starting Coordinates: -- -- ] Ending Coordinates: ---- X: 1621394.68 ? X: 481361.374615991 Y: 15930385.49 I Y: 5930635.88476797 ........................................................... .........Transform....... a Quit Help 2S-06w 09 Intermediate Casing CPA[ Coordinate Converter From: _ _ __.. _ __ - ---__.... _ _ To: - . _---------- _Datum: Datum: Region: NA1)83 + alaska Datum: NAD27 �, Region: alaska + e Latitude/Longitude 'Decimal Degrees (- LatitudelLongitude Decimal Degrees + UTM Zone: F r South r UTM Zone: True F- South Stake Plane Zone: 4 + Units: us-ft i State Plane Zone: 4 + Units:us ft + Legal Description (NAD27 only] C' Legal Description (NAD27 only) Starting Coordinates: ----------- -- Ending Coordinates: X: 1621304 X: 1481270.667327537 Y: 5928647 Y: 16928867.43351369 , ... 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As -built 1 15/28/11SZ I JAH I Created Drawing Per K140173ACS 1 2 11/14/11 SZ I MEH I I Add Well 13 per K150013ACS NOTESw W is s u —0-1 X 14 1. BASIS OF LOCATION AND ELEVATION IS DS2S '° 21 22 MONUMENTATION PER LOUNSBURY & ASSOC. �'-- 21 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 29 RDS 2 Z7 ZONE 4, 27.D. 27, AND GEODETIC COORDINATES �'DW N '3 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 17, TOWNSHIP 10 NORTH, RANGE 8 EAST, UMIAT MERIDIAN. 5. DATES OF SURVEY: 5-2 THRU 5-27-15 FIELD BOOKS L15-28, L15-29, L15-32, L15-35, 11-13-2015 FIELD BOOK L15-75. 6. ALL DISTANCES SHOWN ARE TRUE. 7. CONDUCTOR 15 WAS ORIGINALLY SET AS CONDUCTOR 13. N i i IT11N A, iT1 ON Q.Q R _ I � i6 15 i 13 p 21 � � � 24 t3 ZO 21 Z2 PROJECT f LOCATION ,0 25 i VICINITY MAP NTS LEGEND O AS—BUILT CONDUCTOR LOCATION • EXISTING CONDUCTOR LOCATIONS 17 16 20,21 0 100 200 400 LOUNSBURY SEE PAGE 2 OF 2 FOR LOCATIONS & ASSOCIATES, INC. 1 inch = 200 ft. SURV YORS ENGINEERS PLANNERS AREA: 2S MODULE: XXXX UNIT: D2 ConocoPhillips DS2S WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6219d24 5/28/15 1 CEA—D2SX-6219D24 1 1 OF 2 2 REV DATE 18YICK IAPPI DESCRIPTION RKKI DATE I BY CK I APP I DESCRIPTION 1 5/28/1 1 SZ I JAH I Created Drawing Per 1<140173ACS 2 11/14/1 SZ I MEH I jAdd Well 13 Per K150013ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 17, 1 " -1 T. 10 N., R. 8 E., UMIAT MERIDIAN ` ' Well NAD 27 NAD 27 Section Elev. No. ASP Coordinates Geographic Coordinates Offset. Y X Lat. Long. F.S.L F.E.L. O.G. PAD 1 5,930,036.15 481,309.02 70' 13' 12.058" 150' 09' 02.839" 2268' 1261' 112.0' 120.0' 2 5,930,029.92 481,279.68 70' 13' 11.996" 150' 09' 03.690" 2262' 1291' 112.4' 120.0' 3 5,930,023.62 481,250.32 70' 13' 11.933" 150' 09' 04.543" 2255' 1320' 112.1' 120.0' 4 5,930,017.59 481,221.00 70' 13' 11.873" 150° 09' 05.394" 2249' 1349' 112.0' 120.0' 5 5,930,010.88 481,191.79 70' 13' 11.806" 150' 09' 06.242" 2243' 1378' 111.8° 120.0' 6 5,930,004.80 481,162.27 70' 13' 11.746" 150' 09' 07.098" 2236' 1408' 111.5' 120.0' 7 5,929,998.58 481,133.41 70' 13' 11.684" 150' 09' 07.936" 2230' 1437' 111.4' 120.0' 8 5,929,992.42 481,103.50 70' 13' 11.622" 150° 09' 08.804" 2224' 1467' 111.1' 120.0- 9 5,929,986.08 481,074.22 70' 13' 11.559" 150' 09' 09.654" 2217' 1496' 111.0' 120.0' 10 5,929,979.72 481,044.13 70' 13' 11.496" 150' 09' 10.528" 2211' 1526' 111.1' 120.0' 11 5,929,973.68 481,015.40 70' 13' 11.436" 150' 09' 11.362" 2205' 1555' 111.1' 120.0' 12 5,929,968.02 480,986.10 70' 13' 11.380" 150' 09' 12.212" 2199' 1584' 110.9' 120.0' 13 5,929,948.70 480,898.09 70' 13' 11.187" 150' 09' 14.767" 2180' 1672' 110.5' 120.0' 14 5,929,955.02 480,927.39 70' 13' 11.250" 150' 09' 13.920" 2186' 1643' 110.5' 120.0' 15 5,929,961.45 480,956.55 70' 13' 11.314" 150' 09' 13.070" 2192' 1614' 110.6' 120.0' * CONDUCTOR AS BUILT THIS SURVEY SEE NOTE 7 SHEET 1 REGARDING CONDUCTOR 15. OF SURVEYOR'S CER TI Fl CA TE AV . % •• • •••••• ••• .•••• I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY .. •.................................:.... •�% JEREMIAN F. CaRNELL,� ': DONE BY ME OR UNDER MY DIRECT SUPERVISION AND S �3 ., d+� •, LS 12663 •' THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT • R AS OF NOVEMBER 13, 2015. OUNSBURY A.,,LSO.8,INC. EYORS ENGINEERS PLANNERS AREA: 2S MODULE: XXXX UNIT: D2 ConocoPhilli s DS2S 1" WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE N0. LK6219d24 5 28 15 DRAWING N0. CEA-D2SX-6219D24 PART. 2 of 2 REV: 2 DRILL PAD 1ROE NCDrill Site 2S RTH NORM 12' DRILL SITE PLOT PLAN 30'-O' WELL SPACING (8.53 ACRES) TYP. WELL HOUSE 2525®FT. 17'-6'x 14'-0'x 15'-0' ConocoPhillips TITLE: DS2S LAYOUT DRAWING SCALE: 1'= 50'-0' Alaska, Inc. FORMAT: 11'07" 1 DRAWN BY: ALKET MICI DATE: 06-23-2016 1 REV: 1 2S-06 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Anti -collision Low Run Gyro as needed for magnetic interference. Third well on pad, so no High ECD and swabbing with higher Low real anti -collision risk, only with future plans. Gravel / Sand Sloughing Low Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections. Hole Swabbing / Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Lost circulation Low Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Unsuccessful cement job Moderate Use lower density cement slurry. Adjust the mud properties prior pump cement. Use proper pump rate. 9-7/8" x 11" Hole / 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability Moderate For the unstable HRZ and Kalubik shales with high inclination control MW's required with higher MW and proper tripping practices to avoid surging or swabbing. Minimize pressure cycling by stripping out using MPD to Abnormal Reservoir Pressure Moderate eliminate swab. High ECD and swabbing with higher Low Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Lost circulation Low Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology, add LCM. Use GKA LC decision tree. Keep ECD below known frac gradient of —12.5 ppg in Tarn formations crossed in intermediate. Hole cleaning Low Use PWD and TAD to monitor hole cleaning. Control the ROP and use the best hole cleaning practice. Stuck pipe Low Good hole cleaning, stabilized BHA, proper mud weight, PWD monitor ECD. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. 6-3/4" Hole / 4-1/2" Liner Interval Event Risk Level Mitigation Strategy High ECD and swabbing with higher Moderate Condition mud prior to trips. Monitor ECD's with PWD tool while MW's required drilling across pay interval. Backream out on trips as a last resort. Strip out with MPD to eliminate swab. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Adjust mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Utilize MPD to contain any pressure and prevent allowing an influx in the event pressure is higher than expected. Lost Circulation Moderate Use PWD and TAD to monitor hole cleaning. Reduced pump rates, adjust mud rheology, add LCM. Use GKA LC decision tree. Use of MPD will allow lower mud weights to reduce ECD while shutting on connections to prevent any potential influx. Stuck pipe Moderate Good hole cleaning, stabilized BHA, proper mud weight to minimize differential stuck, PWD monitor ECD. Hole swabbing on trips Moderate Monitor proper hole fill while tripping, good hole cleaning. Backream out to intermediate shoe, then utilize MPD to strip out and eliminate swab. Well: 2S-06 <_=Data Input Name: V Loepp <_= Data Input Mud Weight (ppg) 11.50 — Data Input Weak point or LOT - Measured depth (ft) 2,779' — Data Input Weak point or LOT True vertical depth (ft) 2,661' — Data Input Weak point or LOT - Hole angle (deg) 21.00 — Data Input Weak point or LOT - Hole size (in) 13.500" — Data Input Weak point pressure or LOT - EMW (ppg) 12.50 — Data Input Zone of interest - Measured depth (ft) 16,348' — Data Input Zone of interest - True vertical depth (ft) 6,409' — Data Input Zone of interest - Hole angle (deg) 90.00 — Data Input Zone of interest - Hole size (in) 9.875" — Data Input Zone of interest - Pore pressure EMW (ppg) 11.00 — Data Input Gas gradient (psi/ft) 0.10 <== Data Input Bottom hole assembly OD (in) 8.0" — Data Input Bottom hole assembly length (ft) 200' — Data Input Drill pipe OD (in) 5.500" — Data Input BHA annular vol. @ zone of interest (bbl/ft) 0.0326 DP annular vol. @ zone of interest (bbl/ft) 0.0653 DP annular vol. A weak point bbl/ft 0.1477 Additional safety margin (psi) 0.00 <== Data Input Weak point pressure (psi): PIO 1,730 psi Weak point pressure - Safety margin: Pmax 1,730 psi Pmax EMW 12.50 pp Max anticipated formation pressure (psi): Pf Weak Pt to Zone of Interest distance (TVD ft): OH {TVD} 3,748' Weak Pt to Zone of Interest distance (MD ft): OH {MD} 13,569' Maximum influx height at the bit (TVD ft): H {TVD} 612' Maximum influx height at the bit (MD ft): H {MD} Calc. volume of (H) around BHA: Vlbha 6.5 bbl Calc. volume of (H) around drill pipe: V1dp Calc. volume that H equals @ initial shut in: V1 ####N##########-# Calc. vol. that H equals @ weak point (MD ft): VWp 96.9 bbl Calc. volume of Vwp @ initial shut in: V2 45.7 bbl Kick Tolerance: V2 45.7 bbl NOTE: Prp z/6 —DY.; Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, June 28, 2016 8:18 AM To: 'Alexa, Kurt J' Subject: RE: 2S-06 Permit to Drill Kurt, This email is sufficient; I will update the approved PTD. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a_balaska.pov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.gov From: Alexa, Kurt J [mailto:Kurt.J.Alexa(5)conocophillips.com] Sent: Monday, June 27, 2016 12:54 PM To: Loepp, Victoria T (DOA) Subject: 2S-06 Permit to Drill Victoria, I was just re -reading the Application for Permit to Drill Well 2S-06 and noticed that there was a mistake in the 'Casing and Cement Program' section. For the 7-5/8" Casing, the TOC for the Stage 1 should be 6045' MD and the TOC for Stage 2 should be 4600' MD. The volume calculations are still correct. Would you like me to refile or send you a corrected copy? Apologies, Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 (Office) (907) 787-9637 ( Cell ) TRANSMITTAL LETTER CHECKLIST WELL NAME: L<IR U_ Q S - O (, PTD: 026 - O& /Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: W POOL: �,�/�,f O�' 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 onpermit). 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 sam les are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company) 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 PTD#:2160850 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 2S-06 Program DEV Well bore seg ❑ DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 19 1 Permit fee attached NA 20 2 Lease number appropriate Yes ADL0025603, Surf Loc & Top Prod Interv; ADL0025608, TD. 3 Unique well name and number Yes KRU 2S-06 4 Well located in a defined pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed 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 26 8 If deviated, is wellbore plat included Yes 27 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 110 Operator has appropriate bond in force Yes 29 Appr Date 11 Permit can be issued without conservation order Yes 30 12 Permit can be issued without administrative approval Yes 31 PKB 6/28/2016 Yes 32 13 Can permit be approved before 15 -day wait Yes 33 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 34 15 All wells within 1/4 mile area of review identified (For service well only) NA 35 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 36 80' conductor provided 2779' MD 128% excess Productive interval will be completed with uncemented slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Diverter meets regulations Max formation pressure is 3650 psig(11.0 ppg EMW); will drill w/ 9.3-11.5 ppg EMW MPSP is 3013 psig; will test BOPs to 3500 psig H2S measures required 1-12S measures required. Max potential reservoir pressure is 11.0 ppg EMW; will be drilled using 9.3 to 11.5 ppg mud. Onshore development well to be drilled. Geologic 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs Yes 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie-in long string to surf csg No 22 CMT will cover all known productive horizons No 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes 25 If_a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 7/11/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments)_ Yes 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA PKB 6/28/2016 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA_ 80' conductor provided 2779' MD 128% excess Productive interval will be completed with uncemented slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Diverter meets regulations Max formation pressure is 3650 psig(11.0 ppg EMW); will drill w/ 9.3-11.5 ppg EMW MPSP is 3013 psig; will test BOPs to 3500 psig H2S measures required 1-12S measures required. Max potential reservoir pressure is 11.0 ppg EMW; will be drilled using 9.3 to 11.5 ppg mud. Onshore development well to be drilled. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date 0
