Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
219-065
Permit to Drill 2190650 MD 13093 TVD REQUIRED INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 1/31/2020 Well Name/No. KUPARUK RIV UNIT 1A-04AL1 p Operator ConocoPhillips Alaska, Inc. 6668 Completion Date 10/15/2019 Completion Status WAGIN Current Status WAGIN Mud Log No✓ DATA INFORMATION List of Logs Obtained: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log 31436 Log Header Scans ED C 31436 Digital Data ED C 31436 Digital Data ED C 31436 Digital Data ED C 31436 Digital Data ED C 31437 Digital Data ED C 31437 Digital Data ED C 31437 Digital Data ED C 31437 Digital Data Log 31437 Log Header Scans ED C 31510 Digital Data ED C 31510 Digital Data ED C 31510 Digital Data ED C 31510 Digital Data ED C 31510 Digital Data ED C 31510 Digital Data ED C 31510 Digital Data ED C 31510 Digital Data ED C 31510 Digital Data AOGCC Samples No Log Log Run Interval OHI Scale Media No Start Stop CH 0 0 Page 1 of 4 0 0 8365 13093 API No. 50-029-20621-60-00 UIC Yes Directional Survey Yes (from Master Well Data/Logs) Received Comments 2190650 KUPARUK RIV UNIT 1A-04AL1 LOG HEADERS 11/14/2019 Electronic File: 1A-04AL1 EOW NAD27.pdf 11/14/2019 Electronic File: 1A-04ALl EOW NAD27.txt 11/14/2019 Electronic File: 1A-04AL1 EOW NAD83.pdf 11/14/2019 Electronic File: 1A-04AL1 EOW NAD83.txt 11/14/2019 Electronic File: 1A-04AL1PB1 EOW NAD27.pdf 11/14/2019 Electronic File: 1A-04AL1PB1 EOW NAD27.txt 11/14/2019 Electronic File: 1A-04AL1PB1 EOW NAD83.pdf 11/14/2019 Electronic File: 1A-04ALl PB1 EOW NAD83.txt 2190650 KUPARUK RIV UNIT 1A-04AL1 PB1 LOG HEADERS 11/29/2019 Electronic Data Set, Filename: 1A-04AL1 GAMMA RES.Ias 11/29/2019 Electronic File: 1A-04AL1 21VID Final..cgm 11/29/2019 Electronic File: 1A-04AL1 5MO Final..cgm 11/29/2019 Electronic File: 1A-04AL1 5TVD Final.cgm 11/29/2019 Electronic File: 1A-04AL1 21VID Final.pdf 11/29/2019 Electronic File: 1A-04AL1 5MD Final.pdf 11/29/2019 Electronic File: 1A-04AL1 5TVD Final.pdf 11/29/2019 Electronic File: 1A-04AL1 EOW NAD27.pdf 11/29/2019 Electronic File: 1A-04AL1 EOW NAD27.txt Friday, January 31, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/31/2020 Permit to Drill 2190650 Well Name/No. KUPARUK RIV UNIT 1A-04AL1 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20621-60-00 MD 13093 TVD 6668 Completion Date 10/15/2019 Completion Status WAGIN Current Status WAGIN UIC Yes ED C 31510 Digital Data 11/29/2019 Electronic File: 1A-04AL1 Final Surveys TD at 13093 ft.csv ED C 31510 Digital Data 11/29/2019 Electronic File: 10-04AL1 Final Surveys TO at 13093 ft.xlsx ED C 31510 Digital Data 11/29/2019 Electronic File: 1A-04AL1 Survey Listing.txl ED C 31510 Digital Data 11/29/2019 Electronic File: 1A-04AL1 Surveys.txt ED C 31510 Digital Data 11/29/2019 Electronic File: 1A- 04AL1 _25_tapescan_B H I_CTK.txt ED C 31510 Digital Data 11/29/2019 Electronic File: 1A- 04AL1 _5_tapescan_B H I_CTK.txt ED C 31510 Digital Data 11/29/2019 Electronic File: 1A-04AL1 output -tap ED C 31510 Digital Data 11/29/2019 Electronic File: 1A-04AL1 2MD Final.tif ED C 31510 Digital Data 11/29/2019 Electronic File: 1A-04AL1 51VID Final.tif ED C 31510 Digital Data 11/29/2019 Electronic File: 1A-D4AL1 5TVD Final.tif Log 31510 Log Header Scans 0 0 2190650 KUPARUK RIV UNIT 1A-04AL1 LOG HEADERS ED C 31511 Digital Data 8365 12066 11/29/2019 Electronic Data Set, Filename: IA-04ALIPB1 GAMMA RES.Ias ED C 31511 Digital Data 11/29/2019 Electronic File: 10-04AL1 PB1 21VID Final.cgm ED C 31511 Digital Data 11/29/2019 Electronic File: to-04AL1 PS 51VID Final.cgm ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1PB1 5TVDSS Final.cgm ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1 PB1 21VID Final.pdf ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1 PB1 51VID Final.pdf ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1PB1 5TVDSS Final.pdf ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1PB1 EOW NAD27.pdf ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1PB1 EOW NAD27.txt ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1 PB1 Final Surveys TD 12066.csv ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1 PB1 Final Surveys TO 12066.x1sx ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1PB1 Survey Listing.txt ED C 31511 Digital Data 11/29/2019 Electronic File: 1A-04AL1PB1 Surveys.txt AOGCC Page of Friday, January 31, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1131/2020 Permit to Drill 2190650 Well Name/No. KUPARUK RIV UNIT 1A-04AL1 Operator ConocoPhillips Alaska, Inc. MD 13093 TVD 6668 Completion Date 10/15/2019 ED C 31511 Digital Data ED C 31511 Digital Data ED C 31511 Digital Data ED C 31511 Digital Data ED C 31511 Digital Data ED C 31511 Digital Data Log 31511 Log Header Scans Well Cores/Samples Information: Interval Name Start Stop API No. 50-029-20621-60-00 Completion Status WAGIN Current Status WAGIN UIC Yes 11/29/2019 Electronic File: tA- Directional / Inclination Data Y� 04AL1 PB1_25_tapescan_BHI_CTK.txt 11/29/2019 Electronic File: 1A- Daily Operations Summary b 04AL1 PB1_5_tapescan_BHI_CTK.txt 11/29/2019 Electronic Fife:IA-04AL1 PB 1_output.tap 11/29/2019 Electronic File: to-04AL1 IDS 2MD Final.tif 11/29/2019 Electronic File: 1A-04AL1PB1 5MD Final.tif 11/29/2019 Electronic File: 1A -04A -1P81 5TVDSS Final.tif 0 0 2190650 KUPARUK RIV UNIT to-04AL1 PB1 LOG HEADERS Sample Set Sent Received Number Comments INFORMATION RECEIVED Core Chips Y Completion Report 0 Directional / Inclination Data Y� Production Test Informations Y/N�P Mechanical Integrity Test Information Y / NA Geologic Markers/Tops cY Daily Operations Summary b COMPLIANCE HISTORY Completion Date: 10/15/2019 Release Date: 5/7/2019 Description Date Comments Comments: Mud Logs, Image Files, Digital Data Y /6) Core Chips Y Composite Logs, Image, Data Files O, Core Photographs Y ! Cuttings Samples Y / 9 Laboratory Analyses Y / A AOGCC Page 3 of Friday, January 31, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/31/2020 Permit to Drill 2190650 Well Name/No. KUPARUK RIV UNIT 1A-04AL1 Operator ConocoPhillips Alaska, Inc. API No. 50-029-20621-60-00 MD 13093 TVD 6668 C t-ioon_ Dateyn� 110011512019 Completion Status WAGIN Current Status WAGIN UIC Yes Compliance Reviewed ByDate: '21 (C) (2 -d Z0 AOGC'CPage 4 of 4 Friday. January 31, 2020 219065 31510 g Baker PRINT DISTRIBUTION LIST Hughes COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1A-04AL1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider@_bakerhughes.com STATUS Final Replacement: COMPANY ler ie sign and return one copy of this transmittal form to: DcoPhillips Alaska, Inc. I Osterkamp (WNS Petroleum Technician) G Street. 'loraee. Alaska 99510 LOG TYPE - RES LOG DATE October 13, 2019 TODAYS DATE November 25, 2019 Revision Details: Rev. Requested by: FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS n # OF COPIES # OF COPIES # OF COPIES ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION n n n n n BP North Slope. EOA, PROC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico i ATO 708 RECEIVED r) 700 C Street Anchorage, AK 99510 NOV n 2019 3 �ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC 1 1 Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5'. DNR - Division of Oil & Gas *" 'Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ... Stam. "confidential" on all material deliver to DNR 61 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 Baker S PRINT DISTRIBUTION LIST Hughes COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1A-04ALIPBI FIELD Greater Kunaruk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(cDbakerhughes.com 21 9065 31511 e sign and return one copy of this transmittal form to: )coPhillips Alaska, Inc. Osterkamp (WINS Petroleum Technician) G Street. forage, Alaska 99510 LOG TYPE GR - RES LOG DATE October 7, 2019 TODAYS DATE November 25, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 4 1 or North scope. LOA, PBOC, PRB-20 (Office 109) D&G WO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 FIELDI FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY I# REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES 19 OF COPIES OF COPIES 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 K ,InVVV\I ' q NIS 3 Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Art.: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** 1 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 906 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED NOV 14 2019 WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil I ] Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.10 GINJ ❑ WINJ ❑ WAGE - WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service 0 ' Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp., Susp., or Abend.: 10/15/2019 14. Permit to Drill Number / Sundry: 219-065 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 1013/2019 15. API Number: _;` y, zz� C- Z/,_ 50.0 -60.00 ra. r ,,r 4a. Location of Well (Governmental Section): Surface: 1019' FSL, 311' FWL, Sec 05, T11N, R10E, UM Top of Productive Interval: 4875' FNL, 500' FEL, Sec 06, T1 IN, R10E, UM Total Depth: 2392' FNL, 3234' FEL, Sec 04, TI IN, R10E, UM 8. Date TD Reached: 10/13/2019 16. Well Name and Number: KRU 1A-04ALI MA-04AL1P81 9. Ref Elevations: KB:96 - GL: 61 • BF: 17. Field / Pool(s): Kuparuk River FieldlKuparuk River Oil Pool 10. Plug Back Depth MDfI VD: - 13,01316663 - 18. Property Designation: ADL 25647, ADL 25648 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 540179 y- 5971107 ' Zone- 4 TPI: x- 544652 y- 5970518 Zone- 4 Total Depth: x- 647176 y- 5973016 Zone- 4 11. Total Depth MD/TVD: - 13093/6668 - 19. DNR Approval Number: LONS 83-134 12. SSSV Depth MD/ VD: NIA 20. Thickness of Permafrost MDfrVD: 1586/1563 5. Directional or Inclination Survey: Yes EI (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: . 8785/6389 - 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23, CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 65.5 H-40 32 80 32 80 24 200sx Permafrost 10.75 45.5 K-55 31 2990 31 2631 13.75 1200sx Fondu, 250sx ASII 7 26 K-55 29 6580 29 4987 8.75 1039sx Class G, 42 bbls ASI 2 318 12.6 L-80 8743 13013 6359 6663 4 Slotted Liner 24. Open to production or injection? Yes E] No ❑ If Yes, list each interval open (MD/fVD of Top and Bottom; Perforation Size and Number; Date Perfd): PERFORATIONS @: 8739.13010 MD and 6356-6663 TVD „ UOIVIPLETION DATA (512414 RIFTED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDfTVD) 41/2 6357 6358/4842 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 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 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): INJECTOR WELL ONLY Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casinq Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): )-d0 Form 10-407 Revised 5/2017 i2�1b119 CONTINUED ON PAGE 2ORIGINAL only �•�z��y �ZBDiVi$��'' NOV 2 6 201 bmit ORIGINAL 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� . Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored (MDrTVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1586 1563 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 8881 6449 information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk A4 1A-04AL1PB1 12066 6654 TO 13093 6668 Formation at total de the Ku aruk A ' 31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical report, production or well test results, 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlin er Contact Name: James Haves Authorized Title: S Engineer Contact Email: James.C.Ha es co .com AuthorizedContact Phone: 265-6927 Signature: Date: // �/� 7 INST UCTIONS 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: Wel(Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 41b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1A -04A Final CTD Schematic 16" 65# H-40 shoe @80'MD 110-3/4" 46# K-55 shoel Cal 2990' MD 6580' MD KOP @ 8785' MD A -sand perfs 8848' - 8861' MD 8870' - 8916' MD F -11/2"12.6#L8 MO shoe @ 9160' D 4-1/2" Carrico DB nipple @ 503' MD (3.875" min ID) 4-1/2" 12.6# L-80 NSCT Tubing to surface Baker CMU Sliding Sleeve @ 6237' RKB (shifted closed 12/31/00) (3.875" min ID) Baker S-3 Packer @ 6289' RKB Camco DB landing nipple @ 6305' MD (3.813" min ID) Liner too Baker ZXP liner top packer @ 6358' MD Baker HMC liner hanger @ 6368' MD Camco DB Nipple @ 8533' MD (3.75" min ID) Camco Seai Nipple @ 8689' MD (3.75" min ID) TD= 12,066' MD OH Anchor— 10,401' MD 1A-04ALI TD= 13,093' MD TOL= 8743' MD BOL= 13,013' MD 2-3/8" slotted liner wl deployment sleeve KUP INJ WELL -NAME 1A -04A WELLBORE 1A -04A GOnOCOPhillip5 !N a, ibav Max Angle TD FM OgD Well[w�e APVUWI Wellbore SONS I cll°I MOIM1. Aci Blm lM1nB Alaska. Inc grvFp Nn 500292OFJtn N JUU 52959O 91610 NIPPLE I.. 11/1VN1p7M:aB AS Last Tag Vation ,n D.) AnnoDiane I Cunene.) I EnJDate abalones Dialsat By ........._.........................._................. .......... ..__......._.._. .ER,260 �eCOHDUCTORjDa.1 A]D TVBIND IMPINDEYENT; EpUass NIPPLEso11 SURFACE: alb21xg.1 s1EEVEC;.g31.3 PACKER, a�6 NIPPLE.ao.2 XOIRE40.6.3434 SMASSY 8,311.1 wwoOwA POST. .pW PRDOVLiNIN POSiya a3.P .ama XOTa.Rs.61s41Da- WKIP.K.]BSD IPERF:k0100e,9al. HPBD',.019.0 IPERF; 80]OD819.0 d UNER:% W.0$1hOa LaSt Tag: EKE 89020 linans.. Last Rev Reason AnnohHon E.... Wenbore11 4sI Mctl By Rev Reason: SET WHIPSTOCK 9112/2019 1A -04A mD3ilw Casing Strings Casing Deunptbn ODllnl I011nl TopinOBl sN Depth OKB1 Eel DepN TVDI.. Wbtena Grade Top Tareaa CONDUCTOR 15 1506 32.1 800 80.0 6500 H40 WELDED Casing Desn'so. Do (in) ID tin) Top (SOB) Bet Dean Inns) s«DgNh IWD) WI IL-Gratle Top Tb,eaa SURFACE 10314 9.95 31.2 2,9902 2631.1 45.50 K-55 BUTT Cuing Desnipecn DD ryp 10 (in) TopI 0) SNDeph OOKB) Sat DepM pVD)... 1VYtan B... emEe retaliated PRODUCTION POST ] 6.28 289 6,5800 2600 K-55 BTC SR casing oeecrpu=n ODPn) IO On) ropBue) sel Dept, taks) Sx Dapth ITVO,- W -(I a.. restated WINDOWA 7 6.00 6,4940 6,506.0 26.00 K-55 Casing Dencil,phon Do (in) ID IN) Tap Sea) set Dept, leak) Set Depth DVOT.. LWLen O... Deaths Top TMue LINER 412 3.96 6,345.6 9,160.0 12.60 L-80 NSCT Liner Details Nonan IO TPPOSQQ T=p"DMB) TWIMIC) 1.0. cam On) 8,345.8 PBR PBR TIEBACK EXT. 4.750 aS57.7 PACKER BAKER DtP LINER TOP PACKER 3.930 6,357.7 HANGER HMC HYDRAULIC LINER HANGER 3.958 8,5328 NIPPLE CAMEO DB NIPPLE 3.750 86890 NIPPLE CAMEO SEAL NIPPLE 3750 Tubing Strings Tubing Descrpuon stung ma... IDpnl Top lnKk) set Depth OL set Death( I.) l._W[(thin) Gmee Top Connection TUBING 4112 3.96 26.2 6,356.9 12.60 L-80 1BT Completion Details Top DVD) Topin« Nominal TopinKS, IMB) (°) IOm on, Co. in (in) 28.2 26.2 0.110 HANGER FMC HANGER 4062 503.1 503.1 0.00 NIPPLE CAMEO DB NIPPLE vv6 875- PACKING BORE 38]5 6,237.3 4,762.2 4821 SLEEVE -C BAKER CMU SLIDING SLEEVE (SHIFTED CLOSED 12/31/)0) 1875 6,283.6 4)911.3 48.46 PACKER BAKERS -3 PACKER, ]"x4.9 3.875 6,305.2 NIPPLE CAMCO DB NIPPLE 3.813 SW.9 SEAL STEM BAKER SEAL STEM 3.813 6,34].1 SEALASSY BAKER I9DA]GBH-22 SEAL ASSEMBLY-STABSINTOLINER PBRIPACKER 3.958 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) _ Top OKI) Top Min MKB) Top In=I (-) Des Cam Run Data ID (in) 2000. 200.0 ODDITUBINO IMPINGEMENT TUBINGIMPINGEMENT: DMA IFT FREELY AD3.]0"% 18 FT WHIPSTOCK, ABLE TO PASS WI BOX' GAUGE RING 902019 3.770 8,785.0 1 WHIPSTOCK 1 BAKER GEN H DELTA WON X 4-12" WHIP TO K, LEFT IN HOLE DAL= 12.9S ORIENTATION IS 1.8° LOHS. RA TAG AT 87924' MD 9/1 019 1.000 Perforations S Slots roplDKB) snot Den: Top(ND) BIm DVD) 1M=bM eM Dtl(6) Ifll(B) mKB) L1nkeU Zone Dale ) Type cot, 8,61.0 A5,1A 001 4.0 IPERF /ar SHD DP W- peasin9 7 .0 8,91 fi.0 AA, TA -04 00i?[XI 4.0 IPERF A8" SHD DP W° phasing Frac Summary suM1oa2 P,onsau Deslg'W Db) Prappanlin F«mefbn 9M 27172001 stgr slanoate Top DepN me) It gi&Da) UP11 m Rum System volocanlbbD ValslumtbM) 1 2102001 8848.0 8,9180 Notes: General S Safety Eno Date 1 A-tamn 1213112000 NOTE. SIDETRACKED WELL 812912009 NOTE: WAIVERED WELL -PACKER SET TOO HIGH 712912010 NOTE: View SCeematic w/ Alaska ScNemaec9.0 KUP INJ WELLNAME 1A -04A WELLBORE 1A-04AU ConoeoPhillipsdUKLA,"kl�,,ph'ell Altribub Max Angie TD ltlNameWellmre APYUWI Wellmre Stilus tll't MOh, Act BIm mMBt WBBka.lm 5 nn2 O2062160 IN' 606 90810/ 130930 le.l. n2vmm rosssue Last Tag v. 3uhin.ec lreeW Annomlon De,tp MB) End Date weumre Lar area ay Last Tell I 1A-04AL1 1jernall ...... ...... -------- ---- — Last Rev Reason AnnoMlon Em Dab WelePre Demitasse, Rev Reason CTD Lateral 11142019 1A-0 L1 jenm8 Casing Strings came Description OD (nt men) rop aker ser Depen MNBl set DeW RVDt... WULen(L..Gmda 11mined LINER 23/8 199 8,743.6 13,013.0 6,6632 4.60 L-80 STL Liner Details xommalm Top meet rap lrVDl mxet Top Incl l°l mm Des coat in 8743.5 6,359.0 4451 Uam- YMENT Shorty Deployment Sleeve 1.920 SLEEVE JMO- 11,0)1.3 6,591.6 8355 D L Y'sN 237Y, 6#70,ST-L SICam.h Liner 1.92U SLEEVE Perforations & Slots shat o.n rap mxel am msat mNa) mlcalunxadmna Dere l rya coat 873903,01008°3558BtA-10/15 019 L TTUBINGIM04ALl Frac Summary sheDNe proppentoesl0nedpb) loopWnt In Formhon(ml Nlppr 301.1 2/17/2001 sree sb2 D91a Top Depth mNBI BM mKBt Link to Fluq SpMm VOI CIeanlmQ Val Slurtylbap 1 Z1Z2001 8,848.0 8,916.0 Notes: General & Safety End D's' Ann aarim 111412019 NOTE'. View Schematic w/ Alaska Schematic lDO SURF rah2 ,aan.2� WINOW o' 6p&.OQ98. 0\ ° PRODUCTICNts aMT. sesso SLOlS:eMO-13,0100 Drtare 9.14a.S13.0 3a r Operations Summary (with Timelog Depths) IA-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stars Time End Time Dur(hr) Phase Op Cade Acwily Code Time P-T-X Operation (flKB) Entl Dept (ftKB) 10/1/2019 10/1/2019 2.00 MIRU MOVE RURD P Complte RD checklist, secure stack, 0.0 0.0 06:00 08:00 secure stairs & landings, disconnect PUTZ, Peak trucks slow getting to rig as roads are torn up on Prudhoe side post Parker 242 rig move 10/1/2019 10/1/2019 1.00 MIRU MOVE RURD P Peak trucks arrive at 0800, load up 0.0 0.0 08:00 09:00 shop, PJSM for move 10/1/2019 10/1/2019 1.70 MIRU MOVE MOB P Rig up to sows & pull pits & sub off 0.0 0.0 09:00 10:42 well, PU herculile & sills, jeep up, clean up pad 10/1/2019 10/1/2019 1.80 MIRU MOVE MOB P Move from 1C-Pad to 1A-Pad 0.0 0.0 1042 1230 10/1/2019 10/1/2019 2.90 MIRU MOVE MOB P Lay mat, herculite, & sills at well-head, 0.0 0.0 1230 1524 spot sub & pits over well 10/1/2019 10/1/2019 3.00 MIRU MOVE RURD P Begin RU checklist, drop stairs, MU 0.0 0.0 1524 1824 scaffolding in cellar, spot addional mats around rig, move shop & half- way house to 1A-Pad, 10/1/2019 10/1/2019 2.60 MIRU WHDBOP NUND P Continue RU checklist, MU tiger-tank 0.0 0.0 1824 21:00 hard-line, NU BOP, MU MP line, grease Romeo's & Bravo's Rig Accept: 2100 hrs 10/1/2019 10/2/2019 3.00 MIRU WHDBOP RURD P Complete RU, install fusible cap on 0.0 0.0 21:00 00:00 SSV (install 90 to aid in cap installation), grease swab, tango's, & master, lower test jnts in stack greased up, close 2" rams, verify space out on new tapered jnt for 4- 1/6" tree. 10/2/2019 10/2/2019 0.50 MIRU WHDBOP BOPE P Chase down leak in stack to tree 0.0 0.0 0000 00:30 adapter flange. Inspect and tighten nuts. 10/2/2019 10/2/2019 1.50 MIRU WHDBOP BOPE P Test BOPE 250 psi low 13700 psi 0.0 0.0 0030 0200 high - test witness waived by Adam Earl - AOGCC Tests 1-4 good 10/2/2019 10/2/2019 3.00 MIRU WHDBOP BOPE T Trouble W test 5, leaking needle valve 0.0 0.0 0200 0500 found and replaced, reatempt with no sucess, trouble shoot leak path, found leaking test pannel bleeader leaking. 10/2/2019 10/2/2019 4.50 MIRU WHDBOP BOPE P Good test#5- through draw down 0.0 0.0 05:00 09:30 Skid cart, stab injector Iner reel valve and stripper 10/2/2019 10/2/2019 0.80 MIRU WHDBOP RGRP P Blind off R2 0.0 0.0 09:30 10:18 10/2/2019 10/2/2019 0.50 MIRU WHDBOP RURD P Blow down surface lines 0.0 0.0 10:18 10:48 Fluid packcoil 10/2/2019 10/2/2019 0.40 MIRU WHDBOP RURD P Pressure test CTC to 4000 psi - good 0.0 0.0 1048 11:12 10/2/2019 10/2/2019 0.50 MIRU WHDBOP RURD P PT PDL's and TT line - good 0.0 0.0 11:12 11:42 10/2/2019 10/2/2019 1.60 PROD1 WHPST PULD P PU and PD BHA#1, 0.6°Motor, DSM 0.0 74.0 11:42 1318 2.80" no go " 1000 psi under th master valve, IA 0 psi, OA 236 psi 10/2/2019 10/2/2019 1.90 PRODt WHPST TRIP P RIH turning well over to seawater. 74.0 8,393.0 1318 1512 10/2/2019 10/2/2019 0.20 PROD1 WHPST DLOG P Tie in for-5.5' correction. 8,393.0 8,436.0 15:12 1524 1 I Page 1116 ReportPrinted: 10/16/2019 Operations Summary (with Timelog Depths) 1A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth start Time End Time Dur (hr) Phase W Cade Acdvfty Code Time PJA Opemon (fIKB) End Depth (WB) 10/2/2019 10/2/2019 0.30 PRODt WHPST DISP P Continue to RIH, PU Wt 36 k lbs @ 8,436.0 8,787.0 15:24 15:42 8616'. start duovis down the coil Dry lag pinch point @ 8787'- TOWS @ 8785' 10/212019 10/2/2019 1.00 PROD1 WHPST DISP P Displace well to duovis lite milling fluid 8,436.0 8,737.0 15:42 16:42 w 1% 776 Close EDC. 10/212019 10/212019 0.60 PROD1 WHPST TRIP P Blow down out micro motion to Gear 8,737.0 8,787.6 16:42 17:18 up interference. Set rates, RIH, CT 3680 psi @ 1.77 bpm in and 1.68 bpm out, 11.06 EMW at the window, BHP 3671 psi, WH 471 psi, IA 0 psi, OA 247 psi, Free spi diff 434 psi, RIH Wt 12.2 k lbs. 10/2/2019 1012/2019 2.20 PROD1 WHPST WPST P Continue Milling Window, 1.81 bpm at 8,787.6 8,790.0 17:18 19:30 3,383 psi, Diff --516 psi, WHP=447, BHP=3,636, IA=O, OA=271 CTSW=13.4 k, DHWOB=0.68 k 10/2/2019 10/2/2019 0.75 PROD1 WHPST WPST P Milling ahead, 1.81 bpm at 3,903 psi, 8,790.0 8,791.0 19:30 20:15 Diff -546, WHP=438, BHP=3,622, IA=O, OA=271 10/2/2019 10/2/2019 1.20 PROD1 WHPST WPST P Milling ahead, 1.81 bpm at 3,882 psi, 8,791.0 8,791.9 20:15 21:27 Diff -538, WHP=434, BHP=3,631, IA=O, OA=274 10/212019 10/2/2019 1.00 PROD1 WHPST WPST P Milling ahead, indicating mid -point, 8,791.9 8,792.9 21:27 22:27 DHWOB dropped off 2.9 k - 1.3 k 10/212019 10/3/2019 1.55 PROD1 WHPST WPST P Mills exited casing, continue milling 8,792.9 8,794.8 22:27 00:00 1 1 1.3' full length of tray 10/312019 10/3/2019 0.65 PROD1 WHPST WPST P Milling ahead, allowing string reamer 8,794.8 8,795.6 00:00 00:39 to fully exit casing, 1013/2019 10/3/2019 2.20 PRODt WHPST WPST P Drill rat hole @ 7-10 fph, 2.6 k 8,795.6 8,810.0 00:39 02:51 DHWOB, 12.5-14 k CTSW, 1.80 bpm at 4,169 psi, Diff --754 psi, WHP=482, BHP=3,671, IA=O, OA=290 101312019 10/3/2019 2.80 PRODt WHPST REAM P PUW 36 k, perform reaming pass HS, 8,810.0 8,779.0 02:51 05:39 30` LOHS, 30` ROHS, and 180° ODTF, Dry drift, clean, confirm TD, one last reaming pass at HS on the way up while pumping TO sweeps to the bit. 10/3/2019 10/3/2019 1.60 PROD1 WHPST TRIP P POOH turning the bit chasing sweeps 6,779.0 59.0 05:39 07:15 to surface. 10/3/2019 10/3/2019 1.20 PROD1 DRILL PULD P PUD BHA#1, bit 2.80 No go 59.0 0.0 07:15 08:27 10/3/2019 10/3/2019 0.60 PROW DRILL CIRC P jet stack 59.0 0.0 08:27 09:03 10/3/2019 10/3/2019 1.20 PROD1 DRILL PULD P PPD BHA #2, build drilling assmbly, 0.0 72.0 09:03 10:15 1.2 "AKO w RB BHC dynamus. 10/312019 10/3/2019 1.50 PROD1 DRILL TRIP P RIH 72.0 8,390.0 10:15 11:45 10/312019 10/3/2019 0.20 PROD1 DRILL DLOG P Tie into the K1 for a + 9.5' correction. 8,390.0 8,423.0 11:45 11:57 1013/2019 10/3/2019 0.20 PROD1 DRILL TRIP P PU Wt 33 k lbs, Close EDC, contiune 8,423.0 8,810.0 11:57 12:09 in hole 1013/2019 10/312019 1.60 PROD1 DRILL DRLG P Ct 4267 psi, at 1.88 bpm in and 1.88 8,810.0 8,955.0 12:09 13:45 bpm out, fre spin 533 psi, BHP 3664 psi, WH 478 psi, IA 301 psi OA 270 psi, targeting holding 11.1 emw at the window. CT Wt 14.2 lbs, WOB 2 k lbs 10/3/2019 1013/2019 0.30 PROD1 DRILL WPRT P PU to log K1 and RA lag. 8,955.0 8,394.0 13:45 14:03 1 Page 2116 ReportPrinted: 10/16/2019 Operations Summary (with Timelog Depths) 1 A-04 6 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tura End Time Dur (ho Phase Op Code AcpiMy Cade Time P -T -X Operation (MB) End Depth (WB) 10/3/2019 10/3/2019 0.10 PROD1 DRILL DLOG P Tie into the K1 for a +1' correction. 8,394.0 8,413.0 14:03 14:09 10/312019 10/3/2019 0.10 PROM DRILL TRIP P RIH to log RA tag. 8,413.0 8,800.0 14:09 14:15 10/3/2019 1013/2019 0.10 PROD1 DRILL DLOG P Log RA tag @ 8791.5, -update 8,800.0 8,830.0 14:15 14:21 jewelry sheet. 10/3/2019 1013/2019 0.10 PROD1 DRILL TRIP P RIH 8,830.0 8,955.0 14:21 14:27 10/3/2019 10/3/2019 2.55 PROD1 DRILL TRIP P CT 4296 psi @ 1.88 bpm in and 1.83 8,955.0 9,111.0 14:27 17:00 bpm out, free spin 512 psi, Annular 3785 psi, WH 540 psi, 11.3 EMW at the window. CT Wt 12.5 k Ibs, WOB variable to 3.5 k Itis 10/3/2019 10/3/2019 2.50 PROM DRILL DRLG P Continue drilling build section, 1.8 9,111.0 9,360.0 17:00 19:30 bpm at 4,444 psi, Diff=553, WHP=568, BHP=3,885, IA=355, OA=303 1013/2019 10/3/2019 2.00 PROD1 DRILL TRIP P TD build section, PUW 37 k, hesitate 9,360.0 72.2 19:30 21:30 1 1 1 for sweep, POOH 101312019 10/3/2019 1.50 PROD1 DRILL PULD P At surface, PUDILD build assembly 72.2 0.0 21:30 23:00 10/3/2019 1014/2019 1.00 PROD1 DRILL PULD P PU/PD, Lateral drilling assembly 0.0 78.3 23:00 00:00 10/4/2019 10/4/2019 0.30 PROD1 DRILL PULD P Fiinish PD lateral drilling assembly 78.3 78.3 00:00 00:18 1014/2019 1014/2019 1.50 PROD1 DRILL TRIP P MU lubicator, tag up, reset counters, 78.3 8,390.0 00:18 01:48 RIH, surface test agitator (good -test) 10/4/2019 1014/2019 0.20 PRODt DRILL DLOG P Log formation for depth control (-6.0'), 8,390.0 8,422.0 01:48 02:00 PUW 36 10/42019 10/4/2019 0.30 PROD1 DRILL TRIP P Continue IH, close EDC 8,422.0 9,360.0 02:00 02:18 10/4/2019 10/4/2019 1.60 PROM DRILL DRLG P OBD, 1.9 bpm @ 4,860 psi, Dl"- 60, 9,360.0 9,540.0 02:18 03:54 WHP=662, BHP=4,022, IA=313, OA=278, PUW 38 k 10/4/2019 10/4/2019 1.10 PRODi DRILL DRLG P Drilled into something hard ROP 9,540.0 9,550.0 03:54 05:00 dropped to - 7 R/hr CT 4653 psi, @ 1.85 bpm in and 1.83 bpm out, free spin 1029 psi, BHP 4006 psi, targeting 11.8 ppg EMW, WH 735 psi, IA 369 psi, OA 307 psi. PU's 38 k lbs 10142019 10/4/2019 3.20 PRODi DRILL DRLG P Drilling ahead, 10 k Ct W, 2-3 k WOB, 9,540.0 9,592.0 05:00 0812 ROP - 7 R/hr OBD, 4827 psi, 1.83 bpm in and 1.80 bpm out, BHP 4037 psi, 11.81 ppg EMW @ the window, 11.98 ppg @ the bit. 9,554 PU Wt 38 k lbs Broke out temporarily, back in it at low ROP's 10/4/2019 1014/2019 2.00 PROM DRILL TRIP P POOH for new bit. 9,592.0 78.0 08:12 10:12 WOB to -2.6 k Itis @ 9,018' with motor work 10/4/2019 10/4/2019 1.10 PROD1 DRILL PULD P PUD BHA #3, 78.0 0.0 10:12 11:18 Dropped of A3 bit 10/4/2019 10/412019 1.10 PROM DRILL PULD P PD BHA #4, same BHA, picked up 0.0 78.0 11:18 12:24 Dynamus bit. Checked pack offs -good 10/412019 10/4/2019 1.50 PROD1 DRILL PULD P RIH, 78.0 8,389.0 12:24 13:54 10/4'2019 10/4/2019 0.20 PROD1 DRILL PULD P Tie into the K1 for a -8' correction 8,389.0 8,419.0 13:54 1406 Page 3116 Report Printed: 1 011 612 01 9 Operations Summary (with Timelog Depths) 1A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time our (hr) Phase Op Code Acs0ty Code Time P -T-% Operation (ftm) End DOW (WIR) 10/4/2019 10/4/2019 0.20 PROD1 DRILL PULD P Continue to RIH, park and close EDC, 8,419.0 9,592.0 14:06 14:18 run through the window - clean, Set down in the build, high WOB. Multiple places from 8856'- 8904'. Continue in hole. 10/4/2019 10/4/2019 2.75 PROD1 DRILL DRLG P CT 4730 psi @ 1.89 bpm in and 1.87 9.592.0 9,616.0 1418 17:03 bpm out, free spin 819 psi, BHP 4040 psi, 11.8 ppg EMW at he window, 12.0 at the bit. WH 686 pis, IA357 psi, OA 300 psi. CT Wt 10.9 k lbs, WOB 3 k lbs. 10/4/2019 10/4/2019 1.40 PROD1 DRILL DRLG P Continue Drilling Ahead, 1.91 bpm at 9,616.0 9,645.0 17:03 18:27 4,813 psi, Diff=872, WHP=682, BHP=4,024, IA=39, OA=320 10/4/2019 10/4/2019 2.80 PRODt DRILL DRLG P Broke out of Ankerile, continue drilling 9,645.0 10,000.0 18:27 21:15 ahead, 1.9 bpm at 4,792 psi, Diff -854 psi, WHP=705, BHP=4,018, IA=390, OA=320 10/4/2019 10/4/2019 0.30 PROD1 DRILL WPRT P Wiper up hole to the EOB 9,360', 10,000.0 9,360.0 21:15 21:33 PUW 38 k 10/4/2019 10/4/2019 0.30 PROD1 DRILL WPRT P Wiper back in hole, RIW 14 k 9,360.0 10,000.0 21:33 21:51 10/4/2019 10/4/2019 1.70 PROD1 DRILL DRLG P BOBD, 1.9 bpm at 4,864 psi, Diff --866, 10,000.0 10,221.0 21:51 23:33 WHP=703, BHP=4,092, IA=397, OA=323 10/4/2019 10/4/2019 0.20 PROD1 DRILL WPRT P PUH, PUW 36 k, BHA wiper 10,221.0 10,221.0 23:33 23:45 10/4/2019 10/5/2019 0.25 PROD1 DRILL DRLG P BOBD, 1.9 bpm at 4,966 psi, Diff=867 10,221.0 10,223.0 23:45 00:00 psi, WHP=700, BHP=4,119, IA=401, OA=325 10/5/2019 10/512019 2.00 PROD1 DRILL DRLG P OBD, 1.9 bpm at 5,161 psi, Diff -1,094 10,223.0 10,265.0 00:00 02:00 psi, WHP=689, BHP=4,087, IA=402, OA=328 10/5/2019 10/5/2019 0.15 PROD1 DRILL DRLG P Hard spot, PUH, PUW 35 k 10,265.0 10,265.0 02:00 02:09 10/5/2019 10/5/2019 4.50 PROD1 DRILL DRLG P BOBD, 1.87 bpm at 4,832 psi, 10,265.0 10,400.0 02:09 06:39 Diff=822 psi, WHP=699, BHP=4,099, IA=406, OA=327 10/5/2019 10/5/2019 0.35 PRODt DRILL WPRT P PU Wt 38 k lbs, PUH on wiper #2 10,400.0 9,407.0 06:39 07:00 10/5/2019 10/5/2019 0.35 PRODt DRILL WPRT P RBIH, 9,407.0 10,400.0 07:00 07:21 0.3 bbls cuttings returned on the trip. 10/5/2019 10/5/2019 0.40 PROD1 DRILL DRLG P CT 4122 psi @ 1.89 bpm in and 1.80 10,400.0 10,498.0 07:21 07:45 bpm out, free spin diff 868 psi, BHP 4122 psi, 11.8 ppg EMW @ the window, 12.2 ppg @ the bit. RIH Wt 12.5 k Itis, OBD, 8.5 k Ibs, WOB 2.1 k lbs. Average ROP over interval - 245 fph 10/5/2019 10/5/2019 5.10 PROD1 DRILL DRLG P Back in ankerhe, ROP dropped OBD 10,498.0 10,541.0 07:45 12:51 CT 5151, 1.90 bpm in, on bottom diff 986 psi, CT wt 7.9, WOB 2.9 k lbs, Average ROP over interval - 8.43 fph 10/5/2019 10/5/2019 2.40 PROD1 DRILL DRLG P stall, PU W141 k lbs 10,541.0 10.569.0 12:51 15:15 Average ROP over interval - 11.6 fph 11.6 10/5/2019 10/5/2019 0.60 PROD1 DRILL DRLG P Broke out of ankerite, drill ahead 10,569.0 10,699.0 15:15 15:51 1 Average ROP over interval - 216 fph Page 4116 ReportPrinted: 10/16/2019 Operations Summary (with Timelog Depths) IA -04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Time Dur (hp Phase Op Cade Activity code 7me P -T-% Operation (nKB) End Depth (hKB) 10/5/2019 10/5/2019 2.15 PRODt DRILL DRLG P Found Fault#2. 10,699.0 10,749.0 15:51 18:00 CT 5446 psi @ 1.90 bpm in and 1.90 bpm out, CT Wt 0.83, WOB 3 k lbs, WH 696 psi, IA 430 psi, OA 335 psi. BHP4155 psi, 11.8 ppg EMW @ the windwo, 12.2 at the bit. @ 10,0709 and 16:20 turned down targeting 84.85 °. PU 15' accross the falut @ 110711642 k lbs. 10/5/2019 1015/2019 1.80 FROM DRILL DRLG P Continued didling ahead, 1.9 bpm at 10,749.0 10,850.0 18:00 19:48 5,184, Diff -921 psi, WHP=665, BHP=4,185, IA=438, OA=336 10/5/2019 1015/2019 1.90 PRODi DRILL WPRT P Wiper up hole to the window, PUW 41 10,850.0 8,797.6- 19:48 21:42 It, started pulling heavy @ 9,044'45 k CTSW, DHWOB -2.0 k, unable to turn around, rotate TF as drilled continue PUH -7.0 k DOWOB, DHWOB fail off, continue POOH, counlinue pulling through the window clean, jog 8695'- 8,775', circulate bottoms up. 10/5/2019 10/5/2019 0.20 PROD1 DRILL DLOG P Log the RA marker (+95) 8,797.0 8,954.0 21:42 21:54 10/5/2019 1015/2019 1.35 PRODII DRILL WPRT P Wiper back in hole, RIW 14 It, seen 8,954.0 10,756.0 21:54 23:15 bobble at 9,043', set down 9,832', PUW 38 k, PUH to 9,730', RBIH with reduced rate 1.3 bpm with as DTF clean, continue IH, set down again 10,732', work pipe. PUW 40 k, lowered pump rate to 0.75 bpm and made it through clean, continued IH to next set down 10,756', PUW 39 k 1015/2019 10/6/2019 0.75 PRODi DRILL WPRT P PUH, circulate bottoms up, 10,756.0 10,311.0 23:15 00:00 10/6/2019 10/6/2019 0.25 PROD1 DRILL WPRT P Continue wiper back in hole clean 10,311.0 10,850.0 00:00 00:15 1016/2019 10/6/2019 0.75 PROD1 DRILL DRLG P BOBD, 1.88 bpm at 5,085 psi, 10,850.0 10,901.0 00:15 01:00 Diff --886, WHP=677, BHP=4,202, IA=426, OA=328 1016/2019 10/6/2019 2.00 PRODi DRILL DRLG P PUH, PUW 47 k, BOBD, 1.88 bpm at 10,901.0 11,063.0 01:00 03:00 5,085 psi, Diff -886, WHP=677, BHP=4,202, IA=426, OA=328, PU's 10,930', 10960', and 11022', PUW=44 k 10/6/2019 1016/2019 3.10 PRODi DRILL DRLG P OBD, 1.88 bpm at 5,240 psi, 11,063.0 11,250.0 03:00 06:06 Diff -1,070 psi, WHP=639, BHP=4,234, IA=435, OA=334, PU's 11,065', 11,080', and 11086', PUW 40 k 10/6/2019 1016/2019 0.30 PROD1 DRILL WPRT P PU Wt 45 k lbs, PUH on wiper #11, 11,250.0 10,452.0 06:06 06:24 dragging low side Start pulling heavy @ 10,782' @ 10,740', Pull into 55k CT Wt & -4.6 k WOB, RBIH, stack out w 6k lbs WOB PUH, motor work and slight over pulls until 10,674' Back to clean pulling Ct Wt 39 k lbs, 0 WOB. Page 5116 ReportPrinted: 1011612019 Operations Summary (with Timelog Depths) 1A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (ho Phase Op Code Anviy Code Time P -T -A Operation (fiKB) End Depth (XKB) 10/6/2019 10/6/2019 0.50 FROM DRILL WPRT P RBIH 10,452.0 11,250.0 06:24 06:54 Proactively cut pump rate to 0.4 bpm @ 10,690' Continue in hole across fault #2 @ 50 f imin - clean S/D 10,955' PU, RBIH, S/D again shallower, repeat, Cut pump rate to 1.4 bpm RIH. 0.26 bbls of cuttings returned on the trip 10/6/2019 10/6/2019 2.10 PROD1 DRILL DRLG P CT 5144 psi @ 1.87 bpm in and 1.86 11,250.0 11,324.0 0654 0900 bpm out, Free spin diff 1085 psi, WH 643 psi, IA 428 psi, OA 331 psi. BHP 4233 psi, 11.8 ppg EMW @ the window, 12.4 ppg @ the bit. OBD Ct Wt -3 k lbs, WOB 1.7 k lbs. 10/6/2019 10/6/2019 3.30 PROD1 DRILL DRLG P Drill into Ankerite slow ROP's. 11,324.0 11,358.0 0900 12:18 Swap mud to system # 3. New mud at the bit 11,342'. Retired system #2 @ 1982' drilled w 0.95% DS New mud, CT 4670 psi @ 1.86 bpm in 1.82 bpm out, BHP 4281 psi, 11.8 ppg EMW at the window 12.6 ppg @ the bit. Average ROP over interval = 10 f lhr 10/6/2019 10/6/2019 0.30 PROD1 DRILL DRLG P Broke out, 11,358.0 11,378.0 12:18 12:36 CT At -3.5 k lbs, WOB 1.3 k lbs Average ROP over interval = 66 it/hr 10/6/2019 10/6/2019 4.40 FROM DRILL DRLG P Drill back into Ankerite 11,378.0 11,500.0 12:36 17:00 CT 4653 psi @ 1.88 bpm in and 1.88 out, free spin 874 psi, BHP 4266 psi, WH 678 psi, IA 383 psi, OA 303 psi. OBD Ct -4 k lbs, WOB 2.9 k lbs. Clean PU Wts 41 k lbs. Ratty drilling in and out of ankerite. 10/6/2019 10/6/2019 2.75 FROM DRILL DRLG P Continue Drilling AL1 lateral 1.86 bpm 11,500.0 11,650.0 17:00 19:45 at 4,886 psi, Diff=897, WHP=739, BHP=4,360, IA=414, OA=322 10/6/2019 10/6/2019 0.50 FROM DRILL WPRT P Wlper up hole to 10,900', PUW 45 k 11,650.0 10,900.0 19:45 2015 10/6/2019 10/6/2019 0.50 FROM DRILL WPRT P Wiper back in hole, trouble getting 10,900.0 11,650.0 20:15 20:45 turned around work pipe, lower pump rate, RIH slowly back towords bottom. 15-30 fpm. 10/6/2019 10/6/2019 0.50 FROM DRILL DRLG P BOBD, 1.8 bpm at 4,788 psi,Diff=874, 11,650.0 11,663.0 20:45 21:15 WHP=723, BHP=4,324, IA=417, OA=324 10/6/2019 10/6/2019 1.50 FROM DRILL DRLG P PUH, PUW 44 k, lower pump rate, DD 11,663.0 11,734.0 21:15 22:45 trying to drop INC, 1.5 bpm at 4,098 psi, Diff=744, WHP=771, BHP=4,378, IA=417, OA=324, continue drilling ahead 10/6/2019 10/7/2019 1.25 PROD1 DRILL DRLG P PUH, PUW 44 k, increase pump rate 11,734.0 11,681.0 22:45 00:00 to 1.9 bpm at 4,955 psi, Diff=884. WHP=693, BHP=4,398, IA=416, OA=324, continue drilling ahead 10/7/2019 10/7/2019 0.60 PROD1 DRILL DRLG P OBD, 1.87 bpm at 5,085 psi, Diff=890, 11,681.0 11,762.0 00:00 00:36 WHP=728, BHP=4,444, IA=425, OA=324 Page 6116 Report Printed: 10/16/2019 Operations Summary (with Timelog Depths) 1 A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log oe Sten Depth SMnM End nM Dur hr Dur(hr Phase Op Cate ActiNty Coda Time P -T -X Operetlon (ft End DePih (ftKa) 10/7/2019 10/7/2019 0.50 FROM DRILL DRLG P PUH, PUW 45 k, BOBD, 1.87 bpm at 11,762.0 11,779.0 00:36 01:06 4,986 psi, Diff -871, WHP=726, BHP=4,443, IA=425, OA=324 10/7/2019 10/7/2019 2.00 FROM DRILL DRLG P PUH, PUW 43 k, BOBD, 1.87 bpm at 11,779.0 11,865.0 01:06 03:06 4,923 psi, Diff -835, WHP=735, BHP=4,440, IA=424, OA=326 10/7/2019 10/7/2019 1.00 FROM DRILL DRLG P OBD, 1.85 bpm at 5,009 psi, Diff --934, 11,865.0 11,885.4 03:06 04:06 WHP=701, BHP=4,437, IA=436, OA=332 10/7/2019 10/7/2019 1.90 PROD1 DRILL DRLG P OBD, 1.85 bpm at 5,026 psi, Diff --880, 11,885.4 11,954.0 04:06 06:00 10/7/2019 10/7/2019 3.00 PROD1 DRILL DRLG P Crew change PU, 40 k lbs 11,954.0 12,048.0 06:00 09:00 CT 5039 psi @ 1.87 bpm in and 1.84 bpm out, free spin 879 psi, BHP 4436 psi targeting 11.8 ppg EMW @ the window - 12.86 ppg @ the bit. WH/IA,/0A = 715/442/333 psi OBD, Ct Wt -1.1 k lbs, WOB 1.1 k lbs. pump 5x5 sweep. Average ROP over interval - 10/7/2019 10/7/2019 1.10 FROM DRILL WPRT P PU W148 k lbs, PUH on wiper # 3 12,048.0 9,360.0 09:00 10:06 long wiper to window for tie in chasing sweeps. 10,960', -2.6k lbs WOB with motor work - Fault #4 - isolated 10,920' started seeing - WOB and motor work that peaked @ 10,892' and was clean by 10,886'. Pulled into a quick hard stop W 100 % pack off @ 10,704', 55 k CT Wt -8.5 k WOB, worked pipe twice to -8 CT Wt & 8 k WOB down to 64 k CT wt and - 11 k WOB up. Pulled free continued up hole, 10/7/2019 10/7/2019 0.40 PROD1 DRILL WPRT P Pull through build section chasing 9,360.0 8,757.0 10:06 10:30 sweeps @ 9053' WOB tug to -3 k lbs, pulled clean @ 8994' 10/7/2019 10/7/2019 0.20 PRODi DRILL CIRC P Circulate bottoms up chasing sweeps 8,767.0 8,395.0 10:30 10:42 to surface 10/7/2019 10/7/2019 0.40 PRODi DRILL DLOG P Start logging @ 8395' to low, miss tie 8,395.0 8,416.9 10:42 11:06 in, PUH to 8367' for a redo. Tie into the K1 for+ 22' correction 10/7/2019 10/7/2019 0.40 FROM DRILL DLOG P RIH lifting last sweep to surface, park 8,416.9 8,774.0 11:06 11:30 at 8774 MD bit depth 6250 TVD pressure sensor depth. Trap 11.7 ppg EMW and observe pressure. time pressure EMW 0 3804 11.73 1 3800 11.71 2 3797 11.71 3 3794 11.70 4 3790 11.68 5 3785 11.67 Page 7116 ReportPrinted: 1011612019 Operations Summary (with Timelog Depths) 1A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stag Tme End Time Dur (hr) Phase Op Code Activity Gods Time P -T -X Operetlon (MB) End Depth (8Ke) 10/7/2019 10/7/2019 1.50 PROD1 DRILL TRIP P PU Wt 35 k lbs, bypass high pressure 8,774.0 12,055.0 11:30 13:00 screens, RIH Stacked out W CT and WOB @ 9,808' where we dipped the A5. Pump 2 ppb beads in active mud - started to exit the bit @ 10,570' Proactively cut pump rate to 0.4 bpm @ 10,690', - slight WOB bobbles Large WOB spike @ 10,950 - Fault A Slack out CT Wt @ 11,030'- possible A5 /A4 interface Stack out @ 11,891' when increasing from 1.4 bpm to drill rate, cut rate continue in hole 10/7/2019 10/7/2019 0.30 FROM DRILL DRLG P CT 5126 psi @ 1.87 in and 1.86 out, 12,055.0 12,066.0 13:00 13:18 free spin 879 psi, BHP 4555 psi, OBD, CT Wt -2 k lbs, WOB 1.3 k lbs. 10/7/2019 10/7/2019 0.50 PROM DRILL WPRT T Pick up because of WOB and motor 12,066.0 11,899.0 13:18 13:48 work falling off, PU Wt 42 k lbs Pack off event when atempting to RBIH. Work pipe, flow out returned. PUH, circulating. RBIH, attempt to drill, similar pack off event, PUH, circulation slowly returned. atempt to RBIH, same issues. 10/7/2019 10/7/2019 1.10 FROM DRILL WPRT T PUH slowly timing out sweeps, consult 11,899.0 9,408.0 13:48 14:54 with town. Pulling for sidetrack billet. Start dragging neg WOB @ 10,800 - pull dean @ 10,670' 10/7/2019 10/7/2019 0.30 PROD1 DRILL WPRT T RBIH with sweeps staged in coil. 9,408.0 10,448.0 14:54 15:12 WOB spikes @ 9826 - 9846'- A5/A6 interface 10/7/2019 10/7/2019 2.90 PROD1 DRILL WPRT T PUH chasing sweeps up hole cleaning 10,448.0 78.3 15:12 18:06 up area for billet. Pre load PDL for billet. 9015', pulled into a pack off event CT Wt to 50 k lbs, -9 k WOB. Work pipe, pull free with returns. Continue to surface chasing additional sweeps. Perform jog back in hole 500', continue POOH 10/7/2019 1017/2019 1.20 FROM DRILL PULD T At surface, PUD/LD drilling assembly 78.3 0.0 18:06 19:18 BHA#4 10/7/2019 10(7/2019 1.30 PROD? STK PULD T PU/PD OH Anchored Billet setting 0.0 73.0 19:18 20:36 tools. 10/7/2019 10/7/2019 1.75 PROD1 STK TRIP T RIH, with Open Hole Anchored Billet 73.0 8,390.0 20:36 22:21 w/Baker #10 J setting tool, with open EDC, tripping speed 90 fpm slowing down for Jewelry. 1017/2019 10/7/2019 0.20 PROD1 STK DLOG T Log formation K1 for depth control (- 8,390.0 8,421.0 22:21 22:33 1 1 1 1 1 17.0), close EDC 10!7/2019 10/7/2019 1.10 FROM STK TRIP T Continue IH w/Billet 8,421.0 10,411.8 22:33 23:39 8,800' - 1 k 8,965'- 2.2 k 9,0331- 1.5 k 9,823'- 0.7 k Page 8116 ReportPrinted: 10/16/2019 Operations Summary (with Timelog Depths) 1 A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth StartTime End Time our (h0 Phase Op Code Achvity Code Tone P -T -X Operation (fixe) End Depth (WB) 10/7/2019 10/8/2019 0.35 PRODi STK WPST T PUW 38.5k, RBIH to setting depth 10,411.8 10,400.0 23:39 00:00 10,411.8', PU to 35 k, increase pump trips, bring pump up to shear pressure in stages 2,000 psi, montior DHWOB 0.4 k, 2,500 psi, 0.74 k, 2,800 psi, 0.84 k, 4,200 psi, 3.6 k, set down additional weight 1.2 k, PUW 35 k 10/8/2019 10/8/2019 2.00 PRODt STK TRIP T Continue POOH w/open EDC 10,400.0 72.8 00:00 02:00 10/812019 10/8/2019 0.80 PROD? STK PULD T At surface, PUD/LD setting tools, BHA 72.8 0.0 02:00 02:48 #5 10/8/2019 10/8/2019 0.50 PROD1 DRILL CTOP T Perform bi-weekly Function Test 0.0 0.0 02:48 03:18 10/8/2019 10/8/2019 1.10 PROD1 STK PULD T PU/PD kickoff/drilling assembly, BHA 0.0 78.3 03:18 04:24 #6 10/8/2019 10/8/2019 1.70 PRODt STK TRIP T RIH with Kickoff/Drilling assembly, 78.3 8,400.0 04:24 06:06 BHA #6 Park and Gose EDC Shallow test agitator 1.6 bpm - 720 psi 1.9 bpm - 995 psi 10/8/2019 10/8/2019 0.20 PROD1 STK DLOG T Tie into the K1 for a -7' correction. 8,400.0 8,417.5 06:06 06:18 10/8/2019 10/8/2019rO.701PROD1 STK TRIP T Continue in hole, 8,417.5 10,402.5 06:18 07:00 PU Wt 37 k lbs RIH and dry lag TOB @ 10,402.5'10/8/2019 10/8/2019 PROD1 STK TRIP T PU Ct Wt 38 k lbs, Set rate, RIH, hole 10,402.5 10,107.0 07:00 07:18 started to pack off PU, circulating, returns stabilized near 1 for 1. Consult w town engineering, 10/8/2019 10/8/2019 PROD1 STK TRIP T RBIH to side track off billet. 10,107.0 10,401.0 07:18 07:3010/8/2019 10/8/2019 PROD1 STK KOST T CT 5100 psi @ 1.87 bpm in and 1.87 10,401.0 10,402.0 07:30 08:30 bpm out free spin 1100 psi, WH 674 psi, IA 360 psi, OA 300 psi, BHP 4170 11.8 ppg EMW 12.2 @ the bit. CT Wt 14 k bs, WOB 1 k lbs Motor work @ 10401' lel initial WOB mill off, engage auto drill at 1 ft/hr 10/8/2019 10/8/2019 0.50 PROD1 STK KOST T Increase ROP to 2 ft per hr. 10,402.0 10,403.0 0830 09:00 Annular pressure climbing, Trying to pack off. Pressure built to 4384 psi, 13.15 ECD manipulate choke successfully to flush pack off. 10/8/2019 10/8/2019 0.30 PROD1 STK KOST T Increase ROP to 3 ft per hr. 10,403.0 10,404.0 09:00 09:18 10/8/2019 10/8/2019 0.50 PROD? DRILL DRLG T Start drilling ahead, CT Wt 13.9 k lbs, 10,404.0 10,415.0 09:18 09:48 WOB 0.23 lbs Walk WOB & ROP up slowly to - 60 R/hr and 1 k lbs 10/812019 1018/2019 1.30 PROD1 DRILL DRLG T CT 5135 psi, @ 1.887 bpm in and 10,415.0 10,500.0 09:48 11:06 1.87 bpm out, Annular 4163 psi 11.7 ppd EMW @ the window, 12.3 ppg @ the bit. CT Wt 11.8 k lbs, 1.2 k WOB, 10,463' stall, PU Wt 39 k lbs, RBIH Ct 5179 psi @ 1.86/1.86 bpm in/out. Free spimm 1116 psi, BHP 4318, 11.8 ppg 12.76 ppg @ the bit, WH 548 psi, CTD 10 k lbs, WOB 10/8/2019 101812019 0.20 PROD1 DRILL DRLG T PU for dry drift Ct Wt 38 k Ibs. 10,500.0 10,500.0 11:06 11:18 PUH clean, RBIH Page 9/16 ReportPrinted: 1011612019 Uperations Summary (with Timelog Depths) 1 A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sort Depth Start Time End Time Out (hr) Phase Op Code Activit' Code Time P-T-X Opetstlon (ftKB) End Depth (tlKB) 10/8/2019 10/8/2019 2.20 FROM DRILL DRLG T Cl 5087 psi, 1.9/1.9 bpm in /out. Free 10,500.0 10,730.0 1118 13:30 spin 1031 pi, BHP 4175 psi 11.77 ppg @ the window , 12.35 ppg @ the bit. CT Wt 3 k Ids, WOB 2.4 k IDS. 10,667' PU 39 k Itis 10/8/2019 10/8/2019 4.30 FROM DRILL DRLG T In Ankerite 10,730.0 10,800.0 13:30 17:48 CT 5079 psi 1.89 / 1.83 bpm in/out, free spin 962 psi, BHP 4243 psi, WH 650 psi, CT 2.4 k lbs, WOB 2.5 k lbs, Drilling break @10,722', Fault #2, back in sand, 10,737' losses, gradual at first, briefly as high as 0.8 bpm, healed quickly. 10/8/2019 10/8/2019 0.20 PRODt DRILL WPRT T PUH on wiper#1, PU Wt 38 k lbs 10,800.0 10,453.0 17:48 18:00 10/8/2019 10/8/2019 0.20 PROD1 DRILL WPRT T PUH on wiper #1, PU Wt 38 k lbs 10,453.0 10,800.0 18:00 18:12 10/8/2019 10/9/2019 5.80 PROD1 DRILL DRLG T CT 5054 psi, 1.88 / 1.89 bpm in/out, 10,800.0 10,882.0 18:12 00:00 free spin 978 psi, BHP 4185 psi, 11.8 ppg @ the window and 12.3 ppg @ the bit. CT 4.22 k lbs, WOB 10/9/2019 10/9/2019 2.00 FROM DRILL DRLG T OBD, 1.87 bpm at 5,271 psi, FS 10,882.0 11,056.0 00:00 02:00 Di- 70 psi, WHP=632, BHP=4,194, IA=440, OA=343 10/9/2019 10/9/2019 2.00 PRODt DRILL DRLG T OBD, 1.87 bpm at 5,147 psi, 11,056.0 11,200.0 02:00 04:00 Diff-1,033 psi, WHP=627, BHP=4,260, IA=450, OA=349 10/9/2019 10/9/2019 0.50 FROM DRILL WPRT T Wiper up hole PUW 41 k 11,200.0 10,425.0 04:00 04:30 10/9/2019 10/9/2019 0.40 FROM DRILL WPRT T Wiper back in hole RIW 10 k 10,425.0 11,200.0 04:30 04:54 10/9/2019 10/9/2019 2.00 PRODi DRILL DRLG T BOBD, 1.87 bpm at 5,160 psi, FS 11,200.0 11,334.0 04:54 06:54 Diff--963, WHP=603, BHP=4,263, IA=448, OA=347 10/9/2019 10/9/2019 2.00 PROD1 DRILL DRLG T OBD, 1.87 bpm at 5,333 psi, 11,334.0 11,453.0 06:54 08:54 Diff--1,169 psi, WHP=610, BHP=4,321, IA=459, OA=351 10/9/2019 10/9/2019 2.00 PROD1 DRILL DRLG T OBD, 1.88 bpm at 5,340 psi, 11,453.0 11,536.0 08:54 10:54 Diff-1,183 psi, WHP=605, BHP=4,313, IA=459, OA=351 10/9/2019 10/9/2019 2.00 PROD1 DRILL DRLG T OBD, 1.86 bpm at 5,193 psi, Diff--981 11,536.0 11,600.0 10:54 12:54 psi, WHP=594, BHP=4,355, IA=460, OA=351 "" Note: New mud at the bit 11,563' 10/9/2019 10/9/2019 1.00 FROM DRILL WPRT T Wiper to the window, PLAN 42 k 11,600.0 8,795.0 12:54 1354 10/9/2019 10/9/2019 0.20 PROD1 DRILL DLOG T Log RA marker (+7.5) 8,795.0 8,822.0 13:54 1406 10/9/2019 10/9/2019 1.90 FROM DRILL WPRT T Wiper back in hole, RIW 13 k 8,822.0 11,600.0 14:06 16:00 10/9/2019 10/9/2019 2.50 FROM DRILL DRLG T BOBD, 1.86 bpm at 4,570 psi, FS 11,600.0 11,693.0 16:00 18:30 Dif=920, WHP=665, BHP=4,297, IA=377, OA=304 10/9/2019 10/912019 0.10 PROD1 DRILL WPRT T P/U, PUW=45K. Hard time trying to 11,693.0 11,693.0 18:30 18:36 drop. Trough from 11680'. to 11693 Page 10116 ReportPrinted: 10/16/2019 Operations Summary (with Timelog Depths) 1A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stari Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X OperaGan (ftKB) End Depth(fiKB) 10/9/2019 10/9/2019 1.10 PROD1 DRILL DRLG T 11693', Drill. Drop pump rate to 1.53 11,693.0 11,729.0 1836 19:42 BPM. Trying to drop to 82°. 3690 PSI, BHP=4270. Consult with on site geo. Will need to start turning to stay in polygon. New polygon coordinates given extending polygone east. 10/9/2019 10/9/2019 0.20 PROD1 DRILL WPRT T 11729, PUH 100', PUW=46K. With 11,729.0 11,729.0 1942 19:54 sweeps. troughing on way back in. Still having little results getting angle to drop. 10/9/2019 10/9/2019 0.70 PROD1 DRILL DRLG T 11729', Drill 1.53 BPM @ 3690 PSI 11,729.0 11,754.0 1954 20:36 FS, BHP=4275 10/9/2019 10/10/2019 3.40 PROD1 DRILL DRLG T 11754'. Drill. at desired inclination 11,754.0 11,648.0 2036 00:00 -82°. Bring up pump rate to 1.9 @ 4520 PSI FS, BHP=4275, TF=90L. 10/10/2019 10/10/2019 4.80 PROD1 DRILL DRLG T 11,848', Drill, 1.9 BPM @ 470 PSI FS, 11,848.0 12,000.0 0000 04:48 BHP=4325, WHP=665, RIW=-5K, DHWOB=1.14K 10/10/2019 10/10/2019 0.40 PROD1 DRILL WPRT T Pull 1000' wiper tip #1 with 5 X 5 12,000.0 11,000.0 0448 05:12 sweeps. PUW=45K 10/10/2019 10/10/2019 2.50 PROD1 DRILL WPRT T RBIH 11,450'-11550', PUH slowly 11,000.0 12,000.0 0512 07:42 circulate BU, continue IH lowering pump rate to 0.5 bpm 10/10/2019 10/10/2019 2.90 PROD1 DRILL DRLG T BOBD, 1.88 bpm at 4,901 psi, FS 12,000.0 12,066.0 0742 10:36 Diff=964, WHP=642, BHP=4,340, IA=426, 01 "' Note: Start sending beaded pills 15 bbl beaded High-vis and 5 bbl low-vis 10/10/2019 10/10/2019 2.00 PROD1 DRILL DRLG P OBD, 1.89 bpm at 4,901 psi, FS 12,066.0 12,120.0 1036 1236 Diff=1,083, WHP=617, BHP=4,378, IA=425, 01 10/10/2019 10/10/2019 2.00 PROD1 DRILL DRLG P OBD, 1.89 bpm at 4,901 psi, FS 12,120.0 12,191.0 1236 14:36 Diff=1,083, WHP=617, BHP=4,378, IA=425, 01 10/10/2019 10/10/2019 2.00 PROD1 DRILL DRLG P OBD, 1.89 bpm at 4,901 psi, FS 12,191.0 12,248.0 1436 16:36 Diff=1,083, WHP=617, BHP=4,378, IA=425, 01 10/10/2019 10/10/2019 2.00 PROD1 DRILL DRLG P OBD, 1.89 bpm at 4,901 psi, FS 12,248.0 12,292.0 1636 18:36 Diff=1,083, WHP=617, BHP=4,378, IA=425, 01 10/10/2019 10/10/2019 2.50 PROD1 DRILL DRLG P 12292', Drill, 1.87 BPM @ 4900 PSI 12,292.0 12,337.0 1836 21:06 FS, BHP=4390, Pumping beaded pills25 BBI. Low ROP, Quick pick ups as required 10/10/2019 10/10/2019 0.20 PROD1 DRILL WPRT P 12337, BHA Wiper, PUW=43K 12,337.0 12,337.0 21:06 21:18 10/10/2019 10/10/2019 1.30 PROD1 DRILL DRLG P 12337', Drill,1.88 BPM @ 4900 PSI 12,337.0 12,367.0 21:18 22:36 FS, BHP=4385, RIW=-5.3K, DHWOB=I.2K 10/10/2019 10/11/2019 1.40 PROD1 DRILL DRLG P 12367', Drill, 1.85 BPM @ 4905 PSI 12,367.0 12,375.0 22:36 00:00 FS, BHP=4385, Low ROP, Drilling break @ 12375 to - 40FPM ROP 10/11/2019 10/11/2019 2.20 PRODi DRILL DRLG P 12375', Drill ahead, 1.85 BPM @ 4900 12,375.0 12,400.0 00:00 02:12 PSI FS, BHP=4405. Pumping beaded pills. Low ROP, RIW=-7K, DHWOB1.5K 10/11/2019 10/11/2019 0.40 PROD1 DRILL WPRT P 12,400', PUII 1000' wiper #2 with 12,400.0 11,400.0 0212 0236 sweeps, PUW=45K. Overpull @ 11,606. RBIH come at area at lower speed. Work through. Minor packing off Page 11116 ReportPrinted: 10/16/2019 Operations Summary (with Timelog Depths) 1A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Stan Time End Tim our (hr) Phase Op GDde Ad Ity Cade Time P -T -X Operation (11KB) End Depth (WB) 10/1112019 10/11/2019 0.60 PROW DRILL WPRT P Pump 5 X 5 sweeps. circ to surface 11,400.0 11,230.0 02:36 03:12 before running back in hole 10/11/2019 10/1112019 1.30 PROD1 DRILL WPRT P RBIH to drill, Set down 11,470'. Had to 11,230.0 12,398.0 03:12 04:30 work down to 11770 before trip in got easier. Reduce pump rate to get through this interval 10/11/2019 10/1112019 1.65 PROD1 DRILL DRLG P 12,400' Drill, 1.89 BPM @ 4960 PSI 12,398.0 12,414.0 04:30 06:09 1 1 1 FS, BHP=4394, RIW=-2K off bottom 10/11/2019 10/11/2019 0.50 PROD1 DRILL WPRT P Short BHA viper up hole, PUW 45 k 12,414.0 12,414.0 06:09 06:39 10/1112019 10/11/2019 2.00 PROD1 DRILL DRLG P OBD, 1.89 bpm at 5,171 psi, FS 12,414.0 12,454.0 06:39 08:39 Diff=970 psi, WHP=623, BHP=4,479, IA=430, OA=326 1011112019 10111/2019 2.00 PROD1 DRILL DRLG P OBD, 1.89 bpm at 5,171 psi, FS 12,454.0 12,471.0 08:39 10:39 Diff -970 psi, WHP=623, BHP=4,479, IA=430, OA=326 10111/2019 10/11/2019 2.65 PROD1 DRILL DRLG P OBD, 1.89 bpm at 5,171 psi, FS 12,471.0 12,502.0 10:39 13:18 Diff --970 psi, WHP=623, BHP=4,479, IA=430, OA=326 10/11/2019 10/112019 1.30 PROD1 DRILL WPRT P Wiper up hole, PUW 44 k, jog the 4- 12,502.0 8,385.0 13:18 14:36 1/2" w/ closed EDC — Note: Trouble area's on wiper up hole - 9,803'-9,713', 9,007'-8,954', and 11,450'-11,497' 10111/2019 10/11/2019 0.20 PROD1 DRILL DLOG P Log formation (+19.5') 8,385.0 8.420.0 14:36 14:48 10/11/2019 10/11/2019 2.40 PROD1 DRILL WPRT P Wiper back in hole, RIW 13 k 8,420.0 12,502.0 14:48 17:12 Note: Trouble spots on wiper back in hole, 9,050', 9,820', 10,120', 10,670',11,411',12,136- 0,670',11,411',12,136'10/11/2019 10/11/2019 10/112019 4.50 PROD1 DRILL DRLG P BOBD, 1.8 bpm at 4912 PSI FS, 12,502.0 12,526.0 17:12 21:42 BHP=4420. Low to no ROP, Pumping 40 BBI beaded pills. High vibration. Try different pump rates to reduce vibration. Indicating good DHWOB 1.3K+. 10/11/2019 10/11/2019 0.10 PRODt DRILL WPRT P 12526 BHA wiper, PUW=43K 12,526.0 12,526.0 21:42 21:48 10/11/2019 10/11/2019 1.60 PRODt DRILL DRLG P 12526', Drill 1.7 BPM @ 4500 PSI FS, 12,526.0 12,536.0 21:48 23:24 BHP=4420. Low ROP with high vibration. Multiple pick ups. Multiple beaded pills. Good WOB. low diff pressure 10/11/2019 10/11/2019 0.10 PROD1 DRILL WPRT P BHA wiper, PUW=43K 12,536.0 12,536.0 23:24 23:30 10111/2019 10/12/2019 0.50 PROD1 DRILL DRLG P 12536', Drill, 1.75 BPM @ 4500 PSI 12,536.0 12,539.0 23:30 00:00 FS, BHP=4460 10/12/2019 10/1212019 3.60 PROD1 DRILL DRLG P 12539', Drill, 1.75 BPM @ 4500 PSI, 12,539.0 12,581.0 00:00 03:36 BHP=4460, 10/12/2019 10/12/2019 0.10 PRODi DRILL WPRT P 12581', BHA wiper, PUW=49K 12,581.0 12,581.0 03:36 03:42 10/12/2019 10112/2019 2.00 PROD1 DRILL DRLG P 12581', Drill 1.7 BPM @ 4470 PSI FS, 12,581.0 12,621.0 03:42 05:42 BHP=4405 10112/2019 10/12/2019 2.00 PROD1 DRILL DRLG P OBD, 1.7 bpm at 4,660 psi, Diff=781 12,621.0 12,643.0 05:42 07:42 psi, WHP=652, BHP=4,365, IA=380, OA=309 10/12/2019 10/12/2019 2.00 PRODi DRILL DRLG P OBD, 1.7 bpm at 4,663 psi, Diff -781 12,643.0 12,708.0 07:42 09:42 psi, WHP=652, BHP=4,365, IA=380, OA=309 Page 12/16 ReportPrinted: 1 0/1 612 01 9 Operations Summary (with Timelog Depths) 1 A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stamnine End Time our (hr) Phase Op Code ANWy Code Time P-T-X Operation (RKB) End Depth(ftKB) 10/1212019 10/12/2019 2.00 PROD1 DRILL DRLG P OBD, 1.7 bpm at 4,547 psi, Diff-781 12,708.0 12,732.0 09:42 11:42 psi, WHP=652, BHP=4,365, IA=360, OA=309 10/12/2019 10112/2019 2.00 PROD1 DRILL DRLG P OBD, 1.68 bpm at 4,637 psi, Diff--870 12,732.0 12,795.0 11:42 13:42 psi, WHP=700, BHP=4,357, IA=376, OA=310 10/12/2019 10112/2019 4.10 PROM DRILL DRLG P OBD, 1.68 bpm at 4,637 psi, Diff--870 12,795.0 12,900.0 13:42 17:48 psi, WHP=700, BHP=4,357, IA=376, OA=310 10/12/2019 10112/2019 1.00 PROD1 DRILL WPRT P Pull 1000' wiper, PUW=45K, RBIH @ 12,900.0 12,900.0 17:48 18:48 1.5 BPM @ 40 FPM. One slight stack out @ 12,183 where there was a TF change 10/12/2019 10112/2019 3.90 PROD1 DRILL DRLG P 12900', Drill, 1.7 BPM @ 4640 PSI 12,900.0 12,982.0 18:48 22:42 FS, BHP=4420, Continue pumping beaded pills 10/12/2019 10112/2019 0.10 PROD1 DRILL WPRT P Pull BHA wiper, PUW=46K 12,982.0 12,982.0 22:42 22:48 10/12/2019 10113/2019 1.20 PROD1 DRILL DRLG P 12982', Drill, 1.75 BPM @ 4640 PSI 12,982.0 13,009.0 22:48 00:00 FS, BHP=4360, RIW=-6.5K, DHWOB=I.6K 10113/2019 10/13/2019 4.40 PROD1 DRILL DRLG P 13009', Drill, 1.66 BPM @ 4300 PSI 13,009.0 13,092.0 00:00 04:24 FS, BHP=4310, RIW=-7K, DHWOB=IK 10/13/2019 10/13/2019 0.50 PROM DRILL WPRT P Call TD, Chase 10 X 10 sweeps to 13,092.0 11,526.0 04:24 04:54 swab valve, PUW=46 10/13/2019 10113/2019 0.20 PROD1 DRILL WPRT P Start pulling heavy 11,526', RBIH, 11,526.0 11,460.0 04:54 05:06 work pipe up to 11,460'70 k CTSW, - 13.Ok DHWOB, popped free, continue POOH 10113/2019 10/13/2019 1.00 PROD1 DRILL WPRT P Continue POOH to the window 11,460.0 8,784.0 05:06 06:06 10113/2019 10/13/2019 2.00 PROD1 DRILL WPRT P Pull through window clean, continue 8,784.0 78.3 06:06 08:06 POOH, perform jog back in hole, observed increase in cuttings at the shaker with some brillo pad metal in sample, 10/13/2019 10113/2019 1.60 PROD1 DRILL TRIP P Tag up at surface, reset counters, RIH 78.3 8,395.0 08:06 09:42 10/13/2019 10113/2019 0.30 PROW DRILL DLOG P Log formation for depth control 8,395.0 8,411.5- 09:42 10:00 (+11.0'), Obtain static above window, 11.591 ppg and pressure cointnued to fall '"• Note: Performed SBHP survey @ 8,775.3' CTMD ECD=11.591 ppg AP=3,822 Press TVD=6,347.03' 10/13/2019 10/1312019 2.50 PROD1 DRILL TRIP P Continued to RIH to confirm TD, SID 8,411.0 13,093.0 10:00 12:30 9,857', 10,080', 11,625', and 13,065', confirmed TD 13,093' and is a little sticky on the pickup PUW 49 k CTSW, with 1.6 k DHWOB 10/13/2019 10/13/2019 0.50 PROD1 DRILL DISP P Line up and circulate beaded LRP 13,093.0 13,093.0 12:30 13:00 down coil, PUH slowly 10113/2019 10/13/2019 1.60 PROD1 DRILL TRIP P POOH, laying in beaded 11.8 ppg 13,093.0 8,784.0 13:00 14:36 beaded LRP, Painting EDP (TD) flag @ 11,010' 10/13/2019 10/13/2019 0.55 PROD1 DRILL TRIP P At the window continue POOH laying 8,784.0 6,500.0 14:36 15:09 beaded 11.8 ppg pill, Paintiing EDP (window) flag @ 6,700' Note: Beads are up to 6,500' Page 13116 ReportPrinted: 1011612019 Operations Summary (with Timelog Depths) 1 A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stam Kepth De Start Time End Time our( hr phase Op Cada Activity Code Time P -T -X Operation (rt End Depth (MB) 10/1312019 10/13/2019 1.35 PROD1 DRILL TRIP P Continued POOH displacing well to 6,500.0 78.2 15:09 16:30 completion fluid 10/13/2019 10/13/2019 0.50 PROD1 DRILL OWFF P At surface, check well for flow, PJSM 78.2 78.2 16:30 17:00 Note: 1 bph losses 10/13/2019 10/13/2019 0.60 PROD1 DRILL PULD P LD Drilling Assembly BHA #6 78.2 0.0 17:00 17:36 10/13/2019 10/132019 1.00 COMPZ1 CASING RURD P Clean up rig floor, Rig up to run liner, 0.0 0.0 17:36 18:36 PJSM P/U liner 10/13/2019 10/13/2019 3.70 COMPZ1 CASING PUTB P P/U AU lower liner segment with non 0.0 1,985.9 18:36 22:18 ported bullnose, 53 joins sloted 2 3/8" liner and shorty deployment sleeve, M/U to coil track and set in deployment rams. Skid injector to floor. UT pipe, Min wall hickness .165. Change floats in BHI UQC. Make up to coil and surface test tool 10/13/2019 10/13/2019 1.40 COMPZi CASING RUNL P RIH BHA#7, AL1 lower liner section 1,985.9 8,614.0 22:18 23:42 10/13/2019 10/13/2019 0.10 COMPZ1 CASING DLOG P Correct to flag -28' 8,714.0 8,686.0 23:42 23:48 10/13/2019 10/142019 0.20 COMPZ1 CASING RUNL P Continue in well 8,686.0 8,770.0 23:48 00:00 10/142019 10/14/2019 1.10 COMPZ1 CASING RUNL P Continue in well, set down @ 9640, 8,770.0 10,376.0 00:00 01:06 9866, 10026, 10288 work pipe in these areas 10/14/2019 10114/2019 0.10 COMPZ1 CASING DLOG P Log K1 for+16', Total correction -12' 10,376.0 10,392.0 01:06 01:12 10/142019 10/14/2019 6.50 COMPZ1 CASING RUNL P Continue working pipe to bottom 10,392.0 13,000.0 01:12 07:42 10/142019 10/14/2019 0.50 COMPZ1 CASING RUNL T Liner on bottom, bring pump 13,000.0 13,000.0 07:42 08:12 online.initial pump rate 1.8 bpm with 1.64 bpm returns, noticed no diff on BHA, pump 9 WE still no diff, lost returns, PUH PUW 51 k, -5.9 k DHWOB, RBIH to set depth, attempt to get diff, no success, phone town team, PUH slowly until we established returns @ 0.5 bpm,gettting 1:1 returns, bring pump rate up to 1.6 bpm, 1.0 bpm returns, then returns diminished to 0.26 bpm, decision was made to POOH to inspect Coil and BHA 10/14/2019 10114/2019 1.40 COMPZ1 CASING TRIP T POOH, pumping across the top 13,000.0 6,840.0 08:12 09:36 10/14/2019 10/14/2019 1.50 COMPZ1 CASING TRIP T Stop and remove BHA length from 6,840.0 1,985.9 09:36 11:06 counters, continue POOH 10/14/2019 10/142019 0.50 COMPZ1 CASING OWFF T At surface, PJSM, check well for flow 1,985.9 1,985.9 11:06 11:36 (no -flow) 10/14/2019 10/14/2019 0.30 COMPZ1 CASING PULD T Unstab l NJ H, brake CT connection, 1,985.9 1,985.9 11:36 11:54 slid can back, run coil into mouse hole 30', all looks good, pull back up, install pull plate, slide cart back, install lift nubbin, pull CoilTrak tools up, found EDC has failed, pull BHA and secure liner in well with safety joint. 10/14/2019 10/14/2019 1.10 COMPZi CASING PULD T PJSM, LD failed BHA, PU 1,985.9 1,941.7 11:54 13:00 replacement assembly, MU to liner assembly 10/14/2019 10/142019 0.20 COMPZ1 CASING PULD T Inspect pac-off, stab INJH onto stump, 1,941.7 1,985.9 13:00 13:12 surface test CoilTrak tools (good -test) Page 14116 Report Printed: 1011612019 Operations Summary (with Timelog Depths) 1A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Startlime End Time our (hr) Phase Op Code Actively Code 'rime P-T-X Operawn (WS) End Depth (ftKB) 10114/2019 10/14/2019 2.75 COMPZ1 CASING RUNL T RIH, w1AL1 liner segment#1, correct 1,985.9 13,000.0 13:12 15:57 to the EOP flag -18.7' 10114/2019 10/14/2019 0.20 COMPZi CASING RUNL P On bottom, PUW 46 k, RBIH to setting 13,000.0 11,058.4 15:57 16:09 depth, 13,000' 10114/2019 10/1412019 0.20 COMPZ1 CASING DISP P Heisitate for 11.8 ppg beaded LRP 11,058.0 11,058.4 16:09 16:21 10114/2019 10/1412019 0.60 COMPZ1 CASING TRIP P POOH, laying beaded 11.8 ppg LRP 11,058.4 8,770.0 16:21 16:57 10114/2019 10114/2019 0.20 COMPZ1 CASING DLOG P Log the RA marker 4correction 8,770.0 8,805.0 16:57 17:09 10/14/2019 10114/2019 1.80 COMPZ1 CASING TRIP P Continue out of well Paint EOP flags 8,805.0 55.0 17:09 18:57 @ 8754 & 6344 10/14/2019 10/14/2019 0.30 COMPZ1 CASING PULD P At surface, fow check well, PJSM lay 55.0 0.0 18:57 19:15 down BHA# 8 liner running tools on dead well 10/14/2019 10/14/2019 3.75 COMPZI CASING PUTB P Prep floor to run liner, M/U AL1 upper 2,327.8 2,327.8 19:15 23:00 liner segment with ported bullnose, 69 As slotted liner, shorty deployment sleeve 10/14/2019 10/14/2019 0.50 COMPZ1 CASING PULD P P/U Coil trek BHA# 9 with new EDC. 2,327.8 2,372.1 23:00 23:30 Make up to coil and surface test - Good 10/14/2019 10/15/2019 0.50 COMPZ1 CASING TRIP P Trip in hole BHA #9 2,372.1 5,270.0 23:30 00:00 10/15/2019 10/15/2019 0.60 COMPZt CASING TRIP P Continue in well with AL1 upper liner 5,270.0 8,672.0 00:00 00:36 segment 10/15/2019 10115/2019 0.10 COMPZt CASING DLOG P Tie into window flag for -14'. 8,672.0 8,672.0 00:36 00:42 PUW=38K 10/15/2019 10/15/2019 0.20 COMPZt CASING TRIP P Continue in well 8,672.0 9,303.0 00:42 00:54 10/15/2019 10/15/2019 1.70 COMPZ1 CASING TRIP P Set down @ 9303'. PUW=45K. Start 9,303.0 11,065.0 00:54 02:36 working pipe down 10/15/2019 10/15/2019 0.20 COMPZ1 CASING TRIP P 11065, Tag top of lower liner segment, 11,065.0 8,710.0 02:36 02:48 PUW=52K, DHWOB=-12K. Set back down. Pumps online @ 1.5BPM 2960 PSI. PUW=33K, DHWOB=-2K. PUH remove liner length from mounters, PUH 10/1512019 10/152019 0.30 DEMOB WHDBOP PRTS P Obtain static BHP, Sensor ND 8,710.0 8,710.0 02:48 03:06 6324.89, Annular pressure 3907, EMW=11.89 PPG, PUH to 8370 10/15/2019 10/15/2019 0.10 DEMOB WHDBOP DLOG P Log K1 for+10', BOL-13013, 8,370.0 8,401.0 03:06 03:12 TOL=8742 10/15/2019 10/15/2019 0.10 DEMOB WHDBOP TRIP P RBIH to 8700 8,401.0 8,700.0 03:12 03:18 10/1512019 10115/2019 1.00 DEMOB WHDBOP CIRC P Displace CT to seawater 8,700.0 8,700.0 03:18 04:18 10/15/2019 10115/2019 1.00 DEMOB WHDBOP TRIP P Seawater around CT, start tripping out 8,700.0 2,500.0 04:18 05:18 10/15/2019 10115/2019 1.30 DEMOB WHDBOP Park, LRS on location, PJSM, RU to 2,500.0 2,500.0 05:18 06:36 costumer line, displace coil with 40 bbl of diesel 10115/2019 10115/2019 0.75 DEMOB WHDBOP Continue POOH, freeze protecting 2,500.0 44.2 06:36 07:21 well 10/15/2019 10115/2019 1.50 DEMOB WHDBOP At surface, space out, PUD and LD 44.2 0.0 07:21 08:51 setting tools •" Note: FTP=1,063 psi Page 15116 ReportPrinted: 1011612019 Operations Summary (with Timelog Depths) 1A-04 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth(flKB) 10/15/2019 10/15/2019 0.60 DEMOB WHDBOP Install nozzle and jet stack and Flush 0.0 0.0 0851 09:27 surface lines. 10/15/2019 10/15/2019 2.55 DEMOB WHDBOP SLB N2 on location, RU to costurmer 0.0 0.0 0927 12:00 line, PT hardline to 4,000 psi, line up to tiger tank, blow down reel 1,500 scf/15mins, shutdown, bleed coil pressure off to tiger tank. Unstab INJH, brake off UO assembly Note: Rig Released @ 12:00 noon Page 16/16 ReportPrinted: 10/16/2019 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1A Pad 1A-04AL1 50-029-20621-60 Baker Hughes INTEQ Definitive Survey Report 12 November, 2019 Baker Hughes S ConocoPhillips .mcmSP'ha ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska lnc Kuparuk Project: Kupamk River Unit Site: Kupamk to Pad Well: 1A-04 Wellcome: IA{MALI Design: tA4WAL1 Pit Kupamk River Unit. Norm Slope Alaska, United States Map System: US State Plane 1927 (EKed solution) System Dan Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Well 1A-04 Local Cenrdbeb Reference: Math IA -04 TVD Reference'. IA -04A@%,9@ 959us11(1A-04A*95.9) MD Reference: tA-04A@95.9@95.9usit(1A-04AQ95.9) North Reference: True Survey Calculation Marked: Minimum Curvature Dablasse EDT 14 Alaska Production WellCors Well Position +WS 0.0 raft Northing'. .01 00 usft Elating: Position Uncertainty 00 us" Wellhead Elevation: WellCors 1A-04AL1 Magnetic. Model Name Semple Dab BGGM2018 1011/2019 Design 1A-04ALl Anne Noma: sbrebn: 1.0 Pike.- ACTUAL Urtlul Be.tlon: Depth, From WVD) ]loft) 959 Mean Sea Level Using Well Reference Point Using geodetic scale fader 5S71,10683eaft Latitude: 540, 17852 usft LongKude: Usti Ground Level: Deciphered Dip Angie 1°I (•) 16.40 80.85 Tie On Depth: 10,401.0 aW3 IoM) 00 4fJ4M IdMil 0.9 Dinneen Ih O.00 70° 19 55.196 N 149° 40' 26,725 W 0 0 usft Mid elreltpM rod 5],401.949]8005 IIAM19 3.'S9:521sM Paget CCMP4SS5000146vMl ConocoPhillips Definitive Survey Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation MMhod: DeM6ese: Wall iA-04 IA -04A@95 9 @ 95 9us11 (1A 04A@95,9) tA-01.46$95 9 C 95 9usft (1A -04A@95.9) True Minimum Curvature EDT 14 Alaska Production Survey Program Survey Conoco✓Phillips Company. ConocoPhillipa Alaska Inc Kuparuk Prelecl: Kupemk River Unit Sloe: Kuparuk to Fatl Well: IA -04 We1Oons 1A-04AL1 Design IIA44ALi ConocoPhillips Definitive Survey Report Local Coordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation MMhod: DeM6ese: Wall iA-04 IA -04A@95 9 @ 95 9us11 (1A 04A@95,9) tA-01.46$95 9 C 95 9usft (1A -04A@95.9) True Minimum Curvature EDT 14 Alaska Production Survey Program Survey Data End DaM 856852000 222no01 IOnnol9 From To 1022019 1094019 loanols, fount (am) survey, ByollBorv) Tool Nemo Deaodptlon 1959 6,395.9 1A-04(1 A-04) FINDER -MS SDC Finder muftis0ot 6,493.0 8,116.0 1A -04A (1A -04A) FINDER -MS SDC Finder multialrot 6,984.0 16,90,2.8 129-04ALi P81 MWD -INC (129-04AL1 PEN MW0.1NC_ONLY MWD -INC ONLY FILLER 6,930,9 10,401.0 1A-04ALi PBI 1AWD(1A44AL1PB1) MM OW6G OWSG MWD -Standard 10,432.5 13,0508 1A,04ALI(IA-6AL1) MWDOW5G OW MWD -Standard survey Map Map MO Inc AM 190, 1VD8S .1,114eEf_W No Eam,ng DLs (deft) (1) (1) Iden" (act) (ml )daft) (11) Mind) 10,4010 87M 80.66 8,5116 6,4151 90.6 5729.3 5,911,0869 545,90 .5 0.9 10,4325 84.10 1831 8,513.9 6,410.0 -M9 57sr2 5,01,D920 545,930.3 106 10,450.5 84.50 11.41 6.616.3 6,4204 -39.5 5785.5 5,971,000.3 545.9635 35 10,469.1 03.54 loss 6.519.5 6.4236 -32.3 5,815.1 5,971.105.6 50.5,993.1 60 10,518.8 an 73.00 6,523.6 6,421] -244 5643.4 5971,1130 546,0214 124 10,ss9.0 19.62 1062 6.501 6.432.0 -15.1 5,8717 5,911,1232 546,0496 8.8 10,5180 79M 67,43 6.533.9 6.435.0 49 5,804 5,971,133.6 5160762 108 1080.1 .4380 65.20 6,538.9 6,4430 67 5,92F.6 5.911.145.2 546.1024 85 10836.5 0133 6315 6,543.8 6,4419 202 5,9525 5,971.158.9 5461303 6.6 10F68.4 8131 6060 6,548.3 8,44.4 34.1 5.9186 5,911,1729 546,1562 6.2 106940 aim 50.13 8,552.4 8,456.5 472 6.001.1 5.9711863 546,116.1 7.3 10,M2 02A1 W93 6.556.4 8,463.5 611 6,0241 5,971,200A 546201.6 82 10]56.1 04.22 %in 6,50.5 6,46 .6 81.3 6.4531 5.911.220.6 540.2311 5.6 1QM5 else 5291 6,561.9 8,469.0 101.3 60016 5,971,2406 66.2589 9.1 10,0192 6.25 5435 6,556.4 6,410.5 117.0 6.1030 5,971,256.5 546,2803 5.6 10,0514 71.19 5565 6,556.9 6,474.0 135.3 6.1292 5,9712150 546,303.3 5.2 10,001.5 461 5160 6,513] 6.411.8 1518 6,163 5,971.2918 66.3313 61 19810.1 04.06 5971 6,41 .0 8,4011 1666 6,1165 5.971,336.5 516.3554 8.9 10,940.8 8535 6197 6,49 .8 6AW9 101.3 6.204.9 5.971,321A 546,3018 8.5 11/122019 3:59:APM Pepe3 aek.rwsne.8 Survey Survey mamm End DaM 856852000 222no01 IOnnol9 101612019 109n019 1022019 1094019 loanols, Mental sma on survey Tool Name Annalation (ft) 50.64 MW)a (4) 44.91 MWDGITuG(5) J940 MWD 6056 (5) J M swaav G(5) -24,M MWD0WSG(5) -15.00 MWD GW5G(5) 4.06 vvw a 6(51 656 NBVT) G(5) 2017.MWD OASG(6) 34.07 MWDOASG(5) ,174 MWD 0WSG(5) 6167 MWD CA53(5) 01.33 MWD0 (5) to 25 MWD OABG(5) 117.03 Noes 0AV G(5) 13534 MWD 0ASG(5) 151.01 mom (5) 16659 MWD OWBG(5) 161.34 MWD DW6G (5) TIPIKOP COMPASS 5000.14 Build 05H ConocoPhillips seWauseei ConocoPhillips Definitive Survey Report Company: ConowPhlikps Alaska Inc Kuparuk Local Co-ofemate Reference: Noll iA46 ----.._-------- Prefect: Kupamk River Unit WO Reference: 1A-04A®95.9®95.9usft(1A-04A@95.9) Sim Kupamk 1A PaO MD Reference: 1A-04A@95.9®959usft(1A-04A®85.9) WOO: 1A-01 Norte Reference: TNB Wellbore: Lk-04AL1 Survey C.IWoblon Mello@ Minimum Curvature Design: 1A-04411 Database: EDT is Alaskap uciion S9rvey Map Map Vertical MD 9m Aal M T/D58 +WS 'V-W Northing Easong DLS Sectlon Survey Tool Neme Annotation (Mala (1) r) (Ulm (ell) (we) (use) fft) (R) (.1100) IM) 10.5705 as 62 6471 6.581.9 6,4830 194.0 62316 5,971]M9 5974W.4 1➢1 194]5 MWD 09766(5) t1,W0.2 81.10 6SB4 :.MM3 SABBA 97 2.1 6,258.5 5,971,34).4 SW4M2 93 20].11 MWD OWSG (5) 11,979.9 M91 6686 8,58].4 6,4815 2195 6,265.8 5,971.3590 5464814 10.1 218W MWD OWSG (5) 11,06 24.91 7019 8,593.65.494 94.7 22 91 8,3140 36 5,9]1,99 546,49.5 4A 229.97 MMOV%GG (5) 119703 82.93 6966 6.594.1 6.4902 2383 8,342.0 5,971 380A 5465106 37 M3 N MWD OWSG (6) 111199 84.0 67,82 8.597.2 6,5013 2500 5397.4 5,971,390.9 516$45.9 91 249.0 MAD G(5) H,1497 46.62 65.92 6,$89.4 6,5W5 01.7 6396.8 5,971,402.7 SW.5n2 8.6 261.46 MWD OWSG(5) 11,1802 87 64 6326 6,111 65MG 2]4] 6,424.3 5,971,4159 546,8606 94 Tl4W MWD OWSG (5) 11,2100 87.10 60.47 6,602.3 6.50.4 2987 6,450.5 5.971.4301 546,8.4.0 95 2ftn MWD OWSG(5) 11.2400 STW 5779 B.W3.B 6,507.9 3044 6,418.8 5.9714459 546.852.9 87 AN.W MAD OW5G (5) l 11.2699 07 82 w0 6.605.0 6,148.1 3202 5.501A 5,9714510 5458>)5 3.5 32(17.! am G(5) 112988 14.97 SSW 6.975.8 8,5100 330] 65262 5,971,478.5 516.]022 55 339.74 MWD OWSG )5) 11330.2 W]] 5456 6,60].91 6.5112 3542 6,5512 5,971496.1 54632].1 ]5 31A. MND OWSG(5) H.330.3 87.11 520] 6,608.] 5,5128 3720 6,575.4 5,971,514.0 515]51.2 57 37197 MMMSG (5) 11.30.0 W]7 51.37 6,610.3 6,5144 390.2 6,5988 5,971,9724 5157745 5.2 39022 MM OWSG(5) 11419.9 9722 97.36 8.612.1 6,5162 $CG4 6,5218 5.971551] 546,]9].2 102 4W.Q MWD OWSG(5) 191,449] 84.15 46.61 6,6146 6,5187 429.5 6,597.6 5,971,571.9 546.0180 91 429.54 MWD OASG(5) 11,479.9 MA7 MS 6.6175 8,5219 46.6 6,975.0 5,971,5931 SW.BW.3 60 4W.W MWD OWSG(5) 11.5977 8317 420 6,621.3 8,525.4 4M.t 6,6852 5.971.6147 515860.4 7.6 47214 MWD OWSG(5) 11539) 16.35 418] 6tua.0 6526.1 ANA 6,70.1 6.971,6371 515660.2 107 491.42 MWD GOOD (5) 11597.9 W69 40.91 0.626.1 6530.2 517.0 6,]25.0 5,971,6590 54590.0 33 51702 MWD OMG(5) 11,597.8 8382 40.0 6,6289 5533.0 539.6 6,74.4 5,9]1.682.5 546.9193 54 539.61 MAD MSG (5) 11,051 B5.2D 096 6,6317 6,535.8 Not 6.7635 5,971,70.2 597,09.6 4.9 541.21 MWD 09756(5) 11,654.] 83.40 410 8,634.3 6538A 5884 6,763.9 5.971.]31.5 5459615 4.4 50037 MWD OWSG(5) 11.695.3 85.91 4327 646354 6,540.5 610.8 6,80.6 5.971.7540 SW.982.0 4.8 &1082 am WUSG(5) in.me Was 43.13 8.639.1 6,5432 632.8 6.8282 5,971,7762 547=6 67 63283 MWD CMeG(5) 11,755.5 8124 42M 6642.9 6,547.0 654.6 6,648.4 5,9]1,798.1 547.972.6 92 65461 MNA GWSG(5) 11,746.2 82.98 4060 6,6471 6,5512 V74 6,860.5 5,971,630.9 54],02.6 7.8 enta, MVA OASG(5) 116165 8477 9723 6.66.4 6.551.6 7972 6.888.1 5.9718430 547,062.1 59 76017 MADOWBG(5l 118357 Mill 39.79 6,652.0 6.566.1 7148 8.905 5.97182497.5 547,074.4 62 ]14]8 MAD O'NSG(5) 11860] 84.98 30.12 6,654.1 8,559.2 734.1 6.8161 5,9]1,87.9 517.03.0 7.0 ]34.15 MVAOASG(5) 11/1Y019 3:5951PM Page4 COMPASS 5000.146iA08&7 11/122019 3:69:57PM Page 5 CChNaISS 50010.14 Better OW ConocoPhillips eek«w91+.5 ConOCoPhillip5 Definitive Survey Report Map Company: ConocoPM1illlps Alaska lnc_Kuparuk Local Coardinaa RMamllp: M11 IA -04 MO Profem: Kupamk River Ond TVD Reference: 1M04A@95.9@95.9usfl(1A-04A@95.9) TVOSS Site: Kupamk lA Pad MO Reference'. 1A -04A@95.9@ 95.9usfl(1A4)4AC959) Ee1111 Well: IA -04 WeOpge: 4A4p4AL1 North Reference: Survey Calculation Method: True Minimum Cumaam (1) Design: IA-04AL1 D3WDaee: EDT 14 Alaska Prodeopon (ush) Survey nl IRI (,M56,) 11/122019 3:69:57PM Page 5 CChNaISS 50010.14 Better OW Map Map MO Inc Atl 180 TVOSS 4N1S 4E1 -W N9(ft) Ee1111 DLS stumuVartael Semon Survey Toil Name Annotation (Se") (1) (1) (USM (uafl) (ush) (usfl) nl IRI (,M56,) M 11,890.] 87 02 3933 6,976.2 6560.3 ]A.5 6,934.9 59]1,9014 59>,108.5 00 ]5]49 MWD OW6G (5) 11.9207 86]] 38]] 8.W.3 6,5614 ]80.0 B,9518 5.9)1.924.0 54],12].3 &1 70001 MWD OWSG (5) 11,&508 8960 3867 8.85].] 6661.0 BM.3 8.971.6 5.971,9484 54],146.0 20 SOe 28 MWD OASG(6) 11,501.0 87 94 35.M 6,8.8.3 6,502.4 0283 6.990.9 5,971,97 .5 547,164.2 100 520.31 MWD OWSG (5) 12,010.9 80.20 3337 6,[39.3 6,583.4 052.9 1,007.9 5,9]1,99].2 50.1010 &4 852.92 MADOW6GS) 12041.1 as 56 30.55 6,060.] 6,564.0 0765 ],023.0 5,97,022.9 50,166.9 109 8]0.51 MWD OASG I5) 12.0]0.0 8]5] 2901 6,6622 6,5%.3 904.2 ],038.6 5.92.0487 547,211.4 &3 90424 MWD OWSG(5) 12,1013 SGID 27.43 6.682.8 6,566.9 01.1 7.0529 5,87,0756 54],225.] 106 931.M MWD ON5G (5) 12,1311 89.57 25.M B.M2.0 sees,9 95]] ],066.3 5,972,1022 54],238.9 60 957.7 MWD OW6G (5) 12,16.9 M29 23.29 6663.1 6,5972 964.8 7.0)0.7 5,97.1294 50,2512 86 SUM MMONAGG (5) 12,190.9 88.94 22.22 Start astir 1.012.5 ].0903 5.97,157.2 50,262.6 4,2 1,01247 MM OVOID (5) 12.28.9 90.15 20.62 6,6632 658).3 1040.4 7,101.3 5.9]2,105.1 54]2M4 54 1.04040 MWD OASG (5) 19,2512 049 1949. 6663.1 6,56].2 1,M8.9 ].111] 5.BM.2131 50283.6 3.9 1,06&87 MWD OWSG(5) 12,266.9 9783 17.82 6663.0 6.59.1 1,097.0 ].121.2 5.9]2.2419 50293.0 63 1,D9]01 MWD OWBG(61 12,315.9 91.20 17.63 6,692.2 6,566.3 1,130.3 7.131.8 5,6M,2]5.2 547.303.5 102 1,130.33 MWD OMG (5) 12,340.0 92.34 14.M 6661.0 6,50.1 1159.3 7,130.0 5.97,299.2 547,3103 11.5 1,15920 MND OW6G (5) 12.296.1 92.3] 12.65 66599 6,697.0 1,1788 7,144.8 5.9]2.]23.8 547,318.2 80 1,9881 MWD OWBG(5) 12,562 M43 1016 6.8597 6,a.0 1,20 ,2 71507 5.9M.353.2 50,322.0 1&5 128624 MWD OWBG (5) 12,438.5 9.10 7.24 6,6602 6,564.3 1,26 .1 ],15].1 5,97,395 .2 54]328.2 8 125015 MND Ov3G(5) 4,46 .0 9186 8.46 6,659.0 6,Sees 1,282 7.16.6 5,97,424 .2 5473315 57 12]9]8 MND OASG (5) 12,4%.0 92.34 511 8,658.0 6582.9 130"1 7,163.5 597,452.3 547,334.2 54 1.30724 MWD 0WSG(5) 12,437 SIM 3.66 6,657.9 6,562.0 1,334.6 7.165.6 5,97,479.8 54],336.2 6.5 ISM 70 MND OMG(51 12,58 .6 9817 2.10 6.6573 6,5614 1,357] 7.161,2 5,97,5127 50,3376 49 1,36760 MWD ONSG(5) 12,590.8 9]0 35798 6,6570 6,5611 1,4019 71673 5,97,50.0 50,33].5 122 1,401.9 MND 0A6G (5) 4,MOB 94B 35592 6690 6,56 .9 1,4316 ],165] 5,97,5]6] 50,335.7 7D 1,4316 MWD 0W3G(5) 12,6611 9186 354.55 6,856.3 6,56 .4 1462.1 7,163.1 5.92.671 50,333.0 5.9 1.462M MND OWBG(5) 12,8856 W74 36.34 68555 6,559.6 1,492 7.166 SM.6412 547,328.3 125 14922 MWD Oy26G(5) 12,7162 Best 348.23 66554 6,559.5 15292 7162.9 5,97,912 50,322.5 74 1,52621 MWD OWBG(5) 12,750.9 00.83 34527 66551 6,559.6 1,56 .0 7,145.0 5,97,704.9 50,3144 9.1 1.5% SO MM MSG (5) 12.7859 88.6 34337 6,6565 6,56.6 1,593] 7,1355 5gloi, .6 50,304.] 5.5 1,593 70 MND 09766 (5) 12,@2.0 M13 34104 68576 6.6617 1828.1 7.44.5 5,97.7729 5029.5 &8 1,'6260] MWD OVSG(5) 11/122019 3:69:57PM Page 5 CChNaISS 50010.14 Better OW Survey ConoeoPhillips am.akafata ., ConocoPhillips Definitive Survey Report Company: ConocoPhllllps Alaska Inc Kuparuk Local Co-ordinab Res...: MIDIA-04 Project: Kuparuk River Uml ND Resonance: 1A -04A@95.9@ 959usn(IAA4A@95.9) She: Kuparuk to Pad MD Reference: 10-04A@95.9@959usn (IA-WA@959) Well: IA -04 North Reference: TmB Wellbore: 1A4 l Survey Calculation Method: Minimum Curvamna Design: 1A-04AL1 Database: EDT 14 Alaska Production Survey 11A=()I9 3:59:57PA1 Pape 6 COMPASS 5100.149u9d 95N MD Inc add TVD Woes .W-5 �Ef-W Nanning Eaton 9 DLS Secllon 6urvey ToolName Qn1101d110r1 lusnl 1°I 1°I loan) luartl lural 1u6n1 Inl lkl 1°1190'1 1rt) 12.8509 08.15 33850 6650.5 6,562.6 1,655.2 1.114.5 69n.m9 54].2834 85 1,&620 MWD OWSG(5) 12.0806 89.02 W765 8.659.2 6.553.3 1.031.9 7,1034 5,9R,W6 51],2]1.1 43 1.68292 MWD ONNG(5) 12.997.0 kill 33397 6.659.6 6,5637 17059 7,0930 5,972,850.6 517,M.3 2.7 1]05.94 MVA O`M36(5) 11,9260 89A7 33598 dead 6.561.1 1,T a 7.085.T 5,972,039.0 51],254.2 4.9 1,724.46 MND 09756 (5) 12,9537 8797 335.12 am 6.561.6 17516 7.0734 5,97ZM1 54],241] 50 1,75155 MRD 0NSG(5) 12.9957 07.24 33267 6,652.4 8.555.5 1,)67.4 7,0558 5,972,931.8 547,224.0 81 1,787,41 MN90W5G(5) 13.0258 86.80 33076 6.6639 6.566.0 1,0139 7,0418 5,972,9582 547.206.6 6.5 1.81307 MWDOWSG(5) 13.0508 68.41 329.50 6.6654 6.SW.5 1035.5 7,029.1 5.972.9798 547]9]0 5.3 1.835.W MWD OANSG(5) 13,0930 W41 Man 6,6681 6,582 1.8710 7,007.6 5.973.0160 54795.5 00 1,871.W PROJECTEDto TO 11A=()I9 3:59:57PA1 Pape 6 COMPASS 5100.149u9d 95N ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1A Pad 1A-04AL1PB1 50-029-20621-70 Baker Hughes INTEQ Definitive Survey Report 12 November, 2019 Baker Hughes S Declination Dip Angle rl (°) 1640 80.85 Tie On Depth: 8,716.0 +W-0 Imdg 0.0 [Handles r) 0.00 lskavlisssad 70.19 55.198 N 149" 40' 26 725 W 0 0 usa Field SNengdh mo 57,401 94978005 Survey Progam was ConoeoPhillips 1A-04ALl PBI initiation. Model Name ConocoPhillip5 SumyM1Maleeal Definitive Survey Report Company: C000naPhillips Alaska lnc_Kupamk 1A 04AL1 P9 Local Ooorsinas Reference: WPI, IA -04 Product: Kuparek River Unit FINDER -MS TVD Reference: 1A-04A®95.9@95.9usa(1A-04A®95.9) Sae: Kupaak lA Pad Venlcal Section: MD Reference: 1A -04A®95.9@ 95.9usR(1A-04A®95.9) Well: IA -04 SDC Finder muaicMt North Reference: True Wellall 1A-04AL1PB1 95 9 Survey Calculation Method: Minimum Curvature Design: 1A4MAL1PB1 1002019 Dasaase: EDT 14 Alaska Production Project Kupamk River Unit, North Slope Alaska, United Slates MWDOWSG Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Gao Datum: NAD 1927 (NADCON CONUS) Using Will Reference Point Map Zone: Alaska Zone 04 11/122019 3:59:OSPV Using geodetic was factor Well 1A-04 Well Position .NIS 0.0 uati Northing: 5,971,10683ush Latitude: .FJ -W 0.0 usa Easting: 540, 17652 usft Longitude: Position Uncertainty 0.0 um Wellhead Elevation: usa Ground Level: Declination Dip Angle rl (°) 1640 80.85 Tie On Depth: 8,716.0 +W-0 Imdg 0.0 [Handles r) 0.00 lskavlisssad 70.19 55.198 N 149" 40' 26 725 W 0 0 usa Field SNengdh mo 57,401 94978005 Survey Progam was Wellbore 1A-04ALl PBI initiation. Model Name Semple Distill SumyM1Maleeal BGGM2018 10112019 Design 1A 04AL1 P9 1959 Audit Notes. 1A-04(1 A-04) FINDER -MS Veraom 1 0 Phase- ACTUAL Venlcal Section: 11,7160 Depth Flom(TVD) FINDER -MS SDC Finder muaicMt Juan) 6,781.0 95 9 Declination Dip Angle rl (°) 1640 80.85 Tie On Depth: 8,716.0 +W-0 Imdg 0.0 [Handles r) 0.00 lskavlisssad 70.19 55.198 N 149" 40' 26 725 W 0 0 usa Field SNengdh mo 57,401 94978005 Survey Progam was From luartl To lusnl SumyM1Maleeal Tool Nana paedp6on BYreey Blertwle &IMy End Dole 1959 6,3959 1A-04(1 A-04) FINDER -MS SDC Finder poignant 625,2000 6493.0 11,7160 1",IA(1A A) FINDER -MS SDC Finder muaicMt 2222001 6,781.0 8,902.6 1A -001.I PBI MiAll(1A-04AL1 P0r MWD -INC ONLY MWD -ll _ONLY FILLER 1002019 1OBR019 8,9309 12,029.6 1A-OMLIPBI MWV(1A AL1PB1) MWDOWSG OWSG MWD- Standard 109929 lontaoig 11/122019 3:59:OSPV Pap (3011 1!000.1480:18 H 11/122019 3:59:0590 pop 3 sioneseeinee 1 I AMOtation TIP KOP Interyolatetl Azimuth j Interyolatetl Azimuth Interyolatetl Azimuth Interyolatee Azimuth ConocoPhlllips ConocoPhillips Definitive Survey Report Company: COnncaPhllllps Alaska lnc Kupamk Local Co�ordmata Reference: Wall 1A-04 PmN44: Kupamk River llnh TVD Reference: 1o-04A@959®959us0(IA-0A@959) SIM: Kupamk lA Pad MD Reference: tA44A@959@ 959us6(IA-04A@95.9) We1L 1X04 Norm Reference: Tme Weltbon: IA UPB1 Survey Calculation Mations: Minimum Curvature Deelgn: 1A-04AL1PB1 Database: EDT 14 AMaka Production Survey -- flap Map vildcal MD Inc AD xl TV TVOSS +N18 +EI -W No S OLS Section Survey Tool Name (pall (1) (1) (ueR) 0.11) (ueM) (u.R) '„'ng IR)^g 1.1100) In) &]160 N.59 2456 6,339.4 6,2435 -]26.1 4,4232 5,910,404.5 50,605.1 0.6 -]26.12 MV 114C ONLY (3) 8,84 .0 "40 2467 6,387.9 6.82.0 -502.0 4,9930 5,970,4479 5448247 03 882.82 hl 4INC ONLY (3) 8.011.1 4821 2050 6.406.6 6,310.7 bBf.] 4,4505 5,67045.0 W.,W1 179 -684.75 MK INC_ONLY (3) 8,0015 5258 2050 6.4'26.0 8,330.1 842.8 44Y.] 5,9]0.4850 50.640.2 144 -64281 M INCONLY (3) 8,0723 5722 2050 6,443] 6.328 219.2 4,46].5 5,9]0.5116 S .Mg 15.1 619.21 MN INC_ONLY (3) 0.60 .6 6218 2050 6.459.0 5363.1 6147 4,4T8.] 5970,5382 SM&579 15.6 .594.83 MYNINC_ONLY (3) am 6743 W52 6.4710 6,3751 8]0] 4,985.] 5,910,551 544,8 7 103 -570R MM OWSG 141 8.561.3 7401 1189 6,4819 6,385.1 4543.0 4,495.6 5,9]0,58).2 50676.5 217 -543.78 MND ONSG (4) 8.991.1 7812 1078 6,4889 8.3!1.1 4516.5 4,505.2 5.970,614.5 50,685.9 17.5 -518.10 MVD OWSG (4) 1021.1 00.93 17.91 6,492.1 6.396.2 480.3 4,514.5 5.970,6W28 Wells 196 488.29 MVD GWBG (4) 9,911.0 9175 1788 6.40.0 6.3971 -059.9 45246 5,970,6711 544]91.1 228 451.88 MND GY5G (4) 9,col .1 9606 2033 6,409 8,3950 431.5 4,533.4 5,970,699.7 50.]13] 168 -031,46 MND OWSG (4) 9,111.9 w8`1 2546 6,49]] 8.3916 4032 4,5453 5910,080 54k7Z5 19.6 4ON MWD GNSG (4) 9,140.5 95.29 29.91 8,4959 8.389.1 -370.0 4,556.5 5.970.7533 50,7355 14.8 -370.@ MM 0N5G (4) 9,173.2 93.75 3434 6,182.4 6.386.5 -35.4 4,575.8 5,9m,ni0 544.)55.] 149 -35035 MWD OW3G (4) 9,201.0 9352 3574 6.95.8 6.3&.9 327.4 4.692.8 5.970180.1 W,7n6 159 -32],40 kMD OW8G (4) 9.231.6 W,07 41.07 6.493.] 8,30.8 801 4.6121 5,9]0,028.8 50.791.7 153 -3Wn MND ONSG (4) 9,2617 0791 4721 6.017 8,385.8 303.2 4.633.2 5,970,849A 50.8127 1]] -203.25 MND ONSG (4) 9,92 .4 07 82 5232 6,482a 6.30].0 -263.5 4,8555 5.9]0.089.3 W4.536.0 16.7 -2&-6.90 MWD 0W6G (4) 9,322.4 W05 W87 6,483.7 6.3878 -246.1 4,510 597),005.8 50,85.3 15.7 -245.13 MAD .OW&G(4) 9,35 .4 W85 6059 6.483.9 6.388.0 331.6 470.9 5,9]0,9135 61480.2 136 331.57 MND OWSG I4) 9,35 .6 9003 6537 6,4840 6,3984 -217.8 4731.1 5,970,9144 04.9119 158 -21].91 MWD OW6G (4) 9,4109 555 6815 6,483.0 8397.9 306.9 4,7596 5,970,926.4 W4.849.] 94 -20.91 MWD ONSG (4) 9.00 .9 W.40 7091 6,4836 6.3977 104 4,]67] 5970.93].1 Wallis 9.4 485.0 MVD BWGG (4) 9,4]0] 5.21 7402 6,03.4 8.W75 -186.5 4,016.2 5,9]0.06.2 W,M2 10.3 -186.46 MND GW6G (4) 9,511 9190 76N 6.402.9 6,3870 -1781 46456 5,9/0X54.1 545,024.5 93 -178.5 MWD BWBG (4) 95316 9123 ]95] 6,482.0 8,395.1 -92.3 4,0754 5,970.95] 05.091.3 11.0 -10.9 el OASS (4) 9,5598 5.80 01.98 6,4815 6.385.8 491.8 495.0 5.970,955.3 W5.0819 67 -167.61 MN90N5G (4) 9,50.5 5.65 91.30 6,401.1 6.3852 -164.1 4,9336 5.970,6692 545.1125 ]5 -191.12 MVD BWSG (4) 9681 92.50 W72 6.45.3 8.391.4 -1616 4.W3.2 5.970.9716 515.142.0 104 -161 W MND GASG (4) 11/122019 3:59:0590 pop 3 sioneseeinee 1 I AMOtation TIP KOP Interyolatetl Azimuth j Interyolatetl Azimuth Interyolatetl Azimuth Interyolatee Azimuth ConocoPhillips ConocoPhillips Definitive Survey Report Complain ConoccPhillips Alaska Inc_Kuparuk Local Cobtdnate Reference: ProJ94b Kupamk River Unit TVC RNerence: Sfts: Kupamk lA Pad MD Reference: Well: 1A-04 Dania Reference: Wellbore: IA-04AL1P91 Survey Calculation Method: Conga: IA414AL1PR1 Database-, Sual WeII 1A X 1A -04A®95.9 @ 95.9uaft (1A-04AQ95.9) 1A -04A®95.9 ® 95.9usft (1A-04AQ95.9) TNe Minimum Curvature EDT 14 Alaska Production FFFWWIIHB Y61 1 Page 4 Annotation CDMP.4S5 6000.14 Buitl 8611 Vertical MD Mc AE TVD NDSS aNIS .EI -V4 M Nerg ESWng Sefton Survey Tool Name (lam (°) In lusft) (usft) (.an) (-am IN (ft) MOD) in) g elea7 93.39 00.6] 6,4]8] 6,302.0 IWE 4,99 .7 59]11.991.0 545,1M5 69 450.5] MWD MSG (4) 9,E00.4 no 93.95 6,477,1 63812 183.5 5,023.3 59]09]3.3 545261 80 -16.48 MM OW6G(4) 9,7104 9237 W75 6050 6.3]99 -1814 5,0533 5.970,9T2.5 A523L1 61 -16114 MWD onGG(4) 9,741.0 90.64 92.6 6050 6.3]9.1 -109 5,033.8 69]0,9]1.1 545.2626 57 462.94 MWD OWBG(41 9.70.9 9012 ED 56 6,040 6,3789 -163.8 5,1137 5970,970.4 545,2P25 7.9 463.83 MWD Corso (4) 9,860 6902 086 6.4751 6,3792 -183] 5143.6 5.9T1970.7 545,3924 68 -183.6 MWD CASE (4) 9.030.3 647 683 6,4782 636.3 -163.0 Ein1 5,9]0,9]1.5 545,351.9 8] -163.04 MM OW6G (4) 9,08.4 056 6.32 6.08.0 6382.1 4617 52031 5,970,9]3.0 545.301.9 70 -161.72 MWD ONSG(4) 9,8907 0631 84.6 6.099 63840 ASED 5233.3 5,9]0,9]58 545,4121 67 -159.24 MWO OW6G(4) 9.930.0 6.R 82.15 6,4823 6,36 .4 -151.5 5,2]3.0 5.9]0,9006 545,4510 55 -154.0 MWD CAUSE (4) 9.649 856 02.18 6,484.5 6,36.8 -1499 636.7 59]0.605.4 545,4854 25 -149.6 MM GAVE (4) 99937 056 82.83 646.4 636.5 -146.6 5,332.2 5,970,6080 545.5109 3.1 -146.5] MM 0W5G(4) 1D,0207 8844 82.6 6.48].0 63919 -142.] 5,3B19 5,970,5929 545.5406 89 342.6 MMONSG(4) 10,68.0 87,02 8191 6./89.9 63930 -1391 5,36] 5970,59].0 545564 51 -13873 MND OW5G)4) 1060.9 DEAD 79.64 6.4932 6,394.3 AMD 5,421.4 5,971 Ont) 545.6000 83 43359 MND(h SG(4) 10.110.2 8504 ]8 64 6,4916 6,395] -128.1 545.1 5.971,8080 545,8281 8.8 -128.07 MND ONSG(4) 10.140.3 0370 78.29 6,46 .3 5,398.4 -1216 54]9.4 5,971,0146 X58580 110 -121.W MND ONSG(4) 10.1706 04.65 7483 8,4974 8.401.5 -1140 5,508D 5,971,0223 X5.637.1 62 -114.6 MND 0NSG(4) 10,2010 683 ]IX 64997 6.4038 -1058 553].6 5,971,0307 X5.7163 20 -161.82 MND 001SG(4) 1DtoE7 98.04 7138 9601.0 8905.1 -973 5,56 .1 5,971,69.4 545.7436 109 -970 MND OW8G (4) 10281.1 6.83 0,51 Erna 640.7 -83.8 5,599.6 5971,600 X5,730 04 -06.7 MND ONSG(4) name 84 60 RBI 6,W5.0 546.1 472 5-692.5 5,61,69.7 045.068 112 -]]21 MND ONSG(4) 10,3194 95.11 ]4.28 6`9].5 6,4116 491 5,649.9 5,971,60.0 545.8202 58 -6905 MND ON5G(4) 10,352.7 87.88 7564 0,509.5 64136 804 E&W1 5,971.0769 545.863 83 80.42 MWD 0061) (4) 10,3823 8].33 79.02 6,510.7 64148 -53.9 5,710.9 5.971.8835 X5,960 116 -53.94 MWD OOSG(4) 10,4121 ED0 0104 8512.2 64183 489 5,740.3 59]1,68] 545,918.4 89 486 MND ONS3(4) 10,4429 6.7 saw 8,513.9 6,4180 41.3 5,]70.6 5,971,635 515.948.8 25 443] MND ONSG(4) 10465 DEAD 730 6515.5 6,4196 -393 5707 5,971.686 545,9740 137 -39.25 MWD00c56)4) 10.499.6 83.6 ]53] 6,517.3 64214 -32.2 5.825.9 5,971,1058 SIBpD39 7.0 -3215 MWDOWSG)4) 10.561 DEAD 7446 6,5194 6,423.5 44.2 5855.3 5.9711140 548,033.3 7.0 -24,n MNDOWSG)4) 10,61.5 85.76 n 6,5219 6.428.0 -152 5,96 .3 5,971,1232 546.083.3 79 -1519 MMA ONB3)4) FFFWWIIHB Y61 1 Page 4 Annotation CDMP.4S5 6000.14 Buitl 8611 ConoeoPhillips eaknRwl»a ConocoPhillips Definitive Survey Report Company: ConomPhilllps Alaska Inc Kupamk Local C.-ordeate Rbferaral Mil 1.o-134 Pre1ed: Kupamk RlVer Unit ND Reference: 1A-04A@959@ 95.9ueft(tAA4A@95.9) , Sea: Kupamk lA Patl MD Reference: 1A-04A@959@95.9usft(tA-NA®959) Well: 1A44 Nonni Reference: T. WellEon: 114 AL1PB1 6uney Calculation Method: Minimum Curvature Dealgn: 1A44AL1PBt Database: EDT 14 Alaska Pmdudlon Survey May Map NrMee1 MD Mo Aal TVD "DSS +NIS ell WS 9eglon NO Eeetino gVrvsy TOpl WIM ARRplBflpR IMaIU 19 111 Waft) lural NSR) Ittm let Ntl IRI ('n091 H41 1D,5912 84.50 69.51 6.5244 6,4285 5.5 5,9132 5.971,1330 546,091.1 9.5 540 MM G(4) 10.6218 Sew 642E 6,5 ..0 6,430.9 84 5,9410 5,971,1451 5461109 18.5 643 MWD GWSG(4) 10,%16 6,70 6049 65263 6,432.4 20.3 59676 5,971,1591 546145.3 130 2033 MWD GWSG(4) 10,8]95 0754 6125 6,529.5 6433.8 339 5,9918 5,9]1,1]28 5461076 20 33.91 MWD OWSG(4) 10,]1 6 85.93 60.09 65339 6,435.0 48.6 8018.1 5.971.1877 86,1957 44 4683 MWD 0W6G(4) 10,740.0 86.5 61.76 6,532.7 6.436.8 6±.4 8,044.] 5.971.21126 546.=2 56 63.39 MWD OWBG(4) 10700 04.31 6213 6..535D 6,439.1 ]].5 60711 5,9713160 546,2405 i7 7747 MWD GWSG(4) 10,007.3 82.49 6304 6,5365 6,4426 91.3 6,097.0 5,971,2300 546.275.1 8.7 9130 MM OWSG(4) 10,829.7 81]] Nee 8.542.5 6.4456 104.2 8,123.9 5,971,2438 W..3012 56 104.10 MND OWSG(4) ID.06.5 8144 65.43 6.50.0 6,451.1 117.1 6,151.5 5.971.2568 546,320] 3.0 117.05 MVA OW9G (4) 1D,8904 W79 64.57 6.6517 6.4558 1295 6,178.3 5.971,2694 545,355.4 36 129.54 MN90W9G(4) 10.920.2 83.00 6304 6,55.0 6,459.9 1428 6.2W.8 5,971,2826 507.3010 92 142 fib MVA OWSC(4) 10.919.9 82.0 6042 6,59.4 6.4635 156.5 6.2301 5,971,2957 516.40]] &a 15.52 MND O'NSG(4) 10,980.3 82.12 58.91 6583.4 6.467 5 1]1.] 6,25] 5,9713121 546.433.6 57 171.74 MM CWBG(4) 11,D102 8380 5725 65].9 6.020 1074 8,2818 5,9]1,32]8 546.45] 7.4 WN MNDtl (4) 11,000.2 81D7 58.31 6,5M6 8,061 2036 6.3^.4.6 5,971344.2 546,483.3 34 211360 MND OWSG(4) 11,0701 8107 570 6,5]].2 8.481.3 2197 6,3310 5,971,36D,4 546.508.0 46 219.n MM ONSG(4) 11,1016 NO elm 8.563.1 8.484.2 059 8,35.3 5,971,378] 546.531.8 224 235.5 MWD ON5li(4) 111303 89.29 59.04 6.590.] 6.48.0 2WA 8,383.1 5,971.3914 546,559.5 63 20.38 MN9 W.Sf (4) 11,16.0 8739 5].]8 6.5816 6,4851 2859 6.400.3 5,9]1.40]0 546.58.7 7J 205.91 MND OWBG(4) 11.164 6.20 5]3] 8,563.8 6,W,7 2822 8.433.9 5,971,4235 546810.2 7,3 282.20 MND OWSG(4) 11,220.5 8634 558 6.55.8 6,4893 298 6,46.0 5,971,"0.1 86.6352 63 299]3 MND PASG(4) 11,2501 W20 53.75 6,SW.2 6.4913 3157 6,4831 5,9]145].3 545.652 96 31575 MND ONSG(4) 1126.0 83.25 61,73 6,589.6 6,492.7 3338 8.5^.4.9 5,9]1.4]55 546882.9 98 333.03 MWD OWBG(4) 11,35.5 5.82 5120 6.56.6 6,487 3521 6.5209 5,9714939 86,705.8 23 362.14 MWD OWSG(4) 11.340.0 M52 5037 6,581.0 8.49].1 371.9 6,58.1 5,971,513.9 540.14.9 28 37193 MWD OWSG(4) ' 11,371,2 8.31 506 8.55] 6,499.0 382 6,0774 5,971,5332 86.753.1 4.0 391.16 MWDO (4) 11,46.4 820 465 6.59ad 6.62.7 4101 6,5995 5,171,523 5W,P51 02 410.13 soh!) G(4) 11,4308 047 4545 6.618 6'F a 430.7 6.6214 5,971930 86]98.8 9.1 430.n MWD OWB3(4) 11,460.4 he 13 4389 6,604.5 8,507.6 451.8 6.822 5,9]1,54.1 548.81!.8 104 451.78 MWDOW6G(4) - 114898 W.53 4181 6.85.4 6.510.5 4733 --- _ - 8,621 5,9]1,815] _ 5468374 72 4]3.29 MWD OW6G(4) 11/128019 3:59'05PM Page 5 COMPASS 601111.14 BWd M Conocolahillips aoM,mNMaa ConocoPhillips Definitive Survey Report Company: ConomPhillips Alaska lac Kulamk Project: Kupamk Fanner Unit Site: Kupamk to Pad Well: 1A414 Wellbore: 1A-04AL1PB1 Design: 1A-04AL1P01 Survey Local Co-ordinate Rafteamau Wbll IA -04 ND Reverence: 1AD4A@95.9 C 95.9uaX (1,A-UA®959) MD Rak.nce: lX04A@95 9 Q 95 Oman (IA-04A@M.9) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDT 14 Alaska Pradcdcn Annotation 11/122019 I W OSPM Pepe a COMPASS 5t10014 BaIM Mhf Map Map MD Mc Aad TVD TVDBs MLS E2 -W Eetin9 US Section 6ectlen NOrthin9 1.1100) Survey Tool Name (tell) 1°) n (-am (Main (UM) lush) R I ( 1X) XI 11,5100 8536 3976 6,E08.5 8,511.6 498.1 6,681.8 49]1,638] 546,855.9 78 495.09 MW➢OWSG (4) 11$498 83.51 3X17 6.611.4 6.5155 519.2 6.70.5 5,971,651.9 545,0]5.5 79 519.19 MWDOWBG(4) 11,5799 8567 37.65 6,614.2 6.5103 M2.9 6,7168 5,9]1,885] 546.693.6 77 542.90 MWD OW6G (4) 11,819] 6310 3587 6.6122 6,521.3 5676 S73&S 5,971,7104 546,9111 9.5 55].50 MWD OWBG (4) 11,840.o Si 3564 662(11 6.5242 5912 8,753.9 5.971,TM2 W905 90 59124 MWD GAGS (4) 11,6586 8588 358 8.6222 5.5€.3 6153 6,]]12 5,9]1,]503 546.945.6 06 615M MWDO (4) 11,7002 84.84 35]3 6.624.] 6,5208 840.1 6.7890 5,9]1,]83.2 545841.3 34 "DW MAD OW3G (4) 11]29] 81.28 35.12 6.628.3 6,5MA W3.8 6.809 5,971,070 Want 123 65384 MWD OhNG (4) 11,MDA 02.52 3349 6,632.6 6,53 .7 09.0 Stoat 5.971,023 54099].1 6.6 60.0 MWDOWBG(4) 11,7911 at 32.42 8W7.1 6.541.2 7153 8,640.2 5.9]1,850] 547,D14A 58 71534 WVI[)G(4) 118186 79% 3132 8,841.0 8.505.9 7305 Swett 5.9]1.01.9 54],028.3 62 73.40 MWD OWSG(4) H,802 8305 3.57 6,606.0 0505 780.3 5.8700 5971,07.0 547,043.] 114 780.29 MWD OASG (4) 11,8799 8038 29.52 6.809.6 6.507 Man Baton 5.971, M4 547,98.3 57 70.0 MWD OWBG(4) 11,9399 033 2741 6.652.3 8,504 8180 6.8990 5,9]1,959.] 54],084 ]] 816.0 MWDO G(4) 11,9396 0.37 340 6.653.4 6,557.5 MIS 6,9125 5,9]1,65&3 54],DW] 17.3 802.5] MWD OW6G(4) 11,9696 09.51 2424 6,034 8,55]5 397 6.925.3 5.980135 547,43.4 78 M67 MWD CASG(4) 11.9997 W31 21.92 6653.5 11.5576 073 6,937.1 5,989412 547,1100 02 8978 MWD OW$G(4) 12,M6 W.99 N.0 6.6537 6,5570 6552 6,9479 5,MD692 547.IM7 82 925.23 MWD OWBG(4) 120W.0 W99 ffi0 6,850.3 6,5W4 9593 6,960.7 5,9($103.3 54713.3 0.0 959(5 PROJECTED to TD Annotation 11/122019 I W OSPM Pepe a COMPASS 5t10014 BaIM Mhf RECEIVE® NOV 14 2019 AOGCC Baker Hughes Date: Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 November 13, 2019 219065 31436 Letter of Transmittal Harvey Finch Baker Hughes 795 East 94t" Avenue Anchorage, Alaska 99515 find enclosed the directional survey data for the following well(s): 1A-04AL1PB1 1A-04AL1 (2) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Harvey Finch, Baker Hughes, Wellplanner Harvev.Finch(obakerhughes.com 219065 3 143 6 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1A Pad 1 A-04AL1 50-029-20621-60 Baker Hughes INTEQ Baker Hughes�j Definitive Survey Report 12 November, 2019 9- ConocoPhillips Project ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kupamk Local Co-ordinate Reference: Project Kuparuk River Unit TVD Reference: Site: Kuparuk IA Pad MD Reference: Well: 1A-04 North Reference: Wellbore: 1A-04AL1 Survey Calculation Method: Desi m to-04ALl Database: 9- Project Kuparuk River Unit, North Slope Alaska. United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zane 04 Well 1A-04 Well Position +N/ -S 0.0 usft Northing: +EI -W 0 0 usft Easting: Position Uncertainty 0.0 usft Wellhead Elevation: Wellbore 1A-04AL1 Magnetics Model Name Sample Date BGGM2018 10/1/2019 Design 1A-04AL1 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) ("sit) 95 9 Well 1A-04 1A -04A@95.9 @ 95.9usft (tA-04A@95.9) 1A -04A@95.9 @ 95.9usft (1A -04A@95.9) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,971,108.83 usfl Latitude: 540,178.52usft Longitude: usfl Ground Level: Declination Dip Angle 11 0 18.40 80.85 Tie On Depth: 10,401 0 +N/ -S +EI -W Direction (usft) (usft) (I 00 D.D 000 70" 19'55.196 N 149'40'26 725 W 0.0 usft Field Strength OT) 57,401.94978005 11/1212019 3: 59 57P Page 2 COMPASS 5000 14 Build 85H ConocoPhillips faker Hugh. ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1A-04 Project: Kuparuk River Unit Map TVD Reference: to -04A@95.9 @ 95.9usft (tA-04A@95.9) Vertical Site: Kuparuk 1A Pad Inc MD Reference: 1A -04A@95.9 @ 95.9usft (tA-04A@95.9) TVDSS Well; 1A-04 Northing North Reference: True Section Wellbore: to-04ALl P! Survey Calculation Method: Minimum Curvature (usft) Design: 1A-04AL1 (ft) Database: EDT 14 Alaska Production (R) Survey Program 104010 Date 8065 6.511.6 6.415.7 From To 5.971,086.9 545.9075 8.9 Survey - (usft) (usft) Survey (Wellborn) Tool Name Description Start Date 195.9 6,395.9 1A-04 (1A-04) FINDER -MS SDC Finder multishot 8/25/2000 6,493.0 8,716.0 1A -04A (IA -04A) FINDER -MS SDC Finder multishot 2/22/2001 8,784.0 8,902.6 1A-04ALIPB1 MWD -INC (1A-04A1-1PBt MWD -INC ONLY MWD -INC ONLY -FILLER 10/2/2019 8,930.9 10,401.0 1A-04AL1PBl MWD(1A-04ALiPB1) MWD OWSG OWSG MWD - Standard 10/7/2019 10,432.5 13,050.6 IA-04AL1(1A-04AL1) MWD OWSG OWSG MWD - Standard 10/7/2019 Survey Survey End Date 10/6/2019 10!712019 10/7/2019 Annotation TIP/KOP 111121'2019 3'59:57PM Page 3 COMPASS 5000. 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W Northing Eastin DLS Section Survey Tool Name (usft) P! P) Wait) (usft) (usft) (usft) (ft) (Poe (`/too') (R) 104010 87,08 8065 6.511.6 6.415.7 -50.6 5,7293 5.971,086.9 545.9075 8.9 -5064 MWD OWSG (4) 10,432.5 84.70 78.31 6,513.9 6.418.0 M.9 5,760.2 5.971,0928 545,938.3 106 -04.91 MWD OWSG (5) 10456.5 84.50 7741 6,516.3 6.4204 -39.5 5,785.5 5,971,098.3 545,9635 3.5 -3948 MWD OWBG(5) 10,489.1 83.54 75.54 6,5195 6,423.6 -32.3 5,815.1 5,971,105.6 545,993.1 6.8 -32.35 MWD OWSG (5) !- 10.518.8 80.85 7300 6,523.6 6,427.7 -24.4 5,843.4 5,971,1138 546.021.4 124 -24.38 MWD OWSG (5) 10,549.0 7962 70.62 6,528.7 6,432.8 -15.1 5,871.7 5,971,1232 546,0496 8.8 -1508 MWD OWSG (5) 10,578.0 79.66 6743 6,513.9 6,438.0 4.9 5,898.4 5,971,133.6 546,076.2 10.8 -486 MWD OWSG (5) 10,607.1 8060 65.20 6,5389 6,443.0 67 5,924.6 5,971,145.2 546,102.4 65 6.66 MWD OWSG (5) 10.638.5 81.23 63.15 6,543.8 6447.9 20.2 5,952.5 5,971,158.9 546,133.3 66 20.17 MWD OWSG (5) 10.6684 81.21 6068 6.508.3 6,452.4 34.1 5,9786 5,971,1728 546,156.2 82 34.07 MWD OWSG (5) 10.694.8 8102 58.73 6.552.4 6,456.5 472 6,0011 5,971,1862 546,178.7 73 4722 MWD OWSG (5) 10,7222 82.41 56.93 6,556.4 6,460.5 61.7 6,024.1 5,971,200.8 546,201.6 82 61.67 MWD GWSG(5) 10,758.1 84.22 5602 6,5605 6,464.6 813 6,053.7 5,971220.6 546.2311 5.6 81.33 MWD OWSG (5) 10.792.5 8,165 52.91 6,563.9 6.468.0 101.3 6,081.6 5,971,240.6 546,258.9 9.1 101.26 MWD OWSG (5) 10,819.2 8425 54.36 6.565.4 6,470.5 1170 6,103.0 5,971256.5 546.280.3 56 117.03 MWD OWSG (5) 10,8514 83.19 55.65 6,569.9 6.474.0 135.3 6,129.2 5,971,275.0 546,306.3 5.2 135.34 MWD OWSG (5) -. 10,881.5 8261 57.60 6,5737 6,477.8 151.8 6,154.2 5,971,2916 546,3312 6.7 151.81 MWD OWSG (5) 10,910.4 84.06 59.71 6,577.0 6.481.1 166.6 6,1785 5,971,306.5 546.355.4 8.9 166.59 MWD OWSG (5) 10,940.6 85.35 6197 6.579.8 6.483.9 1813 6,204.9 5971,3214 546,381.8 85 181.34 MWD OWSG (5) Survey End Date 10/6/2019 10!712019 10/7/2019 Annotation TIP/KOP 111121'2019 3'59:57PM Page 3 COMPASS 5000. 14 Build 85H ConocoPhillips baker Hughes8 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc-Kuparuk Local Co-ordinate Referonce: Well 1A-04 project: Kuparuk River Unit TVD Reference: 1A -04A@95.9 @ 95.9usft (1A -04A@95.9) Site: Kuparuk 1A Pad MD Reference: 1A -04A@95.9 @ 95 gush (1A -04A@95.9) Well: 1A-04 North Reference: True Wellbore: 1A-04AL1 Survey Calculation Method: Minimum Curvature Design: 1A-04AL1 Database: EDT 14 Alaska Production Survey Annotation 11/1212019 3: 59: 57PM Page 4 COMPASS 5000 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/S -El-W Northing Easting DLS Section Survey Tool Name (usft) (1) 0 (usft 1 Well ( ) Wait) (usft 1 IRI (ft) ('/100') (ft) 10.970.5 M62 64.71 6,581.9 6,486.0 1948. 6,2316 5971,334.9 546.408.4 10.1 194.75 MM 0WSG(5) 11,0002 84.10 65.89 6,584.3 6,488.4 2071. 6,258.5 5.971,347.4 546,435.2 9.3 207.11 MWD OWSG (5) 110299 8391 68.86 6.587.4 6.491.5 2185 6,285.8 5.971,359.0 546,462.4 10.1 21850 MWD OWSG (5) 110603 83.91 70.19 6,590.6 6,4947 229.1 6,314.0 5,9713697 546,490.6 44 229.05 MWD OWSG(5) 11,090.3 82.93 69.66 6,594.1 6498.2 239.3 6,3420 5,971,380.1 546,518.6 37 239.29 MM OWSG (5) 11,119.9 84.90 67.82 6,5972 6.501.3 250.0 6,369.4 5,971.3909 546.545.9 9.1 249.95 MWD OWSG (5) 11.149.7 86.62 6592 6,599.4 6,503.5 2617 6,396.8 5.971402.7 546.573.2 8.6 261.65 MWD OWSG (5) 11,180.2 87.64 63.26 6.600.9 6,505.0 2747 6,424.3 5,971,415.9 546,600.6 94 27469 MWD OWSG (5) 11,210.0 8718 60.47 6,602.3 6,506.4 288.7 6,450.5 5,971,430.1 546,626.8 95 288.73 MWD OWSG(5) 11,2406 87.30 57.79 6,603.8 6,507.9 304.4 6.476.8 5,971,445.9 546,652.9 8.7 30443 MWD OWSG (5) 11269.9 8782 5692 6,605.0 6.509.1 320.2 6,501.4 5,971,461.8 546,677.5 3.5 320.22 MWD OWSG (5) 11,299.6 88.60 55.60 6.605.9 6.510.0 3367 6,526.2 5.971,478.5 546,702.2 5.5 33674 MWD OWSG (5) 11,3302 8677 54.56 6,607.1 6,511.2 354.2 6,551.2 5,971,496.1 546.727.1 7.5 354.20 MWD OWSG (5) 11,360.3 87.11 5287 6,608.7 6,512.8 372.0 6,5754 5,971,514.0 546751,2 5.7 371.99 MWD OWSG (5) 11390.0 86.77 51.37 6,610.3 6.514.4 3902 6,598.9 5,971,532.4 546.774.5 5.2 390.22 MWD 0W6G(5) 11,419.9 86.22 48.36 6612.1 6,516.2 409.4 6,6216 5.971551 .7 546.7972 10.2 409.42 MWD OWSG (5) 114497 84.15 46.61 6,614.6 6,518.7 429.5 66436 5,971,571.9 546,819.0 9.1 42954 MWD OWSG (5) 11,479.9 83.47 44.29 6,617.8 6,521.9 450.6 6,665.0 5,971,593.1 546,840.3 6.0 450.60 MWD OWSG (5) 11,509.7 83.17 4203 6.621.3 6.525.4 472.1 6,685.2 5,971,614.7 546,860.4 7.6 472.14 MWO OWSG (5) 11.539.7 86.35 41.67 6.624.0 6,528.1 494.4 6,705.1 5,971,637.1 546,880.2 10.7 494.42 MWD OWSG (5) 11,569.9 85.69 40.91 6,626.1 6,530.2 5170 6.725.0 5,971,659.8 546900.0 3.3 517.02 MWD OWSG (5) 11599.8 KM 40.48 6,628.9 6,533.0 5396 6.7*14 5,971,682.5 546919.3 64 53961 MM OWSG (5) 11,629.7 85.20 40.96 66317 6,535.8 562.2 6,7638 5,971,7052 5469386 4.9 562.21 MWD OWSG (5) 11,664.7 86.40 41,90 6,634.3 6,538.4 5884 6,786.9 5,971731 .5 546961.5 44 588.37 MWD OWSG (5) 11,695.3 85.91 43.27 6,636.4 6540.5 610.8 6,8076 5,971,754.0 546.982.0 4.8 610.82 MWD OWSG (5) 11725.6 83.88 43.13 6,639.1 6,543.2 632.8 6.828.2 5.9717762 54],002.6 67 632.83 MWO OWSG (5) 11.755.5 81.24 42.34 6.642.9 6597.0 654.6 6,848.4 5971,798.1 547,022.6 9.2 65464 MWD OWSG (5) 11786.2 82.98 4068 6,647.1 6.5512 677.4 6,868.5 5,971,8209 541,0426 78 677.39 MWD OWSG (5) 11,816.5 84]7 4073 6.650.4 6,559.5 700.2 6.888.1 5.9718438 547062.1 5.9 700.17 MWD OWSG (5) 11,835.7 85.51 3979 6,652.0 6,556.1 714.8 6,900.5 5,971 6585 547,074.4 6.2 71478 MWD OWSG (5) 11,860] 84.96 38.12 6654.1 6558.2 734.1 6,916.1 5,9716779 5470900 70 734.15 MWD OWSG (5) Annotation 11/1212019 3: 59: 57PM Page 4 COMPASS 5000 14 Build 85H ConocoPhillips Boker Hughe 8 ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1A-04 Project. Kuparuk River Unit TVD Reference: 1A -04A@95.9 @ 95.9usft (tA-04A@95.9) Site: Kuparuk 1A Pad MD Reference: 1A -04A@95.9 @ 95.9usft (tA-04A@95.9) Well: 1A-04 North Reference: True Wellbore: 1A-04AL1 Survey Calculation Method: Minimum Curvature Design: 1A-04AL1 Database: EDT 14 Alaska Production Survey Annotation 11/12/2019 3: 59 57P Page 5 COMPASS 5000 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Eating DLS Section Survey Tool Name (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (it) (-1100') (-1100') 11,890.7 87.02 39.33 6,656.2 6,560.3 757.5 6,934.9 5971,9014 547.108.5 80 75749 M%M)OWSG(5) 11,920.7 8877 W, 6,657.3 6.5614 780.8 6:953.8 5,9719248 547127.3 6.1 780.81 MWD OWSG(5) 11,950.8 89.60 38.67 6,657.7 6.5618 804.3 6,972.6 5.971,948.4 547,146.0 2.8 804.28 MND OWSG(5) 11,981.0 87.94 35.66 6,658.3 6,562.4 828.3 6,990.9 5,971,972.5 547.164.2 10.8 82831 MWD OWSG(5) 12,0109 88.28 33.37 6,659.3 6,563.4 852.9 7,W7.9 5,971,997.2 547,181.0 8.4 852.92 MWD OWSG(5) 12,041.1 86.56 30.55 6,660.7 6.564.8 878.5 7,023.8 5,972,0229 547.196.9 10.9 678.51 MND OWSG(5) 12,070.8 87.57 2901 6,662.2 6,566.3 9042 7,0386 5,972,048.7 547.211.4 6.2 904.24 MWD OWSG(5) 12.1012 90.40 2743 6.662.8 6,566.9 9311 7,052.9 5,972,075.6 547,225.7 10.6 931.06 MWD OWSG(5) 12,131.1 89.57 25.84 6.662.8 6.566.9 957.7 7,066.3 5,972,1023 547,238.9 6.0 957.73 MND OWSG(5) 12,160.9 8929 23.29 6.663.1 6,567.2 984.8 7,078.7 5,972,1294 547,251.2 8.6 984.82 MWD OWSG(5) 12.190.9 89.99 22.22 6663.3 6,557.4 1.0125 7,090.3 5.972,157.2 547,262.6 4.2 1,012.47 MWD OWSG(5) 12,220.9 90.15 2062 6663.2 6.567.3 1.0404 7,1013 5.972,185.1 547,2734 5.4 1,04040 MWD OWSG(5) 12,251.2 90.49 1949. 6,663.1 6,567.2 1968.9 7,111.7 5,972,213.7 547,283.6 3.9 1,068.87 MWD OWSG(5) 12,280.9 89.63 17.82 6,663.0 6.5671 19970 7,121.2 5,972,241.9 547,293.0 6.3 1,097.01 MWD OWSG(5) 12.315.9 9320 17.63 6,662.2 6.566.3 1.130.3 7,1318 5,972,275.2 547303.5 10.2 1,130.33 MWD OWSG(5) 12,3408 92.34 14.88 6661.0 6.565.1 1.154.3 7,1388 5,972,2992 547310.3 115 1,15428 MWD OWSG(5) 12,366.1 92.37 12.65 6.659.9 6.564.0 1.1788 7,144.8 5,972,323.8 547316.2 8.8 1.178.81 MND OWSG(5) 12,396.2 8843 10,16 6,659.7 6.563.8 1208.2 7,1507 5,972,353.2 547,322.0 15.5 1,208.24 MND OWSG(5) 12.438.6 90.18 7.24 6.660.2 6.564.3 12501 7,157.1 5,972,395.2 547.328.2 8.0 1,250.15 MWD OWSG(5) 12,457.8 91.66 6.46 6659.8 6.563.9 1,279.2 7,160.6 5.972,424.2 547.331.5 5.7 1,279.18 MND OWSG(5) 12,496.0 9234 5.11 6,658.8 6,562.9 1,307.2 7,163.5 5,972,452.3 547334.2 5.4 1,307.24 MWD OWSG(5) 12,5237 9126 3.65 6,657.9 6,562.0 13me 7.165.6 5,972,4798 547336.2 6.5 1,334.78 MWD OWSG(5) 12,556.6 90.86 2.10 6,657.3 6,561.4 1.3577 7,167.2 5,9725127 547.337.6 4.9 1,367.68 MWD OWSG(5) 12590.8 9018 357.98 6,657.0 6,561.1 1,401.9 7,167.3 5,972,547.0 547337.5 12.2 1,401.90 MWD OWSG(5) 12,620.6 90.46 35592 6,656.8 6,560.9 1.431.6 7,1657 5,972,5767 547,335.7 7.0 1,431,60 MWD OWSG(5) 12,651.1 9166 354.56 6,656.3 6,560.4 1,462.1 7163.1 5,972,W71 547,333.0 5.9 1,462.05 MWD OWSG(5) 12,6856 90.74 350.34 6,655.5 6,5596 1.496.2 7,158.6 5.972,6412 547,328.3 125 1496.22 MND OWSG(5) 12,716.2 89.91 34823 6,655.4 6.559.5 1,526.2 7,1529 5.972,6712 547,322.5 7.4 1,526.21 MND OWSG(5) 12,750.9 88.83 345.27 66557 6.559.8 1,560.0 7,145.0 5.972,704.9 547.3144 9.1 155999 MWD 0WSG(5) 12]85.9 8859 34337 6,656.5 6,560.6 1,593.7 7,135.5 5,9727386 547.304.7 5.5 1,59370 MWD OWSG(5) 12.822.0 8813 341.04 66576 6.5617 1628.1 7.124.5 5.972.7729 547,293.5 66 1,62807 MWD OWSG(5) Annotation 11/12/2019 3: 59 57P Page 5 COMPASS 5000 14 Build 85H 11/1212019 3:59: 57PM Page 6 Baker Hughes gj Annotation COMPASS 5000 14 Build 85H ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well 1A-04 Project: Kuparuk River Unit TVD Reference: 1A-04A@95.9 @ 95.9usft (1A-04A@95.9) Site: Kupamk 1A Pad MD Reference: 1A-04A@95.9 @ 95.9ush (1A-04A@95.9) Well: 1A-04 North Reference: True Wellbore: 1A-04ALl Survey Calculation Method: Minimum Curvature Design: 1A-04AL1 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc AN TVD 7VDSS +N1-S +E/-W Northing Northing Eating Section Survey Tool Name (usft) (1) (7 (usft) (usft) (usft) (usft) ('hoof 12850.9 88.15 338.58 6,658.5 6,562.6 1,655.2 7,114.5 5,972799.9 547,2834 8.5 1,655.20 MWD OWSG (5) 12,8808 89.02 33765 66592 6,563.3 1,682.9 7,1034 5,972.827.6 547,272.1 4.3 1,682.92 MWD OWSG J5) 12,905.8 89.11 336.97 6.6596 6.563.7 17059 7,093.8 5.972,8506 547,262.3 2.7 1,70594 MWD OWSG (6) 12,9260 89.17 33598 6,660.0 6,564.1 1,724.5 7,085] 5,972,869.0 547254.2 4.9 172446 MWD OWSG (5) 12,955.7 67.97 335.12 6660.7 6,564.8 1,751.6 7,073.4 5,972,896.1 547,241.7 50 1751.55 MWD OWSG (5) 12,9957 87.24 332.67 6.6624 6,566.5 1787.4 7055.8 5,972,931.8 5472248 6.4 1,78741 MWD OWSG (5) 13,025.8 86.81 330.76 6.6639 6,568.0 1,8139 70416 5.9729582 547.203.6 65 1,813.87 MND OWSG (5) 13,050.8 86.41 329.50 6,665.4 6,569.5 1,835.5 7029.1 5,972,979.8 547,1970 5.3 1.835.50 MND OWSG 15) 13,093.0 WAI 329.50 6668.1 6,572.2 1871.8 7,007.8 5,973016.0 547.175.5 0.0 1,871.80 PROJECTED to TO 11/1212019 3:59: 57PM Page 6 Baker Hughes gj Annotation COMPASS 5000 14 Build 85H 219065 RI �,�;�� � I 3 1 4 3 7 NOV f 4 201s Letter of Transmittal AQGC - Date:--- Baker Hughes November 13, 2019 i o: From: Abby Bell Harvey Finch AOGCC Baker Hughes 333 West 7 I Ave, Suite 100 795 East 94`h Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 ,Please find enclosed the directional survey data for the following well(s): 1A-04ALlPBI 1A-04AL1 ' (2) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files I Harvey Finch, Baker Hughes, Wellplanner Harvey.FlnchPbakerhughes.com I 2 190 65 31437 ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1A Pad 1 A-04AL1 PB1 50-029-20621-70 Baker Hughes INTEQ BakerHughesv Definitive Survey Report 12 November, 2019 ConocoPhillips ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kupamk Local Co-ordinate Reference: Project Kuparuk River Unit TVD Reference: Site: Kuparuk 1A Pad MD Reference: Well: 1A-04 North Reference: Wellbore: tA-04AL1PB1 Survey Calculation Method: Design: 1 A-04AL1 PB1 Database: Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Geo Datum: NAD 1927 (NADCON CONUS) 8/25/2000 Map Zone: Alaska Zone 04 Survey (Wellbore) Well to -04 1A-04 (1A-04) Well Position +N/ -S 0.0 usft Northing: 8,784.0 +E/ -W 0.0 usft Easting: Position Uncertainty 0.0 usft Wellhead Elevation: Wellbore 1A-04AL1PB1 Magnetics Model Name Sample Date BGGM2018 10/1/2019 Design 1A-04AL1PBI Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) (usft) 95.9 Survey Program Survey Date From To 8/25/2000 (usft) (usft) Survey (Wellbore) 195.9 6,395.9 1A-04 (1A-04) 6,493.0 8,716.0 1A -04A (1A -04A) 8,784.0 8,902.6 1A-04AL1P61 MWD-INC(1A-04AL1PB1 - 8,930.8 12,0286 1A-04AL1P61 MWD(1A-04AL1 PB1) Well 1A-04 1A -04A@95.9 @ 95.9usft (1A -04A@95.9) 1A -04A@95.9 @ 95.9usft (tA-04A@95.9) True Minimum Curvature EDT 14 Alaska Production Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,971,106.83 usft 540,178.52usft usft Declination (I 16.40 Te On Depth: 8,716.0 +N/ -S (usft) 0.0 Tool Name FINDER -MS FINDER -MS MWD-INC—ONLY MWD OWSG Latitude: Longitude: Ground Level: Dip Angle (1) 80.85 +E/ -W Direction (usft) N 00 000 Raker Hughes $ 70° 19'55.196 N 149'40'26.725 W 0.0 usft Field Strength (nn 57,401.94978005 Survey End Date 10/6/2019 10/7/2019 11112/2019 3:%05PM Page 2 COMPASS 5000. 14 Build 85H Survey Description Start Date SDC Finder multishot 8/25/2000 SDC Finder multishot 2/22/2001 MWD-INC—ONLY—FILLER 10/2/2019 OWSG MWD - Standard 10/7/2019 Raker Hughes $ 70° 19'55.196 N 149'40'26.725 W 0.0 usft Field Strength (nn 57,401.94978005 Survey End Date 10/6/2019 10/7/2019 11112/2019 3:%05PM Page 2 COMPASS 5000. 14 Build 85H ConocoPh i l lips tele,augh. ai ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1A-04 Project: Kupamk River Unit TVD Reference: 1A -04A@95.9 @ 95.9usft (IA -04A@95 9) Site: Kuparuk 1A Pad MD Reference: 1A -04A@95.9 @ 95.9usft (tA-04A@95.9) Well: 1A-04 North Reference: True Wellbore: 1A-04ALiPB1 Survey Calculation Method: Minimum Curvature Design: IA-04ALIPB1 Database: EDT 14 Alaska Production Survey Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 11/12/2019 3.59: 05PM Page 3 COMPASS 5000 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS •N1.S +E/ -W Northing Eastin a DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (`/100') Survey Tool Name (Po (ft) (ft) 8,716.0 44.59 24.56 6.339A 6.243.5 -726.1 4,423.2 5.970,404 .5 5446051 06 -726.12 MWD-INC_ONLY (3) 8.784.0 4440 2467 6,387.9 6.292.0 682.8 4,443.0 5.970,4479 544.6247 03 -682.82 MM -INC _ONLY (3) 8,811.1 4821 20.50 6,406.6 6,3107 664.7 4,450.5 5,970,466.0 544632.1 17.9 - 75 MM -INC _ONLY (3) 8.841.5 5258 20.50 6,426.0 6,330.1 642.8 4458.7 5,970,488.0 544640.2 144 642.83 MWD-INC_ONLY (3) 88723 57.22 20.W 6,4437 6,347.8 619.2 4.467.5 5,970,5116 544648.9 15.1 519.21 MWD -INC -ONLY (3) 8,902.6 62.26 2050. 6.459.0 6,363.1 -594.7 4,476.7 5,970,536.2 544.657.9 16.6 59468 MWD-INC_ONLY (3) 8,930.9 67.43 2052. 6.471.0 6,375.1 -570.7 4,4857 5,970,560.2 544.666.7 18.3 57072 MWD OWSG (4) 6%1.3 74.01 1989. 6,481.0 6,365.1 543.8 4,495.6 5,970.587.2 544,876.5 217 -54378 MM OWSG (4) 8,991.1 79.12 18.78 6,488.0 6,392.1 516.5 4,505.2 5,970.614.5 544,6859 175 -51648 MWD OWSG (4) 9,021.1 84.93 1796 6,492.1 6,396.2 -488.3 4,514.5 5.970,642 .8 544,695.1 196 -1W,n MWD OWSG (4) 9,051.0 9175 17.66 6.493.0 6.397.1 -059.9 4,5236 5.970,671.2 5447041 228 4%88 MWD OWSG (4) 9,081.1 96.06 2033. 6,490.9 6,395.0 -0315 4,533.4 5,970,699.7 544713.7 16.8 431,46 MWD OWSG (4) 9,111.9 95.84 25.46 6,487.7 6,391.8 103.2 4,5453 5,970.7280 541,7255 16.6 40324 MWD OWBG(4) 9,1405 95.29 29.69 6,485.0 6,369.1 -378.0 4,558.5 5,970,753.3 544.738.5 14.8 -378.02 MWD OWSG (4) 9,173.2 93.75 34.34 6,482.4 6,386.5 -350.4 4,575.8 5,970,781.0 544.755.7 14.9 -350.35 MWD OWSG (4) 9,201.8 92.52 38.74 6,480.8 6,384.9 -327.4 4,592.8 5,970,804.1 544,772.6 15.9 -32740 MWD OWSG (4) 9,231.6 88.07 4187 6,4807 6,384.8 4304.7 4.612.1 5,970,826.8 544.7917 18.3 -304.72 MWD OWSG (4) 9,261.7 87.91 47.21 6.4817 6.3858 -283.2 4,633.2 5,970,8484 544,812.7 17.7 -283.25 MWD OWSG (4) 9,292.4 8782 52.32 6.482.9 6.3870 -263.5 4,656.5 5970,868.3 544.836.0 16.7 -263.48 MWD OWSG (4) 9,322.4 89.05 56.87 6,483.7 6,387.8 -246.1 4,6810 5,970.8858 544860.3 15.7 -246.13 MWD OWSG (4) 9,3504 8985 60.59 6483.9 6,388.0 -2316 4,704.9 5,9709005 544.8842 136 -23157 MWD OWSG (4) 9,380.6 90.03 6537 6,464.0 6,388.1 -217.8 4,731.9 5.970,9144 544911.0 15.8 -217.84 MWD OWSG (4) 9,410.9 90.55 68.15 6,483.8 6,3879 -205.9 4,759.6 5,970,9264 544938.7 9.4 -205.91 MWD OWSG (4) 9,4409 90.40 70.96 6,483.6 6,387.7 -1954 4,7877 5,970,937.1 544,966.8 9.4 -195.44 MWD OWSG (4) 9,4707 9021 74.02 6,483.4 6,387.5 -186.5 4,816.2 5,970,9462 544,9952 10.3 -186.46 MWD OWSG (4) 9,5012 91.90 7629 6,4829 6,3870 -178.7 4,845.6 5,970,954.1 545,0245 93 -17866 MWD OWSG (4) 9.5316 91.23 79.57 6.482.0 6.386.1 -172.3 4,875.4 5,970,960.7 545,054.3 11.0 -172.29 MWD OWSG (4) 9,559.6 90.60 8198 6.481.5 6,385.6 -167.8 4,903.0 5,970,965.3 545,0819 87 -167.81 MWD OWSG (4) 9,590.5 90.65 8430 6,481.1 6,385.2 -164.1 4.9336 5,970,969.2 545,112.5 75 -164.12 MWD OWSG (4) 9,6201 9258 8672 6,480.3 6,384.4 -161.8 4%3.2 5,970.971.6 545,142.0 104 -161.80 MWD OWSG (4) Annotation TIP KOP Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth 11/12/2019 3.59: 05PM Page 3 COMPASS 5000 14 Build 85H ConocoPhillips mka egfe48 ConocoPhillips Definitive Survey Report Company: Cono Phillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1A-04 Project Kupamk River Unit TVD Reference: to -04A@95.9 @ 95.9usft (tA-04A@95.9) Site: Kuparuk 1A Pad MD Reference: 1A -04A@95.9 @ 95.9usft (1A -04A@95.9) Well: 1A-04 North Reference: True Wellbore: tA-04ALIPB1 Survey Calculation Method: Minimum Curvature Design: 1A-04AL1P81 Database: EDT 14 Alaska Production Survey Annotation 11/12/2019 3:59:05PM Page 4 COMPASS 5000.14 Build 85H Map Map Vertical MD Inc AZI TVD TVDSS +N/ -S •EI -W Northing Eastin 9 DLS Section (usft) (1) 0 (usft) (usft) (usft) (usft) (•1100•) Survey Tool Name (ft) (ft) (ft) 9.6507 93.38 88.67 6478.7 6,382.8 -160.6 4,993.7 5.970,973.0 545.172.5 69 -160.57 MWD OWSG (4) 9,680.4 9267 90.95 6,477.1 6,381.2 -160.5 5.023.3 5.970973.3 545,202.1 8.0 -160.48 MWD OWSG (4) 9,710.4 92.37 92.75 6.475.8 6,379.9 -161.4 5,053.3 5.970,972.5 545,232.1 6.1 -16144 MWD OWSG (4) 9,741.0 90.64 92.86 6,475.0 6,379.1 -162.9 5,083.8 5,970,9711 545,2626 57 -162.94 MWD OWSG (4) 9,770.9 90.12 9056 6,474.8 6378.9 -163.8 5,113.7 5,970,970.4 545292.5 7.9 -163.83 MWD OWSG (4) 9,800.8 89M 8886 6,475.1 6,379.2 -1637 5,1436 5,970,970.7 545.322.4 6.8 -163.68 MWD OWSG (4) 9,830.3 86.47 8865 6.4762 6,380.3 -163.0 5,173.1 5,970.971.5 545.351.9 87 -163.04 MWD OWSG (4) 9,8604 8665 86.32 6,478.0 6,382.1 -161.7 5203.1 5,970,973.0 545,381.9 7.6 -161.72 MWD OWSG (4) 9,890.7 86.31 84.30 64799 6,384.0 -159.2 5,233.3 5.970.9756 545,412.1 67 -15924 MWD OWSG (4) 9930.8 86.72 82.15 6,482.3 6,386.4 -154.5 5,273.0 5,970,9806 545.451.8 5.5 -154.53 MWD OWSG (4) 9,964.9 85.88 82.18 6484.5 6.388.6 -149.9 5,306.7 5,970,9854 545,485.4 25 -149.89 MWD OWSG (4) 9,990.7 85.95 8299 6485.4 6,390.5 -146.6 5,332.2 5,970,988.8 545.510.9 3.1 -146.57 MWD OWSG (4) 10,020.7 88.44 8200. 6,487.8 6,391.9 -1427 5,3619 5,970,992.9 545.540.6 8.9 -14266 MWD OWSG (4) 10,048.8 87.02 81.91 6,488.9 6,393.0 -138.7 5,3897 5,970,997.0 545,568.4 51 -138.73 MWD OWSG (4) 10,060.9 88.43 7964 6.490.2 6394.3 -1336 5,421.4 5,971,002.3 545,600.0 8.3 -133.59 MWD OWSG (4) 10,1102 86.04 7864 6491.6 6,395.7 -128.1 5,450.1 5,971,008.0 545.628.7 8.8 -128.07 MWD OWSG (4) 10.140.3 83.70 76.29 6.494.3 6.398.4 -1216 5,479.4 5,971,014.6 545,658.0 11.0 -121.56 MWD OWSG (4) 10,1706 84.65 7467 6,497.4 6,401.5 -114.0 5,5086 5,971022.3 545,687.1 6.2 -114.00 MWD OWSG (4) 10201.0 8668 74.04 6.499.7 6,403.8 -1058 5,5378 5,971,030.7 545,716.3 7.0 -105.82 MWD OWSG (4) 10,229.7 88.04 71.26 6,5010 6.4051 -97.3 5,565.1 5.971,0394 545,743.6 108 -97.28 MWD OWSG (4) 10.2611 8607 69.51 6,5026 6,406.7 -86.8 5.594.6 5,974,0500 545,773.0 8.4 -86.77 MWD OWSG (4) 10.290.6 84.90 72.61 6,505.0 6,409.1 -77.2 5.622.5 5,9710597 545.800.8 11.2 -77.21 MWD OWSG (4) 10,3194 85.11 7428 6,507.5 6,411.6 69.1 5649.9 5,971,068.0 545,828.2 5.8 -69.05 MWD OWSG (4) 10,3527 87.88 7564 6,509.5 6.413.6 60.4 5,682.1 5,971,076.9 545.860.3 9.3 -6042 MWD OWSG (4) 10,382.3 $733 7902 6,510.7 6,414.8 -53.9 5,7109 5,971083.5 545,889.0 116 -5394 MWD OWSG(4) 10,412.1 W93 8164 6,512.2 6.416.3 48.9 5,740.3 5.971,0887 545918.4 8.9 48.93 MWD OWSG (4) 10,442.9 86.77 80.90 6513.9 6.418.0 14.3 5,7706 5.971,0935 545,948.8 25 -04.27 MWD OWSG (4) 10,469.5 86.19 77.30 6.515.5 6.419.6 -39.3 5,796.7 5.9710986 545,974.8 13.7 -39.25 MWD OWSG (4) 10,499.6 8705 7537 6.517.3 6,421.4 -32.2 5,8259 5,971,105.9 546003.9 7.0 -3215 MWD OWSG (4) 10,530.1 85.13 74.46 6,5194 6,423.5 -242 5.855.3 5,971.114.0 546,033.3 7.0 -24.23 MWD OWSG (4) 10.561.5 8576 7204 6,5219 6,426.0 152 5.8853 5971.1232 546063.3 7.9 -1519 MWN OWSG (4) Annotation 11/12/2019 3:59:05PM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips BakerNugl 5s ; ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well 1A-04 Project: Kupamk River Unit TVD Reference: 1A -04A@95.9 @ 95.9usft (1A -04A@95.9) Site: Kupamk 1A Pad MD Reference: 1A -04A@95.9 @ 95 gust (1A -04A@95.9) Well: 1A-04 North Reference: True Wellbore: tA-04AL1PB1 Survey Calculation Method: Minimum Curvature Design: 1A-04AL7PB1 Database: EDT 14 Alaska Production Survey Annotation 11/1212019 3:59: 05PM Page 5 COMPASS 5000. 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S -E/-W DLS Northing Eating Section Survey Tool Name (usft) (1) (1) (usft) (usft) (usft) (usft) (01100) (ft) (ft) (ft) 10,5912 8450 69.51 6,524.4 6428.5 -5.5 5,913.2 5,971,133.0 546,0911 95 -546 MWD OWSG(4) 10.621.6 86.50 6422 6526.8 6430.9 64 5,941.0 5971,145.1 5461189 185 6.43 MWD OWSG(4) 10,651.6 87.70 60.49 65283 6.432.4 20.3 5,9676 5,971,159.1 546,145.3 13.0 20.33 MWD OWSG(4) 10,6795 87.54 6125 6,529.5 6,433.6 33.9 5,991.9 5,971,1720 546,1696 28 3391 MWD OWSG(4) 10,709.6 86.93 60.09 6,530.9 6435.0 48.6 6,018.1 5,971,1877 546 195 44 48.63 MWD OWSG(4) 10,7400 8659 6176 6,5327 6,436.8 634 6,0447 5,971.202.6 546222.2 5.6 63.39 MWD OWSG(4) 107700 84.31 62.13 6,535.0 6,439.1 77.5 6,071.1 5,971,216.8 546248.5 77 7747 MWD OWSG(4) 10,800.3 82.49 63.A 6.538.5 6.442.6 91.3 6,097.8 5,971,2308 546,275.1 67 9130 MWD OWSG(4) 10,829.7 81.77 64.55 6542.5 6,446.6 1042 6,123.9 5,971,243.8 546,301.2 5.6 104.18 MWD OWSG(4) 108605 8144 6543 6,547.0 6,451.1 117.1 6,151.5 5,971,256.8 546,3287 30 117.06 MW00WSG(4) 108904 80.79 64.57 6.5517 6,455.8 129.5 6,178.3 5.971,2694 546,355.4 3.6 12954 MWD OWSG(4) 10,9202 8308 63.04 6.555.8 6.459.9 1426 6.204.0 5.9712826 546,3818 9.2 142.56 MWD OWSG(4) 10,9499 82.98 6042 6,5594 6,4635 156.5 6.2307 5,971,296.7 546,4077 8.8 156.52 MWD OWSG(4) 10,980.3 82.12 58.91 65634 6,467.5 171.7 6,2567 5,971,312.1 546,4336 57 171.74 MWD OWSG(4) 11,010.2 8069 57.25 6,5679 64720 1874 6.281.9 5,971,327.8 546.458.7 74 187.38 MWD OWSG(4) 11,0402 81.07 56.31 6,5726 6476.7 2036 630.6 5,971,344.2 546.483.3 3.4 203.60 MWD OWSG(4) 11,070.1 8147 5763 6,577.2 6,481.3 219.7 6,3314 5,971,3604 546,506.0 4.6 21972 MWD OWSG(4) 11,1016 88.01 60.30 6,580.1 6,484.2 235.9 6,358.3 5,971,3767 546534.8 224 235.88 MWD OWSG(4) 11,1303 8929 5904 6,5807 6.484.8 250.4 6,383.1 5,971,391.4 546,559.5 6.3 25038 MWD OWSG(4) 11,160.0 87.39 57.76 6,581.6 6,485.7 265.9 6,406.3 5,9714070 546.584.7 7.7 265.91 MWD OWSG(4) 11,190.4 85.20 57.37 6.583.6 6.487.7 282.2 6,433.9 5,971,423.5 546.610.2 73 28220 MWD OWSG(4) 11,2205 86.34 55.84 6,585.8 6,489.9 298.7 6,4590 5,971,440.1 546635.2 6.3 298.73 MWD OWSG(4) 11,250.1 8828 53.75 6,5872 6,4913 3157 6,483.1 5971,457.3 546,659.2 96 315.75 MWD OMG(4) 11,2800 8625 5173 6,588.6 6,492.7 333.8 6,506.9 5.971,475.5 546,682.9 9.6 333.83 MWD OWSG(4) 11,309.5 8582 5120 6.590.6 6494.7 352.1 6,529.9 5,971493.9 546,705.8 23 352.14 MWD OWSG(4) 11,340.8 85.52 50.37 6,593.0 6,497.1 371.9 6,554.1 5,971,513.8 546729.9 2.8 371.90 MWD OWSG(4) 11,371.2 84.31 50.50 6.595.7 6.499.8 391.2 6,577.4 5.9715332 546753.1 40 391.16 MWD OWSG(4) 11400.4 84.28 4809 6.598.6 6.502.7 410.1 6,599.5 5,971.5523 546,775.1 8.2 410.13 MWD OWSG(4) 114306 83-47 45.45 6.601.8 6.505.9 430.7 6,621.4 5.971,5730 546,796.8 9.1 430.72 MWD OWSG(4) 11,4604 66.13 4389 6,604.5 6,508.6 451.8 66422 5.971.594.1 546,8176 104 451.]8 MWD OWSG(4) 114898 86.53 41.81 6,606.4 6510.5 473.3 6,662.1 5,971.6157 546.8374 7.2 473.29 MWD OWSG(4) Annotation 11/1212019 3:59: 05PM Page 5 COMPASS 5000. 14 Build 85H ConocoPhillips Itakei Hughm 5� ConocoPhillips Definitive Survey Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Co-ordinate Reference: Well IA -04 Project Kuparuk River Unit TVD Reference: 1A -04A@95.9 @ 95.9usft (1A -04A@95.9) Site: Kuparuk 1A Pad MD Reference: 1A -04A@95.9 @ 95.9usft (1A -04A@95.9) Well: 1A-04 North Reference: True Wellbore: 1A-04AL1Pe1 Survey Calculation Method: Minimum Curvature Design: 1A-04AL1 P131 Database: EDT 14 Alaska Production Survey 11/1212019 3: 59 05P Page 6 COMPASS 5000. 14 Build 85H Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W DLS (usft) (') (°) (usft) (usft) (usft) (usft) Northing Easting (=1100) Section Survey Tool Name Annotation 11,5200 55.36 39.75 6,608.5 6,512.6 4961 6,681.8 5.9716387 546,856.9 78 496.09 MWD OWSG(4) 11,549.8 83.63 38.17 6.611.4 6.515.5 519.2 6,7005 5.971,661 .9 546,875.5 7.9 519.19 MWD OWSG(4) 11,579.9 W67 3707 6614.2 6.518.3 542.9 6,718.8 5.971,685.7 546,893.6 77 54290 MWD OWSG(4) 11,610.7 83.10 35.67 6,617.2 6,521.3 5676 6,736.9 5,9717104 546,911.7 9.5 567.58 MWD OWSG(4) 11,640.0 85.73 35.64 6,620.1 6,524.2 5912 6,753.9 5,971,7342 546,928.5 9.0 591.24 MWD OWSG(4) 11,669.6 8588 3572 6,622.2 6,526.3 615.3 6,771.2 5,971,758.3 546,945.6 06 61526 MWD OWSG(4) 11700.2 84.84 3573 6,624.7 6,528.8 640.1 6,789.0 5,971,783.2 5469633 34 640.06 MWD OWSG(4) 11,729.7 8128 35.12 6628.3 6,532.4 6638 6,805.9 5,971,807.0 546,980.1 12.3 66384 MWO OWSG(4) 11,7604 8252 3349 6,632.6 6,5367 689.0 6.823.1 5,971,832.3 546,971 66 689.00 MWD OWSG(4) 11,792.1 81.00 32.42 6,637.1 6,541.2 7153 6,840.2 5,971,8567 547014.1 5.8 715.34 MWD OWSG(4) 118198 79.66 31.32 6641.8 6.545.9 738.5 6,854.6 5,971,8819 547,028.3 6.2 738.48 MWD OWSG(4) 11,850.2 83.05 30.57 6.646.4 6.550.5 7643 6,870.0 5971,907.8 547.043.7 11.4 76429 MWD OWSG(4) 11,8799 8438 29.52 6,649.6 6,553.7 789.8 6.884.8 5,971,933.4 547,058.3 57 789.80 MWD OWSG(4) 11,909.9 85.33 27.41 6,652.3 6,556.4 8160 6,899.0 5,971,959.7 547,072.4 77 816.05 MWD OWSG(4) 11,939.6 90.37 26.40 6,653.4 6,5575 8426 6,912.5 5,971,986.3 547.085.7 17.3 842.57 MWD OWSG(4) 11,969.6 89.51 24.24 6,6534 6,5575 869.7 6.925.3 5,972,013.5 547,098.4 78 86967 MWD OWSG(4) ll,%97 90.31 21.92 6,653.5 6,557.6 897.3 6,937.1 5,972,0412 547110.0 8.2 897.32 MWD OWSG(4) 12.0296 88.99 2060 6,653.7 6,557.8 925.2 6,9479 5,972.069.2 5471207 6.2 925.23 MWD OWSG(4) -- 12,066.0 88.99 20.60 6654.3 6.558.4 959.3 6,960.7 5,972,103.3 547,133.3 00 959.28 PROJECTED to TD 11/1212019 3: 59 05P Page 6 COMPASS 5000. 14 Build 85H THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 95510-0360 Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.olaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU IA-04AL1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-065 Surface Location: 1019' FSL, 311' FWL, SEC. 05, TI IN, R10E, UM Bottomhole Location: 2285' FNL, 3306' FEL, SEC. 04, TI IN, R10E, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 200-194, API No. 50-029-20621- 01-00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 7 day May, 2019. M.-ULIVED STATE OF ALASKA f ALAbr\A OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑Q • Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral 0 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 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 1A-04AL1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13015' TVD: 6653' Kuparuk River Field/ Kupamk River Oil Pool ✓ 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1019' FSL, 311' FWL, Sec 05, T11 N, R10E, UM ADL 25647 Pbl.Z5 Top of Productive Horizon: 8. DNR Approval Number: r1.r_0 13. Approximate Spud Date: 4893' FNL, 504' FEL, Sec 05, T11 N, R10E, UM LONS 83-134 131l 5/6/2019 , Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2285' FNL, 3306' FEL, Sec 04, T1IN, R10E, UM 2560 17650' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 96' 15. Distance to Nearest Well Open Surface: x- 540179 y- 5971107 Zone- 4 GL / BF Elevation above MSL (ft): 61' to Same Pool: 168', 1B-02 " 16. Deviated wells: Kickoff depth: 8865 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: 3239 Surface: 2595 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) 3" 2-3/8" 4.7# L-80 ST -L 4155' 8860' 6442' 13015' 6653' Slatted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 9161' 6659' N/A 9062' 6587' WA Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 200 sx Permafrost 80' 80' Surface 2959' 10-3/4" 1200 sx Fondu, 250 sx ASII 2990' 2631' Production 6465' 7" 1039 sx Class G & 42 bbls ASH 6494' 4931' Liner 2814' 4-1/2" 400 sx Class G 9160' 6657' Perforation Depth MD (ft): 8848'-8861* Perforation Depth TVD (ft): 6433'- 6443' 8870'- 8916' 6449'- 6482' Hydraulic Fracture planned? Yes❑ No ❑, 20. Attachments: Property Plat ❑ BOP Sketch Divertter Sketch R ing Program DSleabed Report 8 Drilling eFluid Progrv. Depth am e 20 AAC 25.050 requ ementsot Shallow Hazard El 21. Verbal Approval: Commission Representative: Date 22.1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Keith Herring Authorized Name: James Ohlinger Contact Email: Keith. E. Herrifl CO .com Authorized Title: Staff CTD Engineer Contact Phone: 907-263-4321 Authorized Signature: /� / Date: /0? Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 50- O Z 2— 6 0— O Date: hhIrequirements. 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: amples req'd: Yes E] No[T Mud log req'd: Yes❑ Noy' ' Other: 13oP ti—_574 To 3-760 �J' Samples 119r? h U{C rPit V!k_7fY✓ Z SGO HzSmeasures: Yes [� No❑ Directional svy req'd: Yes [Er No E] S Spacfnpg exsption req'd: Yes No[I�' inclination -only svY req'd: Yes❑ No[g� Post initial injection MIT req'd: YeSff�No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ynr i p✓ r� VTZ 5-/3//9 Submit Form and �pk-407 �e�ii�. 51017 This permit is valid for 0npiifG I ( AL,L al per 20 AAC 25.0005(8) , Attachments in DupI ca e6'f1'6 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 22, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a single lateral out of the KRU 1A - 04A (PTD# 200-194) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in May 2019. The objective will be to drill one lateral, KRU 1A-04AL1 targeting the Kuparuk A -sand interval. Attached to this application are the following documents: - Permit to Drill Application Forms (10401) for 1A-04AL1 - Detailed Summary of Operations - Directional Plans for 1A-04AL1 - Proposed CTD Schematic - Current Wellbore Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerel*Keither'nng�� Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Laterals 1 A-O4AL1 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(6)) ............ . _. _. _......... ......... ................. ....... -.................. . ........ 2 2. Location Summary .................. ........ ......... ..... .... ...... ...... .... 2 (Requirements of 20 AAC 25.005(0)(2)) ._.............. .............................. ..... ...... ........ .. ...__.. ._................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005 (c)(3))....... _........... ............................ ..... _....... .......... ................ ........................................ 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005 (c)(4)).. .... .............. .................. ............ ..... ..................2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)) ... ............ .......... _...... .. ...................... _................... ............. ....... _ ...... ................... 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)) ... .. ............_.... ........._.................. ..........._... ........__.._ _. .......... ...._...........3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))-... .. .................. ....................... ............................................................ ................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AA C 25.005(c)(8)).... ............ ........... ............... _................ ......_............................... . ............... ...._..........3 9. Abnormally Pressured Formation Information.............................................................................4 (Requirements of 20 AAC 25.005(c)(9)) ...................... ... ..... ..... .............. _......... ........._._.._... ............. ............... ................4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10)). .... .. ._........... ....._......... .. ............ ....................4 11. Seabed Condition Analysis............................................................................................................4 (Requirements of 20 AAC 25.005(c)(11)) ..... ............... --- ..................................._....... .........._...... ........... .................4 12. Evidence of Bonding .............. ..... .... ....... ...... .... ..... ....... 4 (Requirements of 20 AAC 25005(c)(12))...... .................... .... ...... . ........... ..._._...... ...... .... ......... ...........4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20AAC 25.005(c)(13))................. ...................... .. ............... _._........ .........._......... ...................... .... ............. 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................5 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 5 (Requirements of 20 AAC 25.005(c)(14)) .................... ........................ ................ ........._........ .........._..... ..... ..... .......... ...............5 15. Directional Plans for Intentionally Deviated Wells....................................................................... 5 (Requirements of 20 AAC 25.050(6))....... _..................... ..... ............ ......................... ............... .............................. ...5 16. Quarter Mile Injection Review (for injection wells only)............................................................... 6 (Requirements of 20 AAC 25.402) ....................... .................... ._........ ................ .......... ._._........... ......................... . 17. Attachments....................................................................................................................................7 Attachment 1: Directional Plans for 1A-04AL1................................................................................................................7 Attachment 2: Current Well Schematic for 1A-04A.........................................................................................................7 Attachment 3: Proposed Well Schematic for 1A-04AL1..................................................................................................7 Page 1 of 7 April 22, 2019 PTD Application: 1A-04AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b)) The proposed lateral described in this document is 1A-04AL1. The lateral will be classified as "Service — WAG' well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The lateral will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1A-04AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,700 psi. Using the maximum formation pressure in the area of 3,239 psi in 1A -04A (i.e. 10.0 ppg EMW), the maximum potential surface pressure in 1A -04A, assuming a gas gradient of 0.1 psi/ft, would be 2,595 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2500 psi. 4. DRriilling Has rds AA c2mati ()(4nd Reservoir Pressure PVO Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1A -04A was measured to be 3,239 psi (10.0 ppg EMW) on 01/24/2019' The maximum downhole pressure in the 1A -04A vicinity is the 1A -04A well. The lowest downhole pressure in the 1A -04A vicinity is to the southeast in the 1 B-13 producer at 2,544 psi (7.7 ppg EMW) measured in September 2016. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1A-04AL1 lateral. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems in the 1A-04AL1 lateral will be shale instability at large fault crossings. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1A-04AL1 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 April 22, 2019 PTD Application: 1A-04ALl 6. Casing and Cementing Program. (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS Conductor 16" 65.0 H-40 Welded Surface 2W' 4.7#, L-80, ST -L slotted liner; 1A-04AL1 8860' 13015' 6346' 6557' deployment sleeve on to Existing Casing/Liner Information Category OD Weight f Grade Connection Top MD Btm MD Top TVD Bt m TVD Burst psi Collapse psi Conductor 16" 65.0 H-40 Welded Surface 80' Surface 80' 1640 670 Surface 10-3/4" 45.5 K-55 BUTT Surface 2990" Surface 2631' 3580 2090 Production 7" 26.0 K-55 BTC Surface 6494' Surface 4931' 4980 4320 Liner 4-1/2" 12.6 L-80 NSCT 6346' 9160' 4834' 6657' 8430 7500 Tubing 4-1/2" 12.6 L-80 IBT Surface 6357' Surface 4841' 8430 7500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Pro milling fluid (8.6 ppg) — Drilling operations: Water based Power -Pro mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5000 -psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1A -04A lateral we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 April 22, 2019 PTD Application: 1A-04AL1 • Pressure at the 1A -04A Window 8865' MD, 6446' TVD Usin MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1A -04A is equipped with 4-1/2" tubing and 4-1/2" production liner. The CTD sidetrack will utilize a single lateral to target the A -sands to the northeast of 1A -04A. The lateral will provide injection support increase A -sand resource recovery and throughput. Prior to CTD operations slickline will obtain a SBHP and conduct a dummy whipstock drift. E -line will caliper the wellbore and set a whipstock at 8865' MD to facilitate cutting a window with CTD. CDR3-AC will mill a window in the liner at 8,865' MD and the 1A-04AL1 lateral will be drilled to TD at 13,015' MD, targeting the A -sand to the northeast. It will be completed with 2-3/8" slotted liner from TD up to 8,860' MD with a deployment sleeve. Pre -CTD Work 1. RU Slick -line: Obtain SBHP and conduct dummy whipstock drift. 2. RU E -line: Caliper and set whipstock. 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coiled tubing. NU 7-1/16" BOPE, test. Page 4 of 7 April 22, 2019 Pumps On 1.9 bpm) Pumps Off A -sand Formation Pressure 10.0 3239 psi 3239 psi Mud Hydrostatic 8.6 2882 psi 2882 psi Annular friction i.e. ECD, 0.08psi/ft) 709 psi 0 psi Mud + ECD Combined no chokepressure) 3591 psi overbalanced -352psi) 2882 psi underbalanced -357psi) Target BHP at Window 11.8 3955 psi 3955 psi Choke Pressure Required to Maintain Target BHP 364 psi 1073 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU well 1A -04A is equipped with 4-1/2" tubing and 4-1/2" production liner. The CTD sidetrack will utilize a single lateral to target the A -sands to the northeast of 1A -04A. The lateral will provide injection support increase A -sand resource recovery and throughput. Prior to CTD operations slickline will obtain a SBHP and conduct a dummy whipstock drift. E -line will caliper the wellbore and set a whipstock at 8865' MD to facilitate cutting a window with CTD. CDR3-AC will mill a window in the liner at 8,865' MD and the 1A-04AL1 lateral will be drilled to TD at 13,015' MD, targeting the A -sand to the northeast. It will be completed with 2-3/8" slotted liner from TD up to 8,860' MD with a deployment sleeve. Pre -CTD Work 1. RU Slick -line: Obtain SBHP and conduct dummy whipstock drift. 2. RU E -line: Caliper and set whipstock. 3. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coiled tubing. NU 7-1/16" BOPE, test. Page 4 of 7 April 22, 2019 PTD 2. 1A-04AL1 Lateral (A4 sand - Northeast) a. Mill 2.80" window at 8,865' MD. b. Drill 3" bi-center lateral to TD of 13,015' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 8,860' MD. 3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post -Rig Work 1. Return well to injection r10r_Qir�_116i Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. — Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed set of ball valve and check valve isolate reservoir pressure internal to the BHA. Slips on the deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. — The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — 1A-04AL1 CTD lateral will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(6)) Page 5 of 7 April 22, 2019 PTD Application: 1A-04AL1 - The Applicant is the only affected owner. - Please see Attachment 1: Directional Plan - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - MWD directional, resistivity, and gamma ray will be run over the entire open hole section. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 A-04AL1 17650' Distance to Nearest Well within Pool Lateral Name Distance Well 1 A-04AL1 1 B-02 168' 16. Quarter Mile Injection Review (for injection wells only) r. wit (�S / (Requirements of 20 AAC 25.402) ` , (e There are three wells and two CTD laterals within %-mile of the 1A-04AL1 lateral. 1A -04A (mother bore) Injector • Classified as a "Waivered Well" - Shallow packer injector • The well is completed with 4.5" 12.6# L-80 tubing and 4.5" 12.6# L-80 production liner. • Baker S-3 7" x 4.5" Packer located at 6289' MD and Baker ZXP liner top packer at 6358' MD. • A -sand perforations: A5: 8848'- 8861' MD and A4: 8870'- 8916' MD. • Production liner was cemented with 400 sx of Class "G" cement. The proposed kick off point for the CTD sidetrack is in the A -sand and should not compromise existing conformance. 1B-02 (Injector), -168' away from the 1A-04AL1 lateral • 1 B-02 is currently injecting water into the Kuparuk A and Unit B sand intervals. • Classified as a "Normal Well" • Well is completed with 3.5" 9.3# L-80 tubing and 7" 26# K-55 production casing. • Packers located at 7062', 7277', 7595', and 7788' MD. • A, C, Unit B perforations: C4 -C1: 7468'- 7646' MD cement squeezed with 23 bbls of cement (2006), Unit B: 7652'- 7669' MD, and A5/A4: 7863'- 7900' MD. • Production casing was cemented with 650 sx Class 'G' cement. 1A-14 (Injector), -1040' away from the 1A-04AL1 lateral • 1A-14 is currently injecting water into the Kuparuk A, C, and Unit B sand intervals. • Classified as a "Problem Well" - Subsidence Surveillance • Well is completed with 3.5" x 2.875" 9.2# J-55 tubing and 7" 26# J-55 production casing. • Packers located at 4665', 4744', 7113', and 7463' MD. • A, C. Unit B perforations: C4 -Unit B: 7280' - 7402' MD, A5: 7572'- 7584' MD, A4: 7594'- 7626' MD. • Production casing was cemented with 1225 sx Class'G' cement. 1A-20 (Producer), -1235' away from the 1A-04AL1 lateral • 1A-20 is currently producing from the Kuparuk C sand interval. • Classified as a "Problem Well" • Well is completed with 4" x 3.5" x 2.875" 11.0# J-55 tubing and 7" 26# J-55 production casing. • Packers located at 8265', 8459', and 8624' MD. • A, C, Unit B perforations: C4/C3: 8344'- 8407' MD (sliding sleeve closed), C2: 8426'- 8434' MD (sliding sleeve closed), C1: 8480'- 8506' MD (cement squeezed with 7 bbls of cement in 2017), A5: 8747'- Page 747'- Page 6 of 7 April 22, 2019 PTD Application: 1A-04AL1 8755' MD (CA -2 plug set in profile at 8666' MD), and A4: 8770'- 8810' MD (CA -2 plug set in profile at 8666' MD). Production casing was cemented with 275 sx Class 'G' cement. 1A-20LI-01 (Producer), —731' away from the 1A-04AL1 lateral • 1A-201_1-01 is currently producing from the Kuparuk C sand interval. • Classified as a "Problem Well" — Parent Wellbore Classification • CTD lateral completed with 2.375" 4.7# L-80 tubing. • Slotted liner: C4/C3: 9322'- 11750' MD. 1A -20L1-02 (Producer), —703' away from the 1A-04AL1 lateral • 1A -20L1-02 is currently producing from the Kuparuk C sand interval. • Classified as a "Problem Well" —Parent Wellbore Classification • CTD lateral completed with 2.375" 4.7# L-80 tubing. • Slotted liner: C2/C1: 8580'- 10980' MD. 17. Attachments Attachment 1: Directional Plans for 1A-04AL1 Attachment 2: Current Well Schematic for 1A -04A Attachment 3: Proposed Well Schematic for 1A-04AL1 Page 7 of 7 April 22, 2019 VI Q a �o 0 C V z i _ Y _ p 4 s g � 9 a _ e C _ o 3 ' < f G (#lBsn<Osb) C 41ji*41nog a ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit Kuparuk 1A Pad IA -04 1 A-04AL1 Plan: 1A-04AL1_wp02 Standard Planning Report 16 April, 2019 BA UGHES a GE company ConocoPhillips Planning Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: BA (ER F�UGHES a GEmmpaey Well 1A-04 Mean Sea Level IA -04A@95.9 @ 95.90usft (1A -04A®95,9) True Minimum Curvature Project Kupawk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Gee, Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor site Kupamk 1A Pad Northing: ConocoPhillips Database: EDT 14 Alaska Production Company: ConowPhillips Alaska lnc_Kupawk Project: Kuparuk River Unit Site: Kuparuk 1A Pad Well: 1A-04 Wellbore: to-04AL1 Design: IA-04AL1_wP02 ConocoPhillips Planning Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: BA (ER F�UGHES a GEmmpaey Well 1A-04 Mean Sea Level IA -04A@95.9 @ 95.90usft (1A -04A®95,9) True Minimum Curvature Project Kupawk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Gee, Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor site Kupamk 1A Pad Northing: 0.00 usft Easting: Site Position: Northing: 5,971467.26 usft Latitude: 70'19'58.741N From: Map Easting: 540,178.17 usft Longitude: 149" 40'26.679 W Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.31 ° Well 1A-04 Well Position -N/-S +E/ -W Position Uncertainty Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: 1A-04AL1 Model Name BGGM2018 IA-04AL1_wp02 Sample Data 5/1/2019 Phase: Depth From (TVD) (usft) 0 00 5,971,106.83 usft Latitude: 540,178.52 usft Longitude: usft Ground Level: Declination (9 16.62 PLAN +N/ -S (Usk) 000 Dip Angle ("1 80.87 70° 19'55.196 N 149' 40'26.725 W 0.00 Usti Field Strength (nT) 57 418 Tie On Depth: 8,808.81 .E/ -W Direction (Usk) (°) 0 00 0.00 411&12019 1:48:37PM Page 2 COMPASS 5000.14 Build 85D Plan Sections ConocoPhillipsER - ConocoPhillips Planning ReportUGHES a6Emmpary Database: EDT 14 Alaska Production Local Coordinate Reference: Well 10-04 Company: ConocoPhillips Alaska Inc Kupamk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1A -04A@95.9 @ 95.90usft (tA-04A@95.9) Site: Kuparuk 1A Pad North Reference: True Well: 1A-04 Survey Calculation Method: Minimum Curvature Wellbore: 1A-04AL1 Rate Rate Design: 1A-04AL1_wp02 (usft) (°) Plan Sections - Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System -NI-S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100usft) (°1100usft) (°/100usft) (°) Target 8,808.81 44.33 24.70 6,309.76 -667.06 4,450.25 0.00 0.00 0.00 0.00 8,865.00 44.44 25.17 6,349.92 -631.42 4466.82 0.61 0.19 0.83 71.76 8,890.00 47.44 25.17 6,367.30 -615.16 4,474.46 12.00 12.00 0.00 0.00 9,006.80 100.00 25.17 6,398.91 -517.21 4,520.49 45.00 45.00 0.00 0.00 9,055.00 93.85 46.14 6,393.03 -478.60 4,548.26 45.00 -12.76 43.50 105.00 9,235.00 88.48 57.54 6,389.35 -367.65 4,689.48 7.00 -2.98 6.34 115.00 9,305.00 87.64 52.71 6,391.72 -327.66 4,746.86 7.00 -1.21 -6.90 260.00 9,585.00 82.14 71.61 6,416.88 -197.89 4,992.15 7.00 -1.96 6.75 107.00 9,895.00 90.92 91.51 6,435.83 -152.99 5,296.42 7.00 2.83 6.42 67.00 10,445.00 90.72 53.01 6,427.67 11.48 5,810.40 7.00 -0.04 -7.00 270.00 10,695.00 89.18 70.44 6,427.88 129.45 6,029.71 7.00 -0.61 6.97 95.00 10,765.00 87.12 74.88 6,430.14 150.30 6,096.47 7.00 -2.95 6.35 115.00 11,005.00 75.39 62.69 6,466.71 235.44 6,316.93 7.00 -4.69 -5.08 225.00 11,105.00 62.39 62.69 6,485.97 280.43 6,404.06 7.00 7.00 0.00 0.00 11,625.00 92.61 27.68 6,509.34 640.89 6,765.94 7.00 1.97 -6.73 285.00 12,185.00 79.54 350.55 6,548.98 1,181.45 6,854.10 7.00 -2.34 -6.63 249.90 12,255.00 84.36 349.70 6,558.78 1,249.71 6,842.22 7.00 6.90 -1.22 350.00 12,325.00 86.83 345.45 6,564.16 1,317.85 6,827.19 7.00 3.52 -6.07 300.00 12,605.00 90.34 4.74 6,571.14 1,595.38 6,803.40 7.00 1.26 6.89 80.00 13,015.00 93.56 33.28 6,556.86 1,978.78 6,935.36 7.00 0.78 6.96 83.20 4/16/2019 1: 48 37P Page 3 COMPASS 5000.14 Build 85D ConocoPhiilips BAKER �� FI Conoco Phillips Planning Report BAT a GEmmpany Database: EDT 14 Alaska Production Local Coordinate Reference: Well 1A-04 Company: ConocoPhillips Alaska Inc-Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1A -04A@95.9 @ 95.90usft (tA-04A@95.9) Site: Kuparuk 1A Pad North Reference: True Well: to -04 Survey Calculation Method: Minimum Curvature Wellbore: 1A-04ALI Map Design; 1A-04AL1_wp02 Inclination Azimuth Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +1,17-S +El -W Section Rate Azimuth Northing Easting (usft) (°) (_) (usft) (usft) (usft) (usft) (°NOOusft) (°) (usft) (usft) 8,808.81 44.33 24.70 6,309 76 -667.06 4,450.25 -667.06 0.00 0.00 5,970,463.68 544,631 .84 TIP 8,865.00 44.44 25.17 6,349.92 -631.42 4,466.82 -631.42 0.61 71.76 5,970,499.41 544,648.22 KOP 8,890.00 47.44 25.17 6,367.30 -615.16 4,474.46 -615.16 12.00 0.00 5,970,515.70 544,655.77 Start Build 45.00 8,900.00 51.94 25.17 6,373.77 -608.26 4,477.71 -608.26 45.00 0.00 5,970,522.62 544,658.98 9,000.00 96.94 25.17 6,399.91 -523.30 4,517.63 -523.30 45.00 0.00 5,970,607.79 544,698.45 9,006.80 100.00 25.17 6,398.91 -517.21 4,520.49 -517.21 45.00 0.00 5,970,613.89 544,701.27 Start DLS 46.00 TFO 105.00 9,055.00 93.85 46.14 6,393.03 -478.60 4,548.26 -478.60 45.00 105.00 5,970,652.64 544,728.83 Start DLS 7.00 TFO 115.00 9,100.00 92.51 48.99 6,390.53 448.29 4,581.41 448.29 7.00 115.00 5,970,683.13 544,761.82 9,200.00 89.53 55.33 6,388.75 -386.99 4,660.32 -386.99 7.00 115.16 5,970,744.84 544,840.39 9,235.00 88.48 57.54 6,389.35 -367.65 4,689.48 -367.65 7.00 115.27 5,970,764.34 544,869.44 Start DLS 7.00 TFO 260.00 9,300.00 87.70 53.06 6,391.52 -330.67 4,742.88 -330.67 7.00 -100.00 5,970,801.60 544,922.63 9,305.00 87.64 52.71 6,391.72 -327.66 4,746.86 -327.66 7.00 -99.85 5,970,804.63 544,926.60 Start DLS 7.00 TFO 107.00 9,400.00 85.71 59.09 6,397.24 -274.51 4,825.35 -274.51 7.00 107.00 5,970,858.19 545,004.79 9,500.00 83.74 65.83 6,406.43 -228.50 4,913.58 -228.50 7.00 106.63 5,970,904.68 545,092.77 9,585.00 82.14 71.61 6,416.88 -197.89 4,992.15 -197.89 7.00 106.01 5,970,935.70 545,171.16 Start DLS 7.00 TFO 67.00 9,600.00 82.55 72.58 6,418.88 -193.32 5,006.29 -193.32 7.00 67.00 5,970,940.34 545,185.28 9,700.00 85.34 79.04 6,429.44 -168.97 5,102.64 -168.97 7.00 66.87 5,970,965.20 545,281.49 9,800.00 88.19 85.44 6,435.09 -155.51 5,201.51 -155.51 7.00 66.19 5,970,979.19 545,380.28 9,895.00 90.92 91.51 6,435.83 -152.99 5,296.42 -152.99 7.00 65.83 5,970,982.23 545,475.16 Start DLS 7.00 TFO 270.00 9,900.00 90.92 91.16 6,435.75 -153.10 5,301.42 -153.10 7.00 -90.00 5,970,982.14 545,480.16 10,000.00 90.91 84.16 6,434.15 -149.02 5,401.26 -149.02 7.00 -90.01 5,970,988.75 545,579.97 10,100.00 90.89 77.16 6,432.58 -132.60 5,499.86 -132.80 7.00 -90.12 5,971,003.50 545,678.47 10,200.00 90.85 70.16 6,431.06 -104.68 5,595.75 -104.68 7.00 -90.23 5,971,032.13 545,774.20 10,300.00 90.81 63.16 6,429.60 -65.08 5,687.49 -65.08 7.00 -90.33 5,971,072.22 545,865.72 10,400.00 90.75 56.16 6,428.24 -14.60 5,773.73 -14.60 7.00 -90.44 5,971,123.16 545,951.68 10,445.00 90.72 53.01 6,427.67 11.48 5,810.40 11.48 7.00 -90.53 5,971,149.42 545,988.20 Start DLS 7.00 TFO 95.00 10,500.00 90.38 56.84 6,427.14 43.08 5,855.40 43.08 7.00 95.00 5,971,181.26 546,033.03 10,600.00 89.77 63.81 6,427.01 92.55 5,942.23 92.55 7.00 95.04 5,971,231.19 546,119.59 10,895.00 89.18 70.44 6,427.88 129.45 6,029.71 129.45 7.00 95.05 5,971,268.56 546,206.85 Start DLS 7.00 TFO 115.00 10,700.00 89.04 70.76 6,427.96 131.12 6,034.42 131.12 7.00 115.00 5,971,270.25 546,211.56 10,765.00 87.12 74.88 6,430.14 150.30 6,096.47 150.30 7.00 115.00 5,971,289.77 546,273.50 Start DLS 7.00 TFO 225.00 10,800.00 85.39 73.15 6,432.43 159.92 6,130.04 159.92 7.00 -135.00 5,971,299.56 546,307.02 10,900.00 80.47 68.12 6,444.75 192.78 6,223.61 192.78 7.00 -134.89 5,971,332.92 546,400.40 11,000.00 75.63 62.95 6,465.46 233.23 6,312.62 233.23 7.00 -134.27 5,971,373.84 546,489.18 11,005.00 75.39 62.69 6,466.71 235.44 6,316.93 235.44 7.00 -133.20 5,971,376.08 546,493.48 Start Build 7.00 11,100.00 82.04 62.69 6,485.30 278.16 6,399.66 278.16 7.00 0.00 5,971,419.23 546,575.97 11,105.00 82.39 62.69 6,485.97 280.43 6,404.06 280.43 7.00 0.00 5,971,421.53 546,580.36 Start DLS 7.00 TFO 286.00 1_200.00 84.15 56.23 6497.11 328.35 6485.27 328.35 7.00 -75.00 5,971,469.88 546,661.30 4/162019 1:48.37PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips BA_ j(ER ConocoPhillips Planning Report IJGHi=S a GEuvapany Database: Company: Project: Site: Well: Wellbore: Design: EDT 14 Alaska Production ConocoPhillips Alaska Inc_Kuperuk Kuparuk River Unit Kuparuk 1A Pad 1A-04 1A-04ALII 1A-04AL1_wp02 Local Coordinate Reference: Well 1A-04 TVD Reference: Mean Sea Level MD Reference: 1A -04A@95.9 @ 95.90usft (1A -04A@95.9) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +EI -W Section Rate Azimuth Northing Easting (usft) (I (°) (usft) (usft) (usft) (usft) (°1100usft) (°) (usft) (usft) 11,300.00 86.09 49.48 6,505.63 388.48 6,56464 388.48 700 -74.24 5,971,530.42 546,740.34 11,400.00 88.08 42.76 6,510.72 457.66 6,63658 457.66 7.00 -73.67 5,971,599.98 546,811.90 11,500.00 90.10 36.06 6,512.31 534.86 6,700.02 534.86 7.00 -73.33 5,971,677.52 546,874.92 11,600.00 92.11 29.35 6,510.37 618.94 6,754.01 618.94 7.00 -73.22 5,971,761.87 546,928.46 11,625.00 92.61 27.68 6,509.34 640.89 6,765.94 640.89 7.00 -73.35 5,971,783.88 546,940.26 Start OLS 7.00 TFO 249.90 11,700.00 90.80 22.75 6,507.10 708.69 6,797.86 708.69 7.00 -110.10 5,971,851.85 546,971.81 11,800.00 88.38 16.18 6,507.81 802.92 6,831.15 802.92 7.00 -110.25 5,971,946.24 547,004.60 11,900.00 85.98 9.59 6,512.74 900.22 6,853.42 900.22 7.00 -110.20 5,972,043.65 547,026.34 12,000.00 83.63 2.97 6,521.80 999.14 6,864.32 999.14 7.00 -109.88 5,972,142.63 547,036.71 12,100.00 81.37 356.29 6,534.87 1,098.22 6,863.69 1,098.22 7.00 -109.28 5,972,241.69 547,035.56 12,185.00 79.54 350.55 6,548.98 1,181.45 6,854.10 1,181.45 7.00 -108.40 5,972,324.86 547,025.53 Start DLS 7.00 TFO 350.00 12,200.00 80.57 350.36 6,551.57 1,196.02 6,851.66 1,196.02 7.00 -10.00 5,972,339.42 547,023.00 12,255.00 84.36 349.70 6,558.78 1,249.71 6,842.22 1,249.71 7.00 -9.97 5,972,393.05 547,013.27 Start DLS 7.00 TFO 300.00 12,300.00 85.94 346.96 6,562.58 1,293.62 6,833.14 1,293.62 7.00 -60.00 5,972,436.90 547,003.97 12,325.00 86.83 345.45 6,564,16 1,317.85 6,827.19 1,317.85 7.00 -59.77 5,972,461.10 546,997.89 Start DLS 7.00 TFO 80.00 12,400.00 87.75 350.62 6,567.71 1,391.11 6,811.67 1,391.11 7.00 80.00 5,972,534.27 546,981.97 12,500.00 89.01 357.51 6,570.55 1,490.47 6,801.34 1,490.47 7.00 79.75 5,972,633.56 546,971.11 12,600.00 90.28 4.39 6,571.17 1,590.40 6,803.00 1,590.40 7.00 79.56 5,972,733.48 546,972.23 12,605.00 90.34 4.74 6,571.14 1,595.38 6,803.40 1,595.38 7.00 79.52 5,972,738.47 546,972.61 Start DLS 7.00 TFO 83.20 12,700.00 91.13 11.34 6,569.92 1,689.39 6,816.67 1,689.39 7.00 83.20 5,972,832.54 546,985.38 12,800.00 91.93 18.30 6,567.25 1,785.97 6,842.22 1,785.97 7.00 83.28 5,972,929.24 547,010.41 12,900.00 92.71 25.26 6,563.18 1,878.70 6,879.27 1,878.70 7.00 83.47 5,973,022.16 547,046.95 13,000.00 93.45 32.23 6,557.80 1,966.19 6,927.26 1,966.19 7.00 83.75 5,973,109.90 547,094.47 13,015.00 93.56 33.28 6,556.88 1,978.78 6,935.36 1,978.78 7.00 84.13 5,973,122.53 547,102.50 Planned TD at 13015 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 13,015.00 6,556.88 23/8' 2.375 3.000 J 4/162019 148: 37PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips BA ER ConocoPhillips Planning Report F IGHES BAT Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc Kuparuk Project: Kupamk River Unit Site: Kupamk 1A Pad Well: to -04 Wellbore: 1A-04AL1 Design: tA-04ALt_wp02 Plan Annotations Measured Vertical Depth Depth §rj (usft) lush) 8,808.81 6,309.76 8,865.00 6,349.92 8,890.00 6,367.30 9,006.80 6,398.91 9,055.00 6,393.03 9,235.00 6,389.35 9,305.00 6,391.72 9,585.00 6,416.88 9,895.00 6,435.83 10,445.00 6,427.67 10,695.00 6,427.88 10,765.00 6,430.14 11,005.00 6,466.71 11,105.00 6,485.97 11,625.00 6,509.34 12,185.00 6,548.98 12,255.00 6,558.78 12,325.00 6,564.16 12,605.00 6,571.14 13,015.00 6,556.88 . Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Local Coordinates -NIS +El -W (usft) (usft) -667.06 4,450.25 -631.42 4,466.82 -615.16 4,474.46 -517.21 4,520.49 478.60 4,548.26 -367.65 4,689.48 -327.66 4,746.86 -197.89 4,992.15 -152.99 5,296.42 11.48 5,810.40 129.45 6,029.71 150.30 6,096.47 235.44 6,316.93 280.43 6,404.06 640.89 6,765.94 1,181.45 6,854.10 1,249.71 6,842.22 1,317.85 6,827.19 1,595.38 6,803.40 1,978.78 6,935.36 Comment Well 1A-04 Mean Sea Level 1A -04A@95.9 @ 95.90usft (1A -04A@95.9) True Minimum Curvature TIP KOP Start Build 45.00 Start DLS 45.00 TFO 105.00 Start DLS 7.00 TFO 115.00 Start DLS 7.00 TFO 260.00 Start DLS 7.00 TFO 107.00 Start DLS 7.00 TFO 67.00 Start DLS 7.00 TFO 270.00 Start DLS 7.00 TFO 95.00 Start DLS 7.00 TFO 115.00 Start DLS 7.00 TFO 225.00 Start Build 7.00 Start DLS 7.00 TFO 285.00 Start DLS 7.00 TFO 249.90 Start DLS 7.00 TFO 350.00 Start DLS 7.00 TFO 300.00 Start OILS 7.00 TFO 80.00 Start OILS 7.00 TFO 83.20 Planned TO at 13015 4/162019 148:37PM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips BERall ConocoPhillips Anticollision Report F�UGHES a GE company Company: ConocoPhillips Alaska lnc Kupamk Project: Kupamk River Unit 1 Reference Site: Kuparuk 1A Pad Site Error: 0.00 usft Reference Well: 1A-04 Well Error: 0.00 usft Reference Wellbore 1A-04AL1 Reference Design: 1A-04AL1_wpO2 Reference 1A-04AL1 wp02 Local Co-ordinate Reference: TVD Reference: MD Reference: Nosh Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Fitter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: Depth Range: 8,808.81 to 13,015.00usft Scan Method: Results Limited by: Maximum center -center distance of 1,491.91 usft Error Surface: Warning Levels Evaluated at: 2.79 Sigma Casing Metho Survey Tool Program Date 4/16/2019 From To (usft) (usft) Survey (Wellbore) 195.90 6,395.90 1A-04 (IA -04) 6,493.00 8,808.81 1 A -04A (1A -04A) 8,808.81 13,015.00 1A-04A11_wP02 (1A-04AL1) Well 1A-04 1A -04A@95.9 @ 95.90usft (1A -04A@95.9) 1A -04A@95.9 @ 95.90usft (1A -04A@95.9) True Minimum Curvature 2.00 sigma EDT 14 Alaska Production Offset Datum ISCWSA Tray. Cylinder North Combined Pedal Curve Added to Error Values Tool Name Description FINDER -MS SDC Finder multishot FINDER -MS SDC Finder multishot MWD MWD -Standard Summary Kupamk lA Pad- 1A -04 -1A -04A -1A -04A Reference Offset Distance -FINDER -MS, 6493-PINDER-MS Measured Measured Between Between Site Name Depth Depth Centres Ellipses Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Kupamk 1A Pad Dlcomes, IA -03 - 1A-03 - to -03 Mnsuc4 Vert) Reference Onset IA -03 - 1A-03 - 1A-03 Offset WellEDre donne aeMeen assesses Minimum 1A -04 -1A -04A -1A -04A 8,825.00 8,825.00 0.25 -0.08 IA -14 - 1A-14 - 1A-14 8,983.81 8,285.00 1,040.11 964.96 IA -17 - 1A-17 - 1A-17 Science.. Factor (usft) les") ruse) 1A-17-1A-17-tA-17 (..ft) less.) N lose) 1A-17 - 1A-17 - to -17 (usft) Nan) Nan) 1A-18 - 1A-18 - to -18 8,825.00 6,417.24 0.04 0.07 1A-18 - 1A-18 - 1A-18 656.78 445199 025 -009 1A -18 -1A -18-1A-18 0.755 STOP Orflin, CC, ES, SF 8,850.00 6,431.96 8,050.00 6,435.11 1A -20 -1A -20-1A-20 10,649.32 9,034.00 1,235.03 1,097.71 1A -20 -1A -201.1 -1A -20L7 8,821.24 10,925.00 702.40 583.83 1A -20 -1A -201.1-01-1A-2011-01 9,608.81 9,700.00 731.29 613.06 1A -20 -1A -201.1-02-1A-201.1-02 9,583.81 9,750.00 698.10 578.63 Kuparuk 1B Pad 8,899.85 6.469.53 8,900.00 6,470.81 0.17 1 B -02 -1B -02-1B-02 11,013.56 7,725.00 166.34 69.89 1B -02 -1B -02-1B-02 11,028.02 7,775.00 172.64 63.97 1B -13 -1B -1312-1B-1312 0.20 0.56 -155.53 -693.42 1B -14 -1B -14-1B-14 7.08 5.32 1.76 4.025 Separation Warning Factor Out of range Out of range 0.755 STOP Drilling, CC, ES, SF 13.840 CC, ES, SF Out of range Out of range Out of range Out of range Out of range Out of range 8.994 CC, ES, SF 5.924 CC, ES, SF 6.185 CC, ES, SF 5.843 CC, ES, SF 1.725 Caution Monitor Closely, CC 1.589 Caution Monitor Closely, ES Out of range Out of range Offset Design Kupamk lA Pad- 1A -04 -1A -04A -1A -04A offaetsae Error. 3.00 usft Sane, Pr.9ram: 196 -FINDER -MS, 6493-PINDER-MS ORset We11 Ertor. 0.00 waft Reference Oases semi Major Arls Dlcomes, Meaamea Vesical Mnsuc4 Vert) Reference Onset Amman Offset WellEDre donne aeMeen assesses Minimum assurance blaming Depth Deem Depth Depth from NOM -1141 EAW Centres Eal,ces Science.. Factor (usft) les") ruse) (usft) (..ft) less.) N lose) (usft) (usft) Nan) Nan) 8,825.00 6.417.12 8,825.00 6,417.24 0.04 0.07 41001 656.78 445199 025 -009 033 0.755 STOP Orflin, CC, ES, SF 8,850.00 6,431.96 8,050.00 6,435.11 0.10 0.20 -109.57 b40.93 4,062.35 0.31 -0.15 0.47 0.674 STOP Drilling 8.075.00 6,45281 8.875.00 6.452.87 0.14 0.32 -131.27 825.00 4,469.78 0.24 -0.20 0.44 0.544 STOP Drilling 8,899.85 6.469.53 8,900.00 6,470.81 0.17 0.44 -155.51 £09.25 4.477.26 1.63 0.80 0.83 1.089 Caution Monitor Closely 8,923.48 6.482]6 8,925.00 6,400.64 0.20 0.56 -155.53 -693.42 4,48438 7.08 5.32 1.76 4.025 8,944.57 6490.51 8.950.00 6.58.49 0.24 0.69 -154.92 577.55 4492.17 16.90 14.34 2.46 6.818 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 41162019 9:28:12AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Project:. Kuparuk River 0nitl Site: Kuparuk to Pad ..m tft xa9nx. xmn. �¢ xw WELLBORE DETAILS: 1A-04AL1 xEFEnaxcE INFoxMPnox Parent Wellbore: 1A -04A Coadkae (Ne) Reknnm: M uo4, nue Nm Well: 1A-04smmmaxs.om Tie on MD: BBOa.61 Vm OVD)Rmemr umn Sm tmd lemon rys1 Rel. snl-iHHON.a WE) Wellbore: 1A-04AL1 on MIe: Hose . an= H 95,01nX(M4049959) Akamnd..x Plan: 1A-0 A1.1 wp02(1A-ON1A-04AL1( il ��e WlmdMx4 WELL DETAILS: 1A-04 2700 +N/ -S +E/ -W Northing Easting Latitude Longitude 0.00 0.00 5971106.83 540178.52 70° 19'55.196 N 149° 40'26.725 W 2400 Sec MD Inc Azi TOSS +N/ -S +Ei-W Oleg TFace V t Annotation 1 8808.81 44.33 24.70 6309.76 667.06 4450.25 0.00 0.00 -667.6 TIP 2100 2 8865.00 44.44 25.17 6349.92 631.42 4466.82 0.61 71.76 631. 2 KOP 3 8890.00 47.44 25.17 6367.30 -615.16 4474.46 12.00 0.00 -615. 6 Start Build 45.00 1900 4 9006.60 100.00 25.17 6398.91 -517.21 4520.49 45.00 0.00 -517. 1 Start DLS 45.00 TFO 105.00 5 9055.00 93.85 46.14 6393.03 -478.60 4548.26 45.00 105.00 -478. 0 Start DLS 7.00 TFO 115.00 1500 6 9235.00 88.48 57.54 6389.35 -367.65 4689.48 7.00 115.00 -367.5 Start DLS 7.00 TFO 260.00 E 7 9305.00 87.64 52.71 6391.72 -327.66 4746.86 7.00 260.00 -327, 6 Start DLS 7.00 TFO 107.00 1200 8 9585.00 62.14 71.61 6416.88 -197.89 4992.15 7.00 107.00 -197. Start DLS 7.00 TFO 67.00 9 9895.00 90.92 91.51 6435.83 -152.99 5296.42 7.00 67.00 -152-9 Start DLS 7.00 TFO 270.00900 0 10 10445.00 90.72 53.01 6427.67 11.48 5810.40 7.00 270.00 11. 8 Start DLS 7.00 TFO 95.00 11 10695.00 89.18 70.44 6427.88 129.45 6029.71 7.00 95.00 129. 5 Start DLS 7.00 TFO 115.00 600 12 10765.00 87.12 74.88 6430.14 150.30 6096.47 7.00 115.00 150. 0 Start DLS 7.00 TFO 225.00 300 13 11005.00 75.39 62.69 6466.71 235.44 6316.93 7.00 225.00 235. 4 Start Build 7.00 0 14 11105.00 82.39 62.69 6485.97 280.43 6404.06 7.00 0.00 280. 3 Start DLS 7.00 TFO 285.00 15 11625.00 92.61 27.68 6509.34 640.89 6765.94 7.00 285.00 640. 9 SW DLS 7.00 TFO 249.90 0 16 12185.00 79.54 350.55 6548.98 1181.45 6854.10 7.00 249.90 1181. 5 Start DLS 7.00 TFO 350.00 17 12255.00 84.36 349.70 6558.78 1249.71 6842.22 7.00 350.00 1249. 1 Start DLS 7.00 TFO 300.00 :5 7.00 -300 18 12325.00 86.83 345.45 6564.16 1317.85 6827.19 7.00 300.00 1317. 5 Start DLS 7.00 TFO 80.00 600 19 12605.00 90.34 4.74 6571,14 1595.38 6803.40 7.00 80.00 1595. 8 Start DLS 700 TFO 83.20 20 13015.00 93.56 33.28 6556.88 1978.78 6935.36 7.00 83.20 1978.8 Planned TD at 13015 -90 r Mean B'°Tuc,F,es a GErompmry {'fRE■■■■■■'■■■■■�� ■■®EN,EEM■■■■■■, ■ �e■ . 11 Ilan �■■■■�e��,. ■■■■� ��■►■0_0 ll�i�■■®®!�■■ 8 8 0 0 0 0 0 0 0 0 0 0 West( -)/East(+) (300 usft/in) Vertical Section at 0.00° (80 usft/in) Well KRU XX -XX Nabors CDR3-AC: 4 -Ram BOP Configuration 2" Date April 24, 2019 Coiled Tubing and 2-3/8" BHA Quick Test Sub to Ot Top of 7" Otis Distances from top o Excluding quick -test Top of Annular Ci Annular Bottom Annular Flan CL Blind/Shears C, 2" Combrs 0. 2-3/8" Combrs 0. 2" Combrs CL of Top P Top of Swa CL Swab 1 Flow Tee CL SSV CL Master LDS Ground Tree Size 3 118 ne 1A -04A Proposed CTD Schematic 16" 65# H-40 shoe @ 80' MD 10-3/4" 46# K-55 shoe @ 2999' MD I7" 26# K-55 shoe @I 6580' MD KOP @ 8865' MD A -sand perfs 8848' - 8861' MD 8870'- 8916' MD 4-1/2" 12.6# L-80 shoe @ 9160' MD 4-1/2" Camco D0 nipple @ 503' MD (3.875" min ID) 4-1/2" 12.6# L-80 NSCT Tubing to surface Baker CMU Sliding Sleeve @ 6237' RKB (shifted closed 12/31/00) (3.875" min ID) Baker S-3 Packer @ 6289' RKB Camco DB landing nipple @ 6305' MD (3.813" min ID) Liner too Baker ZXP liner top packer @ 6358' MD Baker HMC liner hanger @ 6368' MD Cameo DB Nipple @ 8533' MD (3.75" min ID) Camco Seal Nipple @ 8689' MD (3.75" min ID) 1A-04AL1 wp02 TD @ 13,015' MD ideft KUP INJ WELLNAME 1A -04A .LBORE 1A -04A C0rj0C@phi"'pS Alaska. Inc. Well Attributes Max Angle B. MD Fieb Name ZR2=PPINWI Wtllbre BUNS Irl MDIM81 KUPARUK RIVER UNIT 500292062101 INJ n8.04 ],556.OJ TD ReemomKaj 9.1510 SSSVeNIPPLE H2SIPPm) Dale Ana W0� 12J31 - R000 ntlKne M1 RN.Rempr Dne IA04A,I ICOIRIONUMAM LaSt Tag Garan zcnemne'rood) Anutallon oeplh MIUD EMGIe Weamte Laze Moa By No Nor mz - CONDUCTOR. 3].Irb.O NIPp1E',59.1 SURFACE -,H1 SXO BLEEYEG: 6.D].J RACKER NSR6 NIpPLEIrt.] XO TXRFPD:6.NA9 SE -ABBY, 63e].l KiNpOW A: 8.a94,0.S5J5.0 PRODUCTION p05T sm msflS" IPERF', 8619.Pa K10 HPSD, AMC IFERF:sB)(1.66,e180 UNER;"5 r4)J&.0 Last Tag: RKB 89000 1116/2018 1A -04A .,UNP Last Rev Reason rmored-EM Date WeHeard Lazt Molay Armored-Spero Rev Reason: Tag ti /62018 IA-04 fergusp Casing Strings casms Desalmion OD(4n) m(m) Tup(nKej R1Deplh OlK81 Bel Dene d, DI.-WADo D... Grade CONDUCTOR 16 15.06 32.1 800 80.0 65.00 H-40 Top Thread WELDED Greeted Dmmilio, 00 OnlIOpm To We' sal0epih DIN81 Sat DaM4 nw)... WDO` 11... Grant SURFACE 10314 9.95 31.2 2,990.2 2,831.1 45.50 K-55 Top Thread BUTT Gsm, Oesmi,drol OD (in) ID IM) TePmKBI gel Degh mKBI Sed D"ad,(rV01.- WMan A. Gretla TopThrea] PRODUCTION POST ] 6.28 28.9 6.MOB 4,9863 26.00 M TO SR Cezln83ca1pllon OD Rn) ID Iml TOPMN81 Set DeplhmNB) Sel Depth ffGD). WBLen IL. Grande Tep Th. WINDOWA ] 6.00 6,/9d.0 8506.0 4,938.5 26.00 K-55 CaslnP description OD linj IDlin) rAD IRKal at ..Ih mKBI Se10epIh Itvu, WLien D.. Grafi LINER 412 3.96 6,345.6 9.150.0 6,6566 12.60 L-80 TOPTneaa NSCT Liner:Details iep mKBI Try IiVDI mKBI Top Incl P) Item Om Com Nami'ian ID R4. 6,345.8 4. 4.0 .JS PBR PBR TIEBACK EXT. 4.]50 83573 4. 1.9 48,81 PA KEF BAKER ZXP LINER TOPPACKE 3.930 636]) 4,848.5 48.86 HANGER HMC HYDRAULIC LINER HANGER 3.958 8532.8 6,208.5 4402 NIPPLE CAMCO OB NIPPLE 3.750 8689.0 6,3202 44.56 NIPPLE CANDO SEAL NIPPLE 3750 Tubing Strings mhmd Desaiplmn TUBING shied Ma...ID1in1 TOp lxKal is De pm lx_Sal Oepm nwll... wl Ph RR Graae 41/2 3.96 262 6,356.9 4,Bd1d 12.60 L-80 Tup cOOnec4On IBT Completion Details Top(TVD Top Incl nominal Top mKBI W13) 19 It.. om Com ID lin) 262 26.2 .00 0HANGER FMC HANGER 4.W2 503.1 503.1 0.00 NIPPLE CAMCO DB NIPPLE WM.87YPA KING BORE 3675 6.237.3 4,]62.2 48.21 SLEEVE -C BAKER CMU SLIDING SLEEVE(SHIFTED CLOSED 1231/00) 3875 6.3 48.46 PACKER BAKER S-3 PACKER, T x 4.5' 6.288.674�M3.5 3.875 6305.27. 4.55 NIPPLE CAMCO DB NIPPLE 3813 8344.9 435 SEALSTEM BAKER SEAL STEM .13634].15.0 48]6 SEAL ASSY BAKER 1904]GBH-22 SEAL ASSEMBLY. STABS INTO LINER 3.958 PBR/PACKER perforations & Slots TopmKa) BIm mKBI Top RV6) INQj atm nrI mKBI IlnNend Zme Data snol Dene Mnwam 1 Type Gm . 48.0 .,861.0 6,4333 6,443.0 A5, 1A-04 2/&'1001 4.0 IPERF 2 ]iW SHO DP 60 deg phasing 88]0.0 8.916.0 6,449.4 Adl22 A-0, 1A-04 222001 I 4.0 IPERF ]/8"SHDDP60deg phading Frac Summary slat Date PrCpwnt DesldnMBN Prappm In pmmelian IN &17)2001 6G4 rom-Dale mpDepm mK31 Elm mxdl unNm Hub syaem o"Pre p(om) 1 2/172001 11.141.0 8916.0 WISluoylhh0 Notes: General & Safety Go' medoompaten 12/31/2060 NOTE. SIDETRACKED WELL 829/2009 NOTE: WAIVERED WELL- PACKER SET TOO HIGH 1129/21 NOTE: View Schematic w/ Alaska Selmomicu TRANSMITTAL LETTER CHECKLIST WELL NAME: 1<Q, U, 4_.A — C) -A L � PTD: Development/Service Exploratory _ Stratigraphic Test —Non -Conventional 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. SOD – J!J API No. 50-0 - 062 ( Q OO v (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_ __) from records, data and logs acquired for well name on ermit . 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. (CompanyName) 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 PTD#: 2190650 Company CONOCOPHILLIPS ALASKA INC Initial Class/fypa _ Well Name: KUPARUK RIV UNIT 1A-04AL1 Program SER Well bore seg ❑Q SER/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 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 unitboundary...... . . . . . . . . ... . . . . Yes 6 Well located proper distance from other wells - - - - -- - - - - - - - - ---- - - - - - - - - - - Yes 7 Sufficient acreage available in.drilling unit- - - _ _ _ _ _ _ _ _ _ _ _ .... _ _ _ Yes 8 If deviated, is wellbore platincluded_ - Yes - - Directional. plan view and wellbore profile included. 9 Operator only affected party- - - - . . . . . ... . . . . ....... Yes - - - 10 Operator has appropriate bond in force .. - - _ ... - - . ....... . . . . ... Yes 11 Permit can be issued without conservation order. . . . . . . ... . . . . . . . . ...... . Yes Appr Date 12 Permitcan be issued without administrativeapproval - - - - - - - ---- - - - Yes DLB 5/1/2019 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. Yes - - - .... AID No. 2C and CO 43ZD 15 All wells within 1/4-mile area of review identified (For service well only). - - - Yes - -- - - - - - - - ---- - 16 Pre-produced injector; duration of pre-production less than 3 months (For service well only) Yes . . . . . . . . . ....... . 17 Nonconven, gas conforms to AS31.05.0300,1.A),0,2.A-D) 18 Conductor stringprovided- - - - . - _ _ _ _ _ NA - - - - .. Conductor set in KRU 1A-04 Engineering 19 Surface casingprotectsall known USDWs - _ - _ - - - ....NA.. - _ - - - - _ Surface casing set in KRU 1A-04 - - - 20 CMT.vol adequate to circulate-on conductor& surf.csg - - - - .. NA _ ...... Surface casing set and fully cemented - - - - - - 21 CMT-vol adequate to tie-in long string to surf csg. - - _ - - .... - _ No - --- - - - - - - - - - 22 CMT will cover all known productive horizons. _ _ - . No..... - _ . ProductNe.interval will -be completed with. uncemented slotted liner 23 Casing designs adequate for C, T, 6 a. permafrost - - - - - .. Yes 24 Adequate tankage-or reserve pit - - - - - - - Yes - _ - Rig has steel tanks; all wastetoapproved disposal wells 25 Jf 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 - _ - _ - - - - - - - - - - - _ - NA - - - - - - - - - --- - - - - - - - --- - - - --- - - - - - - - - - --- - - - Appr Date 28 Drilling fluid program schematic & equip list adequate- .. - - - - _ - Yes - - .. - - _ _ _ - Max formation pressure is 3239 Psig0Q.Q ppg EMW ); will drill.w/ 8.6-ppg EMW and maintain overbal w/ MPD VTL 5/3/2019 29 BOPES, do they meet regulation - - - - - -- - - - - - -- - - - - - - - ------ - - - - -- Yes 30 BOPE.press rating appropriate; test to (put psig in comments)- - ...... - - .. Yes - - - - .. MPSP is 2595 psig; will test 80Ps_to 37Q0-psig 31 Choke. manifold complies w/API_RP-53(May 64)..-.._ -..-.. ---_- --.Yes ---------------------------------..----- -._-.. 32 Work will occur without operation shutdown---- - - - - - - ... - - - - - - - - - - - _ Yes -----,-__-___ 33 Is presence. of 112S gas probable . . . .... . . . . . ... - - - - .Yes _ H2S measures required. ... 34 Mechanical condition of wells within AOR verified (for service well only) - - - .... - - - - _ Yes - - - - - - - - - ---- - - - - - - - - - - - - - - - - --- - 35 Permitcan be issued w/o. hydrogen_ sulfide measures ..... . . . . . . . ... . . . ... No. - - - - - - _ Wells on 1A-Pad are -H2S bearing, H2S measures required, Geology 36 Data presented on potential overpressure zones_ .. - - - .. ... - Yes . Appr Date 37 Seismic analysis of shallow gas.zones- - - - -- - - - - - - - - _ NA DLB 5/1/2019 38 Seabed condition survey (if off-shore) - - - - - - - - - - - - - - - - - ------- - - - - - - - - - - NA_ - ..... _ - .... _ - _ _ _ - - _ ..... 39 Contact name/phone for weekly-progress reports. [exploratory only] -- - - - - - - ----- - - - NA Geologic Date: Engineering Date Public Commissioner: Date Commissioner: Commissioner
