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Home My WebLink About219-005MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC E-36 MILNE PT UNIT E-36 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 E-36 50-029-23620-00-00 219-005-0 W SPT 4374 2190050 1500 602 601 601 601 4YRTST P Austin McLeod 3/25/2023 MITIA. Monobore 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT E-36 Inspection Date: Tubing OA Packer Depth 353 1685 1624 1607IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230325160245 BBL Pumped:2.5 BBL Returned:2.5 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 9 99 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:20:34 -08'00' Surface Casing by Conductor Annulus Fill Coat Corrosion Inhibitor (CI) Applications Well Field API PTD Top of Cement (ft.) Corrosion Inhibitor Fill Volume (gal) Final Cl Top (ft.) Corrosion Inhibitor Treatment Date E-35 Milne Point 50029236150000 2181520 Surface 22.5 Top of Cond 10/24/2019 E-36 Milne Point 50029236200000 2190050 Surface 15 Top of Cord 10/24/2019 E-38 Milne Point 50029236260000 2190440 Surface 20 Top of Cord 10/24/2019 E-39 Milne Point 50029236400000/60-00 2190960 Surface 20 Top of Cond 10/24/2019 E-40 Milne Point 50029236260000 2190440 Surface 25 Top of Cond 10/25/2019 E-41 Milne Point 50029236220000 2190310 Surface 15 Topof Cond 10/24/2019 E-42 Milne Point 50029236350000/60-00 2190820 Surface 17 Top of Cond 10/25/2019 M-18 Milne Point 50029236320000 2190700 3 50 Top of Cond 10/26/2019 M-06 Milne Point 50029236460000 2191130 3 30 Top of Cond 10/26/2019 Cement to surface means cement is up to the 4" outlets below the wellhead. From the 4" outlets up to the top of conductor was filled with Fill Coat Notes: #7 Initial top of Cement footage measurement was taken from the 4" outlet down to the TOC The 4" conductor outlets are anywhere from Ito Yd own from the top of the conductor nE EIV E® DEC 0 6 2019 DATA SUBMITTAL COMPLIANCE REPORT 6110/2019 Permit to Drill 2190050 Well Name/No. MILNE PT UNIT E-36 Pa 1 . Operator HILCORP ALASKA LLC API No. 50-029-23620-00-00 MD 14605 TVD 4493 Completion Date 3/2/2019 1 Completion Status 1WINJ Current Status 1WINJ UIC Yes REQUIRED INFORMATION Mud Log No I/ Samples No V/ DATA INFORMATION List of Logs Obtained: ROP/ABG/DGR/EWR/ADR 2"/5" MD/P61, ABG/DGR/EWR/ADR 2"/5" TVD/ PBI Well Log Information: Log/ Electr Directional Survey Yes. (from Master Well Data/Logs) Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30520 Digital Data 90 14606 3/28/2019 Electronic Data Set, Filename: MPU E-36 DGR ABG EWR ADR.Ias ED C 30520 Digital Data 6750 14568 3/28/2019 Electronic Data Set, Filename: MPU E-36 ADR Quadrants All Curves.las ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36 LWD MD Final.cgm ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36 LWD TVD Final.cgm ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36—Definitive Survey Report.pdf ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36—Definitive Survey Report.t# ED C 30520 Digital Data 3128/2019 Electronic File: MPU E-36 GIS.txt ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36 LWD MD Final.emf ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36 LWD TVD Final.emf ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36 Geosteering.dlis ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36 Geosteering.ver ED C 30520 Digital Data 328/2019 Electronic File: MPU E-36 LWD MD Final.pdf ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36 LWD TVD Final.pdf ED C 30520 Digital Data 3/28/2019 Electronic File: MPU E-36 LWD MD Final.tif ED C 30520 Digital Data 328/2019 Electronic File: MPU E-36 LWD TVD Final.tif ED C 30520 Digital Data 3/28/2019 Electronic File: EMFView3_1.zip ED C 30520 Digital Data 3/28/2019 Electronic File: Readme.txt Log C 30520 Log Header Scans 0 0 2190050 MILNE PT UNIT E-36 LOG HEADERS AOGCC Page 1 of 3 Monday, June 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permitto Drill 2190050 Well Name/No. MILNE PT UNIT E-36 MD 14605 TVD 4493 Completion Date 3/2/2019 Log C 30521 Log Header Scans ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data ED C 30521 Digital Data Well Cores/Samples Information: Name Interval Start Stop Operator HILCORP ALASKA LLC API No. 50-029-23620-00-00 Completion Status 1WINJ Current Status 1WINJ UIC Yes 0 0 2190050 MILNE PT UNIT E-36 LOG PB1 HEADERS 90 11277 3/28/2019 Electronic Data Set, Filename: MPU E-36 PB1 DGR ABG EW R ADR.Ias 6750 11240 3/28/2019 Electronic Data Set, Filename: MPU E-36 1281 ADR Quadrants All Curves.las 3/28/2019 Electronic File: MPU E-36 PB1 LWD MD Final.cgm 3/28/2019 Electronic File: MPU E-36 PBI LWD TVD Final.cgm 3/28/2019 Electronic File: MPU E-361381_Definitive Survey Report.pdf 3/28/2019 Electronic File: MPU E-36PB1_Definitive Survey Report.txt 3/28/2019 Electronic File: MPU E-36PB1 GIS.txt 3/28/2019 Electronic File: MPU E-361381 LWD MD Final.emf 3/28/2019 Electronic File: MPU E-36 PB1 LWD TVD Final.emf 3/28/2019 Electronic File: MPU E-36 PBt Geosteering.dlis 3/28/2019 Electronic File: MPU E-36 P61 Geosteering.ver 3/28/2019 Electronic File: MPU E-36 PB1 LWD MD Final.pdf 3/28/2019 Electronic File: MPU E-36 PBI LWD TVD Final.pdf 3/28/2019 Electronic File: MPU E-36 PB1 LWD MD Final.tif 3/28/2019 Electronic File: MPU E-36 PB1 LWD TVD Final.tif 3/28/2019 Electronic File: EMFView3_1.zip 3/28/2019 Electronic File: Readme.txt Sample Set Sent Received Number Comments AOGCC Page 2 of 3 Monday, June 10, 2019 DATA SUBMITTAL COMPLIANCE REPORT 6/10/2019 Permit to Drill 2190050 Well Name/No. MILNE PT UNIT E-36 Operator HILCORP ALASKA LLC MD 14605 TVD 4493 INFORMATION RECEIVED Completion Report OY Production Test Information Y NA Geologic Markers/Tops 0 COMPLIANCE HISTORY Completion Date: 3/2/2019 Release Date: 1/17/2019 Description Comments: Completion Date 3/2/2019 Completion Status 1WINJ Current Status 1WINJ Directional / Inclination Data I Y1 Mechanical Integrity Test Information Y / NA Daily Operations Summary %Y Date Comments Compliance Reviewed y: Mud Logs, Image Files, Digital Data Y /�A\ Composite Logs, Image, Data Files Cuttings Samples Y& Date: API No. 50-029-23620-00-00 UIC Yes Core Chips Y/ lA Core Photographs Y(NA/ Laboratory Analyses Y NA AOGCC Page 3 of 3 Monday, June 10, 2019 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg�j�� I DATE: Tuesday, April 2, 2019 P.I. Supervisor �' Ie �Y /(0 It SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC E-36 FROM: Adam Earl MILNE PT UNIT E-36 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT E-36 API Well Number 50-029-23620-00-00 Inspector Name: Adam Earl Permit Number: 219-005-0 Inspection Date: 3/31/2019 ' Insp Num: mitAGE190331170603 Rel Insp Num: Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well E-36 'Type Inj w.'ITVD 4374Tubing 593 594 593 593 PTD 2190050 Type Test SPT Test psi 1500 IA z6z 1744 - 1683 1663 — -- BBL Pumped: 2.8 BBL Returned: 2.8 ' OA Interval L INITAL __P/F P Notes: MIT W Mono bore well Tuesday, April 2, 2019 Page 1 of 1 DATE: 3/26/2019 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU E-36 PTD 219-005 MPU E-36 PB1 ROP DGR ABG EWR ADR MD & TVD CD: HALLIBURTON 03 FEB 2019 (RECEIVED MAR 2 8 2019 AOGCC Log Viewers 3/26/20199:01 AM Filefolder CGM 3/26/26199:02 AM Filefolder Definitive Survey 3126/20199:02 AM Filefolder EMF 3/26,/20199:02 AM Filefolder LAS 3/26/20199:02 AM Filefolder PDF 3/26/20199:02 AM Filefolder TIFF 3/26/2019 9:03 AM Filefolder Please include current contact information if different from above. 21`2005 30520 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 �:!s,.'�L131 � 7 f' _U DATE: 3/26/2019 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL ROP DGR ABG EWR ADR MD & TVD CD: HALLIBURTON 03 FEB 2019 Log Viewers CGM Definitive Survey EMF LAS PDF TIFF RECEIVE® MAR 2 8 2019 AOGCC 126/20199:01 AM Filefolder 3/26/2D1 9 9:02 AM Filefolder 3/26/2019 9:02 AM Filefolder MPU E-36 PTD(219-OOS Filefolder 3/26/2019 9:02 ANI Filefolder MPU E-36 PB1 ROP DGR ABG EWR ADR MD & TVD CD: HALLIBURTON 03 FEB 2019 Log Viewers CGM Definitive Survey EMF LAS PDF TIFF RECEIVE® MAR 2 8 2019 AOGCC 126/20199:01 AM Filefolder 3/26/2D1 9 9:02 AM Filefolder 3/26/2019 9:02 AM Filefolder 312EV20199:D2AM Filefclder 3./26/20199: 02AIA Filefolder 3/26/2019 9:02 ANI Filefolder 3/26/2019 9:03 AM Filefolder Please include current contact information if different from above. 212!005 3052.1 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 RECEIVED STATE OF ALASKA I MAR 1 7 1019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN ta. Well Status: Oil [_Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: ' 20AAC 25. toy 20AAc 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ Q WAG[-] WDSPL ❑ No. of Completions: 1 Service ❑✓ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Abend.: 3/2/2019 14. Permit to Drill Number / Sundry: 219-005 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: February 5, 2019 15. API Number: 50-029-23620-00-00 4a. Location of Well (Governmental Section): Surface: 3617' FSL, 1738' FEL, Sec 25, T13N, R10E, UM, AK Top of Productive Interval: 2103' FSL, 2266' FWL, Sec 24, T13N, R10E, UM, AK Total Depth: 14' FSL, 873' FWL, Sec 14, T13N, R10E, UM, AK r 8. Date TD Reached: February 23, 2019 16. Well Name and Number: MPU E-36 9. Ref Elevations: KB: 48.3' GL: 21.7' BF: 21.7' 17. Field / Pool(s): Milne Point Field Schrader Bluff Oil Pool 10. Plug Back Depth MD/TVD: 13,895' MD / 4,385' TVD 18. Property Designation: ADL025518 / ADL047437 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569407 y- 6016156 + Zone- 4 TPI: x- 568096 y- 6019909 Zone- 4 Total Depth: x- 561394 y- 6023041 Zone- 4 11. Total Depth MD/TVD: 14,605' MD / 4,493' TVD 19. DNR Approval Number: LONS 94-017 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 2,043' MD / 1,794' TVD 5. Directional or Inclination Survey: Yes ✓ (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: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ROP/ABG/DGR/EWR/ADR 2"/5" MD / PB1 Sir i/r,�ry ABG/DGR/EWR/ADR 2"/5" TVD / PB1 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE AMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 215# X-52 Surface 107' Surface 107' 42" x270 ft3 9-5/8" 40# L-80 Surface 6,760' Surface 4,390' 12-1/4" Stg1 L-540 sx/T-447 sx Stg 2 L - 456 sx / T - 268 sx 244 bbls 3-1/2" 9.2# L-80 Surface 6,598' Surface 4,375' Tieback Tieback Tubing 4-1/2" 13.5# L-80 6,586' 13,900' 4,374' 4,385' 8-1/2" Injection Liner w/ ICDs & Swell Packers 24. Open to production or injection? Yes ❑✓ No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ** Please see attached wellbore schematic for Swell Packer and ICD detail** Liner run on 2/28/19 COMPLETION DAT 3 ?all ERIF ED :v 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/rVD) 3-1/2" 6,598' 6,586' MD / 4,374' TVD Liner Top Packer 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) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: NIA Hours Tested: Production for Test Period -1110 Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: I Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate _-J� Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 CONTINUED ON P 23BOM MEWMAR 28 2019 Submit ORIGINIAL rN 28. CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, care 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 Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 2,043' 1,794' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval Schrader NA 7,114' 4,415' information, including reports, per 20 AAC 25.071. SV5 1,909' 1,697' SV1 3,015' 2,491' Ugnu LA3 5,001' 3,878' SB NA 6,070' 4,311' SB OA 6,708' 4,385' Formation at total depth: Schrader Bluff 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Defintive Directional Surveys, Csg and Cmt Report. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: D' ling Mana er Contact Email: cdin er hIICOf .C011l Authorized/�i4 Contact Phone: 777-8389 3aSignature: � Date: INSTRUCTIONS General: This form and t required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only H corp Alaska, LLC KB Elev above MSL: 48.3' To= 14,609 (MD) /TD= 4,493(TVD) PBTD=13,895' (MD) / PBTD= 4,38YMO) Schematic Milne Point Unit Well: MPU E-36 PTD: 219-005 API: 50-029-23620-00-00 TREE & WELLHEAD Tree 1 Cameron 31/16" 5M w/3-1/16" SM Cameron Wing Wellhead I Cameron 11" SK x sliplock bottom w/ (2) 2-1/16" SK outs OPEN HOLE / CEMENT DETAIL 42" '270 ft3 12-1/4" Stg 1-540 sx Lead / 447 sx Tail Top Stg 2 -456 sx Lead / 268 sx Tail (244 bbls back) 8-1/2" Cementless Injection Liner in 8-1/2" hole CASING DETAIL Size Type Wt/Grade/Conn Drift I Top Btm BPF 20" Conductor N/A/X-52/Weld N/A Surface 107' N/A 9-5/8" Surface 40/L-80/TXP 8.75" Surface 6,760' 0.0758 4-1/2" Liner 13.5 / L-80 / Hyd 625 3.85" 6,586' 13,900' 0.0149 TUBING DETAIL 3-1/2" Tubing 9.2/L-80/EUE 2.992" 1 Surf 1 6,598' 1 0.0152 WELL INCLINATION DETAIL KOP @ 290' Max Hole Angle = 92.98" GENERAL WELL INFO API#:50-029-23620-00-00 Completed by Innovation: Future JEWELRY DETAIL No Top MD Item ID Upper Completion 1 2504' X Nipple 2.813 2 5,742' XN Nipple profile: 2.725" No Go/2.813 Packing Bore 2.725 3 6,596' 8.25" No -Go Locater on Tieback Assy ([4] -1" Ported Seal Stem) 2.992 4 6,598' Tieback Shoe 6.180 Lower Completion 4 6,51:16:::::::TLiner Top Packer (TVD=4,374') - 5 13,895' 1 WIV(Ball on Seat/ Closed) PBTD - Depth MD Depth TVD ICD/Swell Packer Detail 6,974' 4,404' Tendeka Water Swell Packer 7,114' 4,416' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 7,181' 4,421' Tendeka Water Swell Packer 7,400' 4,426' Tendeka-ICD w/ 250L mesh, Sliding Sleave 1354 bxp 625 Wedge 7,627 4,419' Tendeka Water Swell Packer 8,084' 4,412' Tendeka- ICD w/ 250L mesh, Sliding Sleave 1354 bxp 625 Wedge 8,272' 4,411' Tendeka Water Swell Packer 8,608' 4,401' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.54 bxp 625 Wedge 9,033' 4,392' Tendeka Water Swell Packer 9,093' 4,390' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 9,359' 4,378' Tendeka Water Swell Packer 9,656' 4,373' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.59 bxp 625 Wedge 10,001' 4,376' Tendcka Water Swell Packer 10,140' 4,38(' Tendeka- ICD w/ 250L mesh, Sliding Sleave 1359 bxp 625 Wedge 10,604' 4,379' Tendeka Water Swell Packer 10,863' 4,380' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 11,087' 4,377' Tendeka Water Swell Packer 11,265' 4,369 Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 11,411' 4,363' Tendeka Water Swell Packer 11,946' 4,366' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 12,133' 4,369' Tendeka Water Swell Packer 12,391' 4,380' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.59 bxp 625 Wedge 12,615' 4,383' Tendeka Water Swell Packer 12,991' 4,391' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 13,179' 4,386' Tendeka Water Swell Packer 13,794' 4,385' Tendeka-ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge UD 3/26/2019 U Well Name: MP E-36 Field: Milne Point County/State: , Alaska r (LAT/LONG): evation (RKB): API #: Spud Date: 2/6/2019 Job Name: 1813045D MPE-36 Drilling Contractor Innovation AFE #: AFE S: Hilcorp Energy Company Composite Report ActivityDatel _ Ops Summary P;� - ,,.: 2/212019 Continue move Rig off of well E-37 and staged on pad while wells group worked on tie in for E-37. Perform rig maintenance and shaker mod while waiting.;Continue with rig maintenance and shaker mod while Wells group performs tie in for E-37.;Cominue with rig maintenance and shaker mod. Roads & Pads prep location for Rig to move over MPU E-36.;Install Cameron Wellhead Sliplock System & Adapter. Spot Herculite & matting boards for Sub Base.;Move rig. Spot Sub Base over Well and level. Set matfina boards omodules. Move catwalk into place, 2/3/2019 Spot pipe shed and Mud module. Start connecting pipe shed and mi interconnects. Continue work on changing out cuttings drag chain. Geology, MWD, and DD on Iocafion.;Spot Gen module. Continue changing out cuttings drag chain & perform modifications to shaker possum belly.;R/U steam, water & air lines. Energize steam system. Plug in lines to Plug Board. Spot and R/U Enviro Vac & Break Room. Continue with drag chain and possum belly work. Rig on high line power at 18:00.;Hook up interconnects completely. Scope up Derrick and bridle down. Work on rig acceptance checklist. Roll pump liners 90° & reassemble Mud Pumps. Spot and berm Cuttings Box. Circulate heated water through pits, pumps and lines to ensure thawed. Remove Saver Sub.;C/O Saver sub & grabber dies.;Continue with Rig acceptance checklist. NIU Stack and Diverter System. Diverter test witness waived by AOGCC Rep Lou Laubenstein 2-3-19 11:15.;Hauled 0 bbis Fluid to MP G&I total = 0 bels HnuloA 7An bhl% H70 from I -Pad I ala, total — 780 hilet, 2/4/2019 Orient diverter "T" and set slips on Cameron Slip Lock system. PIT void 1000 psi w/ 5 min hold (lest good). N/U knife valve. Install koomey lines. Crane diverter line into place and Ml same. Finish loading and recording SIN on 5" die (260jts total). C/O oil filters on TDS (EAM).;Service traveling equipment. Perform derrick inspection.;Finish N/U diverter system. Complete monthly on top drive. Inspect brake assy. Repair broken suction handle in pits (trip tank). Clean shipping grease from box and pin of new die. Test gas alarms -10/20 H2S, 20/40 LEL. Rig accepted at 18:00.;Center Stack. Set Riser and install Flow Box & Bell Nipple air boots. Disconnect lines from knife valve. Set long mouse hole in rotary table, reduce annular pressure and close bag on mouse hole.;Spot containment at end of Diverter line. Continue to clean threads on new drillpipe in shed. Replace worn breakout cobrahead chain. Replace mud pump #2 stripper box seals.;Pick up 5" Drillpipe from shed and rack in Derrick. Drift joints as they are picked up.;Continue picking up 5" drillpipe from shed and rack in Derrick (146 jls of 260 picked up). Brought 290 bbis , 8.8 ppg Spud Mud into pits.;Hauled 50 bbis Fluid to MP G&I total = 50 bbis Hauled 40 bbis H2O from L -Pad Lake total = 820 bbis 2/5/2019 Continue to drift and pick up a total of 260 joints of 5" drill pipe. Pick up 17 joints of HWDP (break in threads) and jars.;Slip and cut 100' of drilling line. Check draw works brake gaps, withing spec.;Remove master bushings and ensure split set of bushings for MPD fits. Rig up 3" rig tongs.;Make up 12.25" Baker Kymera (KM633x) bit to SperryDrill 8" Motor. Install cross over to NC -50 HWDP and run stand in hole.;PJSM. Test Diverter/annular system. Witness waived by AOGCC Rep Lou Laubenstein 2-3-1911:15. Knife open 8 sec, bag close 13 sec. Initial System pressure 2,950 PSI, final charge 2,000 PSI, 200 PSI charge 19 Sec, full charge 52 sec. 6 bottles Nitrogen average 2,325 PSI avemge.;PJSM/Pre-Spud with Crew & Third Parties. Prime pumps through bleeder, fill mud line and PT t/ 3000psh Flood conductor and stack with water. Riser lower air boot leaking, drain stack below boot level and replace. #1 cutting shaker tripped and would not reset, call rig electrician to troubleshoot.;Pick up Flex Collars and rack in Derrick. Start making up remaining BHA on top of motor and RIH. 8" Pony Collar, DM Collar, Gamma Collar, Resistivity Collar, PWD Collar, HUM Collar & TM Collar. SIMOPS: Electrician C/O faulty power cord from "J" Box to Shaker motor.;PJSWPre-Spud with Crew after C/O. Continue MIU BHA #1, MWD TM Collar & UBHO Sub, cross over to NC -50. Obtain RFO & orient UBHO. Plug in and upload MWD tools. Hang Gyro sheave and prep wireline tools while uploading.;Cleaning out 20" Conductor with water to 107' MD. Start drilling to 112' MD and displace water W/ 8.7+ opa Sud Mud. Drill stand own to 1630 PSI 50 t.ftri stalling . Pull back into Conductor while troubleshooting.;Adjust main idler sprocket alignment and tension on drag chain. Roll pumps every 10-15 min to keep from heezing.;Rotary drill 12.25" hole F/ 156'- TI 218' MD. 450 GPM, 750 PSI, 50 RPM, TRQ 1.7K, WOB 2-5K. P/U 50K, SIO 50K, ROT 50K. 9.3 ECD's.;Hauled 47 bbis Fluid to MP G&I total = 97 bbls Hauled 180 bible H2O from L -Pad Lake total = 1000 bbis Lost 0 bale to formation total fluid lost = 0 bbls 2/6/2019 Blow down top drive. POOH from 218' racking back two stands HWDP. Pick up and RIH with stand of drill collars and stand of HWDP. Tag up on tight spot at 199. Wash and ream working down from 190'to 218' while carrying scribe line to verify Gyro.;Confinue drilling 12-1/4" surface hole from 21& to 401' sliding as necessary, Started build at 276'targeting 3-4°1100' build rates. Gyro survey every stand. 183' Total (46 AROP) 450 GPM, 960 PSI, 50 RPM, TRQ 3K, WOB 6- 10k. P/U 59K, SLK 59K, ROT 59K.;Continue drilling 12-1/4" surface hold from 401'to 713' sliding as necessary. Gyro survey every stand. 312' Total (52' AROP) 450 GPM, 1060 PSI, 50 RPM, TRQ 3.6K, WOB 6-10k. P/U 69K, SLK 68K, ROT 68K. Pump through bleeder while collecting gyro surveys to clear out flow Iine.;Take short survey at 426' and swap to gravity tool face with 4.67° inclination.;Drill and slide F/ 713! to 1,160' MD. (1,135' TVD) 44T Total (74' AROP) 575 GPM, 1,560 PSI, 80 RPM, TRQ 4.5K, WOB 12-17K. PIU 76K, SLK 74K, ROT 75K. Backream slide intervals at full rate, reduce flow 50% on downstroke. Pump through bleeder while collecting gyro survey's to clear out flow Iine.;Last Gyro survey at 790' sensor depth, 902' bit depth. Drilled to 1030' and with 3 consecutive clean MWD surveys, gyro loggers were released. (23:00) . Closest approach CC to E-17, (Shut in injector), was at 710' MD at 39.47'. Well EJi was shut in at 1030', 23:00hr.;Drill and slide F/ 1,160'to 1790' MD. (1534' TVD) 630' Total (105' AROP) 615 GPM, 1,950 PSI, 80 RPM, TRQ 6-8K, WOB 8-12K. P/U 89K, SIO 74K, ROT 82K. Slide Him 5.92, Rot Him 3.01, Bit Hrs 9.94 , Jar Him 53.02;Hauled 741 bbis Fluid to MP G&I total = 838 bbls Hauled 980 bbis H2O from L -Pad Lake total = 1980 bible Lost 0 bbis to formation total fluid lost = 0 bible 2/7/2019 Continue drilling 12-114" surface hole from 1790' to 2423' maintenance slides through tangent. 633' Total (105' AROP) 80 RPM, TRQ 6K, WOB 2-4k. PN 105K, SLK 79K, ROT 8K. Initial 600 gpm/1700 psi, ECD's 9.95ppg. At 2330' due to G&I issues limit ROP to 150 fph and 450gpm/1200 psi.;Waiting on additional supersuckers and approval for disposal at i B/BP G&I. Backream at full rate, slowing pumps to 400 gpm on downstroke to minimize surge.;Continue drilling 12- 1/4" surface hole from 2423'to 3060' maintenance slides through tangent. 637' Total (106' AROP) 450 -550 gpm/ 1800 psi 80 RPM, TRQ 7.7K, WOB 8k. P/U 118K, SLK 82K, ROT 97K. Backream at full rate, slowing pumps to 400 gpm on downstroke to minimize surge.;At 2530'MD12153'TVD observe gas breaking out at rotary table. Adjust gas trap 830U of gas hydrates. Continue drilling at 150 fph 450 gpm with 450U - 1084U of gas. Observe gas dissipate to 8U at 2830'MD/2356'TVD. At 2383' we appeared to cross a fault with 70' of throw;Continue drilling 12-1/4" surface hole from 3060'to 3460' maintenance slides through tangent. 400' Total (67' AROP) 80 RPM, TRQ 73K, WOB 8k. P/U 129K, SIO 89K, ROT 104K. 600 gpm/1900psi, ECUs 10.01 ppg. Running DeGasser. Pump Tandem sweeps @ 3313', back on time with 10% increase.;Limit ROP to 150 fph and adjust flow as shakers dictate, minimizing excess fluid, (450-600gpm) due to G&I issues. Gas start increasing @ 3155' MD/ 2589' TVD. Max Gas 2075u @ 3312' MD with Drilling BGG of 1200-1500u. Continue limit ROP to-150'/hr. Start increase MW U 9.4ppg @ 3400' MD.;Drill and slide 12.25" hole F/ 3460 to 4014' MD. ( 3204' TVD) 554' Total (92' AROP) 450-600 GPM, 2100 PSI, 80 RPM, TO 10.21K, WOB 8- 12K, 10.15ppg ECD. P/U 149K,S/0 115K, ROT 141K. Max Gas 24260. Slide Hrs 2.52, Rot Hrs 10.62, Bit Hrs 23.08 , Jar Hrs 66.16.;Background gas increased to 800+units through the SV -2, and has remained elevated into the Ugnu section. Start seeing slight oil at shakers @ -3500' MD. Current BGG @ -600u. Drilling in middle of Ugnu 4A, sand, clays and thin coalbeds.;Distance to WP #12a 11.07', 6.18 Low, 9.19 Right.;Hauled 570 bbis Fluid to MP G&I total= 1408 bbis Hauled 518 bbls to 1-B for injection total = 518 bbis Hauled 114 bbis to BP G&I for injection total= 114 bbis Hauled 1560 bbis H2O from L -Pad Lake total = 3540 bbis 2/8/2019 Drill and slide 12.25" hole F/ 4014'to 4210' MD. 196' Total (98' AROP) 550 gpm/1920 PSI, 80 RPM, TO 11.21K, WOB 8-12K, 10.1 ppg ECD with 9.5 ppg mud. P/U 146K, S/O 89K, ROT 112K. Background gas 300-400U.;Obsewe wash pipe leaking. Rack back 1 stand. B/D top drive. Rig up head pin. Change out wash pipe while circulating 5 bpm. Rig down head pin and blow down Iines.;Drill and slide 12.25" hole F/ 4219to 4399' MD. 1 89'Total (75.6' AROP) 580 gpm/2150 PSI, 80 RPM, TO 10.51K, WOB 9K, 10.3ppg ECD with 9.5 ppg mud. P/U 154K, S/O 93K, ROT 115K. Max Gas 7930, Start 4°/100 turn and build at 4,333'. Backream full stands.;Note: 250-350U BGG for two bottoms up after changing swivel packing (pumps down -30 min).;Drill and slide 12.25" hole -F/ 4,399' to 4,781' MD. 382' Total (64' AROP). Sliding as needed 590 gpm/2310 PSI, 80 RPM, TO 12.51K, WOB 9-20K, 10.36ppg ECD wfth 9.6 ppg mud. P/U 161K, SIO 95K, ROT 120K. Max Gas 8040; consistent 250-350U BGG. Back ream full stands.;Drill and slide 12.25" hole F/44781 to 5244' MD. ( 4020' TVD) 463' Total (77' AROP) 550-600 GPM, 2200 PSI, 80 RPM, TO 12.5-14.5K, WOB 2-25K, 10.42ppg ECD. P/U 172K, SIO 96K, ROT 122K. Max Gas 1133U @ 4976'. BGG 300-600u. Back ream full stands.;Phase 2 conditions in field @ 21:00 turned to phase 3 conditions @ 23:30. Approved for travel infield with R&P escort only. Reduce flow (<550 GPM) and ROP (<150) to minimize cuttings rate for disposal & water usage. Rig crews performing minimal job duties with no work involved outside.;Drill and slide 12.25" hole F/ 5244 to 5542' MD. ( 4148' TVD) 298' Total (50' AROP) 500-600 GPM, 2495 PSI, 80 RPM, TO 12-18K, WOB 2-30K, 10.42ppg ECD. P/U 171 K, S/O 92K, ROT 124K. Max Gas 4620. BGG 100400. Slide Hrs 7.41, Rot Hrs 6.14, Bit Hrs 36.63 , Jar Hrs 79.71. Back ream full stands.;Confinue with reduced speed and workload operations due to phase conditions.;Hauled 1145 bbis Fluid to MP G&I total = 2553 bbis Hauled 0 blots to l -B for injection total=518bbis Hauled 0 bbis to BP G&I for injection total = 114 bbis Hauled 1300 blols H2O from L -Pad Lake total = 4840 bbis Lost 0 bbls to formation total fluid lost = 0 blots 2/92019 Drill and slide F/ 5544'to 5735' MD. ( 4215' TVD) 191' Total (32' AROP) 550 GPM, 2265 PSI, ECD 10.1 ppg, 80 RPM, TRQ 15-18K, WOB 20K. PIU 171 K, SLK 91 K, ROT 120K. BGG - 50U.;Drill and slide F15735' to 6022' MD. ( 4294' TVD) 287' Total (48' AROP) 615 GPM, 2265 PSI, ECD 10.24ppg, 80 RPM, TRQ 15- 19K, WOB 11 K. P/U 175K, SLK 92K, ROT 122K. Pump tandem low wt/vis, high wWis sweeps @ 5988'. Back on time, no increase in cuttings.;Drill and slide F/ 6022' to 6372' MD. ( 4347' TVD) 350' Total (58' AROP) 615 GPM, 2650 PSI, ECD 10.22ppg, 80 RPM, TRQ 13-19K, WOB 32K. P/U 176K, S/O 89K, ROT 124K. Max Gas 448u, BGG 100u.;Drilt and slide 12.25" hole F/ 6372' to 6770' MD. ( 4390' TVD) 398' Total (66' AROP) 600 GPM, 2495 PSI, 80 RPM, TO 12- 18K, WOB 2-30K, 10.37ppg ECD. P/U 171 K. S/O 88K, ROT 118K. Max Gas 454U. Slide Hrs 9.02, Rot Hrs 5.93, Bit Hrs 51.58, Jar Hrs 94.66.;TD called by on- site geologist at 6770' MD. Est top of OA sand @ 6720' MD. Distance to WP #12a 4.89', 1.28 High, 4.72 Left.;Obtain final survey and backream out of hole V 6750' MD. 600 GPM, 2195 PSI, 80 RPM, Tq 14K.;Hauled 1134 bbis Fluid to MP G&I total = 3687 bbis Hauled 0 bbis to 1-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bbis Hauled 780 bbls H2O from L -Pad Lake total = 5620 bbls Lost 0 bbis to formation total fluid lost = 0 bbls 2/10/2019 Continue to BROOH from 6770'to 6625' at 600 gpm/2230 psi, 80 rpms/15Kft-lbs. Monitor well, static.;Pump tandem high vis/weight and low vis/wt sweep (back on time 10% increase) and circulate hole clean 3 x bottoms up; 600 gpm/2130 psi, 80rpms/141(ft-lbs reciprocating pipe.;RIH from 6626to 6670' with no issues. PUW 175K, SOW 91 K.;BROOH from 6770' to 6181', 600 gpm2100 psi, 80 rps/15-17Kft-lbs pulling 10-12 fpm, ECUs 9.97 ppg with 9.5 ppg mud. PUW 171 K, SOW 88K, ROTW 118K.;Continue to BROOH from 618 Vto 4000' at 600 gpm/1900 psi, 80 rpms/11 K -ft -lbs at 13 fpm. ECUs 10.1 ppg. No issues. PUW 150K, SOW 88K, ROTW 109K.;Continue to BROOH from 4000' to 1916' at 600 gpm/1650 psi, 80 rpms/9K-ft-lbs at 13 fpm. ECUs 10.1 ppg. No issues. P/U 106K, S/O 88K, ROT 85K. Max Gas 405u @ 2450'.;Slight increase in cuttings and thick mud back with the gas spike @ 2459. Circulated 2x BU while backreaming 2 stds from 2232' to 2106, 2207hr pulling speed.;Conflnue to BROOH from 1946 to 216' at 600 gpm/1650 psi, 80 rpms/9K-ft-lbs at 13 fpm. ECUs 10.1 ppg. No issues. P/U 106K, SIO 88K, ROT 85K. Max Gas 193u @ 1351'.;Hole unloading at 1400'and again @ 1000'-800'. Attempted to pull HWDP on elevators with no success. Continue BROOH t/ 216'.;Stop all non essential operations due to weather Phase conditions. Bit is positioned 100' below conductor. String will be worked intermittently to ensure free movement.;Hauled 934 blots Fluid to MP G&I total = 4621 bbls Hauled 0 bbis to 1-B for injection total = 518 bbis Hauled 0 bbis to BP G&I for injection total = 114 bbis Hauled 910 bbis H2O from L -Pad Lake total = 6530 bbis Lost 0 bbis to formation total fluid lost= 0 blots 2/11/2019 Continue to wait on phase conditions. At 216' reciprocate pipe every 20 min, no issues. Monitor well on trip tank, 26PH loss rate.;PJSM. Rack back 1 stand HWDP. UD drill collars. Download MWD. Continue to UD BHA. Bit grade 3-3-WT-A-F-1-CT-TD.;Clean and clear rig floor. UD 3" tongs.;Service rig, grease crown, TD, wash pipe.;Rig up to run 9-5/8" L-80 TXC casing. Rig up Volant tool, bails and extensions, double stack tongs.;PJSM with rig and casing crew. MIN 9- 5/8" shoe track as per detail. Bakerlok shoe track connections. Check floats, good. Install bypass baffle on top of FC. Run 9-5/8", TXP BTC, 40#, L-80 casing F1 surface - T/ 1,530' as per detail.;lnstall bow spring centralizers as per detail and record displacement every 5 jts. 21k fl/lbs make up tq (optimum). Adjust stack alignment due to collars hanging up below riser. Losses continue at—2BPH.;Cont Run 9-5/8" TXP BTC, L-80, 40# casing F/ 1,530'- T/ 2352' MD. Record disp every 5 jts.128k up, 78k dn. 21 k tq connections. Losses at-38PH.;Circulate annular volume staging pumps up to 7 bpm/170 psi, loss rate 9 bph.;Cont Run 9- 5/8" TXP BTC, L-80, 40# casing F/2,352'- T/ 3314' MD. Record disp every 5 jts.192k up, 86k dn. 21k tq connections. Losses at-2BPH.;Hauled 342 bible Fluid to MP GW total = 4963 bbls Hauled 0 bbls to i-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bible Hauled 390 bbls H2O from L-Pad Lake total = 6920 bbls 2/12/2019 Cont Run 9-5/8" TXP BTC, L-80, 40# casing F/ 3114" - T/ 4550' MD. 222k up, 95k dn. 21 k tq connections. Losses at-1.5 BPH.;Circulate and condition mud staging pumps up to 7 bpm/200 psi reciprocating pipe loss rate 3 bph. Circulate 2 x annular volume.;Cont Run 9-518" TXP BTC, L-80, 40# casing F/ 4550" -T/ �Sk 6760' MD. 277k up, 92k dn. 21ktq connections.;Circulate hole clean staging pumps up to 7 bpm/280 psi reciprocating pipe. Prep pits for cement job. Rig up cementers, blow down top drive. Rig up cement line and re-establish circulation at 7 bpm/540 psi through cement Iine.;Cement as per detail: HES flood lines with 7 bale water. PT lines 1000/4000 psi - good. 60 bbls 10ppg Clean Spacer at 4 bpm/280 psi Drop Bypass plug 225 bbls Type Ifli 12 ppg Lead cement at 5bpn✓380 psi 92 bbls Class G 15.8 ppg Tail cement at 4bpm/685 psi.;Drop closing plug. Displace cement with 20 bbls FW (HES) 274 bible 9.5 ppg spud mud at t( 7.5 bpm/580psi 40 bbls spacer (spotted across ESCIP) at 6 bpm/580 psi, 173.9 bbls 9.5 ppg spud mud at FCP 3bpm/900 psi, (4.94 bbis over calculated). Pressure up to 1400 psi and held 5 min.:Bled back 3 bbls. Floats held. CIP 00:57. Full returns. Reciprocated pip until 380 bbls into displacement. Inflate packer: pressure up to 2280 psi, observe 100 psi drop. Pressure up in 100 psi increments x 5 observing 10 - 30 psi drop. Observe ES shear open at 2700 psi.;Attempt to break circulation; 2 bpm pressure climbing with no returns stage pumps up to 6 bpm/1700 psi prior to obtaining partial circulation (10-20% eturns). After pumping 300 bbls obtain full returns with 246 bbls lost. Circulate 2 bottoms up at 4.5bpm/850 psi ;Observe 101 bbls of cement contaminated mud 5 with trace of cement.;Drain stack, disconnect knife valve and flush stack x 2 functioning annular with black water.;Continue circulating through ES cementer while {' prepping for second stage cement job 4bpm/710 psi.;Hauled 404 bbls Fluid to MP G&I total = 5367 bbls U Hauled 0 bbls to i-B for injection total=518bbls Hauled 0 bbls to BP G&I for injection total= 114 bbls Hauled 450 bbls H2O from L-Pad Lake total = 7370 bbls Lost 292 bible to formation total fluid lost = 312 bbls 2/13/2019 Circulate thru ESCMTR while prep for 2nd Clean cuttings box, Offload excess mud from pits and offload at G&I for disposal. Spot trucks for 2nd stage cmt job. �1 Top rinse pits and ready for 2nd cmt job. Fill water tank and heat to 80°F for cmt job.;PJSM, Pump 2nd stage cmt job Lineup to cmtrs, wet lines w/ 5 bbls FW. 60 bbls 10.0# Tuned Spacer III w/ 4# red dye first 10 bbls, 5 BPM, 656 psi. 352 bbls 10.7# lead Perm "L" cmt, 4.33 yld, 344 sxs, 5 BPM, 754 psi, 56 bbls 15.8# tail �. Premium "G" cmt, 1.169 yld, 268 sxs, 3.5 BPM, 600psi.;Drop closing plug. HES pump 20 bbls FW, 6.5 bpm, 900 psi. 244 bible of lead cement back at surface.;Turnover to rig. Disp & bump Q 168.7 bible / 2727 stks (168.7 bbls calc) 9.3# mud 4.5 BPM, 960 psi. Slowed last 8 bbls, 3 bpm, 700FCP. Bumped and psi up to 2000 psi (ES shift @ 1350 psi)Held 5 min. Bled back 1 bbls flow stopped. CIP @ 13:15 hrs. 100% returns.;Flush cement lines and stack with black water. Blowdown cement service line to unit. RID Weatherford casing CRT. RD cement lines and clear same. LD CRT to cradle. RU side door elevators. Blow down TDS. LD remaining WOT equipment and release casing crew. Flush stack / surface lines with black water.;P1U BOP stack off conductor, PU to 150K on jnt. Wellhead Reps installed slips, centered joint in wellhead. SO setting casing with 130K on slips. (rough cut on casing and LD same. Out off jnt= 29.96) Re-set stack on conductor.;Clean and clear rig floor of casing and pipe handling equipment. MU stack wash tool on TDS. Flush stack and wellhead with black water. Blow down lop drive. Remove bell nipple. N/d starting head, DSA. Stand back BOP and diverter' T' on stump.;Make final 9-5/8" casino cut. Bevel and dress stump. N/U 11" Cameron sliplock. Test P seals 500 psi/2400 psi 5/15 min -good. Set sliplock slips. NIU wellhead and test'o' ring seals between wellhead and sliplock 500/5000 psi 5115 minutes - good. f J / Clean pits;N1U 11" x 13-5/8" DSA and 13-518" spacer spooL;Hauled 1704 bats Fluid to MP G&I total = 7071 bats �✓ �,(�w�"'J��l1 Hauled 0 bbls to 1-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total= 114 bbls Hauled 735 bbls H2O from L-Pad Lake total = 8105 bbls Lost 292 bbls to formation total fluid lost= 312 bible 2/1412019 Prep to modify flow box for MPD: remove drip pan, and flow box. Take flow box to shop for modifications. SimOps: change out swab and liner on MP #2, receive 580 bible of drilling fluid.;Clean flow box and modify for MPD equipment. Clear out cellar of diverter'T' and starting head. Rig down and crane off remaining diverter section anchor and rig mat.;Bring split master bushing to rig floor and UD solid bushing. Bring RCD element into cellar and modified flow box.;Torque spacer spool to DSA. VU 13-5/8" BOP and torque.;Re-install flow box, and bolt to flowline.;Torque BOPE bolts from spacer spool to BOPE.;Seal flow box with foam and silicone. Install drip pan. Bring MPD bearings to rig floor. Hoist RCD element on top of BOP stack.;Hauled 1141bb1s Fluid to MP G&I total = 7185 bbls Hauled 0 bbls to 1-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bbls Hauled 735 bbis H2O from L-Pad Lake total = 8105 bible Lost 0 bbls to formation total fluid lost = 312 bbls 2/15/2019 Install MPD Rotating head & Tq studs to spec. Stage "sing sleeve and MPD bushing on rig floor. Inspect saver sub and grabber dies. Clean and grease Master Bushings for storage. Hook up MPD 3" hard line ff Rot Head back to MPD Skid. Tie in steam lines and wrap around MPD Unes.;Test run aluminum drip pan and send back to shop for Mods. Hook up choke and Kill Lines. Install Koomey Lines as needed, Pressure up Koomey Unit. Attemptto install both 20" and 16" Riser, unable to slide airboot stem by flow box, remove & modify 16". Reinstall same.;Rig up testing equipment. M/U test plug and set as per wellhead hand. Fill stack with water, leaking by test plug. Pull test plug. Re-install test plug. Fill stack with water. Obtain RKB's. Shell test - good.;Test BOPE's 250/3000 psi on 5" and 4- 1/2" test joint. State's right to witness test waived by Adam Earl. Test gas alarms. F/P on lower IBOP, function purge air and retest. Accumulator drawdown: starting pressure 2950 psi final 1500 psi, first 200 psi recharge 24 sec,;final 91 seconds. 6N2 bottles at 2366 ave. Rig down test joint.;Pu11 riser, install cap on RCD. Fill lines to test MPD lines and equipment.;Hauled 105bbis Fluid to MP G&I total = 7290 bbls Hauled 0 bbls to 1-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total= 114 bbls Hauled 160 bbls H2O from L-Pad Lake total = 8265 bbls Lost 0 bbls to formation total fluid lost =312 bbls 2/1612019 PJSM, Finish purging MPD HP Lines. Test MPD Mud Lines and Choke 1/250/1500 psi, 10 min test ea. Test Mud Pump Sensor Line to 250/1500 psi, 10 min ea.. Blow sown MPD Lines and R/D Test equipment.;PJSM, Perform training test run for Rotating Head w/MPD Reps. R/D Plug flange on Rotating Head, R/U Riser and air boot, pull lest plug, Drain stack and set wear bushing. P/U and M/U 3 stands f/Derrick and RIH, Pull out Risers, Break out single and L/D Risem,;M/U MPD Bushing to single and WU to stump, RIH w/Bushing and set in Rotating Head.;Crew Change. Continue training incoming crew on MPD Bushing Deployment. Remove MPD Bushing and Re-Install 16" Riser and 20" Riser. Clear excess MPD Bushing Equipment from rig floor.;Rack Back 3 stands. Break out and UD Stack Jetting tool.;lnstall and seal cellar drip pan. fix Hyd leak in cellar HPU. Service Crown and Inspect Derrick. Install Mouse Hole.;M/U drill out BHA: 8- 1/2" Smith Tricone, SperryDrill 1.5' bend motor, Ll (6) HWDP, Jars, If 1) HWDP. Continue to RIH to 2430', wash and ream down to 24901 tag cement.;Drill cement and ESICP from 2490'to 2501'. Tag up on ESICP on depth at 2499'. 390 gpm/625 psi, 30 rpms/6600ft-lbs, WOB 8-1 OK. Wipe through multiple times with and without pumps/rotary. No issues. Blow down top drive.;Continue to RIH with 5" DP from derrick from 2501' to 6505'. Wash down to 6627' and tag up. Clean and inspect boxes and pins.;Circulate hole clean 1.5x BU 415 gpm, 990 psi 20 rpms 19Kft-lbs reciprocating pipe. PUW 200k, SOW 78K.;Blow down top drive. Rig up to test casing.;Hauled 230 bible Fluid to MP G&I total = 7520 bbls Hauled 0 bbls to 1-B for injection total = 518 bbis Hauled 0 bbls to SP G&I for injection total = 114 bels Hauled 260 bbis H2O from L-Pad Lake total = 8525 bbls Lost 0 bbis to formation total fluid lost = 312 bels 2/17/2019 Pressure test 9-5/8" casing to 2500 psi for 30 minutes pumped 4.8 bbls with 4 bbls returned. Good test. R/D test equipment.;Drill out shoe track and 20' of new hole from 6631' to 6780', tag upon BA, FC, and shoe track on depth. Work through two times with no issues. 460gpm/1015psi, 40rpms/19Kft-lbs, WOB 10K.;Displace to 8.9 ppg Baradril-N drilling fluid; pump 40 bels high vis spacer followed Baradril-N. 460 gpm/920 psi. Circulate hole clean until even MW in and out.;POOH into shoe. Rig up and conduct FIT to 12.0 ppg EMW with 8.9 ppu muds Pumped 1.6 bels, bled back 1.4 bels. Rig down testing equipment. Blow down choke and kill Iines.;Rig up E-Line. RIH with Gyro on E-line to 5000', lost down weight. Continue pumping gyro down staging up to 10 bpm to 6714', on depth. POOH with gyro collecting surveys. R/D E-Iine.;Obtain SPR's. Pump dryjob. UD single and POOH to 593'. UD excess HWDP. UD BHA. Bit Grade 1- 1-WT-A-E-I-NO-BHA.;Clean and clear rig floor. Bring BHA components to rig floor.;Service blocks, crown, top drive, spinners and draw works.;PJSM. M/U RSS drilling BHA. M/U 8-112 PDC bit to Geo-pilot 7600 XL, ADR/HCIM collar, DGR collar, PWD, DM collar, TM collar,III sub to 86.76'. Plug in and upload MWD.;Hauled 814 bbis Fluid to MP G&I total = 8334 bbls Hauled 0 bels to 1-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bbls Hauled 390 labile H2O from L-Pad Lake total = 8915 bbis Lost 0 bbis to formation total fluid lost = 312 bbls 211812019 Continue to upload MWD tools. Continue to P/U BHA, (3) flex collars, Float sub, (1) HWDP, jars, (1) HWDP as per DD.;PJSM pick up drift and single in the hole with 5" drill pipe from 272'to 6756'. Inspect threads and ensure clear of shipping dope, spin up slow. PUW 170K, SOW 87K, calculated hole file.;Fill pipe and circulate string volume 235 gpm/450 psi.;Slip and out 84' of drill Iine.;Rig Service: Grease and inspect blocks, top drive, spinners and crown.;lnstall MPD bearing on bottom of stand and rack back.;Wash and ream from 6756' to 6790'. Drill 8.5" Production hole F/ 6790'to 6895' MD 105' Total (53' AROP), 550gpm/1,640psi, 120rpm/13.6Kft-lbs, WOB 8-14K, ECD 9.9 ppg with 8.9ppg mud. PUW 161 K, SOW 76K, ROTW 118K. Max Gas 115U. Appear to have crossed a fault before surface casing point at 6744';with a 31' DTW throw. Drop inclination to 85° to re-enter OA-1.;Drill 8.5" Production hole F/ 6895'to 7600' MD 705' Total (117.5' AROP), 550gpm/1,730psi, 160rpm/14.60-lbs, WOB 4-8K, ECD 10.29 ppg with 9.Oppg mud. PUW 140K, SOW 82K, ROTW 114K. Max Gas 1024U. Re- entered OA-1 sands at 7094'.;0 concretions in the mother bore for a total thickness of 0' (0% of the lateral). 72' Drilled so far in OA-1; 61' in OA-2; 236' in OA-3 Distance to well plan: 37.11' L;Hauled 57 bbls Fluid to MP G&I total = 8391 bbls Hauled 0 bbls to 1-B for injection total = 518 bbis Hauled 0 bels to BP G&I for injection total= 114 bels Hauled 130 bels H2O from L-Pad Lake total = 9045 bbis Lost 0 bbls to formation Total fluid lost= Obbls 2/192019 Drill 8.5" Production hole F/ 7,600'to 8,350' MD 4,421' TVD) 750' Total (125' AROP), 460 GPM, 1,360 PSI, 140 RPM, TRQ 12K, WOB 7K, ECD 10.10 ppg. P/U 141K, SLK 91K, ROT 114K. Max Gas 797U.;Drill 8.5" Production hole F/ 8,350'to 8,984' MD (4,405' TVD)634' Total (105.7' AROP), 500 GPM, 1,605 PSI, 140 RPM, TRQ 11.8K, WOB SK, ECD 10.3 ppg. P/U 144K, SLK 82K, ROT 113K. Max Gas 1,278U.;Pumped tandem 25 bbl 10.6 ppg, 280 Vis, 25 bbl 8.5 ppg, 42 Vis sweeps at 8,970' MD, returned 10 bbis late W/ 0% increase at Shakers. SPR at 8,420' MD ( 4,420' ND) MW 9.0 ppg MP #1 32-240, 48-300 MP #2 32-240, 48- 305.;Drill 8.5" Production hole F/ 8,984'to 9,434' MD (4,386' TVD) 450' Total (75' AROP), 535 GPM, 1,795 PSI, 140-160 RPM, TRQ 13.5K, WOB 8-15K, ECD 10.4 ppg. P/U 142K, SLK 81K, ROT 111K. Max Gas 674U.;SPR at 9,308' MD ( 4,391' TVD) MW 9.0 ppg MP #1 32-290,48350 MP #2 32-290, 48-350.;DHII 8.5" Production hole F/ 9,434' to 10,199' MD (4,393' ND) 765' Total (127.5' AROP), 530 GPM, 1,805 PSI, 160 RPM, TRQ 14-17K, WOB 3-6K, ECD 10.5 ppg. P/U 149K, SLK 75K, ROT 111 K. Max Gas 1,042U. Crossed fault at 10,060' MD with 15' throw to east going from OA-2 to OA-3.;SPR at 9,821' MD (4,38W TVD) MW 9.0 ppg MP #1 32-280, 48-335 MP #2 32-280, 48-340.;Two faults have been crossed. One at 6,744' and with a throw of 31' DTW, and one at 8,220' and with a throw of 25' DTE. 12 concretions have been drilled so far, for a total length of 123' (3.7% of the lateral). 1,058' Drilled so far in OA-1; 558' in OA-2; 1,278' in OA- 3, 80' in OA-4.;From 8,984'09,434MD, Got a maximum of 81.57' left of planned line. Distance to well plan (#12A): 6.24' L.;Hauled 577 bbis Fluid to MPG&I total = 8,968 bbls Hauled O bbis to 1-B for injection total=518bbis Hauled 0 bbis to BP G&I for injection total = 114 bbis Hauled 490 bbis H2O from L-Pad Lake total = 9,535 bbls Lost 0 bbls to formation Total fluid lost= 312 bbls 2202019 Drill 8.5" Production hole F/ 10,199'to 10,613' MO (4,385' TVD) 414' Total (69' AROP), 470 GPM, 1,500 PSI,140 RPM, TRQ 18-20K, WOB 5-7K, ECD 10.3 ppg. P/U 156K, SLK 70K, ROT 111 K. Max Gas 1,074u. Adjust parameters as needed to drill concretions. (Slower ROP) Increase MW to 9.2 to mitigate BGG.;SPR at 10,321' (4,390' TVD) MW 9.0 ppg MP #132-290, 48-355 MP #2 32-290, 48-355.;Drill 8.5" Production hole F/ 10,613'to 10,898' MD (4,382' TVD) 285' Total (47' AROP), 450 GPM, 1,455 PSI, 140 RPM, TRQ 18-20K, WOB 7-12K, ECD 10.5 ppg. P/U 159K, SLK 61 K, ROT 111 K. Max Gas 794u. Adjust parameters as needed to drill concretions. (See 15-20 ROP) Increase MW to 9.2 to mitigate BGG.;Slow ROP due to concretion F/ 10,545'to 10,716' MD. SPR at 10,989' (4,381' TVD) MW 9.15 ppg MP #132-295, 48-360 MP #2 32-295, 48-360.;Drill 8.5" Production hole F/ 10,898'to 10,960' MD (4,381' TVD) 62' Total (62' AROP), 490 GPM, 1,672 PSI, 140 RPM, TRQ 22K, WOB 7-12K, ECD 10.6 ppg. PN 164K, SLK 50K, ROT 111K. Max Gas 671U. Encountered fault at 10,911' MD (4,380' TVD);PJSM Pump out of hole F/ 10,960'to 10,832' MD. 490 GPM, 1,735 PSI, P/U 165K, SLK 50K. After discussion with Geologists decision was made to Cont. drilling ahead. RIH to 10 960' MD ;Dri118 5" Production hole F/ 10 960'to 11,27T MD (4,376 TVD1 317'Total (79 25' AROP) 490 GPM 1,84a PSI, 140 RPM, TRQ 21 K, WOB 7-12K, ECD 10.6 ppg. P/U 164K, SLK 41 K, ROT 107K. Max Gas 374U.;After encountering Fault#4 at 10,911' built to 96° Inc and drilled 366' for a total of 26' in TVD with no indication of OA Sand. Decision was made to POOH to 10,510' MD and perform open hole side track.;Rotate and reciprocate F/ 11,277to 11,212' MD CBU at 490 GPM, 1,760 PSI, 100 RPM,79Q 19-20K. Max Gas 182U, P/U 164K, SLK 45K, ROT 107K. ECD 10.9 ppg. Monitor well for 10 Min. Slight seepage Ioss.;PJSM. POOH on elevators F/ 11,277to 10,510' MD. Encountered tight spots at 11,026,10.850'& 10,725' pulled 20K over. No losses to formation. P/U 188K, SLK 68K.;Start side track operations at 10,510' MD. Hold 180° W/ 100% deflection 90.5° Inc. Trough 4X at 100 FPH F/ 10,510' to 10,530' MD. Dropped to 89.9° Inc. Slowed to 20 FPH to 10,537' Inc at 89.7' worked through new hole 2X without issue. 450 GPM, 1,410 PSI, 140 RPM, TRQ 18-21K.;Drill 8.5" Production hole F/ 10,537'to 10,643' MD (4,386' TVD) 106' Total (70.6' AROP), 510 GPM, 1,735 PSI, 140 RPM, TRQ 20K, WOB 3K, ECD 10.6 ppg. P/U 171K, SLK 45K, ROT 109K. Max Gas 386U.;SPR at 10,579' (4,387' TVD) MW 9.25 ppg MP #1 32-275, 48-340 MP #2 32-275, 48- 340.;4 faults have been crossed so far. One at 6,744' MD with a throw of 31' DTW, one at 8,220' MD with a throw of 25' DTE, one at 10,060' MD with a throw of 15' DTE, and one at 10,911' MO with a throw -30' DTW. 15 concretions have been drilled so far in the motherbore lateral, for a total length of 131';We have a PB1 from 10,510'to 11,277' and (767' long).;Hauled 403 bbis Fluid to MP G&I total = 9,371 bbls Hauled 0 bbls to 1-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bbls Hauled 650 bbls H2O from L -Pad Lake total= 10,185 bbls Lost 0 bbls to formation Total fluid lost = 312 bbls 2/21/2019 Drill 8.5" Production hole F/ 10,643'to 11,184' MD (4,384' TVD) 541' Total (90.1' AROP), 525 GPM, 1,860 PSI, 100 RPM, TRQ 21.51K, WOB IOK, ECD 10.8 ppg. P/U 179K, SLK 53K, ROT 111 K. Max Gas 873U.;SPR at 10,579' (4,387' TVD) MW 9.25 ppg MP #1 32-325, 48-390 MP #2 32-325, 48-390.;Drill 8.5" Production hole F/ 11,184'to 11,678' MD (4,377' TVD) 494' Total (82.3' AROP), 535 GPM, 2,015 PSI, 100-120 RPM, TRQ 23.8K -25K, WOB 8-10K, ECD 10.8 ppg. P/U 174K, SLK 38K, ROT 108K. Max Gas 664U.;Drill 8.5" Production hole F/ 11,678'to 12,108' MD (4,379' TVD) 430' Total (71.6' AROP), 545 GPM, 2,070 PSI, 100-120 RPM, TRQ 23-28K, TRQ OFF 26K, WOB 6-16K, ECD 11 ppg. P/U 186K, SLK 35K, ROT 109K. Max Gas 729U. Lost down weight at 11,853' MD. Increase MW to 9.3 ppg due to BGG.;Control drill F/ 12,080'to 12,220' MD at 60 FPH to clean up hole due to TRQ and ECD's. SPR at 11,915' (4,376 TVD) MW 9.25 ppg MP #1 32-340, 48-410 MP #2 32-340, 48-400.;Dril18.5" Production hole F/ 12,108' to 12,490' MD (4,393' TVD) 382' Total (63.6' AROP), 550 GPM, 2,215 PSI, 140 RPM, TRQ 24.5-28K, WOB 4-20K, ECD 11.1 ppg. P/U 185K, SLK 36K, ROT 108K. Max Gas 303U.;5 Faults have been crossed so far. One at 6,744' and w/ a throw of 31' DTW, one at 8,220' and with a throw of 25' DTE, one at 10,060' and with a throw of 15' DTE, one at 10,930' and with a throw -22' DTW, and one at 12,055' with a throw of i V DTE. 32 concretions have been drilled so far in the mother.;Footage 1,938' in CA. 1, 883' in OA -2, 2,405' in OA -3, 80' in OA - 4. Total footage in OA Sands 5,306', out of zone 334'. Distance to well plan (#12A): 11.09' R.;Hauled 635 bbls Fluid to MP G&I total= 10,006 bbls Hauled 0 bbls to 1-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bbls Hauled 520 bbls H2O from L -Pad Lake total = 10,705 bbls Lost 0 bbls to formation Total fluid lost = 312 bbls 222/2019 Drill 8.5" Production hole F/ 12,490'to 12,903' MD (4,400' TVD) 413' Total (69' AROP), 550 GPM, 2,270 PSI, 120 RPM, TRQ 26K, WOB 5-8K, ECD 11.1 ppg. P/U 180K, SLK 36K, ROT 108K. Max Gas 303U.;Drill 8.5" Production hole F/ 12,903'to 13,305' MD (4,395' TVD) 402' Total (67' AROP), 550 GPM, 2,260 PSI, 120 RPM, TRQ 24K, WOB 7-10K, ECD 11.1 ppg. P/U 160K, SLK 35K, ROT 108K. Max Gas 650U. F/ 12,928'to 12,935 TRQ increased to 29K, WOB SK.;Add 1 Drum of NXS Lube to to Sweep. Send Sweep and note Tq Dn F26K to 20K when sweep to surface on time with 50% increase at Shakers. SPR at 13,000' MD (4,395' TVD) W/ 9.3 ppg MW MP #1 32-360,48-440 MP #2 32-360, 48-445.;Drill 8.5" Production hole F/ 13,305'to 13„856' MD (4,397' TVD) 551' Total (91.8' AROP), 550 GPM, 2,440 PSI, 120-140 RPM, TRQ 22-25K, WOB 7-10K, ECD 11.3 ppg. P/U 163K, SLK 35K, ROT 106K. Max Gas 1,084U. Started increasing MW F/ 9.3 to 9.4 ppg.;SPR at 13,505' MD (4,390' TVD) W/ 9.3 ppg MW MP #1 32-375, 48-445 MP #2 32-370, 48-450.;Drill 8.5” Production hole F/ 13,856' to 14,277' MD (4,443' TVD) 421' Total (70.2' AROP), 550 GPM, 2,530 PSI, 140 RPM, TRQ 22-25K, WOB 7-18K, ECD 11.5 ppg. P/U 165K, SLK 35K, ROT 106K. Max Gas 8280. Crossed fault #6 at 13,924' MD, drop 80° Inc W/ 4' drop rate to getto OA Sands.;Entered OA -1 Sand at 14,169' MD. Probable fault at 14,218' MD possibly above OA Sand. Maintain 78° Inc. Control drill at 14,140' at 60 FPH to control ECD's at 11.6 ppg. Pumped tandem Hi/Vis, LowNis sweep at 14,210' MD back on time, W/ 40% increase.;6 faults crossed so far. One at 6,744' MD with a throw of 31' DTW, 8,220' MD with a throw of 25' DTE, 10,060' MD with a throw of 15' DTE, 10,930' MD with a throw -22' DTW, 12,055' MD with a throw of 1 VOTE, 13,924' MD with a throw of ^20' DTW.;42 concretions drilled in the mother bore lateral, for a total length of 302' (4.0% of the lateral). Distance to well plan (#12A): 18.14', 18.02' high, 2.07 L.;Hauled 446 bbls Fluid to MP G&I total= 10,452 bbls Hauled 0 bbls to 1-13 for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bbls Hauled 650 bbls H2O from L -Pad Lake total = 11,355 bbls Lost 0 bbls to formation Total fluid lost = 312 bbls r�� 2/23/2019 Drill 8.5" Production hole F/ 14,277'to 14,605' MD (4,504' TVD) 328' Total (109.3' AROP), 550 GPM, 2,590 PSI, 140 RPM, TRO 25.8K, TRQF 20K, WOB 5K, ECD 11.5 ppg. P/U 175K, SLK 35K, ROT 107K. Max Gas 787U. Distance to Plan (#12A): 91.62', 91.60' High, 1.95' Right.;SPR at 14,605' MD (4,504' TVD) MW 9.4 ppg MP #1 32-355, 48-435. MP #2 32-350, 48-438.;BROOH F/ 14,605 to 13,952' MD 550 GPM, 2,508 PSI Observed slight over pull at 14,517' MD, work through clean.;CBU for 1 stand F/ 13,952'to 13,888' MD 550 GPM, 2,470 PSI, 140 RPM, TRQ 20.2K, ECD 11.45 ppg, ROT 106K, Max Gas 141 U.;Circ. and reciprocate F/ 13,888' to 13,816' MD 550 GPM, 2,480 PSI, 160 RPM, TRQ 20-21 K, ECD 11.1 ppg, P/U 167K, SLK 35K, ROT 106K.;RIH 1 stand. Circ. and reciprocate F/ 13,952' to 13,888' MD. 550 GPM, 2,520 PSI, 50 to 30 RPM, TRQ 15-16K, ECD 11.1 ppg, P/U 167K, SLK 35K, ROT 105K. Reduced RPM F/ 50 to 30 RPM, Circ. surface and hole volume screening Shakers up F/ 200's to 270's.;Circ. another surface and hole volume W/ 270's on Shakers. 550 GPM, 2,375 PSI, 20 RPM, TRQ 14-15K, ECD 10.9 ppg, Max Gas 20U, P/U 150K, SLK 65K, ROT 106K.;Perform PST W/ 250 Micron and 350 ML 9.4 ppg Mud, at 7,000 strokes into second cleanup cycle from under shakers. i at 7.03 sec, 2nd 9.4 sec, 3rd 7.55 sec. Avr 7.99 sec. Pass At 20,000 strokes into second cleanup cycle from under shakers. 1 st 7.13 sec, 2nd 9.17 sec, 3rd 8.2 sec. Avr 7.50 sec. Pass.;From flow line at 25,000 strokes into second cleanup cycle from under shakers. 1 st 6.75 sec, 2nd 7.3 sec, 3rd 6.7 sec. Avr 6.92 sec. Pass.;PJSM Monitor well for 10 Min, static. BROOH F/ 13,952' to 12,808' MD 550 GPM, 2,290 PSI, 150 RPM, TRQ 16-17K, ECD 10.9 ppg, Max Gas 171 U. P/U 159K, SLK 54K, ROT 107K. Pulling 500 FPH (8.3 fpm).;SPR at 13,950' MD (4,397' TVD) MW 9.4 ppg MP #1 32-300, 48-380 MP #2 32-295, 48-375.;BROOH F/ 12,808' to 11,279' MD 550 GPM, 1,975 PSI, 150 RPM, TRQ 14-15K, ECD 10.7 ppg, Max Gas 25U. P/U 177K, SLK 75K, ROT 107K. Pulling 500 FPH (8.3 fpm) Calc Displacement 11.1 bbls, actual 28 bbls, total 16.9 bbls. Dynamic loss rate about 3 bph.;7 faults. at 6,744' MD throw 31' DTW, 8,220' MD throw 25' DTE, 10,060' MD throw 15' DTE, 10,930' MD throw 22' DTW, 12,055'throw 11' DTE, 13,924' MD throw 20' DTW, 14,218' MD throw 32' DTW.;42 concretions were in the motherbore lateral, for a total length of 302' (3.8% of the lateral). Total footage OA-1 2,621', OA-2 1,281', OA-3 3,092', OA4 86'. Cumulative in OA Sand 7,080'.;Hauled 289 bbls Fluid to MP G&I total = 10,741 bbls Hauled 0 bbls to 1-B for injection total = 518 bbls Hauled 0 bbls to SP G&I for injection total = 114 bbls Hauled 520 bbls H2O from L-Pad Lake total= 11,875 bbls Lost 0 bbls to formation Total fluid lost= 312 bbls U Well Name: MP E-36 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): API #: Hilcorp Energy Company Composite Report Spud Date: 2/6/2019 Job Name: 1813045C MPE-36 Completion Contractor Innovation AFE #: AFE $: Activity Date Ops Summary 2,'24/2019 BROOH F/ 11,279' to 8,668' MD 550 GPM, 1,855 PSI, 150 RPM, TRO 9-10K, ECD 10.3 ppg, Max Gas 18U. P/U 144K, SLK 85K, ROT 108K. Pulling 2,200 FPH (36.6 fpm). Calc Displacement 19.5 bbls, actual 48.5 bbls, total lost 29 bbls. Dynamic loss rate about 4 bph.,BROOH F/ 8,668' to 6,704' MD 550 GPM, 1,700 PSI, 150 RPM, TRQ 6.3K, ECD 10.2 ppg, Max Gas 18U. P/U 144K, SLK 104K, ROT 114K. Pulling 2,200 FPH (36.6 fpm) Calc Displacement 11.2 bbls, actual 18.5 bbls, total lost 7.3 bbis. Dynamic loss rete about 1 bph. At 7,135' MD 15K TRQ encountered and shakers loading up, slowed pulling speed and parameters as needed. Pulled thru Shoe with out issue.,Circ. and reciprocate F/ 6,686' to 6,624' MD First Surf to Surf pumping at reduced rate 350 GPM due to Shakers blinding off. Staged pumps up to 550 GPM, 1,650 PSI, 50 RPM, TRQ 5.21K. Pumped 200 Vis 30 bbl Hi Vis Sweep, returned on time W/ 100% increase at Shakers -Perform PST W/ 250 Micron and 350 ML 9.4 ppg Mud, at 12,000 strokes into first cleanup cycle from under shakers. 1st 6.25 sec, 2nd 8.03 sec, 3rd 7.34 sec. Avr 7.21 sec. Pass At 5,000 strokes into second cleanup cycle from under shakers. 1st 7.0 sec, 2nd 6.97 sec, 3rd 8.0 sec. Avr 7.32 sec. Pass From flow line at 9,000 strokes into second cleanup cycle from under shakers. 1s16.09 sec, 2nd 7.65 sec, 3rd 7.18 sec. Avr 6.97.,PJSM for RID MPD Bearing. Monitor well, static. Break down MPD Bearing and UD Bearing and 5" D.P. as per Beyond Rep onsite.,Service rig, grease crown, Blocks, Top Drive and Swivel Packing. Check oil in Top Drive.,PJSM for UD D.P. Pump Dry Job. Blow down Top Drive and Geo Skid. Tie off stripping rubber in Stack., POOH on elevators UD 5" D.P. to Pipe Shed F/ 6,704' to 272' MD. PIU 56K, SLK 54K. Calc Displacement 56.5 bbls, actual 68.6 bbis, total lost 12.1 bbis-Hauled 231 blots Fluid to MP G&I total = 10,872 bbls Hauled 0 bbls to i -B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bbis Hauled 390 bbis H2O from L -Pad Lake total = 12,265 bbis Lost 73 bbis to formation, Total Production hole 73 bbis 2125/2019 PJSM UD 5" HWDP, Jars, Flex Collar, Corrosion Ring, Download Sperry Tools. UD Float Collar TM, DM MWD, Geo Pilot and 8.5" Bit. Bit Grade: 1 -1 -CT -N -X- I -WT -TD -Clean and clear rig floor of BHA #3 components. SIMOPS install rebuilt Bleeder.,PJSM M/U Johnny Whacker to 5" 50#, 5-135 HWDP M/U TRQ 34.5K. Single in hole from Skate to 2,612' MD. (Drift 2.668") Break in all new HAK HWDP, M/U and B/O 2X. Cleaning threads and applying new dope. P/U 129K, SLK 120K. Calc. Disp. 47 bbls, actual 37 bbis. Lost 10 bbls. Static lass -1 bph.,Clear rig floor, prep for RIH F/ Derrick. Static loss rate 1.4 bph.,PJSM RIH on elevators 5" D.P. F/ 2,612' to 6,744' MD. P/U 168K, SLK 125K. Calc. Disp. 36 bbis, actual 39 bbis. Lost 3 bbis. Static loss -1 bph.,PJSM Prep floor for UD 5" D.P. Pump 20 bbl 10.9 ppg Dry Job. POOH L/D 5" D.P. to Pipe Shed F/ 6,744'to 6,119' MD. Calc. Disp. 5.5 bbls, actual 8.8 bbls. Lost 3.3 bbls. Static loss -1.5 bph.,PJSM Cont. POOH UD 5" D.P. to Pipe Shed F/ 6,119'to 2,612' MD. Calc. Disp. 33.3 bbis, actual 41.7 bbls. Lost 8.4 bbis. Static loss 2 bph. P/U 140K, SLK 85K.,PJSM Rack back 5" HWDP in Derrick F/ 2,612' to surface. Calc. Disp. 47.54 bbls, actual 54.9 bbls. Lost 7.36 bbls. Static loss 2.4 bph.,Hauled 58 bbis Fluid to MP G&I total= 11,030 bbis Hauled 0 bbis to 1-B for injection total = 518 bbls Hauled 0 bbls to BP G&I for injection total = 114 bbis Hauled 230 bbis H2O from L -Pad Lake total = 12,495 bbls Lost 18 bbls to formation Total Production hole 91 bbis 2/26/2019 Bring tools to rig floor. M/U safety joint and stage in shed. C/O 4-112 IF Saver sub.,PJSM R/U Weatherford casing equipment for 4.5" pipe. PJSM, Run 4.5", 13.5#, 625 WEDGE L-80 from surface to 3,500' as per detail. P/U 71 K, SLK 63K. Calc. Disp 16.2 bbls actual 11.4 bbis, loss rate -1 bph. Reduce speed to 120 FPM due to pushing fluid away.,Cont. RIH 4.5" Liner as per tally F/ 3,500' to 7,285' MD. WU TRQ 9,600K. PIU 98K, SLK, 72K. Calc. Disp 17.6 bbls actual 16.2 bbls, loss rate .6 bph. Reduce speed to 135 FPM due to pushing fluid away. At shoe 6,760' MD P/U 95K, SLK 74K.,PJSM Install FOSV. Monitor well, -1 BPH. Clear Rig floor of all 4.5" Equip. R/U BOT False Bowl and install all 2.375" handling Equip.,PJSM P/U M/U Slick Stick to 2.375" 5.95#, P-110 Inner String to 80' MD. M/U TRQ 3,000K.,PJSM RIH 2.375" 5.95#, P-110 Inner String to F/ 80' to 4,135' MD. M/U TRQ 3,000K. PIU 52K, SLK 47K. Calc Disp 7.0 bbis, actual 5.5 bbls. Lost 1.5 bbls., Hauled 0 bbls Fluid to MP G&I total= 11,030 bbls Hauled 0 bbls to i -B for injection total = 518 bbls Hauled 0 bbis to BP G&I for injection total= 114 bbis Hauled 230 bbis H2O from L -Pad Lake total = 12,725 bbis Lost 28 bbls to formation Total Production hole 119 bbis 2/27/2019 Continue RIH w/ 2-3/8", 5.95# PH-6 inner string F/ 4,135'- T/ 7,268' MD (232 jts + 14.9'). Set do 2x w/ 5k @ 7,268' MD. 62k up, 51 k dn. 1.5 bbl loss for trip. UD jt #233. M/U swivel and pup jt (8.66' total length/ 6.24' off No Go).,C/O elevators, M/U hanger to inner string. M/U complete assy to 4.5" liner. P/U 125k, 94k w/ both strings. R/D false table and inner string handling equipment. R/D Weatherford power tongs and stage on Floor. Mix and install Pal Mix. M/U std of 5" and RIH T/ 7,356' MD.,PJSM Clear rig floor of Weatherford & Baker tools and Equip. R/U Tongs.,PJSM, Obtain parameters 1 BPM, 430 PSI, 2 BPM, 925 PSI, 2.25 BPM 1,195 PSI, RPM 10& 20 TRO 7.3K, P/U 122K, SLK 91 K, ROT 106K. RIH 5" D.P. F/ 7,356to 9,360' MD, 5" HWDP F/ 9,360' to 10,479" MD, Running max 60 FPM. Fill every 10 stands. Rabbit F/ Derrick 2.34". P/U 158K, SLK 107K. Work tight area at 7,518' to 7,528' MD. set down 5K, work up to 10K down pulling 15K over., Kelly up and wash through at 2 BPM, 925 PSI.,Cont. RIH 5" HWDP F/ 10,479' to 11,972' MO. Cont RIH W/ 5" DP F/ 11,972' to 13,435' MD. Max run speed 60 FPM. Fill every 10 stands, rabbit F/ Derrick 2.34". P/U 196K, SLK 102K. Working 4.5" Liner down at 13,435' to 13,672' MD 2 BPM, 1,200 PSI. Wash and ream F/ 13,672'to 13,681' MD. Rotate at 10 RPM, TRO Limit set @ 10K, 2 BPM, 1,200 PSI. Cont. wash down and work liner F1 13,681' to 13,879' MD 2 BPM, 1,200 PSI.,Calc Disp 163 bbls, actual 126 bbis. Lost 37 bbls.,P/U a single 5" D.P. wash down F/ 13,879' to 13,910' MD then pull up to 13,900' MD to put liner intension. 2 bpm, 1,200 PSI. TOL at 6,760' MD. P/U 192K, SLK 78K.,Cont. Circ. at 2 BPM, 1,200 PSI staging up to 2.3 BPM, 1,400 PSI. Circ, open hole volume. SIMOPS Off load excess mud from Pits for displacement. Dynamic loss rate 2 BPH. PJSM with all parties. Start pumping HiVis Sweep 250 Vis, 38 BBIS. Chase W/ 9.4 3%/ NaCl ppg Brine, 382 bbis away. Lost 6 bbls.,Hauled 58 bbis Fluid to MP G&I total = 11,088 bbis Hauled 0 bbis to i-B for injection total = 518 bbis Hauled 0 bbis to BP G&I for injection total= 114 bbis Hauled 230 bbis H2O from L-Pad Lake total = 12,725 bbls Lost 43 bbis to formation, Total Production hole 162 bbis 2/28/2019 Continue displacing well w/ 9.4 ppg 3% NaCl. 2.3 bpm, 1395 psi, 21 % F/O. 540 bbis brine, 3x 40 bbl sapp pills w/ 50 bbis spacer between. Follow w/ clean 9.4 brine taking returns to cutting box. Circulate close loop once brine cleaned up at shakers and continue circulating chem train out of hole.,PJSM Cont. displacing SAPP Pills to cutting box W/ 9.4 ppg 3% KCL/NaCl Brine at 2.3 BPM, 1,275 PSI. Total bbis pumped 1,023 bbls.,Drop 1.25" Phenolic Ball as per BOT Rep. Chase down string at 2 BPM, 875 PSI. Ball seated 1,495 Stks. Press. up W/ Mud Pump, SLZXP set at 2,600 PSI. Cont to Press. up to 3,000 PSI. SLK off to 80K (set do 20k). psi up test pump to 4,100 PSI. Release from HRD, neutralize Pusher Tool. P/U to string weight 192K. R/U and PT annulus 9 5/8" X 5" to 1,500 PSI for 10 Min. Good test. All operations charted. 3 bbl pump,3 back.,TOL at 6,586' MD.,Pressure up string to 200 PSI, PIU 8' to 13,834' MD and disengage Pack Off. Pressdropped to 60 PSI Cont Circ 2X annulus volume 2 3/8" X 4.5" at 3 BPM, 1,865 PSI.,PJSM Blow down Top Drive. POOH on elevators 5" D.P. F/ 13,834' to 12,700' MD. P/U 188K. Calc Disp 8.3 bbls, actual 12.8 bbis. Lost 4.5 bbls.,PJSM Cut and slip drilling line. Cut 88' of drilling line. Calibrate Blocks. Monitor well on Trip Tank static loss 2.6 BPH.,PJSM POOH on elevators 5" D.P. and 5" HWDP F/ 12,700' to 8,306' MD. P/U 86K. Calc Disp 69.9 bbls, actual 88.5 bbis. Lost 18.6 bbls. Static loss rate 5.3 BPH.,PJSM POOH on elevators 5" D.P. and 5" HWDP F/ 8,306' to 7247' MD. P/U 68K, SLK 48K. Calc Disp 13.9 bbls, actual 23.2 bbls. Lost 9.3 bbls.,UD BOT running tool and inspect as per BOT Rep onsite. Monitor well, 4 BPH loss rate.,PJSM W/ Weatherford. R/U Weatherford Tongs, Elevators and Equip. Begin UD 2 3/8" inner string to Pipe Shed F/ 7,247' to 4,725' MD.. Calc Disp 13.5 bbis, actual 26.5 bbis. Lost 13 bbis. Static loss 4 BPH.,Hauled 2,456 bbis Fluid to MP G&I total = 13,544 bbls Hauled 0 bbis to 1-B for injection total = 518 bbis Hauled 0 bbis to BP G&I for injection total = 114 bbis Hauled 100 bbls H2O from L-Pad Lake total = 12,825 bbis Lost 46 bbis to formation, Total Production hole: 208 bbis 3/1/2019 Continue POOH laying down 2-3/8" WTS inner string F/ 4 725' - T/ surface. 26 bbl loss for total trip out. Static loss rate after trip @ 2.5 bph +/-, B/O and UD slick stick wl xo.,R/D Weatherford double stack power tongs. Clean and clear rig floor. C/O handling equipment. B/O and UD safety joint. Drain stack and M/U wear bushing puller.,PJSM Pull Wear Ring. P/U 5" Test Jnt, M/U TIW, Dart, Side entry Sub and test Plug. Perform shell test to 3,000 PSI. Mezz Kill leaked, worked valve without success. Isolate Mezz Kill, good test. Remove Mezz Kill for rebuild. Cont. ROPE Testing.,PJSM. Test 250 PSI low and 3,000 PSI high for 5 Min ea, charted. Test W/ 5" & 3.5" Test Jnt. Test Annular, Upper and Lower Rams, Choke Manifold, Choke Kill and HCR, Upper and Lower IBOP, 5" TIW, Dart, Super and Manual Choke, Mezz Kill after replacing bad O Ring. Test Gas and PVT alarms.,Perform Koomey draw down, Initial Accum Press 1,500 PSI, Manifold 1,350 PSI, Annular 1,300 PSI, after function Accum 3,000 PSI, Manifold 1,500 PSI, Annular 1,300 PSI. 200 Press increase 23 Sec, full charge 90 Sec. 6 bottle Nitrogen Avg 2,366 PSI. Witnessed by AOGCC Rep Austin Mcleod., PJSM Break down Test Jnt, set Wear Ring ID 9" and blow down Choke Manifold., PJSM Grease Wash Pipe, Spinners, Blocks, Crown and elevators., PJSM Install 5" Elevators. P/U M/U Wash Tool and NoGo. RIH W/ 5" D.P. and 5" HWDP to 3,803' MD. Fill string at 2,000' MD. Calc Disp 47 bbls, actual 41 bbls. Lost 6 bbls.,Cont. RIH W/ 5" D.P. and 5" HWDP 3,803? to 6,583' MD. Fill string every 2,000' MD. P/U a stand 5" D.P. and wash down at 2 BPM, 53 PSI to TOL. Press. increased to 80 PSI and set down 6K, (TOL 6,589 MD) as per BOT Rep onsite. P/U 200K, SLK 130K. Calc Disp 33 bbis, actual 27 bbis. Lost 6 bbls.,lncrease to 9 BPM, 725 PSI pulling up to 6,578' MD washing out liner lap. Rack back one stand. Circ. at 10.5 bpm, 995 PSI for 2X BU. F/ 6,300 to 8,267 strokes had to slow pump rate down to 8 BPM due screens blinding off, increased rate back to 10.5 BPM, 840 PSI. Shakers cleaned up at 9,798 total stroke. Lost 4 bbls.,PJSM for laying down D.P. Pump 25 bbl 9.7 PPG Dry Job. Blow down Top Drive. Monitor well, static loss about -1 BPH.,POOH UD 5" D.P. and 5" HWDP to Pipe Shed F/ 6,578' to 4,647' MD. Calc Disp 11.2 bbis, actual 15.1 bbls. Lost 4 bbls.,Hauled 142 bbis Fluid to MP G&I total = 13,453 bbis Hauled 0 bbis to 1-B for injection total = 518 bbls Hauled 0 bbis to BP G&I for injection total = 114 bbis Hauled 200 bbis H2O from L-Pad Lake total = 13,025 bbis Lost 51 bbis to formation, Total Production hole: 259 bbis 3/2/2019 Continue POOH laying down 5" dp F/ 4647'- T/ surface. 4 bbl loss. B/O and UD 3.5" wash tool.,Pull wear bushing. R/U Weatherford casing crew. Load remaining 24 jts into shed and prep to run.,PJSM, Run 3.5" 8rd EUE L-80 upper completion as per detail F/ surface - T/ 6,589' MD. M/U TRO 3,200#. Tag L TOL and UD 3 Jnts. P/U M/U 2 ea 8' Pups and i ea 3.5" Tubing (Jnt 217) P/U M/U Hanger to 3.5" Tubing. Land Hanger and verified by NOS Rep. P/U 2' and unseat Hanger. Kelly up and R/U to reverse Circ. P/U 70K, SLK 59K. Calc Dis 22.4 bbis, pushed away 27 bbls for the trip.,PJSM for pumping inhibitor and Freeze Protect. Pump down Kill Line and remove air. Shut Bag and Press. up IA to 400 PSI for 5 Min. Strip out of hole W/ 125K P/U WT and observe Press. drop at 10". SLK off 1' to ensure Mule Shoe is engaged. Break Circ. at 3 BPM, 171 PSI pumping 230 bbis 9.4 ppg Inhibited Brine, 10 bbis 9.4 ppg Brine, Pump 195 bbis Diesel at 3 BPM ICP 171 PSI, FCP 540 PSI. Lost 14 bbls.,Stdp down 5'covering 1" ports. Bleed off 380 PSI and open Bag. Slack off and landed Hanger. RILDS. R/U to test IA. Blow down Top Drive and Equip. Discuss with town about reducing test Press from 3,000 PSI to 2,500 PSI due to loading Liner Hanger to upper limits. Start test no IA to 2.500 PSI for 30 Min-Haulad 372 bbis Fluid to MP G&I total = 13,825 bbis Hauled 0 bbis to 1-B for injection total = 518 bbis 1 Hauled 0 bbis to BP G&I for injection total = 114 bbis l Hauled 0 bbis H2O from L-Pad Lake total = 13,025 bbis Lost 72 bbis to formation, Total Production hole: 331 bbls forward onto AOGCC. Post BOP test report submitted to AOGCC (3/1/19 test date).,PJSM UD 35' Landing Joint. Drain stack. P/U Tee Bar and set BPV. RID 3.5" handling Equip.,PJSM Remove Mouse Hole, Riser, Rig Pan, disconnect RCD, and Choke bolts. SIMOPS Clean Pits, check tires, repair Skate and pre for Rig Move.,PJSM Switch to Gen Power at 12:00. Remove Choke and Kill lines oft Stack. Set BOP on pedestal. Lower RCD. Remove spacer spool and DSA. N/U Tree. SIMOPS Cont. cleaning Pits, R/D MP, Prep for scoping down Derrick.,PJSM Test Hanger void to 500 PSI for 5 min and 5,000 PSI high for 15 Min. Re torque bolts due leak. Retest, good. SIMOPS Get Bridal lines to Rig Floor. Cont. working on MP inspection and cleaning Pits.,PJSM Pull BPV and install TWC. Test Tree to 500 PSI low for 5 MIN and 5,000 PSI high for 15 Min. Pull TWC and install BPV. R/U LRS and pump 26 bbis Diesel at 1 BPM, ICP 0, FCP 300 PSI. SIMOPS Bridal up and scope down Derrick. Blow down H2O and start disconnecting interconnects. Peak on location @ 19:30 hrs.,PJSM Blow down Steam, split interconnects, Move Pipe Shed, Motor Mod and trouble shot Mud Mod HPU. Note: Rig released at 00:00 hrs.,Last report for MPU E-36. Next well report MPU E-15.,Hauled 781 bbls Fluid to MP G81 total = 14,606 bbis Hauled 0 bbis to 1-B for injection total = 518 bbis Hauled 0 bbis to BP G81 for injection total = 114 bbis Hauled 0 bbis H2O from L-Pad Lake total = 13,025 bbis Lost 14 bbis to formation, Total Production hole: 345 bbis Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-36 MPU E-36 Sperry Drilling Definitive Survey Report 25 February, 2019 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US + CANADA 'roject Milne Point, ACT, MILNE POINT Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU E-36 Depth From (TVD) +NIS (usft) (usft) Well Position +N/S 0.00 usft Northing: 6,016,156.74 usft Latitude: 70.454 Inc +E/ -W 0.00 usft Easting: 569,407.52 ush Longitude: -149.434 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 21.70 usft Wellbore MPU E-36 (usft) (usft) (usft) (usft) Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0.00 26.65 -21.70 V) (1) (nT) 569,407.52 BGGM2018 2/21/2019 16.83 80.97 57,438.34164110 Design MPU E-36 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +NIS (usft) (usft) 26.65 0.00 Tie On Depth: 10,509.90 +FJ -W Direction (usft) (') 0.00 295.12 Survey Program Date 2/23/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 86.43 6,678.86 E-36PB1 SDI Survey - surface section- (2_Gyro-NS-CT_Drill pipe H037Ga: Continuous on wireline in drill pipe 02/18/2019 6,769.02 10,509.90 MPU E-36PB1 MWD IFR2 Tied into Corr 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 02/07/2019 10,573.00 14,533.92 MPU E-36 MWD+IFR2+MS+Sag (3) (MF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 02/21/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (') (') (usft) (usft) (usft) (usft) (ft) (ft) (`/1001 (ft) Survey Tool Name 26.65 0.00 0.00 26.65 -21.70 0.00 0.00 6,016,156.74 569,407.52 0.00 0.00 UNDEFINED 86.43 0.67 66.64 86.43 38.08 0.14 0.32 6,016,156.88 569,407.84 1.12 -0.23 2_Gyro-NS-CT_Dnllpipe(1) 90.00 0.46 82.15 90.00 41.65 0.15 0.35 6,016,156.89 569,407.87 7.23 -0.26 2_Gyro-NS-CT_Drill pipe (1) 115.00 0.21 112.18 115.00 66.65 0.15 0.50 6,016,156.89 569,408.01 1.19 -0.39 2_Gym-NS-CT_Drillpipe(1) 140.00 0.17 173.63 140.00 91.65 0.09 0.54 6,016,156.84 569,408.06 0.79 -0.45 2_Gyro-NSCT_Drill pipe (1) 165.00 0.17 143.36 165.00 116.65 0.02 0.57 6,016,156.77 569,408.09 0.36 -0.50 2_Gyro-NS-CT_Drill pipe (1) 190.00 0.16 128.32 190.00 141.65 -0.03 0.62 6,016,156.72 569,408.14 0.18 -0.57 2 Gyro-NS-CT_Drill pipe (1) 215.00 0.27 109.93 215.00 166.65 -0.07 0.70 6,016,156.68 569,408.22 0.51 -0.66 2_Gyro-NS-CT_Dnp pipe (1) 240.00 0.31 87.47 240.00 191.65 -0.09 0.82 6,016,156.66 569,408.34 0.48 -0.78 2_Gyro-NS-CT_Drill pipe (1) 265.00 0.49 79.76 265.00 216.65 -0.06 1.00 6,016,156.69 569,408.52 0.75 -0.93 2_Gyro-NS-CT_D611 pipe (1) 290.00 1.05 71.59 289.99 241.64 0.03 1.32 6,016,156.78 569,408.84 2.28 -1.18 2_Gym-NS-CT_Drill pipe (1) 315.00 1.48 67.92 314.99 266.64 0.22 1.84 6,016,156.98 569,409.35 1.75 -1.57 2_Gyro-NS-CT_Drill pipe (1) 2252019 5:36.*05PM Page 2 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Rig: MPU E-36 Wellbore: MPU E-36 Design: MPU E-36 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: Well MPU E-36 TVD Reference: MPU E-36 Actual RKB @ 48.35usft MD Reference: MPU E-36 Actual RKB @ 48.35usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Map Vertical Easting DLS Section (ft) Map MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing (usft) (°) V) (usft) (usft) (usft) (usft) (ft) 340.00 1.68 58.19 339.98 291.63 0.54 2.45 6,016,157.30 365.00 2.36 58.12 364.96 316.61 1.00 3.20 6,016,157.77 390.00 3.22 56.73 389.93 341.58 1.66 4.22 6,016,158.44 415.00 4.04 52.18 414.88 366.53 2.58 5.50 6,016,159.37 440.00 4.75 49.83 439.81 391.46 3.79 6.99 6,016,160.60 465.00 5.40 46.99 464.71 416.36 5.26 8.64 6,016,162.08 490.00 5.95 44.37 489.59 441.24 6.99 10.41 6,016,163.83 515.00 6.63 42.52 514.44 466.09 8.98 12.29 6,016,165.83 540.00 7.52 40.72 539.25 490.90 11.28 14.33 6,016,168.16 565.00 8.52 38.64 564.00 515.65 13.97 16.55 6,016,170.86 590.00 9.54 37.81 588.69 540.34 17.05 18.98 6,016,173.97 615.00 10.47 36.66 613.31 564.96 20.51 21.61 6,016,177.45 640.00 11.67 36.10 637.85 589.50 24.38 24.45 6,016,181.34 665.00 13.16 35.97 662.26 613.91 28.72 27.61 6,016,185.72 690.00 14.70 35.49 686.53 638.18 33.61 31.13 6,016,190.64 715.00 15.72 35.24 710.65 662.30 38.96 34.92 6,016,196.02 740.00 16.83 34.96 734.65 686.30 44.69 38.95 6,016,201.79 765.00 17.88 34.91 758.51 710.16 50.80 43.22 6,016,207.94 790.00 19.43 34.84 782.19 733.84 57.37 47.79 6,016,214.54 815.00 21.67 35.21 805.60 757.25 64.55 52.83 6,016,221.77 840.00 23.14 35.73 828.71 780.36 72.31 58.36 6,016,229.58 865.00 24.40 36.20 851.59 803.24 80.46 64.28 6,016,237.79 890.00 25.75 36.74 874.24 825.89 88.98 70.58 6,016,246.37 915.00 27.25 37.01 896.61 848.26 97.91 77.27 6,016,255.35 940.00 29.00 37.39 918.66 870.31 107.29 84.40 6,016,264.80 965.00 29.56 36.38 940.46 892.11 117.07 91.74 6,016,274.65 990.00 29.75 36.05 962.19 913.84 127.05 99.04 6,016,284.70 1,015.00 30.26 35.40 983.84 935.49 137.20 106.34 6,016,294.91 1,040.00 30.56 34.55 1,005.40 957.05 147.57 113.60 6,016,305.35 1,065.00 30.74 33.63 1,026.91 978.56 158.13 120.74 6,016,315.97 1,090.00 30.78 32.30 1,048.39 1,000.04 168.85 127.70 6,016,326.76 1,115.00 31.02 31.62 1,069.84 1,021.49 179.74 134.49 6,016,337.71 1,140.00 31.23 30.87 1,091.24 1,042.89 190.79 141.19 6,016,348.82 1,165.00 31.49 29.99 1,112.59 1,064.24 202.01 147.78 6,016,360.10 1,190.00 31.69 28.32 1,133.89 1,085.54 213.45 154.16 6,016,371.59 1,215.00 31.84 26.73 1,155.14 1,106.79 225.12 160.24 6,016,383.32 1,240.00 31.86 25.31 1,176.38 1,128.03 236.97 166.03 6,016,395.23 1,265.00 32.02 23.95 1,197.59 1,149.24 248.99 171.54 6,016,407.30 1,290.00 32.12 22.68 1,218.78 1,170.43 261.18 176.80 6,016,419.53 1,315.00 32.37 22.05 1,239.92 1,191.57 273.52 181.87 6,016,431.91 Map Vertical Easting DLS Section (ft) (°1100') (ft) Survey Tool Name 569,409.96 1.34 -1.99 2_Gyro-NS-CT_D611 pipe (1) 569,410.71 2.72 -2.47 2_Gyro-NS-CT_Drill pipe (1) 569,411.72 3.45 -3.12 2_Gyro-NS-CT_Drill pipe (1) 569,413.00 3.47 -3.88 2_Gyro-NSCT_Drill pipe (1) 569,414.47 2.93 4.72 2_Gyro-NS-CT_Drill pipe (1) 569,416.11 2.79 -5.59 2_Gyro-NS-CT_Drill pipe (1) 569,417.86 2.43 -6.45 2_Gyro-NS-CT_Drill pipe (1) 569,419.72 2.84 -7.31 2_Gyro-NS-CT_Drill pipe (1) 569,421.74 3.67 -8.18 2_Gyro-NS-CT_Drill pipe (1) 569,423.94 4.16 -9.06 2_Gyro-NS-CT_Drill pipe (1) 569,426.34 4.11 -9.95 2_Gyro-NS-CT_Drill pipe (1) 569,428.93 3.80 -10.86 2_Gyro-NS-CT Drill pipe (1) 569,431.74 4.82 -11.79 2_Gyro-NS-CT_Dnll pipe (1) 569,434.86 5.96 -12.81 2_Gyro-NS-CT_Drill pipe (1) 569,438.33 6.18 -13.92 2_Gyro-NS-CT_Drill pipe (1) 569,442.08 4.09 -15.08 2_Gyro-NSCT_Will pipe (1) 569,446.05 4.45 -16.30 2_Gyro-NSCT_Drill pipe (1) 569,450.26 4.20 -17.57 2 -Gyro -NS -CT -Drill pipe (1) 569,454.77 6.20 -18.92 2 Gyro-NS-CT_Dnll pipe (1) 569,459.74 8.98 -20.43 2_Gyro-NS-CT_Drill pipe (1) 569,465.20 5.93 -22.15 2_Gyro-NS-CT_Drill pipe (1) 569,471.04 5.10 -24.04 2_Gyro-NS-CT_Drill pipe (1) 569,477.26 5.48 -26.13 2_Gyro-NS-CT_Drill pipe (1) 569,483.87 6.02 -28.40 2_Gyro-NS-CT_Drill pipe (1) 569,490.91 7.04 -30.87 2_Gym-NS-CT_Drill pipe (1) 569,498.15 2.99 -33.36 2_Gyro-NS-CT_Drill pipe (1) 569,505.37 1.00 -35.74 2_Gyro-NS-CT_Drill pipe (1) 569,512.57 2.42 -38.04 2_Gyro-NS-CT_Drill pipe (1) 569,519.73 2.10 -40.21 2_Gym-NS-CT_Drill pipe (1) 569,526.77 2.01 42.19 2_Gyro-NS-CT_Drill pipe (1) 569,533.63 2.73 43.94 2_Gyro-NS-CT_Dnll pipe (1) 569,540.32 1.69 45.47 2_Gyro-NS-CT_Drill pipe (1) 569,546.92 1.76 46.85 2_Gyro-NS-CT_Drill pipe (1) 569,553.40 2.11 48.05 2 -Gyro -NS -CT Drill pipe (1) 569,559.67 3.59 48.97 2_Gyro-NS-CT_Drill pipe (1) 569,565.64 3.40 49.52 2_Gyro-NS-CT Drill pipe (1) 569,571.32 3.00 49.73 2_Gyro-NS-CT_Drill pipe (1) 569,576.72 2.95 49.62 2_Gyro-NS-CT_Drill pipe (1) 569,581.86 2.73 49.20 2_Gyro-NS-CT_Drill pipe (1) 569,586.82 1.68 48.56 2_Gyro-NS-CT Drill pipe (1) 2252019 5:36:05PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US+CANADA Survey Map Map MD Inc Azi TVD TVDSS +Nl-S +EJ -W Northing Easting DLS (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) ("1100') 1,340.00 32.50 20.96 1,261.02 1,212.67 285.99 186.79 6,016,444.43 569,591.62 2.40 1,365.00 32.93 20.04 1,282.06 1,233.71 298.65 191.52 6,016,457.13 569,596.23 2.63 1,390.00 33.43 18.85 1,302.98 1,254.63 311.55 196.07 6,016,470.07 569,600.66 3.28 1,415.00 33.77 17.74 1,323.80 1,275.45 324.69 200.41 6,016,483.25 569,604.88 2.81 1,440.00 34.35 16.60 1,344.52 1,296.17 338.06 204.54 6,016,496.66 569,608.89 3.45 1,465.00 34.71 15.82 1,365.11 1,316.76 351.67 208.50 6,016,510.30 569,612.72 2.28 1,490.00 35.38 14.94 1,385.58 1,337.23 365.51 212.31 6,016,524.18 569,616.39 3.36 1,515.00 36.12 14.08 1,405.87 1,357.52 379.65 215.96 6,016,538.35 569,619.92 3.58 1,540.00 37.24 12.94 1,425.92 1,377.57 394.17 219.45 6,016,552.90 569,623.27 5.24 1,565.00 38.70 11.98 1,445.63 1,397.28 409.19 222.77 6,016,567.95 569,626.45 6.30 1,590.00 39.88 10.93 1,464.97 1,416.62 424.71 225.91 6,016,583.49 569,629.44 5.42 1,615.00 41.23 10.01 1,483.97 1,435.62 440.69 228.86 6,016,599.50 569,632.25 5.91 1,640.00 42.52 9.25 1,502.58 1,454.23 457.14 231.65 6,016,615.98 569,634.88 5.54 1,665.00 43.30 8.80 1,520.89 1,472.54 473.95 234.32 6,016,632.81 569,637.39 3.35 1,690.00 43.95 8.57 1,538.99 1,490.64 491.00 236.93 6,016,649.88 569,639.84 2.68 1,715.00 44.04 8.49 1,556.98 1,508.63 508.17 239.50 6,016,667.08 569,642.25 0.42 1,740.00 43.84 8.54 1,574.98 1,526.63 525.33 242.07 6,016,684.25 569,644.66 0.81 1,765.00 43.65 8.78 1,593.04 1,544.69 542.42 244.67 6,016,701.36 569,647.11 1.01 1,790.00 43.19 8.90 1,611.20 1,562.85 559.40 247.31 6,016,718.37 569,649.59 1.87 1,815.00 43.02 9.08 1,629.45 1,581.10 576.27 249.98 6,016,735.26 569,652.10 0.84 1,840.00 43.26 9.17 1,647.69 1,599.34 593.15 252.69 6,016,752.16 569,654.65 0.99 1,865.00 43.88 9.22 1,665.80 1,617.45 610.16 255.45 6,016,769.20 569,657.25 2.48 1,890.00 43.89 9.24 1,683.82 1,635.47 627.27 258.23 6,016,786.33 569,659.87 0.07 1,915.00 44.43 9.42 1,701.76 1,653.41 644.45 261.05 6,016,803.54 569,662.53 2.22 1,940.00 44.41 9.51 1,719.61 1,671.26 661.71 263.93 6,016,820.82 569,665.25 0.26 1,965.00 44.28 9.65 1,737.49 1,689.14 678.94 266.84 6,016,838.08 569,668.00 0.65 1,990.00 43.93 9.76 1,755.44 1,707.09 696.09 269.77 6,016,855.25 569,670.77 1.43 2,015.00 43.74 9.97 1,773.48 1,725.13 713.15 272.74 6,016,872.33 569,673.58 0.96 2,040.00 44.00 10.11 1,791.50 1,743.15 730.21 275.76 6,016,889.42 569,676.44 1.11 2,065.00 44.11 10.09 1,809.47 1,761.12 747.33 278.80 6,016,906.56 569,679.32 0.44 2,090.00 44.03 10.14 1,827.43 1,779.08 764.44 281.86 6,016,923.70 569,682.22 0.35 2,115.00 43.91 10.10 1,845.42 1,797.07 781.53 284.91 6,016,940.82 569,685.11 0.49 2,140.00 43.87 9.80 1,863.44 1,815.09 798.60 287.90 6,016,957.91 569,687.94 0.85 2,165.00 44.08 9.76 1,881.43 1,833.08 815.71 290.85 6,016,975.05 569,690.73 0.85 2,190.00 44.26 9.32 1,899.36 1,851.01 832.89 293.74 6,016,992.25 569,693.46 1.42 2,215.00 44.39 9.05 1,917.25 1,868.90 850.13 296.53 6,017,009.52 569,696.09 0.92 2,240.00 44.62 9.10 1,935.08 1,886.73 867.44 299.29 6,017,026.85 569,698.69 0.93 2,265.00 44.64 8.86 1,952.87 1,904.52 884.79 302.03 6,017,044.22 569,701.27 0.68 2,290.00 44.99 8.43 1,970.60 1,922.25 902.21 304.68 6,017,061.66 569,703.75 1.85 2,315.00 45.34 8.00 1,988.23 1,939.88 919.75 307.21 6,017,079.23 569,706.12 1.86 Vertical Section (ft) Survey Tool Name -47.71 2_Gyro-NS-CT_Drill pipe (1) 46.62 2_Gym-NS-CT_Drill pipe (1) -45.27 2_Gyro-NS-CT_Drill pipe (1) -43.62 2 -Gyro -NS -CT -Drill pipe (1) -41.69 2_Gym-NS-CT_Drl1 pipe (1) -39.49 2_Gyro-NS-CT_Drill pipe (1) -37.06 2_Gyro-NS-CT_Drill pipe (1) -34.37 2_Gyro-NS-CT_Drill pipe (1) -31.36 2_Gym-NS-CT_Ddll pipe (1) -27.99 2_Gym-NS-CT_Drill pipe (1) -24.25 2_Gym-NS-CT_Drill pipe (1) -20.14 2_Gyro-NS-CT_Drill pipe (1) -15.68 2_Gyro-NS-CT_Drill pipe (1) -10.96 2_Gyro-NS-CT_Drill pipe (1) -6.08 2_Gyro-NS-CT_Drill pipe (1) -1.12 2_Gym-NS-CT_Drill pipe (1) 3.84 2 Gyro-NS-CT_Drill pipe (1) 8.73 2 Gym-NS-CT_Drill pipe (1) 13.55 2_Gyro-NS-CT_Drill pipe (1) 18.30 2_Gym-NS-CT Drill pipe (1) 23.01 2_Gym-NS-CT_Drill pipe (1) 27.74 2_Gyro-NS-CT_Ddll pipe (1) 32.48 2_Gyro-NS-CT_Dnll pipe (1) 37.22 2 Gyro-NS-CT_Drill pipe (1) 41.94 2_Gyro-NS-CT_Drill pipe (1) 46.62 2_Gyro-NS-CT_Drill pipe (1) 51.25 2_Gyro-NS-CT_Drill pipe (1) 55.80 2_Gyro-NS-CT_Drill pipe (1) 60.31 2_Gyro-NS-CT_Drill pipe (1) 64.82 2_Gyro-NS-CT_Drill pipe (1) 69.32 2 Gyro-NS-CT_Drill pipe (1) 73.81 2 -Gyro -NS -CT Drill pipe (1) 78.35 2 -Gyro -NS -CT -Drill pipe (1) 82.94 2_Gyro-NS-CT_Drill pipe (1) 87.62 2_Gym-NS-CT_Drill pipe (1) 92.41 2 -Gyro -NS -CT -Drill pipe (1) 97.26 2_Gyro-NS-CT_Drill pipe (1) 102.14 2_Gym-NS-CT_Drill pipe (1) 107.14 2 -Gyro -NS -CT -Drill pipe (1) 112.29 2_Gym-NS-CT_Drill pipe (1) 2/252019 5:36:05PM Page 4 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Rig: MPU E-36 Wellbore: MPU E-36 Design: MPU E-36 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (°) (') (usft) (usft) (usft) (usft) (ft) 2,340.00 45.20 7.93 2,005.82 1,957.47 937.34 309.67 6,017,096.84 2,365.00 44.78 7.91 2,023.50 1,975.15 954.85 312.11 6,017,114.36 2,390.00 44.34 7.91 2,041.32 1,992.97 972.22 314.52 6,017,131.76 2,415.00 44.72 7.78 2,059.14 2,010.79 989.59 316.92 6,017,149.15 2,440.00 45.25 7.65 2,076.82 2,028.47 1,007.10 319.29 6,017,166.68 2,465.00 45.33 7.48 2,094.41 2,046.06 1,024.71 321.63 6,017,184.31 2,490.00 44.83 7.61 2,112.06 2,063.71 1,042.26 323.95 6,017,201.88 2,515.00 44.55 7.60 2,129.83 2,081.48 1,059.69 326.28 6,017,219.32 2,540.00 44.37 7.63 2,147.68 2,099.33 1,077.05 328.60 6,017,236.70 2,565.00 44.16 7.60 2,165.58 2,117.23 1,094.34 330.91 6,017,254.01 2,590.00 43.68 7.67 2,183.59 2,135.24 1,111.53 333.22 6,017,271.22 2,615.00 43.72 7.71 2,201.66 2,153.31 1,128.65 335.53 6,017,288.36 2,640.00 43.91 7.71 2,219.70 2,171.35 1,145.80 337.85 6,017,305.53 2,665.00 43.90 7.70 2,237.71 2,189.36 1,162.98 340.17 6,017,322.73 2,690.00 43.45 7.84 2,255.80 2,207.45 1,180.08 342.51 6,017,339.85 2,715.00 42.97 7.91 2,274.02 2,225.67 1,197.04 344.85 6,017,356.83 2,740.00 42.65 8.02 2,292.36 2,244.01 1,213.86 347.21 6,017,373.67 2,765.00 42.55 8.16 2,310.76 2,262.41 1,230.62 349.59 6,017,390.45 2,790.00 42.81 8.37 2,329.14 2,280.79 1,247.39 352.03 6,017,407.24 2,815.00 43.52 8.45 2,347.37 2,299.02 1,264.31 354.53 6,017,424.18 2,840.00 43.44 8.47 2,365.51 2,317.16 1,281.32 357.06 6,017,441.21 2,865.00 43.21 8.67 2,383.70 2,335.35 1,298.29 359.61 6,017,458.20 2,890.00 43.02 8.64 2,401.95 2,353.60 1,315.18 362.18 6,017,475.11 2,915.00 43.57 8.51 2,420.15 2,371.80 1,332.13 364.74 6,017,492.08 2,940.00 44.40 8.41 2,438.13 2,389.78 1,349.30 367.29 6,017,509.28 2,965.00 44.75 8.43 2,455.94 2,407.59 1,366.66 369.86 6,017,526.66 2,990.00 44.86 8.36 2,473.68 2,425.33 1,384.09 372.44 6,017,544.11 3,015.00 44.81 8.41 2,491.41 2,443.06 1,401.53 375.01 6,017,561.57 3,040.00 44.39 8.41 2,509.21 2,460.86 1,418.89 377.57 6,017,578.95 3,065.00 44.21 8.45 2,527.10 2,478.75 1,436.16 380.13 6,017,596.25 3,090.00 44.17 8.30 2,545.03 2,496.68 1,453.40 382.67 6,017,613.51 3,115.00 44.67 8.18 2,562.88 2,514.53 1,470.72 385.18 6,017,630.85 3,140.00 45.12 8.01 2,580.59 2,532.24 1,488.19 387.66 6,017,648.34 3,165.00 44.95 8.02 2,598.26 2,549.91 1,505.71 390.13 6,017,665.87 3,190.00 44.68 8.03 2,615.99 2,567.64 1,523.15 392.59 6,017,683.34 3,215.00 44.42 8.29 2,633.81 2,585.46 1,540.51 395.08 6,017,700.72 3,240.00 44.05 8.43 2,651.72 2,603.37 1,557.77 397.62 6,017,718.00 3,265.00 43.72 8.47 2,669.74 2,621.39 1,574.91 400.16 6,017,735.16 3,290.00 43.06 8.62 2,687.91 2,639.56 1,591.89 402.71 6,017,752.17 3,315.00 42.62 8.71 2,706.24 2,657.89 1,608.70 405.27 6,017,768.99 Well MPU E-36 MPU E-36 Actual RKB @ 48.35usft MPU E-36 Actual RKB @ 48.35usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (^1106•) (ft) Survey Tool Name 569,708.42 0.59 117.53 2_Gyro-NS-CT_Drill pipe (1) 569,710.69 1.68 122.76 2_Gyro-NS-CT_Drill pipe (1) 569,712.94 1.76 127.95 2_Gyro-NS-CT_Drill pipe (1) 569,715.18 1.56 133.15 2_Gyro-NS-CT_Dnll pipe (1) 569,717.38 2.15 138.44 2 Gyro-NS-CT_Drll pipe (1) 569,719.56 0.58 143.80 2_Gym-NS-CT_Drill pipe (1) 569,721.72 2.03 149.14 2_Gyro-NS-CT_Drill pipe (1) 569,723.88 1.12 154.43 2_Gyro-NS-CT Drill pipe (1) 569,726.04 0.72 159.70 2_Gyro-NS-CT_Dnll pipe (1) 569,728.19 0.84 164.95 2_Gyro-NS-CT_Dnll pipe (1) 569,730.34 1.93 170.16 2_Gyro-NS-CT_Drill pipe (1) 569,732.49 0.19 175.33 2_Gyro-NS-CT_Drill pipe (1) 569,734.65 0.76 180.51 2_Gyro-NS-CT Drill pipe (1) 569,736.81 0.05 185.70 2_Gyro-NS-CT_Drill pipe (1) 569,738.99 1.84 190.85 2_Gyro-NS-CT_Drill pipe (1) 569,741.18 1.93 195.92 2_Gyro-NS-CT_Drill pipe (1) 569,743.37 1.31 200.94 2_Gyrc-NS-CT_Drill pipe (1) 569,745.60 0.55 205.89 2_Gyro-NS-CT_Drill pipe (1) 569,747.88 1.19 210.81 2 Gyro-NS-CT_Drill pipe (1) 569,750.22 2.85 215.72 2Gyrc-NS-CT Drill pipe (1) 569,752.59 0.32 220.65 2_Gyro-NS-CT_Drill pipe (1) 569,754.99 1.07 225.54 2_Gyro-NS-CT_Drill pipe (1) 569,757.40 0.76 230.38 2_Gyro-NS-CT_Drill pipe (1) 569,759.80 2.23 235.27 2_Gyro-NS-CT_Drill pipe (1) 569,762.20 3.33 240.24 2_Gyro-NS-CT_Drill pipe (1) 569,764.60 1.40 245.29 2_Gyro-NS-CT_Drill pipe (1) 569,767.01 0.48 250.36 2_Gyro-NS-CT Drill pipe (1) 569,769.42 0.24 255.43 2_Gyro-NS-CT_DO pipe (1) 569,771.82 1.68 260.48 2_Gyro-NS-CT_Drill pipe (1) 569,774.22 0.73 265.49 2_Gyro-NS-CT_Drill pipe (1) 569,776.60 0.45 270.51 2_Gyrc-NS-CT_Drill pipe (1) 569,778.95 2.03 275.59 2_Gyro-NS-CT_Drill pipe (1) 569,781.27 1.86 280.76 2_Gyro-NS-CT_Drill pipe (1) 569,783.57 0.68 285.96 2_Gyro-NS-CT_Dril pipe (1) 569,785.87 1.08 291.14 2_Gyro-NS-CT_Dnll pipe (1) 569,788.20 1.27 296.26 2 Gyro-NS-CT_Dnll pipe (1) 569,790.57 1.53 301.29 2_Gym-NS-CT_Drill pipe (1) 569,792.96 1.32 306.26 2_Gyro-NS-CT_Drill pipe (1) 569,795.35 2.67 311.16 2_Gyro-NS-CT_Drill pipe (1) 569,797.75 1.78 315.97 2_Gyro-NS-CT_Dnll pipe (1) 2/252019 5:36:05PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US+CANADA Survey Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) 3,340.00 42.37 8.90 2,724.67 2,676.32 1,625.39 407.86 6,017,785.70 3,365.00 42.96 8.82 2,743.06 2,694.71 1,642.13 410.47 6,017,802.47 3,390.00 43.85 8.83 2,761.22 2,712.87 1,659.10 413.10 6,017,819.46 3,415.00 43.97 8.89 2,779.23 2,730.88 1,676.24 415.77 6,017,836.62 3,440.00 43.39 8.93 2,797.31 2,748.96 1,693.29 418.45 6,017,853.70 3,465.00 42.84 8.89 2,815.56 2,767.21 1,710.17 421.10 6,017,870.60 3,490.00 42.62 8.91 2,833.92 2,785.57 1,726.93 423.72 6,017,887.38 3,515.00 42.39 8.83 2,852.35 2,804.00 1,743.62 426.32 6,017,904.09 3,540.00 42.31 8.76 2,870.83 2,822.48 1,760.26 428.90 6,017,920.76 3,565.00 42.40 8.64 2,889.30 2,840.95 1,776.91 431.45 6,017,937-43 3,590.00 42.52 8.52 2,907.75 2,859.40 1,793.60 433.96 6,017,954.14 3,615.00 42.90 8.30 2,926.12 2,877.77 1,810.38 436.44 6,017,970.93 3,640.00 43.91 8.00 2,944.28 2,895.93 1,827.38 438.88 6,017,987.96 3,665.00 44.49 7.62 2,962.20 2,913.85 1,844.65 441.25 6,018,005.25 3,690.00 45.13 7.38 2,979.94 2,931.59 1,862.12 443.55 6,018,022.73 3,715.00 45.38 7.48 2,997.54 2,949.19 1,879.72 445.84 6,018,040.36 3,740.00 45.48 7.65 3,015.08 2,966.73 1,897.38 448.19 6,018,058.03 3,765.00 45.26 7.67 3,032.64 2,984.29 1,915.01 450.56 6,018,075.68 3,790.00 44.75 7.89 3,050.32 3,001.97 1,932.53 452.95 6,018,093.22 3,815.00 44.52 7.81 3,068.11 3,019.76 1,949.93 455.35 6,018,110.64 3,840.00 44.60 7.97 3,085.92 3,037.57 1,967.30 457.76 6,018,128.04 3,865.00 44.93 8.19 3,103.67 3,055.32 1,984.73 460.23 6,018,145.49 3,890.00 45.73 8.25 3,121.25 3,072.90 2,002.33 462.78 6,018,163.11 3,915.00 45.98 8.27 3,138.66 3,090.31 2,020.08 465.35 6,018,180.88 3,940.00 45.98 8.24 3,156.03 3,107.68 2,037.88 467.93 6,018,198.69 3,965.00 45.89 8.36 3,173.42 3,125.07 2,055.65 470.53 6,018,216.49 3,990.00 45.68 8.47 3,190.85 3,142.50 2,073.38 473.15 6,018,234.24 4,015.00 45.40 8.74 3,208.36 3,160.01 2,091.02 475.82 6,018,251.90 4,040.00 45.52 8.92 3,225.90 3,177.55 2,108.63 478.56 6,018,269.53 4,065.00 45.83 8.44 3,243.37 3,195.02 2,126.31 481.25 6,018,287.24 4,090.00 46.15 7.42 3,260.74 3,212.39 2,144.11 483.73 6,018,305.06 4,115.00 46.49 6.77 3,278.00 3,229.65 2,162.06 485.97 6,018,323.02 4,140.00 46.23 6.55 3,295.26 3,246.91 2,180.03 488.07 6,018,341.01 4,165.00 46.08 6.88 3,312.57 3,264.22 2,197.93 490.17 6,018,358.94 4,190.00 45.98 7.02 3,329.93 3,281.58 2,215.79 492.35 6,018,376.81 4,215.00 45.78 7.21 3,347.34 3,298.99 2,233.60 494.57 6,018,394.64 4,240.00 46.00 7.34 3,364.74 3,316.39 2,251.41 496.85 6,018,412.47 4,265.00 45.92 7.64 3,382.12 3,333.77 2,269.23 499.19 6,018,430.30 4,290.00 45.84 7.65 3,399.52 3,351.17 2,287.01 501.58 6,018,448.11 4,315.00 45.79 7.24 3,416.94 3,368.59 2,304.79 503.90 6,018,465.91 Map Vertical Easting DLS Section (ft) (*If 001) (ft) Survey Tool Name 569,800.18 1.12 320.72 2 -Gyro -NS -CT Drill pipe (1) 569,802.64 2.37 32546 2_Gyro-NS-CT_Drill pipe (1) 569,805.11 3.56 330.28 2_Gyro-NS-CT_Drill pipe (1) 569,807.62 0.51 335.14 2_Gyro-NS-CT_Drill pipe (1) 569,810.14 2.32 339.96 2_Gym-NS-CT_Drill pipe (1) 569,812.63 2.20 344.73 2_Gym-NS-CT_Drill pipe (1) 569,815.09 0.88 349.46 2_Gyro-NS-CT_Drill pipe (1) 569,817.54 0.95 354.19 2_Gyro-NS-CT_Drill pipe (1) 569,819.96 0.37 358.93 2_Gyro-NS-CT_Drill pipe (1) 569,822.36 0.48 363.69 2_Gyro-NS-CT_Drill pipe (1) 569,824.72 0.58 368.49 2_Gyro-NS-CT_Drill pipe (1) 569,827.04 1.63 373.37 2_Gym-NS-CT_Drill pipe (1) 569,829.32 4.12 378.38 2_Gyro-NS-CT_Drill pipe (1) 569,831.52 2.55 383.57 2_Gyro-NS-CT_Drill pipe (1) 569,833.66 2.65 388.90 2_Gyro-NS-CT_Drill pipe (1) 569,835.79 1.04 394.30 2_Gyro-NS-CT_Drill pipe (1) 569,837.97 0.63 399.67 2 Gym-NS-CT_Drill pipe (1) 569,840.18 0.88 405.01 2_Gyro-NS-CT_Drill pipe (1) 569,842.41 2.13 410.28 2_Gym-NS-CT_Drill pipe (1) 569,844.65 0.95 415.49 2_Gyro-NS-CT_Drill pipe (1) 569,846.89 0.55 420.69 2_Gyro-NS-CT_Drill pipe (1) 569,849.20 1.46 425.84 2_Gyro-NS-CT_Drill pipe (1) 569,851.58 3.20 431.01 2_Gym-NS-CT_Drill pipe (1) 569,853.99 1.00 436.22 2_Gyro-NS-CT_Drill pipe (1) 569,856.41 0.09 441.43 2_Gyro-NS-CT_Drill pipe (1) 569,858.83 0.50 446.63 2_Gyro-NS-CT_Drill pipe (1) 569,861.29 0.90 451.78 2_Gym-NS-CT_Ddll pipe (1) 569,863.80 1.36 456.85 2_Gyro-NS-CT_Drill pipe (1) 569,866.37 0.70 461.85 2_Gym-NS-CT_Drill pipe (1) 569,868.90 1.85 466.91 2_Gyro-NS-CT_Drill pipe (1) 569,871.22 3.20 472.23 2_Gym-NS-CT_Drill pipe (1) 569,873.28 2.32 477.82 2_Gym-NS-CT_Drill pipe (1) 569,875.21 1.22 483.55 2_Gyro-NS-CT_Drill pipe (1) 569,877.15 1.13 489.24 2_Gym-NS-CT_Drill pipe (1) 569,879.16 0.57 494.85 2_Gym-NS-CT_Drill pipe (1) 569,881.22 0.97 500.40 2_Gym-NS-CT_Drill pipe (1) 569,883.33 0.96 505.90 2_Gyro-NS-CT_Drill pipe (1) 569,885.50 0.92 511.35 2_Gyro-NS-CT_Drill pipe (1) 569,887.72 0.32 516.73 2_Gyro-NS-CT_Dnll pipe (1) 569,889.88 1.19 522.18 2_Gyro-NS-CT_D411 pipe (1) 2/252019 5:36:05PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (`) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-1100') (ft) Survey Tool Name 4,340.00 45.50 5.94 3,434.42 3,386.07 2,322.55 505.95 6,018,483.68 569,891.77 3.89 527.96 2 Gyra-NS-CT Drill pipe (1) 4,365.00 45.46 4.45 3,451.95 3,403.60 2,340.30 507.57 6,018,501.44 569,893.22 4.25 533.93 2_Gyro-NS-CT_Drill pipe (i) 4,390.00 45.87 3.06 3,469.42 3,421.07 2,358.14 508.74 6,018,519.29 569,894.22 4.30 540.45 2_Gyro-NS-CT_Drill pipe (1) 4,415.00 46.31 1.68 3,486.76 3,438.41 2,376.13 509.48 6,018,537.29 569,894.80 4.35 547.41 2_Gym-NS-CT_Dn1l pipe (1) 4,440.00 46.48 0.53 3,504.00 3,455.65 2,394.23 509.83 6,018,555.39 569,894.98 3.40 554.78 2_Gym-NS-CT_Drill pipe (1) 4,465.00 46.54 359.39 3,521.21 3,472.86 2,412.37 509.82 6,018,573.53 569,894.79 3.32 562.49 2_Gyro-NS-CT_Drill pipe (1) 4,490.00 46.16 358.56 3,538.47 3,490.12 2,430.46 509.49 6,018,591.61 569,894.30 2.84 570.46 2_Gyro-NS-CT_Drill pipe (1) 4,515.00 46.40 357.40 3,555.75 3,507.40 2,448.51 508.86 6,018,609.65 569,893.50 3.49 578.70 2_Gyro-NS-CT_Drill pipe (1) 4,540.00 46.13 356.07 3,573.03 3,524.68 2,466.54 507.83 6,018,627.68 569,892.30 3.99 587.29 2_Gyro-NS-CT_Drill pipe (1) 4,565.00 46.18 355.07 3,590.35 3,542.00 2,484.52 506.43 6,018,645.64 569,890.74 2.89 596.18 2_Gym-NS-CT_Drill pipe (1) 4,590.00 46.17 354.10 3,607.66 3,559.31 2,502.48 504.73 6,018,663.57 569,888.87 2.80 605.34 2_Gyro-NS-CT_Drill pipe (1) 4,615.00 46.26 352.89 3,624.96 3,576.61 2,520.41 502.69 6,018,681.48 569,886.66 3.51 614.81 2_Gyro-NS-CT_Drill pipe (1) 4,640.00 46.63 351.31 3,642.18 3,593.83 2,538.35 500.20 6,018,699.40 569,884.00 4.81 624.68 2_Gyro-NS-CT_Drill pipe (1) 4,665.00 47.11 349.44 3,659.28 3,610.93 2,556.34 497.15 6,018,717.36 569,880.78 5.79 635.08 2_Gyro-NS-CT_Drill pipe (1) 4,690.00 47.02 347.76 3,67631 3,627.96 2,574.28 493.53 6,018,735.26 569,877.00 4.93 645.97 2_Gyro-NS-CT_Drill pipe (1) 4,715.00 47.29 346.64 3,693.31 3,644.96 2,592.15 489.47 6,018,753.10 569,872.77 3.46 657.24 2_Gyro-NS-CT_Drill pipe (1) 4,740.00 47.41 346.04 3,710.25 3,661.90 2,610.02 485.12 6,018,770.92 569,868.27 1.83 668.75 2_Gyro-NS-CT_Drill pipe (1) 4,765.00 47.62 345.23 3,727.13 3,678.78 2,627.88 480.55 6,018,788.73 569,863.53 2.53 680.48 2_Gyro-NS-CT_Drill pipe (1) 4,790.00 48.12 344.23 3,743.90 3,695.55 2,645.77 475.67 6,018,806.57 569,858.48 3.58 692.49 2_Gyro-NS-CT_Drill pipe (1) 4,815.00 48.68 343.32 3,760.50 3,712.15 2,663.72 470.44 6,018,824.47 569,853.09 3.53 704.84 2_Gyro-NS-CT_Drill pipe (1) 4,840.00 49.17 342.74 3,776.93 3,728.58 2,681.74 464.94 6,018,842.44 569,847.42 2.63 717.47 2_Gyro-NS-CT_Dnll pipe (1) 4,865A0 49.55 342.34 3,793.21 3,744.86 2,699.84 459.25 6,018,860.48 569,841.56 1.95 730.31 2_Gyro-NS-CT_Drill pipe (1) 4,890.00 50.11 341.74 3,809.33 3,760.98 2,718.01 453.36 6,018,878.60 569,835.50 2.89 743.36 2_Gyro-NS-CT_Drill pipe (1) 4,915.00 51.01 340.59 3,825.22 3,776.87 2,736.28 447.12 6,018,896.81 569,829.09 5.06 756.76 2_Gyro-NS-CT Drill pipe (1) 4,940.00 51.56 339.42 3,840.85 3,792.50 2,754.61 440.45 6,018,915.07 569,822.25 4.26 770.58 2_Gyro-NS-CT_Drill pipe (1) 4,965.00 52.20 338.23 3,856.29 3,807.94 2,772.95 433.35 6,018,933.35 569,814.98 4.54 784.80 2_Gyro-NS-CT_Drill pipe (1) 4,990.00 52.39 337.38 3,871.58 3,823.23 2,791.26 425.88 6,018,951.59 569,807.34 2.80 799.34 2_Gyro-NS-CT_Drill pipe (1) 5,015.00 52.72 336.64 3,886.78 3,838.43 2,809.54 418.12 6,018,969.78 569,799.42 2.70 814.11 2_Gyro-NS-CT_Drill pipe (1) 5,040.00 52.82 335.66 3,901.90 3,853.55 2,827.74 410.08 6,018,98291 569,791.20 3.15 829.13 2_Gym-NS-CT_Drill pipe (1) 5,065.00 53.22 334.86 3,916.94 3,868.59 2,845.88 401.72 6,019,005.97 569,782.67 3.02 844.40 2_Gyro-NS-CT_Drill pipe (1) 5,090.00 53.53 333.63 3,931.86 3,883.51 2,863.95 393.00 6,019,023.95 569,773.79 4.14 859.96 2_Gyro-NS-CT_Drill pipe (1) 5,115.00 54.04 332.29 3,946.63 3,898.28 2,881.91 383.83 6,019,041.83 569,764.45 4.78 875.89 2_Gyro-NS-CT_Drill pipe (1) 5,140.00 54.33 331.08 3,961.26 3,912.91 2,899.76 374.21 6,019,059.59 569,754.67 4.09 892.17 2_Gym-NS-CT_DnII pipe (1) 5,165.00 54.60 330.14 3,975.79 3,927.44 2,917.48 364.23 6,019,077.22 569,744.52 3.24 908.74 2_Gyro-NS-CT_Drill pipe (1) 5,190.00 55.16 329.00 3,990.17 3,941.82 2,935.12 353.87 6,019,094.75 569,734.00 4.35 925.60 2_Gym-NS-CT_Drill pipe (1) 5,215.00 55.37 328.38 4,004.41 3,956.06 2,952.67 343.20 6,019,112.20 569,723.17 2.20 942.72 2 Gym-NS-CT_Drlll pipe (1) 5,240.00 57.26 327.55 4,018.28 3,969.93 2,970.30 332.16 6,019,129.73 569,711.97 8.05 960.19 2_Gyro-NS-CT_Drill pipe (1) 5,265.00 59.26 326.44 4,031.43 3,983.08 2,988.13 320.58 6,019,147.44 569,700.22 8.85 978.25 2_Gyro-NS-CT_Drill pipe (1) 5,290.00 61.08 325.05 4,043.86 3,995.51 3,006.05 308.37 6,019,165.25 569,687.85 8.73 996.91 2 Gyro-NS-CT_Dnll pipe (1) 5,315.00 62.26 323.67 4,055.73 4,007.38 3,023.93 295.55 6,019,183.01 569,674.86 6.77 1,016.11 2_Gyro-NS-CT_Drill pipe (1) 2,25/2019 5:36:05PM Page 7 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-5 +E/ -W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) (`118(I') (ft) Survey Tool Name 5,340.00 63.01 322.38 4,067.22 4,018.87 3,041.67 282.19 6,019,200.62 569,661.34 5.48 1,035.73 2_Gyro-NS-CT_Drill pipe (1) 5,365.00 63.76 321.30 4,078.42 4,030.07 3,059.24 268.38 6,019,218.06 569,647.37 4.89 1,055.70 2_Gyro-NS-CT_Drill pipe (1) 5,390.00 64.34 320.62 4,089.36 4,041.01 3,076.70 254.22 6,019,235.39 569,633.05 3.37 1,075.93 2_Gyno-NS-CT_Dnll pipe (1) 5,415.00 65.12 320.39 4,100.03 4,051.68 3,094.15 239.85 6,019,252.70 569,618.51 3.23 1,096.35 2_Gyro-NS-CT_Drill pipe (1) 5,440.00 66.45 320.19 4,110.29 4,061.94 3,111.69 225.28 6,019,270.10 569,603.78 5.37 1,116.99 2_Gyro-NS-CT Drill pipe (1) 5,465.00 67.19 319.53 4,120.13 4,071.78 3,129.26 210.46 6,019,287.53 569,588.81 3.83 1,137.86 2_Gyro-NS-CT_Drill pipe (1) 5,490.00 68.37 318.58 4,129.58 4,081.23 3,146.74 195.30 6,019,304.86 569,573.48 5.89 1,159.01 2_Gyro-NS-CT_Drill pipe (1) 5,515.00 69.56 317.19 4,138.55 4,090.20 3,164.04 179.65 6,019,322.02 569,557.67 7.04 1,180.53 2_Gyro-NS-GT_Drill pipe (1) 5,540.00 69.87 315.79 4,147.22 4,098.87 3,181.05 163.50 6,019,338.87 569,541.37 5.40 1,202.37 2_Gyr NS-CT_Dnll pipe (1) 5,565.00 69.72 314.23 4,155.86 4,107.51 3,197.64 146.92 6,019,355.31 569,524.63 5.89 1,224.43 2_Gyro-NS-CT_Drill pipe (1) 5,590.00 69.69 312.45 4,164.53 4,116.18 3,213.73 129.87 6,019,371.24 569,507.43 6.68 1,246.70 2_Gyro-NS-CT_Drill pipe (1) 5,615.00 69.62 310.95 4,173.22 4,124.87 3,229.33 112.36 6,019,386.67 569,489.79 5.63 1,269.16 2_Gyro-NS-CT_Ddll pipe (1) 5,640.00 69.91 309.66 4,181.87 4,133.52 3,244.50 94.48 6,019,401.67 569,471.76 4.98 1,291.80 2 -Gyro -NS -CT -D411 pipe (1) 5,665.00 69.96 308.33 4,190.45 4,142.10 3,259.28 76.23 6,019,416.28 569,453.38 5.00 1,314.60 2_Gyro-NS-CT_Drill pipe (1) 5,690.00 70.12 307.02 4,198.98 4,150.63 3,273.64 57.63 6,019,430.46 569,434.65 4.97 1,337.53 2_Gyru-NS-CT_Drill pipe (1) 5,715.00 69.92 305.56 4,207.52 4,159.17 3,287.54 38.69 6,019,444.19 569,415.58 5.55 1,360.58 2_Gyro-NS-CT_Drlll pipe (i) 5,740.00 69.70 304.12 4,216.15 4,167.80 3,300.95 19.43 6,019,457.41 569,396.20 5.48 1,383.71 2_Gyro-NS-CT_Drill pipe (1) 5,765.00 69.90 302.44 4,224.78 4,176.43 3,313.82 -0.18 6,019,470.10 569,376.47 6.36 1,406.93 2_Gyro-NS-CT_Drill pipe (1) 5,790.00 70.24 300.96 4,233.31 4,184.96 3,326.17 -20.18 6,019,482.26 569,356.36 5.73 1,430.28 2_Gyro-NS-CT_Drlll pipe (1) 5,815.00 70.80 299.54 4,241.64 4,193.29 3,338.04 40.54 6,019,493.95 569,335.90 5.80 1,453.75 2_Gyro-NS-CT_Drill pipe (1) 5,840.00 71.28 298.36 4,249.77 4,201.42 3,349.49 -61.22 6,019,505.19 569,315.10 4.86 1,477.34 2_Gyro-NS-CT_Drill pipe (1) 5,865.00 71.91 297.39 4,257.66 4,209.31 3,360.58 -82.19 6,019,516.09 569,294.03 4.46 1,501.04 2_Gyro-NS-CT_Drill pipe (1) 5,890.00 72.40 296.51 4,265.32 4,216.97 3,371.36 -103.41 6,019,526.67 569,272.72 3.88 1,524.82 2_Gyro-NS-CT_Drill pipe (1) 5,915.00 73.07 295.83 4,272.74 4,224.39 3,381.89 -124.83 6,019,537.00 569,251.20 3.73 1,548.69 2_Gyro-NS-CT_Drill pipe (1) 5,940.00 73.73 295.01 4,279.88 4,231.53 3,392.17 -146.47 6,019,547.08 569,229.47 4.10 1,572.65 2_Gyro-NS-CT_Drill pipe (1) 5,965.00 74.56 294.29 4,286.71 4,238.36 3,402.20 -168.33 6,019,556.91 569,207.52 4.32 1,596.70 2_Gyro-NS-CT_Drill pipe (1) 5,990.00 75.33 294.03 4,293.21 4,244.86 3,412.08 -190.35 6,019,566.58 569,185.41 3.24 1,620.83 2 -Gyro -NS -CT -Drill pipe (1) 6,015.00 76.24 293.52 4,299.35 4,251.00 3,421.85 -212.53 6,019,576.14 569,163.14 4.14 1,645.06 2 -Gyro -NS -CT -Drill pipe (1) 6,040.00 77.20 292.72 4,305.09 4,256.74 3,431 Al -234.91 6,019,585.49 569,140.68 4.94 1,669.38 2_Gyro-NS-CT_Drill pipe (1) 6,065.00 78.21 292.03 4,310.41 4,262.06 3,440.71 -257.50 6,019,594.57 569,118.01 4.86 1,693.78 2_Gyro-NS-CT_Drill pipe (1) 6,090.00 79.65 291.38 4,315.21 4,266.86 3,449.78 -280.29 6,019,603.43 569,095.13 6.30 1,718.27 2 Gyro-NS-CT_Drill pipe (1) 6,115.00 80.80 291.13 4,319.46 4,271.11 3,458.71 -303.25 6,019,612.15 569,072.09 4.70 1,742.85 2_Gyro-NS-CT_Drill pipe (1) 6,140.00 81.73 290.75 4,323.25 4,274.90 3,467.54 -326.33 6,019,620.76 569,048.94 4.01 1,767.49 2_Gyro-NS-CT_D411 pipe (1) 6,165.00 82.26 290.34 4,326.74 4,278.39 3,476.23 -349.51 6,019,629.23 569,025.68 2.67 1,792.17 2 -Gyro -NS -CT -Drill pipe (1) 6,190.00 82.62 290.20 4,330.02 4,281.67 3,484.82 -372.76 6,019,637.60 569,002.35 1.54 1,816.86 2 -Gyro -NS -GT -Drill pipe (1) 6,215.00 83.07 290.10 4,333.14 4,284.79 3,493.36 -396.05 6,019,645.93 568,978.99 1.84 1,841.57 2_Gyro-NS-CT_Drill pipe (1) 6,240.00 83.47 289.79 4,336.07 4,287.72 3,501.83 419.38 6,019,654.18 568,955.57 2.02 1,866.30 2_Gyro-NS-CT_Drill pipe (1) 6,265.00 83.71 289.32 4,338.86 4,290.51 3,510.14 442.80 6,019,662.28 568,932.09 2.10 1,891.03 2_Gyro-NS-CT_Drill pipe (1) 6,290.00 83.92 288.94 4,341.55 4,293.20 3,518.29 466.28 6,019,670.20 568,908.53 1.73 1,915.75 2_Gyro-NS-CT Drill pipe (1) 6,315.00 83.58 288.41 4,344.27 4,295.92 3,526.25 389.82 6,019,677.94 568,884.92 2.51 1,940.44 2_Gyro-NS-CT_Dnll pipe (1) 2252019 5.,36:05PM Page 8 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (usft) (') (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 6,340.00 83.54 287.83 4,347.08 4,298.73 3,533.97 -513.43 6,019,685.44 568,861.24 2.31 1,965.10 2_Gyro-NS-CT_Drill pipe (1) 6,365.00 83.45 287.39 4,349.91 4,301.56 3,541.49 -537.11 6,019,692.74 568,837.50 1.79 1,989.72 2_Gym-NS-CT_Drill pipe (1) 6,390.00 83.45 287.01 4,352.76 4,304.41 3,548.83 -560.83 6,019,699.86 568,813.71 1.51 2,014.32 2_Gyra-NS-CT_Dnll pipe (1) 6,415.00 83.45 287.09 4,355.61 4,307.26 3,556.11 -584.58 6,019,706.92 568,789.90 0.32 2,038.91 2 Gyro-NS-CT_Drill pipe (1) 6,440.00 83.11 287.27 4,358.54 4,310.19 3,563.45 -608.30 6,019,714.03 568,766.11 1.54 2,063.50 2_Gym-NS-CT_Dnll pipe (1) 6,465.00 83.13 287.03 4,361.53 4,313.18 3,570.77 -632.01 6,019,721.13 568,742.33 0.96 2,088.08 2 -GYM -NS -CT -Drill pipe (1) 6,490.00 83.03 286.74 4,364.55 4,316.20 3,577.98 -655.76 6,019,728.11 568,718.52 1.22 2,112.65 2_Gyro-NS-CT_Drill pipe (1) 6,515.00 84.24 286.46 4,367.32 4,318.97 3,585.07 -679.57 6,019,734.99 568,694.65 4.97 2,137.22 2_Gym-NS-CT_Drill pipe (1) 6,540.00 84.35 286.38 4,369.80 4,321.45 3,592.11 -703.43 6,019,741.80 568,670.72 0.54 2,161.81 2_Gyro-NS-CT_Drill pipe (1) 6,565.00 84.69 286.07 4,372.19 4,323.84 3,599.06 -727.33 6,019,748.53 568,646.77 1.84 2,186.39 2_Gyro-NS-CT_Drill pipe (1) 6,590.00 85.26 286.01 4,374.38 4,326.03 3,605.94 -751.26 6,019,755.18 568,622.77 2.29 2,210.99 2_Gyro-NS-CT_Drill pipe (1) 6,615.00 85.00 285.97 4,376.50 4,328.15 3,612.80 -775.21 6,019,761.82 568,598.77 1.05 2,235.58 2_Gyma NS -CT Drill pipe (1) 6,640.00 84.41 286.09 4,378.81 4,330.46 3,619.68 -799.13 6,019,768.47 568,574.78 2.41 2,260.16 2 -Gyro -NS -CT -Drill pipe (1) 6,665.00 84.18 286.05 4,381.30 4,332.95 3,626.56 -823.04 6,019,775.13 568,550.82 0.93 2,284.73 2_Gyrc-NS-CT_Drill pipe (1) 6,678.86 84.47 285.91 4,382.67 4,334.32 3,630.36 -836.30 6,019,778.81 568,53252 2.32 2,298.34 2_Gyrc-NS-CT_Drill pipe (1) 6,789.02 85.87 285.70 4,391.94 4,343.59 3,660.25 -941.91 6,019,807.72 568,431.64 1.28 2,406.66 2_MWD+IFR2+MS+Sag(2) 6,822.07 86.18 286.56 4,394.23 4,345.88 3,669.41 -973.58 6,019,816.58 568,399.89 2.76 2,439.23 2_MWD+IFR2+MS+Sag(2) 6,886.99 86.86 286.28 4,398.17 4,349.82 3,687.73 -1,035.74 6,019,834.32 568,337.57 1.13 2,503.28 2_MWD+IFR2+MS+Sag(2) 6,949.25 86.36 287.01 4,401.85 4,353.50 3,705.53 -1,095.29 6,019,851.56 568,277.87 1.42 2,564.75 2_MWD+IFR2+MS+Sag(2) 7,013.22 85.13 288.32 4,406.60 4,358.25 3,724.89 -1,156.07 6,019,870.35 568,216.91 2.80 2,628.00 2_MWD+IFR2+MS+Sag (2) 7,077.68 84.50 288.55 4,412.43 4,364.08 3,745.19 -1,216.97 6,019,890.08 568,155.83 1.04 2,691.76 2_MWD+IFR2+MS+Sag (2) 7,140.53 85.31 289.45 4,418.01 4,369.66 3,765.57 -1,276.16 6,019,909.91 568,096.46 1.92 2,754.01 2_MWD+IFR2+MS+Sag (2) 7,203.50 87.61 291.64 4,421.90 4,373.55 3,787.63 -1,335.01 6,019,931.41 568,037.42 5.04 2,816.65 2_MWD+IFR2+MS+Sag(2) 7,266.61 87.85 293.16 4,424.40 4,376.05 3,811.66 -1,393.31 6,019,954.89 567,978.90 2.44 2,879.64 2_MWD+IFR2+MS+Sag(2) 7,330.02 89.52 294.78 4,425.85 4,377.50 3,837.41 -1,451.23 6,019,980.10 567,920.75 3.67 2,943.01 2_MWD+IFR2+MS+Sag(2) 7,393.99 90.07 295.62 4,426.08 4,377.73 3,864.65 -1,509.11 6,020,006.80 567,862.62 1.57 3,006.98 2_MWD+IFR2+MS+Sag(2) 7,456.84 90.26 295.89 4,425.90 4,377.55 3,891.96 -1,565.72 6,020,033.57 567,805.77 0.53 3,069.83 2_MWD+IFR2+MS+Sag(2) 7,520.09 92.61 296.31 4,424.32 4,375.97 3,919.77 -1,622.49 6,020,060.86 567,748.74 3.77 3,133.04 2_MWD+IFR2+MS+Sag(2) 7,582.96 92.98 296.82 4,421.25 4,372.90 3,947.85 -1,678.66 6,020,088.41 567,692.32 1.00 3,195.82 2_MWD+IFR2+MS+Sag(2) 7,645.85 92.73 296.05 4,418.12 4,369.77 3,975.82 -1,734.90 6,020,115.85 567,635.82 1.29 3,258.61 2_MWD+IFR2+MS+Sag(2) 7,708.96 91.55 295.86 4,415.76 4,367.41 4,003.42 -1,791.61 6,020,142.92 567,578.87 1.89 3,321.67 2_MWD+IFR2+MS+Sag(2) 7,772.23 89.88 294.77 4,414.97 4,366.62 4,030.47 -1,848.80 6,020,169.43 567,521.44 3.15 3,384.93 2_MWD+IFR2+MS+Sag(2) 7,836.06 90.38 294.24 4,414.83 4,366.48 4,056.94 -1,906.87 6,020,195.36 567,463.12 1.14 3,448.76 2_MWD+IFR2+MS+Sag(2) 7,899.66 91.31 295.54 4,413.89 4,365.54 4,083.71 -1,964.56 6,020,221.58 567,405.19 2.51 3,512.35 2_MWD+IFR2+MS+Sag (2) 7,962.52 90.38 295.65 4,412.96 4,364.61 4,110.86 -2,021.24 6,020,248.20 567,348.26 1.49 3,575.20 2_MWD+IFR2+MS+Sag(2) 8,025.67 90.88 295.92 4,412.27 4,363.92 4,138.33 -2,078.10 6,020,275.14 567,291.16 0.90 3,638.34 2_MWD+IFR2+MS+Sag(2) 8,088.95 90.38 294.77 4,411.57 4,363.22 4,165.41 -2,135.29 6,020,301.69 567,233.73 1.98 3,701.62 2_MWD+IFR2+MS+Sag(2) 8,152.37 90.19 292.23 4,411.26 4,362.91 4,190.70 -2,193.44 6,020,326.43 567,175.34 4.02 3,765.00 2_MWD+IFR2+MS+Sag (2) 8,215.99 90.50 289.69 4,410.87 4,362.52 4,213.46 -2,252.85 6,020,348.63 567,115.74 4.02 3,828.45 2_MWD+IFR2+MS+Sag (2) 8,278.66 90.13 290.33 4,410.53 4,362.18 4,234.90 -2,311.73 6,020,369.52 567,056.66 1.18 3,890.87 2_MWD+IFR2+MS+Sag(2) 2/252019 5:36:05PM Page 9 COMPASS 5000.15 Build 91 Survey MD Inc (usft) (°) 8,342.08 90.13 8,405.37 91.37 8,469.39 91.86 8,532.81 93.11 8,596.53 92.91 8,660.11 92.66 8,723.73 90.25 8,788.02 90.26 8,851.73 90.01 8,915.61 91.49 8,979.44 91.37 9,043.08 92.36 9,106.68 93.10 9,170.86 92.67 9,233.78 92.29 9,297.61 92.42 9,362.15 92.30 9,425.90 92.23 9,489.85 91.49 9,553.63 90.44 9,617.15 88.95 9,680.86 88.84 9,744.48 90.01 9,808.78 90.75 9,872.39 90.26 9,935.62 88.77 9,999.25 88.03 10,063.52 88.03 Azi 290.29 289.81 289.28 289.36 289.81 289.65 284.44 281.20 280.32 283.37 282.84 284.38 286.63 289.14 291.25 294.30 297.09 300.00 302.06 304.34 306.51 308.33 311.03 313.06 313.78 312.54 311.82 310.83 10,126.99 88.09 309.33 10,190.74 89.58 307.81 10,254.32 91.38 306.30 10,318.28 91.06 306.09 10,382.21 90.94 306.24 10,446.06 90.56 306.00 10,509.90 90.63 304.04 10,573.00 88.03 304.77 10,636.05 87.97 306.08 10,701.16 89.70 306.56 10,762.20 90.88 304.68 10,824.98 90.50 303.07 TVD (usft) 4,410.38 4,409.56 4,407.75 4,405.00 4,401.66 4,398.57 4,396.95 4,396.66 4,396.51 4,395.68 4,394.08 4,392.01 4,388.98 4,385.75 4,383.03 4,380.41 4,377.75 4,375.23 4,373.15 4,372.08 4,372.42 4,373.64 4,374.28 4,373.86 4,373.30 4,373.83 4,375.61 4,377.82 4,379.97 4,381.26 4,380.73 4,379.37 4,378.25 4,377.42 4,376.75 4,377.49 4,379.69 4,381.02 4,380.71 4,379.95 TVDSS (usft) 4,362.03 4,361.21 4,359.40 4,356.65 4,353.31 4,350.22 4,348.60 4,348.31 4,348.16 4,347.33 4,345.73 4,343.66 4,340.63 4,337.40 4,334.68 4,332.06 4,329.40 4,326.88 4,324.80 4,323.73 4,324.07 4,325.29 4,325.93 4,325.51 4,324.95 4,325.48 4,327.26 4,329.47 4,331.62 4,332.91 4,332.38 4,331.02 4,329.90 4,329.07 4,328.40 4,329.14 4,331.34 4,332.67 4,332.36 4,331.60 +N1 -S (usft) 4,256.91 4,278.61 4,300.02 4,320.98 4,342.31 4,363.75 4,382.38 4,396.64 4,408.54 4,421.65 4,436.12 4,451.08 4,468.06 4,487.75 4,509.45 4,534.13 4,562.09 4,592.52 4,625.47 4,660.39 4,697.20 4,735.91 4,776.52 4,819.58 4,863.30 4,906.55 4,949.26 4,991.67 5,032.51 5,072.25 5,110.55 5,148.32 5,186.04 5,223.67 5,260.30 5,295.95 5,332.47 5,371.03 5,406.58 5,441.57 Map +E1 -W Northing (usft) (ft) -2,371.21 6,020,390.98 -2,430.66 6,020,412.12 -2,490.96 6,020,432.96 -2,550.75 6,020,453.36 -2,610.70 6,020,474.13 -2,670.48 6,020,495.01 -2,731.26 6,020,513.08 -2,793.94 6,020,526.75 -2,856.53 6,020,538.06 -2,919.04 6,020,550.59 -2,981.18 6,020,564.47 -3,043.00 6,020,578.86 -3,104.21 6,020,595.27 -3,165.21 6,020,614.38 -3,224.20 6,020,635.53 -3,283.00 6,020,659.67 -3,341.10 6,020,687.08 -3,397.05 6,020,716.99 -3,451.82 6,020,749.42 -3,505.17 6,020,783.83 -3,556.93 6,020,820.16 -3,607.52 6,020,858.39 -3,656.47 6,020,898.54 -3,704.22 6,020,941.15 -3,750.42 6,020,984.43 -3,796.54 6,021,027.25 -3,843.67 6,021,069.51 -3,891.91 6,021,111.47 -3,940.44 6,021,151.85 -3,990.27 6,021,191.12 -4,041.01 6, 021, 228.95 -4,092.61 6,021,266.22 -4,144.22 6,021,303.46 -4,195.79 6,021,340.61 -4,248.06 6,021,376.75 4,300.12 6,021,411.91 -4,351.46 6,021,447.95 -4,403.91 6,021,486.01 4,453.53 6,021,521.09 4,505.64 6,021,555.58 Map Easting DLS (ft) ("1100') 566,996.99 0.06 566,937.34 2.10 566,876.85 1.13 566,816.87 1.98 566,756.73 0.77 566,696.76 0.47 566,635.81 9.02 566,573.01 5.04 566,510.32 1.44 566,447.70 5.31 566,385.43 0.85 566,323.48 2.88 566,262.12 3.72 566,200.95 3.96 566,141.76 3.40 566,082.74 4.78 566,024.38 4.32 565,968.16 4.56 565,913.09 3.42 565,859.42 3.94 565,807.33 4.14 565,756.39 2.86 565,707.06 4.63 565,658.92 3.36 565,612.32 1.37 565,565.80 3.07 565,518.28 1.62 565,469.65 1.54 Vertical Section (ft) Survey Tool Name 3,954.07 2_MWD+IFR2+MS+Sag (2)M 4,017.10 2_WD+IFR2+MS+Sag(2) 4,080.79 2_MWD+IFR2+MS+Sag (2) 4,143.83 2_MWD+IFR2+MS+Sag(2) 4,207.16 2_MWD+IFR2+MS+Sag(2) 4,270.39 2_MWD+IFR2+MS+Sag (2) 4,333.33 2_MWD+IFR2+MS+Sag (2) 4,396.14 2_MWD+IFR2+MS+Sag(2) 4,457.85 2_MWD+IFR2+MS+Sag(2) 4,520.01 2_MWD+IFR2+MS+Sag (2) 4,582.42 2_MWD+IFR2+MS+Sag(2) 4,644.75 2_MWD+IFR2+MS+Sag (2) 4,707.38 2_MWD+IFR2+MS+Sag(2) 4,770.96 2_MWD+IFR2+MS+Sag(2) 4,833.59 2_MWD+IFR2+MS+Sag (2) 4,897.30 2_MWD+IFR2+MS+Sag (2) 4,961.78 2_MWD+IFR2+MS+Sag(2) 5,025.36 2_MWD+IFR2+MS+Sag (2) 5,088.93 2_MWD+IFR2+MS+Sag (2) 5,152.06 2 MWD+IFR2+MS+Sag (2) 5,214.55 2_MWD+IFR2+MS+Sag (2) 5,276.79 2_MWD+IFR2+MS+Sag(2) 5,338.35 2_MWD+IFR2+MS+Sag(2) 5,399.86 2_MWD+IFR2+MS+Sag(2) 5,460.25 2_MWD+IFR2+MS+Sag(2) 5,520.37 2_MWD+IFR2+MS+Sag (2) 5,581.18 2_MWD+IFR2+MS+Sag(2) 5,642.85 2 MWD+IFR2+MS+Sag(2) 565,420.74 2.36 Halliburton 565,370.55 3.34 5,766.12 2MWD+IFR2+MS+Sag (2) Definitive Survey Report 3.70 Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual IRKS @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US+CANADA Survey MD Inc (usft) (°) 8,342.08 90.13 8,405.37 91.37 8,469.39 91.86 8,532.81 93.11 8,596.53 92.91 8,660.11 92.66 8,723.73 90.25 8,788.02 90.26 8,851.73 90.01 8,915.61 91.49 8,979.44 91.37 9,043.08 92.36 9,106.68 93.10 9,170.86 92.67 9,233.78 92.29 9,297.61 92.42 9,362.15 92.30 9,425.90 92.23 9,489.85 91.49 9,553.63 90.44 9,617.15 88.95 9,680.86 88.84 9,744.48 90.01 9,808.78 90.75 9,872.39 90.26 9,935.62 88.77 9,999.25 88.03 10,063.52 88.03 Azi 290.29 289.81 289.28 289.36 289.81 289.65 284.44 281.20 280.32 283.37 282.84 284.38 286.63 289.14 291.25 294.30 297.09 300.00 302.06 304.34 306.51 308.33 311.03 313.06 313.78 312.54 311.82 310.83 10,126.99 88.09 309.33 10,190.74 89.58 307.81 10,254.32 91.38 306.30 10,318.28 91.06 306.09 10,382.21 90.94 306.24 10,446.06 90.56 306.00 10,509.90 90.63 304.04 10,573.00 88.03 304.77 10,636.05 87.97 306.08 10,701.16 89.70 306.56 10,762.20 90.88 304.68 10,824.98 90.50 303.07 TVD (usft) 4,410.38 4,409.56 4,407.75 4,405.00 4,401.66 4,398.57 4,396.95 4,396.66 4,396.51 4,395.68 4,394.08 4,392.01 4,388.98 4,385.75 4,383.03 4,380.41 4,377.75 4,375.23 4,373.15 4,372.08 4,372.42 4,373.64 4,374.28 4,373.86 4,373.30 4,373.83 4,375.61 4,377.82 4,379.97 4,381.26 4,380.73 4,379.37 4,378.25 4,377.42 4,376.75 4,377.49 4,379.69 4,381.02 4,380.71 4,379.95 TVDSS (usft) 4,362.03 4,361.21 4,359.40 4,356.65 4,353.31 4,350.22 4,348.60 4,348.31 4,348.16 4,347.33 4,345.73 4,343.66 4,340.63 4,337.40 4,334.68 4,332.06 4,329.40 4,326.88 4,324.80 4,323.73 4,324.07 4,325.29 4,325.93 4,325.51 4,324.95 4,325.48 4,327.26 4,329.47 4,331.62 4,332.91 4,332.38 4,331.02 4,329.90 4,329.07 4,328.40 4,329.14 4,331.34 4,332.67 4,332.36 4,331.60 +N1 -S (usft) 4,256.91 4,278.61 4,300.02 4,320.98 4,342.31 4,363.75 4,382.38 4,396.64 4,408.54 4,421.65 4,436.12 4,451.08 4,468.06 4,487.75 4,509.45 4,534.13 4,562.09 4,592.52 4,625.47 4,660.39 4,697.20 4,735.91 4,776.52 4,819.58 4,863.30 4,906.55 4,949.26 4,991.67 5,032.51 5,072.25 5,110.55 5,148.32 5,186.04 5,223.67 5,260.30 5,295.95 5,332.47 5,371.03 5,406.58 5,441.57 Map +E1 -W Northing (usft) (ft) -2,371.21 6,020,390.98 -2,430.66 6,020,412.12 -2,490.96 6,020,432.96 -2,550.75 6,020,453.36 -2,610.70 6,020,474.13 -2,670.48 6,020,495.01 -2,731.26 6,020,513.08 -2,793.94 6,020,526.75 -2,856.53 6,020,538.06 -2,919.04 6,020,550.59 -2,981.18 6,020,564.47 -3,043.00 6,020,578.86 -3,104.21 6,020,595.27 -3,165.21 6,020,614.38 -3,224.20 6,020,635.53 -3,283.00 6,020,659.67 -3,341.10 6,020,687.08 -3,397.05 6,020,716.99 -3,451.82 6,020,749.42 -3,505.17 6,020,783.83 -3,556.93 6,020,820.16 -3,607.52 6,020,858.39 -3,656.47 6,020,898.54 -3,704.22 6,020,941.15 -3,750.42 6,020,984.43 -3,796.54 6,021,027.25 -3,843.67 6,021,069.51 -3,891.91 6,021,111.47 -3,940.44 6,021,151.85 -3,990.27 6,021,191.12 -4,041.01 6, 021, 228.95 -4,092.61 6,021,266.22 -4,144.22 6,021,303.46 -4,195.79 6,021,340.61 -4,248.06 6,021,376.75 4,300.12 6,021,411.91 -4,351.46 6,021,447.95 -4,403.91 6,021,486.01 4,453.53 6,021,521.09 4,505.64 6,021,555.58 Map Easting DLS (ft) ("1100') 566,996.99 0.06 566,937.34 2.10 566,876.85 1.13 566,816.87 1.98 566,756.73 0.77 566,696.76 0.47 566,635.81 9.02 566,573.01 5.04 566,510.32 1.44 566,447.70 5.31 566,385.43 0.85 566,323.48 2.88 566,262.12 3.72 566,200.95 3.96 566,141.76 3.40 566,082.74 4.78 566,024.38 4.32 565,968.16 4.56 565,913.09 3.42 565,859.42 3.94 565,807.33 4.14 565,756.39 2.86 565,707.06 4.63 565,658.92 3.36 565,612.32 1.37 565,565.80 3.07 565,518.28 1.62 565,469.65 1.54 Vertical Section (ft) Survey Tool Name 3,954.07 2_MWD+IFR2+MS+Sag (2)M 4,017.10 2_WD+IFR2+MS+Sag(2) 4,080.79 2_MWD+IFR2+MS+Sag (2) 4,143.83 2_MWD+IFR2+MS+Sag(2) 4,207.16 2_MWD+IFR2+MS+Sag(2) 4,270.39 2_MWD+IFR2+MS+Sag (2) 4,333.33 2_MWD+IFR2+MS+Sag (2) 4,396.14 2_MWD+IFR2+MS+Sag(2) 4,457.85 2_MWD+IFR2+MS+Sag(2) 4,520.01 2_MWD+IFR2+MS+Sag (2) 4,582.42 2_MWD+IFR2+MS+Sag(2) 4,644.75 2_MWD+IFR2+MS+Sag (2) 4,707.38 2_MWD+IFR2+MS+Sag(2) 4,770.96 2_MWD+IFR2+MS+Sag(2) 4,833.59 2_MWD+IFR2+MS+Sag (2) 4,897.30 2_MWD+IFR2+MS+Sag (2) 4,961.78 2_MWD+IFR2+MS+Sag(2) 5,025.36 2_MWD+IFR2+MS+Sag (2) 5,088.93 2_MWD+IFR2+MS+Sag (2) 5,152.06 2 MWD+IFR2+MS+Sag (2) 5,214.55 2_MWD+IFR2+MS+Sag (2) 5,276.79 2_MWD+IFR2+MS+Sag(2) 5,338.35 2_MWD+IFR2+MS+Sag(2) 5,399.86 2_MWD+IFR2+MS+Sag(2) 5,460.25 2_MWD+IFR2+MS+Sag(2) 5,520.37 2_MWD+IFR2+MS+Sag (2) 5,581.18 2_MWD+IFR2+MS+Sag(2) 5,642.85 2 MWD+IFR2+MS+Sag(2) 565,420.74 2.36 5,704.14 2_MWD+IFR2+MS+Sag (2) 565,370.55 3.34 5,766.12 2MWD+IFR2+MS+Sag (2) 565,319.47 3.70 5,828.32 2_MWD+IFR2+MS+Sag (2)M 565,267.52 0.60 5,891.08 2_WD+IFR2+MS+Sag(2) 565,215.57 0.30 5,953.81 2_MWD+IFR2+MS+Sag(2) 565,163.65 0.70 6,016.48 2_MWD+IFR2+MS+Sag (2)M 565,111.04 3.07 6,079.37 2_WD+IFR2+MS+Sag (2) 565,058.66 4.28 6,141.63 2_MWD+IFR2+MS+Sag (3) 565,006.98 2.08 6,203.62 2_MWD+IFR2+MS+Sa9(3) 564,954.19 2.76 6,267.48 2_MWD+IFR2+MS+Sag (3) 564,904.25 3.64 6,327.49 2_MWD+IFR2+MS+Sag(3) 564,851.81 2.63 6,389.53 2_MWD+IFR2+MS+Sag(3) 2/252019 5:36:05PM Page 10 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual IRKS @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (°) (`) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,890.41 90.69 300.97 4,379.27 4,330.92 5,476.25 -4,551.11 6,021,589.75 564,796.02 3.22 6,454.48 2_MWD+IFR2+MS+Sag (3) 10,953.55 90.32 299.16 4,378.71 4,330.36 5,507.88 -4,615.75 6,021,620.87 564,741.10 2.93 6,517.38 2_MWD+IFR2+MS+Sag (3) 11,017.37 90.75 296.73 4,378.12 4,329.77 5,537.79 -4,672.13 6,021,650.24 564,684.45 3.87 6,581.12 2_MWD+IFR2+MS+Sag(3) 11,080.62 91.81 294.66 4,376.71 4,328.36 5,565.20 4,729.10 6,021,677.12 564,627.23 3.68 6,644.34 2_MWD+IFR2+MS+Sag(3) 11,140.94 91.62 292.07 4,374.90 4,326.55 5,589.11 -4,784.45 6,021,700.51 564,571.67 4.30 6,704.60 2_MWD+IFR2+MS+Sag(3) 11,207.13 93.23 291.78 4,372.10 4,323.75 5,613.80 -4,845.79 6,021,724.63 564,510.10 2.47 6,770.63 2_MWD+IFR2+MS+Sag (3) 11,270.75 92.98 292.00 4,368.65 4,320.30 5,637.49 4,904.74 6,021,747.76 564,450.94 0.52 6,834.05 2_MWD+IFR2+MS+Sag (3) 11,334.86 91.92 291.35 4,365.91 4,317.56 5,661.14 -4,964.26 6,021,770.86 564,391.21 1.94 6,897.99 2_MWD+IFR2+MS+Sag(3) 11,398.65 91.86 292.57 4,363.81 4,315.46 5,684.99 -5,023.39 6,021,794.15 564,331.87 1.91 6,961.65 2_MWD+IFR2+MS+Sag(3) 11,462.86 89.82 291.14 4,362.87 4,314.52 5,708.88 -5,082.97 6,021,817.49 564,272.07 3.88 7,025.74 2_MWD+IFR2+MS+Sag(3) 11,526.65 90.01 288.72 4,362.96 4,314.61 5,730.63 -5,142.94 6,021,838.67 564,211.91 3.81 7,089.26 2_MWD+IFR2+MS+Sag (3) 11,590.36 89.08 289.97 4,363.47 4,315.12 5,751.73 -5,203.05 6,021,859.21 564,151.61 2.45 7,152.65 2_MWD+IFR2+MS+Sag(3) 11,654.22 87.84 289.35 4,365.18 4,316.83 5,773.21 -5,263.16 6,021,880.12 564,091.31 2.17 7,216.19 2_MWD+IFR2+MS+Sag (3) 11,718.03 89.09 289.22 4,366.89 4,318.54 5,794.27 -5,323.37 6,021,900.63 564,030.91 1.97 7,279.65 2_MWD+IFR2+MS+Sag(3) 11,781.61 90.39 288.71 4,367.18 4,318.83 5,814.93 -5,383.50 6,021,920.73 563,970.60 2.20 7,342.86 2_MWD+IFR2+MS+Sag (3) 11,845.06 91.50 288.23 4,366.14 4,317.79 5,835.03 -5,443.67 6,021,940.26 563,910.25 1.91 7,405.87 2_MWD+IFR2+MS+Sag (3) 11,909.15 89.63 286.88 4,365.50 4,317.15 5,854.36 -5,504.77 6,021,959.02 563,848.98 3.60 7,469.40 2_MWD+IFR2+MS+Sag(3) 11,972.95 89.45 286.12 4,366.02 4,317.67 5,872.48 -5,565.94 6,021,976.56 563,787.65 1.22 7,532.47 2_MWD+IFR2+MS+Sag(3) 12,036.75 88.90 288.79 4,366.93 4,318.58 5,891.61 -5,626.79 6,021,995.13 563,726.63 4.27 7,595.69 2_MWD+IFR2+MS+Sag(3) 12,099.22 88.59 290.67 4,368.30 4,319.95 5,912.70 -5,685.57 6,022,015.66 563,667.66 3.05 7,657.87 2_MWD+IFR2+MS+Sag (3) 12,161.85 88.28 292.51 4,370.01 4,321.66 5,935.73 -5,743.78 6,022,038.15 563,609.24 2.98 7,720.35 2_MWD+IFR2+MS+Sag(3) 12,227.19 86.92 292.89 4,372.75 4,324.40 5,960.93 -5,804.01 6,022,062.78 563,548.79 2.16 7,785.57 2_MWD+IFR2+MS+Sag (3) 12,291.25 87.48 293.55 4,375.88 4,327.53 5,986.15 -5,862.81 6,022,087.45 563,489.76 1.35 7,849.52 2_MWD+IFR2+MS+Sag(3) 12,354.73 87.85 295.20 4,378.47 4,330.12 6,012.33 -5,920.58 6,022,113.09 563,431.75 2.66 7,912.94 2_MWD+IFR2+MS+Sag (3) 12,418.47 87.85 295.28 4,380.86 4,332.51 6,039.49 -5,978.19 6,022,139.71 563,373.89 0.13 7,976.64 2_MWD+IFR2+MS+Sag (3) 12,482.03 89.09 295.16 4,382.55 4,334.20 6,066.56 -6,035.67 6,022,166.24 563,316.17 1.96 8,040.17 2_MWD+IFR2+MS+Sag (3) 12,544.87 90.20 295.26 4,382.94 4,334.59 6,093.33 -6,092.53 6,022,192.47 563,259.08 1.77 8,103.01 2_MWD+IFR2+MS+Sag(3) 12,608.69 89.76 295.20 4,382.97 4,334.62 6,120.53 -6,150.26 6,022,219.13 563,201.10 0.70 8,166.83 2_MWD+IFR2+MS+Sag(3) 12,672.19 89.70 295.17 4,383.26 4,334.91 6,147.55 -6,207.72 6,022,245.62 563,143.39 0.11 8,230.33 2_MWD+IFR2+MS+Sag(3) 12,735.95 88.65 295.49 4,384.18 4,335.83 6,174.83 -6,265.34 6,022,272.35 563,085.52 1.72 8,294.08 2_MWD+IFR2+MS+Sag (3) 12,799.29 88.53 296.06 4,385.74 4,337.39 6,202.36 -6,322.36 6,022,299.35 563,028.25 0.92 8,357.40 2_MWD+IFR2+MS+Sag (3) 12,863.07 88.03 296.18 4,387.66 4,339.31 6,230.43 -6,379.60 6,022,326.88 562,970.76 0.81 8,421.14 2_MWD+IFR2+MS+Sag (3) 12,925.62 88.41 296.04 4,389.60 4,341.25 6,257.94 -6,435.74 6,022,353.87 562,914.37 0.65 8,483.65 2_MWD+IFR2+MS+Sag(3) 12,990.38 89.89 296.86 4,390.56 4,342.21 6,286.78 -6,493.72 6,022,382.17 562,856.14 2.61 8,548.38 2_MWD+IFR2+MS+Sag (3) 13,052.01 92.18 297.40 4,389.45 4,341.10 6,314.88 -6,548.55 6,022,409.75 562,801.05 3.82 8,609.96 2_MWD+IFR2+MS+Sag (3) 13,117.36 92.05 295.70 4,387.03 4,338.68 6,344.07 -6,606.97 6,022,438.39 562,742.37 2.61 8,675.24 2_MWD+IFR2+MS+Sag(3) 13,180.76 90.19 294.57 4,385.79 4,337.44 6,370.99 -6,664.35 6,022,464.77 562,684.74 3.43 8,738.63 2_MWD+IFR2+MS+Sag(3) 13,242.78 90.75 293.44 4,385.29 4,336.94 6,396.22 -6,721.01 6,022,489.47 562,627.86 2.03 8,800.63 2_MWD+IFR2+MS+Sag(3) 13,307.45 91.19 294.17 4,384.19 4,335.84 6,422.32 -6,780.16 6,022,515.02 562,568.47 1.32 8,865.27 2_MWD+IFR2+MS+Sag (3) 13,370.75 91.62 294.63 4,382.64 4,334.29 6,448.46 -6,837.79 6,022,540.62 562,510.60 0.99 8,928.55 2_MWD+IFR2+MS+Sag(3) 71152019 5.36:05PM Page 11 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36 Survey Calculation Method: Minimum Curvature Design: MPU E-36 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) V) (`) (usft) (usft) (usft) (usft) (ft) (ft) ('/100'j (ft) Survey Tool Name 13,434.15 91.68 294.62 4,380.81 4,332.46 6,474.87 -6,895.40 6,022,566.48 562,452.75 0.10 8,991.92 2_MWD+IFR2+MS+Sag(3) 13,497.23 90.81 294.22 4,379.44 4,331.09 6,500.94 -6,952.83 6,022,592.02 562,395.10 1.52 9,054.98 2_MWD+IFR2+MS+Sag (3) 13,560.62 89.51 294.16 4,379.27 4,330.92 6,526.91 -7,010.65 6,022,617.45 562,337.04 2.05 9,118.36 2_MWD+IFR2+MS+Sag (3) 13,624.79 88.65 294.59 4,380.30 4,331.95 6,553.39 -7,069.09 6,022,643.38 562,278.36 1.50 9,182.52 2 MWD+IFR2+MS+Sag (3) 13,688.96 88.90 294.15 4,381.67 4,333.32 6,579.86 -7,127.53 6,022,669.30 562,219.68 0.79 9,246.67 2_MWD+IFR2+MS+Sag (3) 13,752.63 87.78 294.05 4,383.51 4,335.16 6,605.85 -7,185.62 6,022,694.75 562,161.35 1.77 9,310.30 2_MWD+IFR2+MS+Sag (3) 13,816.81 88.96 294.35 4,385.34 4,336.99 6,632.15 -7,244.14 6,022,720.50 562,102.60 1.90 9,374.44 2_MWD+IFR2+MS+Sag (3) 13,880.05 90.14 295.03 4,385.84 4,337.49 6,658.56 -7,301.59 6,022,746.37 562,044.91 2.15 9,437.68 2_MWD+IFR2+MS+Sag (3) 13,944.01 89.76 295.13 4,385.89 4,337.54 6,685.68 -7,359.52 6,022,772.94 561,986.73 0.61 9,501.64 2 MWD+IFR2+MS+Sag (3) 14,008.34 87.47 294.40 4,387.45 4,339.10 6,712.61 -7,417.92 6,022,799.33 561,928.10 3.74 9,565.94 2_MWD+IFR2+MS+Sag (3) 14,071.76 84.75 294.19 4,391.75 4,343.40 6,738.64 -7,475.58 6,022,824.82 561,870.20 4.30 9,629.20 2_MWD+IFR2+MS+Sag (3) 14,135.62 81.76 294.02 4,399.25 4,350.90 6,764.54 -7,533.46 6,022,850.18 561,812.09 4.69 9,692.61 2_MWD+IFR2+MS+Sag (3) 14,199.62 78.95 293.99 4,409.97 4,361.62 6,790.21 -7,591.09 6,022,875.30 561,754.22 4.39 9,755.68 2_MWD+IFR2+MS+Sag (3) 14,263.53 77.88 293.85 4,422.80 4,374.45 6,815.59 -7,648.32 6,022,900.15 561,696.76 1.69 9,818.28 2_MWD+IFR2+MS+Sag (3) 14,326.91 78.26 294.61 4,435.91 4,387.56 6,841.04 -7,704.87 6,022,925.07 561,639.99 1.32 9,880.28 2_MWD+IFR2+MS+Sag(3) 14,390.16 78.27 294.99 4,448.77 4,400.42 6,867.02 -7,761.09 6,022,950.52 561,583.54 0.59 9,942.21 2_MWD+IFR2+MS+Sag(3) 14,453.31 78.00 295.80 4,461.75 4,413.40 6,893.52 -7,816.92 6,022,976.50 561,527.47 1.33 10,004.00 2_MWD+IFR2+MS+Sag(3) 14,516.85 78.20 296.38 4,474.86 4,426.51 6,920.86 -7,872.76 6,023,003.32 561,471.38 0.95 10,066.17 2_MWD+IFR2+MS+Sag(3) 14,533.92 78.14 296.82 4,478.36 4,430.01 6,928.34 -7,887.70 6,023,010.66 561,456.38 2.55 10,082.87 2_MWD+IFR2+MS+Sag(3) 14,605.00 78.14 296.82 4,492.96 4,444.61 6,959.73 -7,949.77 6,023,041.46 561,394.01 0.00 10,152.40 PROJECTEDto TD Checked By: Chelsea Wright Approved By: Mitch Laird - - Date: 2-25-2019 2/252019 5:36:05PM Page 12 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Pointn M Pt E Pad q fpx MPU E-36PB1 1 500292362070 �I Sperry Drilling Definitive Survey Report 25 February, 2019 HALLIBURTON 6porry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-36PB1 Database: NORTH US+CANADA 'roject Milne Point, ACT, MILNE POINT Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU E-36 MPU E-36PB1 Date Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore MPU E-36PB1 (usft) (usft) 6,016,156.74 usfi Latitude: 70.454 569,407.52 usfi Longitude: -149.434 0.00 usfi Ground Level: 21.70 usft Magnetics Model Name Sample Date Declination (1) BGGM2018 1/29/2019 Design MPU E-36PB1 Date Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/ -S (usft) (usft) 26.65 0.00 Dip Angle Field Strength (1) (nT) 16.87 80.97 57,440.44067207 Tie On Depth: 26.65 +E/ -W Direction (usft) (1) 0.00 295.12 Survey Program Date 2/23/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 86.43 6,678.86 E-36PB1 SDI Survey - surface section - (2_Gyro-NS-CT_Drill pipe H037Ga: Continuous on wireline in drill pipe 02/18/2019 6,789.02 11,207.71 MPU E-36PB1 MWD IFR2 Tied into Corr 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 02/07/2019 --- Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +FJ -W Northing Easting DLS Section (usft) (1 0 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.65 0.00 0.00 26.65 -21.70 0.00 0.00 6,016,156.74 569,407.52 0.00 0.00 UNDEFINED 86.43 0.67 66.64 86.43 38.08 0.14 0.32 6,016,156.88 569,407.84 1.12 -0.23 2_Gyro-NS-CT_Drill pipe (1) 90.00 0.46 82.15 90.00 41.65 0.15 0.35 6,016,156.89 569,407.87 7.23 -0.26 2_Gyn,NS-CT_Dril pipe (1) 115.00 0.21 112.18 115.00 66.65 0.15 0.50 6,016,156.89 569,408.01 1.19 -0.39 2_Gyro-NS-CT_on[[ pipe (1) 140.00 0.17 173.63 140.00 91.65 0.09 0.54 6,016,156.84 569,408.06 0.79 -0.45 2_Gyro-NS-CT_DO pipe (1) 165.00 0.17 143.36 165.00 116.65 0.02 0.57 6,016,156.77 569,408.09 0.36 -0.50 2_Gyro-NS-CT_Drill pipe (1) 190.00 0.16 128.32 190.00 141.65 -0.03 0.62 6,016,156.72 569,408.14 0.18 -0.57 2_Gyro-NS-CT_Dn11 pipe (1) 215.00 0.27 109.93 215.00 166.65 -0.07 0.70 6,016,156.68 569,408.22 0.51 -0.66 2_Gyro-NS-CT_Drill pipe (1) 240.00 0.31 87.47 240.00 191.65 -0.09 0.82 6,016,156.66 569,408.34 0.48 -0.78 2_Gyro-NS-CT_Drill pipe (1) 265.00 0.49 79.76 265.00 216.65 -0.06 1.00 6,016,156.69 569,408.52 0.75 -0.93 2_Gyro-NS-CT_Drill pipe (1) 290.00 1.05 71.59 289.99 241.64 0.03 1.32 6,016,156.78 569,408.84 2.28 -1.18 2 -Gyro -1,18 -CT -Drill pipe (1) 315.00 1.48 67.92 314.99 266.64 0.22 1.84 6,016,156.98 569,409.35 1.75 -1.57 2_Gyro-NS-CT_Dnll pipe (1) 340.00 1.68 58.19 339.98 291.63 0.54 2.45 6,016,157.30 569,409.96 1.34 -1.99 2_Gyra-NS-CT_Ddli pipe (1) 2252019 5:33:47PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36PB1 Survey Calculation Method: Minimum Curvature Design: MPU E -36P81 Database: NORTH US + CANADA Survey - �_-- Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) (-/too.) (ft) Survey Tool Name 365.00 2.36 58.12 364.96 316.61 1.00 3.20 6,016,157.77 569,410.71 2.72 -2.47 2_Gyro-NS-CT_Drill pipe (1) 390.00 3.22 56.73 389.93 341.58 1.66 4.22 6,016,158.44 569,411.72 3.45 -3.12 2 -Gyro -NS -CT Drill pipe (1) 415.00 4.04 52.18 414.88 366.53 2.58 5.50 6,016,159.37 569,413.00 3.47 -3.88 2_Gyro-NS-CT_Dnll pipe (1) 440.00 4.75 49.83 439.81 391.46 3.79 6.99 6,016,160.60 569,414.47 2.93 -4.72 2_Gyro-NS-CT_Dnll pipe (1) 465.00 5.40 46.99 464.71 416.36 5.26 8.64 6,016,162.08 569,416.11 2.79 -5.59 2_Gyro-NS-CT_Drill pipe (1) 490.00 5.95 44.37 489.59 441.24 6.99 10.41 6,016,163.83 569,417.86 2.43 -6.45 2_Gyro-NS-CT_Drill pipe (1) 515.00 6.63 42.52 514.44 466.09 8.98 12.29 6,016,165.83 569,419.72 2.84 -7.31 2_Gyro-NS-GT_Drill pipe (1) 540.00 7.52 40.72 539.25 490.90 11.28 14.33 6,016,168.16 569,421.74 3.67 -8.18 2_Gyro-NS-CT_Drill pipe (1) 565.00 8.52 38.64 564.00 515.65 13.97 16.55 6,016,170.86 569,423.94 4.16 -9.06 2_Gym-NS-CT_Drill pipe (1) 590.00 9.54 37.81 588.69 540.34 17.05 18.98 6,016,173.97 569,426.34 4.11 -9.95 2_Gyro-NS-CT_Drill pipe (1) 615.00 10.47 36.66 613.31 564.96 20.51 21.61 6,016,177.45 569,428.93 3.80 -10.86 2_Gyro-NS-CT_Drill pipe (1) 640.00 11.67 36.10 637.85 589.50 24.38 24.45 6,016,181.34 569,431.74 4.82 -11.79 2_Gyro-NS-CT_Dn1l pipe (1) 665.00 13.16 35.97 662.26 613.91 28.72 27.61 6,016,185.72 569,434.86 5.96 -12.81 2_Gyro-NS-CT_Drill pipe (1) 690.00 14.70 35.49 686.53 638.18 33.61 31.13 6,016,190.64 569,438.33 6.18 -13.92 2_Gyro-NS-CT_Drill pipe (1) 715.00 15.72 35.24 710.65 662.30 38.96 34.92 6,016,196.02 569,442.08 4.09 -15.08 2_Gyro-NS-CT_Drill pipe (1) 740.00 16.83 34.96 734.65 686.30 44.69 38.95 6,016,201.79 569,446.05 4.45 -16.30 2_Gyro-NS-CT_Drill pipe (1) 765.00 17.88 34.91 758.51 710.16 50.80 43.22 6,016,207.94 569,450.26 4.20 -17.57 2_Gyro-NS-CT_Drill pipe (1) 790.00 19.43 34.84 782.19 733.84 57.37 47.79 6,016,214.54 569,454.77 6.20 -18.92 2_Gyro-NS-CT_Drill pipe (1) 815.00 21.67 35.21 805.60 757.25 64.55 52.83 6,016,221.77 569,459.74 8.98 -20.43 2_Gyro-NS-CT_Dri1l pipe (1) 840.00 23.14 35.73 828.71 780.36 72.31 58.36 6,016,229.58 569,465.20 5.93 -22.15 2_Gyro-NS-CT_Drill pipe (1) 865.00 24.40 36.20 851.59 803.24 80.46 64.28 6,016,237.79 569,471.04 5.10 -24.04 2 -Gyro -!\!S -0T Drill pipe (1) 890.00 25.75 36.74 874.24 825.89 88.98 70.58 6,016,246.37 569,477.26 5.48 -26.13 2_Gyro-NS-CT_Drill pipe (1) 915.00 27.25 37.01 896.61 848.26 97.91 77.27 6,016,255.35 569,483.87 6.02 -28.40 2_Gyro-NS-CT_Drill pipe (1) 940.00 29.00 37.39 918.66 870.31 107.29 84.40 6,016,264.80 569,490.91 7.04 -30.87 2_Gyro-NS-CT_Dnll pipe (1) 965.00 29.56 36.38 940.46 892.11 117.07 91.74 6,016,274.65 569,498.15 2.99 -33.36 2_Gyro-NS-CT_Drill pipe (1) 990.00 29.75 36.05 962.19 913.84 127.05 99.04 6,016,284.70 569,505.37 1.00 -35.74 2 -Gym -NS -CT -Drill pipe (1) 1,015.00 30.26 35.40 983.84 935.49 137.20 106.34 6,016,294.91 569,512.57 2.42 -38.04 2_Gyro-NS-CT_Drill pipe (1) 1,040.00 30.56 34.55 1,005.40 957.05 147.57 113.60 6,016,305.35 569,519.73 2.10 40.21 2 Gyro-NS-CT_Dnll pipe (1) 1,065.00 30.74 33.63 1,026.91 978.56 158.13 120.74 6,016,315.97 569,526.77 2.01 42.19 2_Gyro-NS-CT_Drill pipe (1) 1,090.00 30.78 32.30 1,048.39 1,000.04 168.85 127.70 6,016,326.76 569,533.63 2.73 43.94 2_Gyro-NS-CT_Dnl1 pipe (1) 1,115.00 31.02 31.62 1,069.84 1,021.49 179.74 134.49 6,016,337.71 569,540.32 1.69 45.47 2_Gyro-N8-CT_Dri1l pipe (1) 1,140.00 31.23 30.87 1,091.24 1,042.89 190.79 141.19 6,016,348.82 569,546.92 1.76 -46.85 2 -Gyro -NS -CT Drill pipe (1) 1,165.00 31.49 29.99 1,112.59 1,064.24 202.01 147.78 6,016,360.10 569,553.40 2.11 -48.05 2_Gyro-NS-CT_Drill pipe (1) 1,190.00 31.69 28.32 1,133.89 1,085.54 213.45 154.16 6,016,371.59 569,559.67 3.59 -48.97 2_Gyro-NS-CT_Drill pipe (1) 1,215.00 31.84 26.73 1,155.14 1,106.79 225.12 160.24 6,016,383.32 569,565.64 3.40 49.52 2 -Gyro-NS-CT Drill pipe (1) 1,240.00 31.86 25.31 1,176.38 1,128.03 236.97 166.03 6,016,395.23 569,571.32 3.00 -49.73 2_Gyro-NS-CT_Drill pipe (1) 1,265.00 32.02 23.95 1,197.59 1,149.24 248.99 171.54 6,016,407.30 569,576.72 2.95 -49.62 2_Gyro-NS-CT_Dn1l pipe (1) 1,290.00 32.12 22.68 1,218.78 1,170.43 261.18 176.80 6,016,419.53 569,581.86 2.73 -49.20 2 Gyro-NS-CT_Drill pipe (1) 1,315.00 32.37 22.05 1,239.92 1,191.57 273.52 181.87 6,016,431.91 569,586.82 1.68 -48.56 2_Gyro-NS-CTDn1l pipe (1) 1,340.00 32.50 20.96 1,261.02 1,212.67 285.99 186.79 6,016,444.43 569,591.62 2.40 -47.71 2 -Gyro -NS -CT -Drill pipe (1) 21252019 5:33:47PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Rig: MPU E-36 Wellbore: MPU E-36PB1 Design: MPU E-36PB1 survey MD Inc Azi TVD TVDSS +N1 -S (usft) (1) (1) (usft) (usft) (usft) 1,365.00 32.93 20.04 1,282.06 1,233.71 298.65 1,390.00 33.43 18.85 1,302.98 1,254.63 311.55 1,415.00 33.77 17.74 1,323.80 1,275.45 324.69 1,440.00 34.35 16.60 1,344.52 1,296.17 338.06 1,465.00 34.71 15.82 1,365.11 1,316.76 351.67 1,490.00 35.38 14.94 1,385.58 1,337.23 365.51 1,515.00 36.12 14.08 1,405.87 1,357.52 379.65 1,540.00 37.24 12.94 1,425.92 1,377.57 394.17 1,565.00 38.70 11.98 1,445.63 1,397.28 409.19 1,590.00 39.88 10.93 1,464.97 1,416.62 424.71 1,615.00 4123 10.01 1,483.97 1,435.62 440.69 1,640.00 42.52 9.25 1,502.58 1,454.23 457.14 1,665.00 43.30 8.80 1,520.89 1,472.54 473.95 1,690.00 43.95 8.57 1,538.99 1,490.64 491.00 1,715.00 44.04 8.49 1,556.98 1,508.63 508.17 1,740.00 43.84 8.54 1,574.98 1,526.63 525.33 1,765.00 43.65 8.78 1,593.04 1,544.69 542.42 1,790.00 43.19 8.90 1,611.20 1,562.85 559.40 1,815.00 43.02 9.08 1,629.45 1,581.10 576.27 1,840.00 43.26 9.17 1,647.69 1,599.34 593.15 1,865.00 43.88 9.22 1,665.80 1,617.45 610.16 1,890.00 43.89 9.24 1,683.82 1,635.47 627.27 1,915.00 44.43 9.42 1,701.76 1,653.41 644.45 1,940.00 44.41 9.51 1,719.61 1,671.26 661.71 1,965.00 44.28 9.65 1,737.49 1,689.14 678.94 1,990.00 43.93 9.76 1,755.44 1,707.09 696.09 2,015.00 43.74 9.97 1,773.48 1,725.13 713.15 2,040.00 44.00 10.11 1,791.50 1,743.15 730.21 2,065.00 44.11 10.09 1,809.47 1,761.12 747.33 2,090.00 44.03 10.14 1,827.43 1,779.08 764.44 2,115.00 43.91 10.10 1,845.42 1,797.07 781.53 2,140.00 43.87 9.80 1,863.44 1,815.09 798.60 2,165.00 44.08 9.76 1,881.43 1,833.08 815.71 2,190.00 44.26 9.32 1,899.36 1,851.01 832.89 2,215.00 44.39 9.05 1,917.25 1,868.90 850.13 2,240.00 44.62 9.10 1,935.08 1,886.73 867.44 2,265.00 44.64 8.86 1,952.87 1,904.52 884.79 2,290.00 44.99 8.43 1,970.60 1,922.25 902.21 2,315.00 45.34 8.00 1,988.23 1,939.88 919.75 2,340.00 45.20 7.93 2,005.82 1,957.47 937.34 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-36 MPU E-36 Actual RKB @ 48.35usft MPU E-36 Actual RKB @ 48.35usft True Minimum Curvature NORTH US + CANADA 225/1019 5.33:47PM Page 4 COMPASS 5000.15 Build 91 Map Map Vertical +E/ -W Northing Easing DLS Section (usft) (ft) (ft) ('1100) (ft) Survey Tool Name 191.52 6,016,457.13 569,596.23 2.63 46.62 2_Gyro-NS-CT_Drill pipe (1) 196.07 6,016,470.07 569,600.66 3.28 45.27 2 -Gyro -NS -CT Drill pipe (1) 200.41 6,016,483.25 569,604.88 2.81 43.62 2_Gyro-NS-CT_Dnll pipe (1) 204.54 6,016,496.66 569,608.89 3.45 41.69 2_Gyro-NS-CT_Drill pipe (1) 208.50 6,016,510.30 569,612.72 2.28 -39.49 2_Gyro-NS-GT_Dnll pipe (1) 212.31 6,016,524.18 569,616.39 3.36 -37.06 2_Gyro-NS-CT_Drill pipe (1) 215.96 6,016,538.35 569,619.92 3.58 -34.37 2 -Gyro -NS -CT Drill pipe (1) 219.45 6,016,552.90 569,623.27 5.24 -31.36 2 -Gyro -NS -CT Drill pipe (1) 222.77 6,016,567.95 569,626.45 6.30 -27.99 2_Gyro-NS-CT_Drill pipe (1) 225.91 6,016,583.49 569,629.44 5.42 -24.25 2 -Gyro -NS -CT -Drill pipe (1) 228.86 6,016,599.50 569,632.25 5.91 -20.14 2_Gyro-NS-CT_Drill pipe (1) 231.65 6,016,615.98 569,634.88 5.54 -15.68 2_Gyro-NS-CT_Drill pipe (1) 234.32 6,016,632.81 569,637.39 3.35 -10.96 2_Gym-NS-CT_Drill pipe (1) 236.93 6,016,649.88 569,639.84 2.68 -6.08 2_Gyro-NS-CT_Drill pipe (1) 239.50 6,016,667.08 569,642.25 0.42 -1.12 2_Gyro-NS-CT_Drill pipe (1) 242.07 6,016,684.25 569,644.66 0.81 3.84 2_Gyro-NS-CT_Drill pipe (1) 244.67 6,016,701.36 569,647.11 1.01 8.73 2_Gyro-NS-CT_Drill pipe (1) 247.31 6,016,718.37 569,649.59 1.87 13.55 2_Gym-NS-CT_Drill pipe (1) 249.98 6,016,735.26 569,652.10 0.84 18.30 2_Gyro-NS-CT_Drill pipe (1) 252.69 6,016,752.16 569,654.65 0.99 23.01 2_Gyro-NS-CT_Drill pipe (1) 255.45 6,016,769.20 569,657.25 2.48 27.74 2 -Gyro -NS -CT -Drill pipe (1) 258.23 6,016,786.33 569,659.87 0.07 32.48 2_Gyro-NS-CT_Dnll pipe (1) 261.05 6,016,803.54 569,662.53 2.22 37.22 2_Gyro-NS-CT_Drill pipe (1) 263.93 6,016,820.82 569,665.25 0.26 41.94 2_Gyrc-NS-CT_Drill pipe (1) 266.84 6,016,838.08 569,668.00 0.65 46.62 2 -Gyro -NS -CT -Drill pipe (1) 269.77 6,016,855.25 569,670.77 1.43 51.25 2_Gyro-NS-CT_Drill pipe (1) 272.74 6,016,872.33 569,673.58 0.96 55.80 2_Gyro-NS-CT_DOI] pipe (1) 275.76 6,016,889.42 569,676.44 1.11 60.31 2_Gyro-NS-CT_Drill pipe (1) 278.80 6,016,906.56 569,679.32 0.44 64.82 2_Gyro-NS-CT_Drill pipe (1) 281.86 6,016,923.70 569,682.22 0.35 69.32 2 -Gym -NS -CT -Drill pipe (1) 284.91 6,016,940.82 569,685.11 0.49 73.81 2_Gyro-NS-CT_DOI pipe (1) 287.90 6,016,957.91 569,687.94 0.85 78.35 2 -Gyro -NS -CT Drill pipe (1) 290.85 6,016,975.05 569,690.73 0.85 82.94 2_Gyro-N8-CT_DnII pipe (1) 293.74 6,016,992.25 569,693.46 1.42 87.62 2_Gym-NS-CT_Drill pipe (1) 296.53 6,017,009.52 569,696.09 0.92 92.41 2_Gyro-NS-CT_Drill pipe (1) 299.29 6,017,026.85 569,698.69 0.93 97.26 2_Gyro-NS-CT_Drill pipe (1) 302.03 6,017,044.22 569,701.27 0.68 102.14 2_Gyro-NS-CT_Dnll pipe (1) 304.68 6,017,061.66 569,703.75 1.85 107.14 2_Gyro-NS-CT_Dnll pipe (1) 307.21 6,017,079.23 569,706.12 1.86 112.29 2_GymAS-CT_Dnll pipe (1) 309.67 6,017,096.84 569,708.42 0.59 117.53 2 -Gyro -INS -CT -Drill pipe (1) 225/1019 5.33:47PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-36PB1 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 2,365.00 44.78 7.91 2,023.50 1,975.15 954.85 312.11 6,017,114.36 569,710.69 1.68 122.76 2_Gyra-NS-CT_Drill pipe (1) 2,390.00 44.34 7.91 2,041.32 1,992.97 972.22 314.52 6,017,131.76 569,712.94 1.76 127.95 2_Gymo NS -CT Drill pipe (1) 2,415.00 44.72 7.78 2,059.14 2,010.79 989.59 316.92 6,017,149.15 569,715.18 1.56 133.15 2_Gyro-NS-CT_Drill pipe (1) 2,440.00 45.25 7.65 2,076.82 2,028.47 1,007.10 319.29 6,017,166.68 569,717.38 2.15 138.44 2_Gym-NS-CT Dnll pipe (1) 2,465.00 45.33 7.48 2,094.41 2,046.06 1,024.71 321.63 6,017,184.31 569,719.56 0.58 143.80 2_Gyro-NS-CT_Dnll pipe (1) 2,490.00 44.83 7.61 2,112.06 2,063.71 1,042.26 323.95 6,017,201.88 569,721.72 2.03 149.14 2_Gym-NS-CT_Drill pipe (1) 2,515.00 44.55 7.60 2,129.83 2,081.48 1,059.69 326.28 6,017,219.32 569,723.88 1.12 154.43 2_Gyro-NS-CT_Drill pipe (1) 2,540.00 44.37 7.63 2,147.68 2,099.33 1,077.05 328.60 6,017,236.70 569,726.04 0.72 159.70 2_Gym-NS-CT_Drill pipe (1) 2,565.00 44.16 7.60 2,165.58 2,117.23 1,094.34 330.91 6,017,254.01 569,728.19 0.84 164.95 2_Gym-NS-CT_Drill pipe (1) 2,590.00 43.68 7.67 2,183.59 2,135.24 1,111.53 333.22 6,017,271.22 569,730.34 1.93 170.16 2_Gyro-NS-CT_Drill pipe (1) 2,615.00 43.72 7.71 2,201.66 2,153.31 1,128.65 335.53 6,017,288.36 569,732.49 0.19 175.33 2_Gyro-NS-CT_Drill pipe (1) 2,640.00 43.91 7.71 2,219.70 2,171.35 1,145.80 337.85 6,017,305.63 569,734.65 0.76 180.51 2_Gyro-NS-CT_DO pipe (1) 2,665.00 43.90 7.70 2,237.71 2,189.36 1,162.98 340.17 6,017,322.73 569,736.81 0.05 185.70 2_Gyro-NS-CT_Drill pipe (1) 2,690.00 43.45 7.84 2,255.80 2,207.45 1,180.08 342.51 6,017,339.85 569,738.99 1.84 190.85 2_Gyro-NS-CT_Drill pipe (1) 2,715.00 42.97 7.91 2,274.02 2,225.67 1,197.04 344.85 6,017,356.83 569,741.18 1.93 195.92 2_Gyro-NS-CT_Drill pipe (1) 2,740.00 42.65 8.02 2,292.36 2,244.01 1,213.86 347.21 6,017,373.67 569,743.37 1.31 200.94 2 -Gyro -NS -CT -Drill pipe (1) 2,765.00 42.55 8.16 2,310.76 2,262.41 1,230.62 349.59 6,017,390.45 569,745.60 0.55 205.89 2_Gyro-NS-CT_Drill pipe (1) 2,790.00 42.81 8.37 2,329.14 2,280.79 1,247.39 352.03 6,017,407.24 569,747.88 1.19 210.81 2_Gyro-NS-CT_Drill pipe (1) 2,815.00 43.52 8.45 2,347.37 2,299.02 1,264.31 354.53 6,017,424.18 569,750.22 2.85 215.72 2 -Gym -NS -CT -Drill pipe (1) 2,840.00 43.44 8.47 2,365.51 2,317.16 1,281.32 357.06 6,017,441.21 569,752.59 0.32 220.65 2_Gyro-NS-CT_Drill pipe (1) 2,865.00 43.21 8.67 2,383.70 2,335.35 1,298.29 359.61 6,017,458.20 569,754.99 1.07 225.54 2_Gyro-NS-CT_Drill pipe (1) 2,890.00 43.02 8.64 2,401.95 2,353.60 1,315.18 362.18 6,017,475.11 569,757.40 0.76 230.38 2_Gyro-NS-CT_Drill pipe (1) 2,915.00 43.57 8.51 2,420.15 2,371.80 1,332.13 364.74 6,017,492.08 569,759.80 2.23 235.27 2_Gyro-NS-CT_Dnll pipe (1) 2,940.00 44.40 8.41 2,438.13 2,369.78 1,349.30 367.29 6,017,509.28 569,762.20 3.33 240.24 2_Gyro-NS-CT_Drill pipe (1) 2,965.00 44.75 8.43 2,455.94 2,407.59 1,366.66 369.86 6,017,526.66 569,764.60 1.40 245.29 2_Gyro-NS-CT_Drill pipe (1) 2,990.00 44.86 8.36 2,473.68 2,425.33 1,384.09 372.44 6,017,544.11 569,767.01 0.48 250.36 2_Gyro-NS-CT_Dnll pipe (1) 3,015.00 44.81 8.41 2,491.41 2,443.06 1,401.53 375.01 6,017,561.57 569,769.42 0.24 255.43 2_Gyro-NS-CT_Dnll pipe (1) 3,040.00 44.39 8.41 2,509.21 2,460.86 1,418.89 377.57 6,017,578.95 569,771.82 1.68 260.48 2 Gyro-NS-CT_Drill pipe (1) 3,065.00 44.21 8.45 2,527.10 2,478.75 1,436.16 380.13 6,017,596.25 569,774.22 0.73 265.49 2_Gyro-NS-CT_Drill pipe (1) 3,090.00 44.17 8.30 2,545.03 2,496.68 1,453.40 382.67 6,017,613.51 569,776.60 0.45 270.51 2_Gyro-NS-CT_Drill pipe (1) 3,115.00 44.67 8.18 2,562.88 2,514.53 1,470.72 385.18 6,017,630.85 569,778.95 2.03 275.59 2_Gyro-NS-CT_Drill pipe (1) 3,140.00 45.12 8.01 2,580.59 2,532.24 1,488.19 387.66 6,017,648.34 569,781.27 1.86 280.76 2_Gym-NS-CT_Drill pipe (1) 3,165.00 44.95 8.02 2,598.26 2,549.91 1,505.71 390.13 6,017,665.87 569,783.57 0.68 285.96 2_Gyro-NS-CT_Drill pipe (1) 3,190.00 44.68 8.03 2,615.99 2,567.64 1,523.15 392.59 6,017,683.34 569,785.87 1.08 291.14 2 -Gym -NS -CT -Drill pipe (1) 3,215.00 44.42 8.29 2,633.81 2,585.46 1,540.51 395.08 6,017,700.72 569,788.20 1.27 296.26 2 Gyro-NS-CT_Drill pipe (1) 3,240.00 44.05 8.43 2,651.72 2,603.37 1,557.77 397.62 6,017,718.00 569,790.57 1.53 301.29 2_Gyro-NS-CT_Drill pipe (1) 3,265.00 43.72 8.47 2,669.74 2,621.39 1,574.91 400.16 6,017,735.16 569,792.96 1.32 306.26 2_Gyro-NS-CT_Drill pipe (1) 3,290.00 43.06 8.62 2,687.91 2,639.56 1,591.89 402.71 6,017,752.17 569,795.35 2.67 311.16 2_Gyro-NS-CT_Drill pipe (1) 3,315.00 42.62 8.71 2,706.24 2,657.89 1,608.70 405.27 6,017,768.99 569,797.75 1.78 315.97 2_Gyro-NS-CT_Drill pipe (1) 3,340.00 42.37 8.90 2,724.67 2,676.32 1,625.39 407.86 6,017,785.70 569,800.18 1.12 320.72 2_Gyro-NS-CT Dnll pipe (1) 2/25!1019 5.33:47PM Page 5 COMPASS 5000.15 Build 91 Company: Project: Site: Well: Wellbore: Design: Survey Hiloorp Alaska, LLC Milne Point M Pt EPad Rig: MPU E-36 MPU E-36PB1 MPU E-36PB1 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-36 MPU E-36 Actual RKB @ 48.35usft MPU E-36 Actual RKB @ 48.35usft True Minimum Curvature NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) ("1100-) (ft) Survey Tool Name 3,365.00 42.96 8.82 2,743.06 2,694.71 1,642.13 410.47 6,017,802.47 569,802.64 2.37 325.46 2 -Gyro -NS -CT Drill pipe (1) 3,390.00 43.85 8.83 2,761.22 2,712.87 1,659.10 413.10 6,017,819.46 569,805.11 3.56 330.28 2_Gyro-NS-CT_Ddll pipe (1) 3,415.00 43.97 8.89 2,779.23 2,730.88 1,676.24 415.77 6,017,836.62 569,807.62 0.51 335.14 2_Gyro-NS-CT_Drill pipe (1) 3,440.00 43.39 8.93 2,797.31 2,748.96 1,693.29 418.45 6,017,853.70 569,810.14 2.32 339.96 2_Gyro-NS-CT_Drill pipe (1) 3,465.00 42.84 8.89 2,815.56 2,767.21 1,710.17 421.10 6,017,870.60 569,812.63 2.20 344.73 2_Gyro-NS-CT_Drill pipe (1) 3,490.00 42.62 8.91 2,833.92 2,785.57 1,726.93 423.72 6,017,887.38 569,815.09 0.88 349.46 2_Gyro-NS-CT_Drill pipe (1) 3,515.00 42.39 8.83 2,852.35 2,804.00 1,743.62 426.32 6,017,904.09 569,817.54 0.95 354.19 2 -Gyro -NS -CT -Drill pipe (1) 3,540.00 42.31 8.76 2,870.83 2,822.48 1,760.26 428.90 6,017,920.76 569,819.96 0.37 358.93 2 -Gym -NS -CT -Drill pipe (1) 3,565.00 42.40 8.64 2,889.30 2,840.95 1,776.91 431.45 6,017,937.43 569,822.36 0.48 363.69 2_Gyro-NS-CT_Drill pipe (1) 3,590.00 42.52 8.52 2,907.75 2,859.40 1,793.60 433.96 6,017,954.14 569,824.72 0.58 368.49 2_Gyro-NS-CT_Drill pipe (1) 3,615.00 42.90 8.30 2,926.12 2,877.77 1,810.38 436.44 6,017,970.93 569,827.04 1.63 373.37 2_Gyro-NS-CT_Drill pipe (1) 3,640.00 43.91 8.00 2,944.28 2,895.93 1,827.38 438.88 6,017,987.96 569,829.32 4.12 378.38 2 -Gyro -NS -CT Drill pipe (1) 3,665.00 44.49 7.62 2,962.20 2,913.85 1,844.65 441.25 6,018,005.25 569,831.52 2.55 383.57 2_Gyro-NS-CT_Drill pipe (1) 3,690.00 45.13 7.38 2,979.94 2,931.59 1,862.12 443.55 6,018,022.73 569,833.66 2.65 388.90 2_Gyro-NS-CT_Drill pipe (1) 3,715.00 45.38 7.48 2,997.54 2,949.19 1,879.72 445.84 6,018,040.36 569,835.79 1.04 394.30 2_Gyro-NS-CT_Drill pipe (1) 3,740.00 45.48 7.65 3,015.08 2,966.73 1,897.38 448.19 6,018,058.03 569,837.97 0.63 399.67 2_Gyro-NS-CT_Drill pipe (1) 3,765.00 45.26 7.67 3,032.64 2,984.29 1,915.01 450.56 6,018,075.68 569,840.18 0.88 405.01 2_Gyro-NS-CT_Drill pipe (1) 3,790.00 44.75 7.89 3,050.32 3,001.97 1,932.53 452.95 6,018,093.22 569,842.41 2.13 410.28 2_Gyra-NS-CT_Drill pipe (1) 3,815.00 44.52 7.81 3,068.11 3,019.76 1,949.93 455.35 6,018,110.64 569,844.65 0.95 415.49 2_Gyro-NS-CT_Drill pipe (1) 3,840.00 44.60 7.97 3,085.92 3,037.57 1,967.30 457.76 6,018,128.04 569,846.89 0.55 420.69 2_Gyro-NS-CT_Drill pipe (1) 3,865.00 44.93 8.19 3,103.67 3,055.32 1,984.73 460.23 6,018,145.49 569,849.20 1.46 425.84 2 -Gyro -NS -CT -Drill pipe (1) 3,890.00 45.73 8.25 3,121.25 3,072.90 2,002.33 462.78 6,018,163.11 569,851.58 3.20 431.01 2_Gyro-NS-CT_Drill pipe (1) 3,915.00 45.98 8.27 3,138.66 3,090.31 2,020.08 465.35 6,018,180.88 569,853.99 1.00 436.22 2 -Gyro-NS-CT-Drill pipe (1) 3,940.00 45.98 8.24 3,156.03 3,107.68 2,037.88 467.93 6,018,198.69 569,856.41 0.09 441.43 2_Gyro-NS-CT_Drill pipe (1) 3,965.00 45.89 8.36 3,173.42 3,125.07 2,055.65 470.53 6,018,216.49 569,858.83 0.50 446.63 2_Gyro-NS-CT_Drill pipe (1) 3,990.00 45.68 8.47 3,190.85 3,142.50 2,073.38 473.15 6,018,234.24 569,861.29 0.90 451.78 2_Gyro-NS-CT_Drill pipe (1) 4,015.00 45.40 8.74 3,208.36 3,160.01 2,091.02 475.82 6,018,251.90 569,863.80 1.36 456.85 2 Gyro-NS-CT_Drill pipe (1) 4,040.00 45.52 8.92 3,225.90 3,177.55 2,108.63 478.56 6,018,269.53 569,866.37 0.70 461.85 2_Gyru-NS-GT_Dnll pipe (1) 4,065.00 45.83 8.44 3,243.37 3,195.02 2,126.31 481.25 6,018,287.24 569,868.90 1.85 466.91 2_Gyro-NS-CT_Drill pipe (1) 4,090.00 46.15 7.42 3,260.74 3,212.39 2,144.11 483.73 6,018,305.06 569,871.22 3.20 472.23 2_Gyro-NS-CT_Drill pipe (1) 4,115.00 46.49 6.77 3,278.00 3,229.65 2,162.06 485.97 6,018,323.02 569,873.28 2.32 477.82 2_Gyro-NS-CT_Drill pipe (1) 4,140.00 46.23 6.55 3,295.26 3,246.91 2,180.03 488.07 6,018,341.01 569,875.21 1.22 483.55 2_Gyro-NS-CT_Drill pipe (1) 4,165.00 46.08 6.88 3,312.57 3,264.22 2,197.93 490.17 6,018,358.94 569,877.15 1.13 489.24 2_Gyro-NS-CT_Drill pipe (1) 4,190.00 45.98 7.02 3,329.93 3,281.58 2,215.79 492.35 6,018,376.81 569,879.16 0.57 494.85 2 -Gyro -NS -CT -Drill pipe (1) 4,215.00 45.78 7.21 3,347.34 3,298.99 2,233.60 494.57 6,018,394.64 569,881.22 0.97 500.40 2 -Gym -NS -CT -Drill pipe (1) 4,240.00 46.00 7.34 3,364.74 3,316.39 2,251.41 496.85 6,018,412.47 569,883.33 0.96 505.90 2_Gyro-NS-CT_Drill pipe (1) 4,265.00 45.92 7.64 3,382.12 3,333.77 2,269.23 499.19 6,018,430.30 569,885.50 0.92 511.35 2_Gyro-NS-CT_Drill pipe (1) 4,290.00 45.84 7.65 3,399.52 3,351.17 2,287.01 501.58 6,018,448.11 569,887.72 0.32 516.73 2 Gyro -NS -CT Drill pipe (1) 4,315.00 45.79 7.24 3,416.94 3,368.59 2,304.79 503.90 6,018,465.91 569,889.88 1.19 522.18 2_Gyro-NS-CT_Drill pipe (1) 4,340.00 45.50 5.94 3,434.42 3,386.07 2,322.55 505.95 6,018,483.68 569,891.77 3.89 527.86 2_Gyro-NS-CT_Drill pipe (1) 7115/2019 5:33:47PM Page 6 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Rig: MPU E-36 Wellbore: MPU E-36PB1 Design: MPU E-36PB1 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-36 MPU E-36 Actual RKB @ 48.35usft MPU E-36 Actual RKB @ 48.35usft True Minimum Curvature NORTH US+CANADA Map Map MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS (usft) (`) (°) (usft) (usft) (usft) (use) (ft) (ft) (°1100') 4,365.00 45.46 4.45 3,451.95 3,403.60 2,340.30 507.57 6,018,501.44 569,893.22 4.25 4,390.00 45.87 3.06 3,469.42 3,421.07 2,358.14 508.74 6,018,519.29 569,894.22 4.30 4,415.00 46.31 1.68 3,486.76 3,438.41 2,376.13 509.48 6,018,537.29 569,894.80 4.35 4,440.00 46.48 0.53 3,504.00 3,455.65 2,394.23 509.83 6,018,555.39 569,894.98 3.40 4,465.00 46.54 359.39 3,521.21 3,472.86 2,412.37 509.82 6,018,573.53 569,894.79 3.32 4,490.00 46.16 358.56 3,538.47 3,490.12 2,430.46 509.49 6,018,591.61 569,894.30 2.84 4,515.00 46.40 357.40 3,555.75 3,507.40 2,448.51 508.86 6,018,609.65 569,893.50 3.49 4,540.00 46.13 356.07 3,573.03 3,524.68 2,466.54 507.83 6,018,627.68 569,892.30 3.99 4,565.00 46.18 355.07 3,590.35 3,542.00 2,484.52 506.43 6,018,645.64 569,890.74 2.89 4,590.00 46.17 354.10 3,607.66 3,559.31 2,502.48 504.73 6,018,663.57 569,888.87 2.80 4,615.00 46.26 352.89 3,624.96 3,576.61 2,520.41 502.69 6,018,681.48 569,886.66 3.51 4,640.00 46.63 351.31 3,642.18 3,593.83 2,538.35 500.20 6,018,699.40 569,884.00 4.81 4,665.00 47.11 349.44 3,659.28 3,610.93 2,556.34 497.15 6,018,717.36 569,880.78 5.79 4,690.00 47.02 347.76 3,676.31 3,627.96 2,574.28 493.53 6,018,735.26 569,877.00 4.93 4,715.00 47.29 346.64 3,693.31 3,644.96 2,592.15 489.47 6,018,753.10 569,872.77 3.46 4,740.00 47.41 346.04 3,710.25 3,661.90 2,610.02 485.12 6,018,770.92 569,868.27 1.83 4,765.00 47.62 345.23 3,727.13 3,678.78 2,627.88 480.55 6,018,788.73 569,863.53 2.53 4,790.00 48.12 344.23 3,743.90 3,695.55 2,645.77 475.67 6,018,806.57 569,858.48 3.58 4,815.00 48.68 343.32 3,760.50 3,712.15 2,663.72 470.44 6,018,824.47 569,853.09 3.53 4,840.00 49.17 342.74 3,776.93 3,728.58 2,681.74 464.94 6,018,842.44 569,847.42 2.63 4,865.00 49.55 342.34 3,793.21 3,744.86 2,699.84 459.25 6,018,860.48 569,841.56 1.95 4,890.00 50.11 341.74 3,809.33 3,760.98 2,718.01 453.36 6,018,878.60 569,835.50 2.89 4,915.00 51.01 340.59 3,825.22 3,776.87 2,736.28 447.12 6,018,896.81 569,829.09 5.06 4,940.00 51.56 339.42 3,840.85 3,792.50 2,754.61 440.45 6,018,915.07 569,822.25 4.26 4,965.00 52.20 338.23 3,856.29 3,807.94 2,772.95 433.35 6,018,933.35 569,814.98 4.54 4,990.00 52.39 337.38 3,871.58 3,823.23 2,791.26 425.88 6,018,951.59 569,807.34 2.80 5,015.00 52.72 336.64 3,886.78 3,838.43 2,809.54 418.12 6,018,969.78 569,799.42 2.70 5,040.00 52.82 335.66 3,901.90 3,853.55 2,827.74 410.08 6,018,987.91 569,791.20 3.15 5,065.00 53.22 334.86 3,916.94 3,868.59. 2,845.88 401.72 6,019,005.97 569,782.67 3.02 5,090.00 53.53 333.63 3,931.86 3,883.51 2,863.95 393.00 6,019,023.95 569,773.79 4.14 5,115.00 54.04 332.29 3,946.63 3,898.28 2,881.91 383.83 6,019,041.83 569,764.45 4.78 5,140.00 54.33 331.08 3,961.26 3,912.91 2,899.76 374.21 6,019,059.59 569,754.67 4.09 5,165.00 54.60 330.14 3,975.79 3,927.44 2,917.48 364.23 6,019,077.22 569,744.52 3.24 5,190.00 55.16 329.00 3,990.17 3,941.82 2,935.12 353.87 6,019,094.75 569,734.00 4.35 5,215.00 55.37 328.38 4,004.41 3,956.06 2,952.67 343.20 6,019,112.20 569,723.17 2.20 5,240.00 57.26 327.55 4,018.28 3,969.93 2,970.30 332.16 6,019,129.73 569,711.97 8.05 5,265.00 59.26 326.44 4,031.43 3,983.08 2,988.13 320.58 6,019,147.44 569,700.22 8.85 5,290.00 61.08 325.05 4,043.86 3,995.51 3,006.05 308.37 6,019,165.25 569,687.85 8.73 5,315.00 62.26 323.67 4,055.73 4,007.38 3,023.93 295.55 6,019,183.01 569,674.86 6.77 5,340.00 63.01 322.38 4,067.22 4,018.87 3,041.67 282.19 6,019,200.62 569,661.34 5.48 Vertical Section (ft) Survey Tool Name 533.93 2 -Gyro -NS -CT -Drill pipe (1) 540.45 2_Gyro-NS-CT_Drill pipe (1) 547.41 2_Gyro-NS-CT_0611 pipe (1) 554.78 2_Gyro-NS-CT_Dnll pipe (1) 562.49 2_Gyro-NS-CT_Dnll pipe (1) 570.46 2_Gyro-NS-CT_Drill pipe (1) 578.70 2 -Gyro -NS -CT -Drill pipe (1) 587.29 2_Gyrc-NS-CT_Drill pipe (1) 596.18 2_Gyro-NS-CT_Drill pipe (1) 605.34 2_Gyro-NS-CT_Drill pipe (1) 614.81 2_Gyro-NS-CT Drill pipe (1) 624.68 2_Gyro-NS-CT_Drill pipe (1) 635.08 2_Gym-NS-CT_Drill pipe (1) 645.97 2_Gyro-NS-CT_Drill pipe (1) 657.24 2_Gyro-NS-CT_Drill pipe (1) 668.75 2_Gyro-NS-CT_Drll pipe (i) 680.48 2_Gyro-NS-CT_DnIl pipe (1) 692.49 2_Gyro-NS-CT_Dnll pipe (1) 704.84 2 -Gyro -NS -CT -Drill pipe (1) 717.47 2_Gyro-NS-CT_Drill pipe (1) 730.31 2_Gyro-NS-CT_Drill pipe (1) 743.36 2_Gyro-NS-CT_Drill pipe (1) 756.76 2_Gyro-NS-CT Drill pipe (1) 770.58 2_Gyro-NS-CT_Dril pipe (1) 784.80 2_Gyro-NS-CT_Dnll pipe (1) 799.34 2_Gyro-NS-CT_Drill pipe (1) 814.11 2_Gyro-NS-CT_Ddll pipe (1) 829.13 2_Gym-NS-CT_Dnll pipe (1) 844.40 2_Gym-NS-CT_Drill pipe (1) 859.96 2_Gyro-NS-CT_Drill pipe (1) 875.89 2_Gyro-NS-CT_Drill pipe (1) 892.17 2_Gy10-NS-CT_Dnll pipe (1) 908.74 2_Gyro-NS-CT_Drill pipe (1) 925.60 2_Gyro-NS-CT_Dnll pipe (1) 942.72 2_Gyro-NS-CT_Dnll pipe (1) 960.19 2_Gyro-NS-CT_Drill pipe (1) 978.25 2_Gyro-NS-CT_Drill pipe (1) 996.91 2 -Gyro -NS -CT -Drill pipe (1) 1,016.11 2 -Gyro -NS -CT -Drill pipe (1) 1,035.73 2_Gyro-NS-CT_Drill pipe (1) 2/152019 5:33:47PM Page 7 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Rig: MPU E-36 Wellbore: MPU E-36PB1 Design: MPU E-36PB1 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-36 MPU E-36 Actual RKB @ 48.35usft MPU E-36 Actual RKB @ 48.35usft True Minimum Curvature NORTH US + CANADA Map Map MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) ("1100') 5,365.00 63.76 321.30 4,078.42 4,030.07 3,059.24 268.38 6,019,218.06 569,647.37 4.89 5,390.00 64.34 320.62 4,089.36 4,041.01 3,076.70 254.22 6,019,235.39 569,633.05 3.37 5,415.00 65.12 320.39 4,100.03 4,051.68 3,094.15 239.85 6,019,252.70 569,618.51 3.23 5,440.00 66.45 320.19 4,110.29 4,061.94 3,111.69 225.28 6,019,270.10 569,603.78 5.37 5,465.00 67.19 319.53 4,120.13 4,071.78 3,129.26 210.46 6,019,287.53 569,588.81 3.83 5,490.00 68.37 318.58 4,129.58 4,081.23 3,146.74 195.30 6,019,304.86 569,573.48 5.89 5,515.00 69.56 317.19 4,138.55 4,090.20 3,164.04 179.65 6,019,322.02 569,557.67 7.04 5,540.00 69.87 315.79 4,147.22 4,098.87 3,181.05 163.50 6,019,338.87 569,541.37 5.40 5,565.00 69.72 314.23 4,155.86 4,107.51 3,197.64 146.92 6,019,355.31 569,524.63 5.89 5,590.00 69.69 312.45 4,164.53 4,116.18 3,213.73 129.87 6,019,371.24 569,507.43 6.68 5,615.00 69.62 310.95 4,173.22 4,124.87 3,229.33 112.36 6,019,386.67 569,489.79 5.63 5,640.00 69.91 309.66 4,181.87 4,133.52 3,244.50 94.48 6,019,401.67 569,471.76 4.98 5,665.00 69.96 308.33 4,190.45 4,142.10 3,259.28 76.23 6,019,416.28 569,453.38 5.00 5,690.00 70.12 307.02 4,198.98 4,150.63 3,273.64 57.63 6,019,430.46 569,434.65 4.97 5,715.00 69.92 305.56 4,207.52 4,159.17 3,287.54 38.69 6,019,444.19 569,415.58 5.55 5,740.00 69.70 304.12 4,216.15 4,167.80 3,300.95 19.43 6,019,457.41 569,396.20 5.48 5,765.00 69.90 302.44 4,224.78 4,176.43 3,313.82 -0.18 6,019,470.10 569,376.47 6.36 5,790.00 70.24 300.96 4,233.31 4,184.96 3,326.17 -20.18 6,019,482.26 569,356.36 5.73 5,815.00 70.80 299.54 4,241.64 4,193.29 3,338.04 -40.54 6,019,493.95 569,335.90 5.80 5,840.00 71.28 298.36 4,249.77 4,201.42 3,349.49 -61.22 6,019,505.19 569,315.10 4.86 5,865.00 71.91 297.39 4,257.66 4,209.31 3,360.58 -82.19 6,019,516.09 569,294.03 4.46 5,890.00 72.40 296.51 4,265.32 4,216.97 3,371.36 -103.41 6,019,526.67 569,272.72 3.88 5,915.00 73.07 295.83 4,272.74 4,224.39 3,381.89 -124.83 6,019,537.00 569,251.20 3.73 5,940.00 73.73 295.01 4,279.88 4,231.53 3,392.17 -146.47 6,019,547.08 569,229.47 4.10 5,965.00 74.56 294.29 4,286.71 4,238.36 3,402.20 -168.33 6,019,556.91 569,207.52 4.32 5,990.00 75.33 294.03 4,293.21 4,244.86 3,412.08 -190.35 6,019,566.58 569,185.41 3.24 6,015.00 76.24 293.52 4,299.35 4,251.00 3,421.85 -212.53 6,019,576.14 569,163.14 4.14 6,040.00 77.20 292.72 4,305.09 4,256.74 3,431.41 -234.91 6,019,585.49 569,140.68 4.94 6,065.00 78.21 292.03 4,310.41 4,262.06 3,440.71 -257.50 6,019,594.57 569,118.01 4.86 6,090.00 79.65 291.38 4,315.21 4,266.86 3,449.78 -280.29 6,019,603.43 569,095.13 6.30 6,115.00 80.80 291.13 4,319.46 4,271.11 3,458.71 -303.25 6,019,612.15 569,072.09 4.70 5,140.00 81.73 290.75 4,323.25 4,274.90 3,467.54 -326.33 6,019,620.76 569,048.94 4.01 6,165.00 82.26 290.34 4,326.74 4,278.39 3,476.23 -349.51 6,019,629.23 569,025.68 2.67 6,190.00 82.62 290.20 4,330.02 4,281.67 3,484.82 -372.76 6,019,637.60 569,002.35 1.54 6,215.00 83.07 290.10 4,333.14 4,284.79 3,493.36 -396.05 6,019,645.93 568,978.99 1.84 6,240.00 83.47 289.79 4,336.07 4,287.72 3,501.83 419.38 6,019,654.18 568,955.57 2.02 6,265.00 83.71 289.32 4,338.86 4,290.51 3,510.14 442.80 6,019,662.28 568,932.09 2.10 6,290.00 83.92 288.94 4,341.55 4,293.20 3,518.29 -466.28 6,019,670.20 568,908.53 1.73 6,315.00 83.58 288.41 4,344.27 4,295.92 3,526.25 489.82 6,019,677.94 568,884.92 2.51 6,340.00 83.54 287.83 4,347.08 4,298.73 3,533.97 -513.43 6,019,685.44 568,861.24 2.31 Vertical Section (ft) Survey Tool Name 1,055.70 2_Gyro-NS-CT_Drill pipe (1) 1,075.93 2_Gyro-NS-CT_Drill pipe (1) 1,096.35 2_Gyro-NS-CT_Drill pipe (1) 1,116.99 2_Gyro-NS-GT_DHll pipe (1) 1,137.86 2_Gyr -NS-CT Drill pipe (1) 1,159.01 2_Gyro-NS-CT_Drill pipe (1) 1,180.53 2_Gyro-NS-CT_Drill pipe (1) 1,202.37 2_Gyro-NS-CT_Drill pipe (1) 1,224.43 2_Gyro-NS-CT Dnll pipe (1) 1,246.70 2_Gym-NS-CT_Drill pipe (1) 1,269.16 2_Gyro-NS-CT_DHII pipe (1) 1,291.80 2_Gyro-NS-CT_Drill pipe (1) 1,314.60 2 -Gyro -NS -CT -Drill pipe (1) 1,337.53 2_Gyro-NS-CT_Drill pipe (1) 1,360.58 2_Gyro-NS-CT_Drill pipe (1) 1,383.71 2_Gyro-NS-CT_Drill pipe (1) 1,406.93 2_Gyro-NS-CT_Drill pipe (1) 1,430.28 2_Gyro-NS-CT_Drill pipe (1) 1,453.75 2_Gyro-NS-CT_Drill pipe (1) 1,477.34 2_Gyro-NS-CT_Drill pipe (1) 1,501.04 2_Gyro-NS-CT_Drill pipe (1) 1,524.82 2_Gyro-NS-CT_Drill pipe (1) 1,548.69 2_Gyro-NS-CT_Drill pipe (1) 1,572.65 2_Gyro-NS-CT_Drill pipe (1) 1,596.70 2 -Gyro -NS -CT -Drill pipe (1) 1,620.83 2_Gyro-NS-CT_Drill pipe (1) 1,645.06 2 -Gyro -NS -CT Drill pipe (1) 1,669.38 2_Gyro-NS-CT_D611 pipe (1) 1,693.78 2_Gyro-NS-CT_DO pipe (1) 1,718.27 2_Gyro-NS-CT_Drill pipe (1) 1,742.85 2_Gyro-NS-CT_Drill pipe (1) 1,767.49 2_Gyro-NS-CT Dnll pipe (1) 1,792.17 2_Gyro-NS-CT_Drill pipe (1) 1,816.86 2_Gyro-NS-CT_Drill pipe (1) 1,841.57 2_Gyro-NS-CT_Drill pipe (1) 1,866.30 2_Gyro-NS-CT_Dnll pipe (1) 1,891.03 2_Gyro-NS-CT_DHII pipe (1) 1,915.75 2 Gyro-NS-CT_DHII pipe (1) 1,940.44 2_Gym-NS-CT_Dnll pipe (1) 1,965.10 2_Gyro-NS-CT_DHII pipe (1) 2/252019 5:33:47PM Page 8 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Project: Milne Point TVD Reference: Site: M Pt E Pad MD Reference: Well: Rig: MPU E-36 North Reference: Wellbore: MPU E-36PB1 Survey Calculation Method: Design: MPU E-36PB1 Database: Survey Map MD Inc Azi TVD TVDSS +NI -S +El -W Northing (usft) (°) 0 (usft) (usft) (usft) (usft) (ft) 6,365.00 83.45 287.39 4,349.91 4,301.56 3,541.49 -537.11 6,019,692.74 6,390.00 83.45 287.01 4,352.76 4,304.41 3,548.83 -560.83 6,019,699.86 6,415.00 83.45 287.09 4,355.61 4,307.26 3,556.11 -584.58 6,019,706.92 6,440.00 83.11 287.27 4,358.54 4,310.19 3,563.45 -608.30 6,019,714.03 6,465.00 83.13 287.03 4,361.53 4,313.18 3,570.77 -632.01 6,019,721.13 6,490.00 83.03 286.74 4,364.55 4,316.20 3,577.98 -655.76 6,019,728.11 6,515.00 84.24 286.46 4,367.32 4,318.97 3,585.07 -679.57 6,019,734.99 6,540.00 84.35 286.38 4,369.80 4,321.45 3,592.11 -703.43 6,019,741.80 6,565.00 84.69 286.07 4,372.19 4,323.84 3,599.06 -727.33 6,019,748.53 6,590.00 85.26 286.01 4,374.38 4,326.03 3,605.94 -751.26 6,019,755.18 6,615.00 85.00 285.97 4,376.50 4,328.15 3,612.80 -775.21 6,019,761.82 6,640.00 84.41 286.09 4,378.81 4,330.46 3,619.68 -799.13 6,019,768.47 6,665.00 84.18 286.05 4,381.30 4,332.95 3,626.56 -823.04 6,019,775.13 6,678.86 84.47 285.91 4,382.67 4,334.32 3,630.36 -836.30 6,019,778.81 6,789.02 85.87 285.70 4,391.94 4,343.59 3,660.25 -941.91 6,019,807.72 6,822.07 86.18 286.56 4,394.23 4,345.88 3,669.41 -973.58 6,019,816.58 6,886.99 86.86 286.28 4,398.17 4,349.82 3,687.73 -1,036.74 6,019,834.32 6,949.25 86.36 287.01 4,401.85 4,353.50 3,705.53 -1,095.29 6,019,851.56 7,013.22 85.13 288.32 4,406.60 4,358.25 3,724.89 -1,156.07 6,019,870.35 7,077.68 84.50 288.55 4,412.43 4,364.08 3,745.19 .1,216.97 6,019,890.08 7,140.53 85.31 289.45 4,418.01 4,369.66 3,765.57 -1,276.16 6,019,909.91 7,203.50 87.61 291.64 4,421.90 4,373.55 3,787.63 -1,335.01 6,019,931.41 7,266.61 87.85 293.16 4,424.40 4,376.05 3,811.66 -1,393.31 6,019,954.89 7,330.02 89.52 294.78 4,425.85 4,377.50 3,837.41 -1,451.23 6,019,980.10 7,393.99 90.07 295.62 4,426.08 4,377.73 3,864.65 -1,509.11 6,020,006.80 7,456.84 90.26 295.89 4,425.90 4,377.55 3,891.96 -1,565.72 6,020,033.57 7,520.09 92.61 296.31 4,424.32 4,375.97 3,919.77 .1,622.49 6,020,060.86 7,582.96 92.98 296.82 4,421.25 4,372.90 3,947.85 .1,678.66 6,020,088.41 7,645.85 92.73 296.05 4,418.12 4,369.77 3,975.82 -1,734.90 6,020,115.85 7,708.96 91.55 295.86 4,415.76 4,367.41 4,003.42 -1,791.61 6,020,142.92 7,772.23 89.88 294.77 4,414.97 4,366.62 4,030.47 -1,848.80 6,020,169.43 7,836.06 90.38 294.24 4,414.83 4,366.48 4,056.94 -1,906.87 6,020,195.36 7,899.66 91.31 295.54 4,413.89 4,365.54 4,083.71 -1,964.56 6,020,221.58 7,962.52 90.38 295.65 4,412.96 4,364.61 4,110.86 -2,021.24 6,020,248.20 8,025.67 90.88 295.92 4,412.27 4,363.92 4,138.33 .2,078.10 6,020,275.14 8,088.95 90.38 294.77 4,411.57 4,363.22 4,165.41 -2,135.29 6,020,301.69 8,152.37 90.19 292.23 4,411.26 4,362.91 4,190.70 -2,193.44 6,020,326.43 8,215.99 90.50 289.69 4,410.87 4,362.52 4,213.46 -2,252.85 6,020,348.63 8,278.66 90.13 290.33 4,410.53 4,362.18 4,234.90 -2,311.73 6,020,369.52 8,342.08 90.13 290.29 4,410.38 4,362.03 4,256.91 -2,371.21 6,020,390.98 71252019 5:33:47PM Page 9 Well MPU E-36 MPU E-36 Actual RKB @ 48.35usft MPU E-36 Actual RKB @ 48.35usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (-iloo') (ft) Survey Tool Name 568,837.50 1.79 1,989.72 2_Gym.NS-CT_Drill pipe (1) 568,813.71 1.51 2,014.32 2_Gyro-NS-CT_Drill pipe (1) 568,789.90 0.32 2,038.91 2 -Gyro -NS -CT -Drill pipe (1) 568,766.11 1.54 2,063.50 2_Gyro-NS-CT_Drill pipe (1) 568,742.33 0.96 2,088.08 2_Gyro-NS-CT_Drill pipe (1) 568,718.52 1.22 2,112.65 2_Gyro-NS-CT_Drill pipe (1) 568,694.65 4.97 2,137.22 2_Gyro-NS-CT_Drill pipe (1) 568,670.72 0.54 2,161.81 2_Gyro-NS-CT_Drill pipe (1) 568,646.77 1.84 2,186.39 2_Gyro-NS.CT_Drill pipe (1) 568,622.77 2.29 2,210.99 2_Gyro-NS-CT_Drill pipe (1) 568,598.77 1.05 2,235.58 2_Gyro-NS-CT_DHII pipe (1) 568,574.78 2.41 2,260.16 2_Gyro-NS-CT_DHII pipe (1) 568,550.82 0.93 2,284.73 2_Gyro-NS-CT_Drill pipe (1) 568,537.52 2.32 2,298.34 2_Gyro-NS-CT_Drill pipe (1) 568,431.64 1.28 2,406.66 2_MWD+IFR2+MS+Sag (2) 568,399.89 2.76 2,439.23 2_MWD+IFR2+MS+Sag(2) 568,337.57 1.13 2,503.28 2_MWD+IFR2+MS+Sag(2) 568,277.87 1.42 2,564.75 2_MWD+IFR2+MS+Sag (2) 568,216.91 2.80 2,628.00 2_MWD+IFR2+MS+Sag(2) 568,155.83 1.04 2,691.76 2_MWD+IFR2+MS+Sag(2) 568,096.46 1.92 2,754.01 2_MWD+IFR2+MS+Sag (2) 568,037.42 5.04 2,816.65 2_MWD+IFR2+MS+Sag (2) 567,978.90 2.44 2,879.64 2_MWD+IFR2+MS+Sag(2) 567,920.75 3.67 2,943.01 2_MWD+IFR2+MS+Sag(2) 567,862.62 1.57 3,006.98 2_MWD+IFR2+MS+Sag(2) 567,805.77 0.53 3,069.83 2_MWD+IFR2+MS+Sag(2) 567,748.74 3.77 3,133.04 2_MWD+IFR2+MS+Sag(2) 567,692.32 1.00 3,195.82 2_MWD+IFR2+MS+Sag (2) 567,635.82 1.29 3,258.61 2_MWD+IFR2+MS+Sag (2) 567,578.87 1.89 3,321.67 2_MWD+IFR2+MS+Sag (2) 567,521.44 3.15 3,384.93 2_MWD+IFR2+MS+Sag (2) 567,463.12 1.14 3,448.76 2_MWD+IFR2+MS+Sag (2) 567,405.19 2.51 3,512.35 2_MWD+IFR2+MS+Sag (2) 567,348.26 1.49 3,575.20 2_MWD+IFR2+MS+Sag(2) 567,291.16 0.90 3,638.34 2_MWD+IFR2+MS+Sag(2) 567,233.73 1.98 3,701.62 2_MWD+IFR2+MS+Sag(2) 567,175.34 4.02 3,765.00 2_MWD+IFR2+MS+589(2) 567,115.74 4.02 3,828.45 2_MWD+IFR2+MS+Sag(2) 567,056.66 1.18 3,890.87 2_MWD+IFR2+MS+Sag(2) 566,996.99 0.06 3,954.07 2_MWD+IFR2+MS+Sag(2) COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-36 Project: Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft Site: M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Well: Rig: MPU E-36 North Reference: True Wellbore: MPU E-36PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-36PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 8,405.37 91.37 289.81 4,409.56 4,361.21 4,278.61 -2,430.66 6,020,412.12 566,937.34 2.10 4,017.10 2_MWD+IFR2+MS+Sag(2) 8,469.39 91.86 289.28 4,407.75 4,359.40 4,300.02 -2,490.96 6,020,432.96 566,876.85 1.13 4,080.79 2_MWD+IFR2+MS+Sag (2) 8,532.81 93.11 289.36 4,405.00 4,356.65 4,320.98 -2,550.75 6,020,453.36 566,816.87 1.98 4,143.83 2_MWD+IFR2+MS+Sag (2) 8,596.53 92.91 289.81 4,401.66 4,353.31 4,342.31 -2,610.70 6,020,474.13 566,756.73 0.77 4,207.16 2_MWD+IFR2+MS+Sag(2) 8,660.11 92.66 289.65 4,398.57 4,350.22 4,363.75 -2,670.48 6,020,495.01 566,696.76 0.47 4,270.39 2_MWD+IFR2+MS+Sag(2) 8,723.73 90.25 284.44 4,396.95 4,348.60 4,382.38 -2,731.26 6,020,513.08 566,635.81 9.02 4,333.33 2_MWD+IFR2+MS+Sag(2) 8,788.02 90.26 281.20 4,396.66 4,348.31 4,396.64 -2,793.94 6,020,526.75 566,573.01 5.04 4,396.14 2_MWD+IFR2+MS+Sag (2) 8,851.73 90.01 280.32 4,396.51 4,348.16 4,408.54 -2,856.53 6,020,538.06 566,510.32 1.44 4,457.85 2_MWD+IFR2+MS+Sag(2) 8,915.61 91.49 283.37 4,395.68 4,347.33 4,421.65 -2,919.04 6,020,550.59 566,447.70 5.31 4,520.01 2_MWD+IFR2+MS+Sag(2) 8,979.44 91.37 282.84 4,394.08 4,345.73 4,436.12 -2,981.18 6,020,564.47 566,385.43 0.85 4,582.42 2_MWD+IFR2+MS+Sag (2) 9,043.08 92.36 284.38 4,392.01 4,343.66 4,451.08 -3,043.00 6,020,578.86 566,323.48 2.88 4,644.75 2_MWD+IFR2+MS+Sag(2) 9,106.68 93.10 286.63 4,388.98 4,340.63 4,468.06 -3,104.21 6,020,595.27 566,262.12 3.72 4,707.38 2_MWD+IFR2+MS+Sag (2) 9,170.86 92.67 289.14 4,385.75 4,337.40 4,487.75 -3,165.21 6,020,614.38 566,200.95 3.96 4,770.96 2_MWD+IFR2+MS+Sag (2) 9,233.78 92.29 291.25 4,383.03 4,334.68 4,509.45 -3,224.20 6,020,635.53 566,141.76 3.40 4,833.59 2_MWD+IFR2+MS+Sag (2) 9,297.61 92.42 294.30 4,380.41 4,332.06 4,534.13 -3,283.00 6,020,659.67 566,082.74 4.78 4,897.30 2_MWD+IFR2+MS+Sag (2) 9,362.15 92.30 297.09 4,377.75 4,329.40 4,562.09 -3,341.10 6,020,687.08 566,024.38 4.32 4,961.78 2_MWD+IFR2+MS+Sag(2) 9,425.90 92.23 300.00 4,375.23 4,326.88 4,592.52 -3,397.05 6,020,716.99 565,968.16 4.56 5,025.36 2_MWD+IFR2+MS+Sag (2) 9,489.85 91.49 302.06 4,373.15 4,324.80 4,625.47 3,451.82 6,020,749.42 565,913.09 3.42 5,088.93 2_MWD+IFR2+MS+Sag (2) 9,553.63 90.44 304.34 4,372.08 4,323.73 4,660.39 -3,505.17 6,020,783.83 565,859.42 3.94 5,152.06 2_MWD+IFR2+MS+Sag (2) 9,617.15 88.95 306.51 4,372.42 4,324.07 4,697.20 -3,556.93 6,020,820.16 565,807.33 4.14 5,214.55 2_MWD+IFR2+MS+Sag (2) 9,680.86 88.84 308.33 4,373.64 4,325.29 4,735.91 -3,607.52 6,020,858.39 565,756.39 2.86 5,276.79 2_MWD+IFR2+MS+Sag (2) 9,744.48 90.01 311.03 4,374.28 4,325.93 4,776.52 -3,656.47 6,020,898.54 565,707.06 4.63 5,338.35 2_MWD+IFR2+MS+Sag(2) 9,808.78 90.75 313.06 4,373.86 4,325.51 4,819.58 -3,704.22 6,020,941.15 565,658.92 3.36 5,399.86 2_MWD+IFR2+MS+Sag(2) 9,872.39 90.26 313.78 4,373.30 4,324.95 4,863.30 -3,750.42 6,020,984.43 565,612.32 1.37 5,460.25 2_MWD+IFR2+MS+Sag (2) 9,935.62 88.77 312.54 4,373.83 4,325.48 4,906.55 -3,796.54 6,021,027.25 565,565.80 3.07 5,520.37 2_MWD+IFR2+MS+Sag(2) 9,999.25 88.03 311.82 4,375.61 4,327.26 4,949.26 -3,843.67 6,021,069.51 565,518.28 1.62 5,581.18 2_MWD+IFR2+MS+Sag(2) 10,063.52 88.03 310.83 4,377.82 4,329.47 4,991.67 -3,891.91 6,021,111.47 565,469.65 1.54 5,642.85 2_MWD+IFR2+MS+Sag (2) 10,126.99 88.09 309.33 4,379.97 4,331.62 5,032.51 -3,940.44 6,021,151.85 565,420.74 2.36 5,704.14 2_MWD+IFR2+MS+Sag (2) 10,190.74 89.58 307.81 4,381.26 4,332.91 5,072.25 -3,990.27 6,021,191.12 565,370.55 3.34 5,766.12 2_MWD+IFR2+MS+Sag(2) 10,254.32 91.38 306.30 4,380.73 4,332.38 5,110.55 4,041.01 6,021,228.95 565,319.47 3.70 5,828.32 2_MWD+IFR2+MS+Sag(2) 10,318.28 91.06 306.09 4,379.37 4,331.02 5,148.32 -4,092.61 6,021,266.22 565,267.52 0.60 5,891.08 2_MWD+IFR2+MS+Sag(2) 10,382.21 90.94 306.24 4,378.25 4,329.90 5,186.04 -4,144.22 6,021,303.46 565,215.57 0.30 5,953.81 2_MWD+IFR2+MS+Sag(2) 10,446.06 90.56 306.00 4,377.42 4,329.07 5,223.67 -4,195.79 6,021,340.61 565,163.65 0.70 6,016.48 2_MWD+IFR2+MS+Sag(2) 10,509.90 90.63 304.04 4,376.75 4,328.40 5,260.30 4,248.06 6,021,376.75 565,111.04 3.07 6,079.37 2_MWD+IFR2+MS+Sag (2) 10,572.89 90.57 300.89 4,376.09 4,327.74 5,294.11 -4,301.20 6,021,410.05 565,057.60 5.00 6,141.83 2_MWD+IFR2+MS+Sag (2) 10,636.81 91.19 299.11 4,375.11 4,326.76 5,326.06 -4,356.55 6,021,441.49 565,001.96 2.95 6,205.51 2_MWD+IFR2+MS+Sag (2) 10,700.66 91.80 297.13 4,373.45 4,325.10 5,356.15 4,412.84 6,021,471.04 564,945.40 3.24 6,269.24 2_MWD+IFR2+MS+Sag(2) 10,763.49 91.86 298.05 4,371.44 4,323.09 5,385.23 4,468.50 6,021,499.60 564,889.48 1.47 6,331.98 2_MWD+IFR2+MS+Sag (2) 10,826.90 91.06 298.64 4,369.82 4,321.47 5,415.33 4,524.28 6,021,529.18 564,833.42 1.57 6,395.27 2_MWD+IFR2+MS+Sag (2) 10,889.65 90.50 297.95 4,368.97 4,320.62 5,445.07 4,579.53 6,021,558.40 564,777.90 1.42 6,457.92 2_MWD+IFR2+MS+Sag(2) 2/252019 5:33:47PM Page 10 COMPASS 5000.15 Build 91 Company Project: Site: Well: Wellbore: Design: Survey Halliburton Definitive Survey Report Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU E-36 Milne Point TVD Reference: MPU E-36 Actual RKB @ 48.35usft M Pt E Pad MD Reference: MPU E-36 Actual RKB @ 48.35usft Rig: MPU E-36 North Reference: True MPU E-36PB1 Survey Calculation Method: Minimum Curvature MPU E-36PB1 Database: NORTH US+CANADA Checked By: Chelsea Wright-'--"'.---' Approved By: Mitch Laird Date: 2-25-2019 212512019 5:33:47PM Page 11 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (It) (°1100') (ft) Survey Tool Name 10,953.72 90.69 296.88 4,368.30 4,319.95 5,474.56 4,636.40 6,021,587.36 564,720.76 1.70 6,521.93 2_MWD+IFR2+MS+Sag(2) 11,014.64 92.55 297.07 4,366.58 4,318.23 5,502.19 4,690.67 6,021,614.47 564,666.24 3.07 6,582.79 2_MWD+IFR2+MS+Sag (2) 11,076.34 94.65 296.60 4,362.71 4,314.36 5,529.98 -4,745.61 6,021,641.75 564,611.05 3.49 6.644.34 2_MWD+iFR2+MS+Sag(2) 11,142.24 95.83 294.79 4,356.69 4,308.34 5,558.43 4,804.74 6,021,669.65 564,551.66 3.27 6,709.96 2_MWD+IFR2+MS+Sag(2) 11,207.71 96.13 293.28 4,349.87 4,301.52 5,584.95 -4,864.21 6,021,695.61 564,491.96 2.34 6,775.06 2_MWD+IFR2+MS+Sag(2) 11,277.00 96.13 293.28 4,342.47 4,294.12 5,612.18 -4,927.50 6,021,722.25 564,428.43 0.00 6,843.92 PROJECTED to TO Checked By: Chelsea Wright-'--"'.---' Approved By: Mitch Laird Date: 2-25-2019 212512019 5:33:47PM Page 11 COMPASS 5000.15 Build 91 Hilcorp Energy Company CASING 3 CEMENTING REPORT Lease &Well No. 277.000 Type Float Collar. Comambonal MP E3 Casing (Or Liner) Debut Date Run 11 -Feb -19 County Setting Depths State Alaska Supv. CMornague/J Vanderpool W. Grace CASING RECORD Make Length Bottom Top wdara � Shoe 103/4 TO 6,770.00 Ships Depth: 6,760.00 PBTD: 1.62 6,760.00 No. its. Delivered 180 No. its. Run 171 No, its. Retuned 7 40.0 Fig, Delivered 7,075.34 Fig. Run 6,688.32 Fig. Returned Length Meesurements WM Threats Ftg. Cut Jt 31.32 Fig. Balance Float Collar 103/4 RKB 26.50 RKB to BHF RKBto CHF RKB to THF Csg M. On Hook: 277.000 Type Float Collar. Comambonal No. Him to Ru?: Casing (Or Liner) Debut Csg M. On Slips: 145,000 Type of Shoe: Winces Setting Depths its. Component Size W. Grace THD Make Length Bottom Top Liner top Packer?. Shoe 103/4 TOC: Returns Floats Held BTC Antelope 1 1.62 6,760.00 6,758.38 2 Casing 95/8 40.0 L-80 TXP 80.35 6,758.38 6,678.03 Float Collar 103/4 BTC 1.71 6,767.03 6,676.32 1 Casing 95/8 40.0 L-80 TXP 40.28 6,676.32 6,636.04 Baffle Adapter 103/4 TXP Halliburton 1.89 6,636.04 6,634.15 105 Casing 95/8 40.0 L-80 TXP 4,109.27 6,634.15 2,524.88 Pup Joint - Casing 95/8 40.0 L-80 TXP 14.10 2,524.88 2,510.78 ESICP stage collar 103/4 TXP Halliburton 11.90 2,510.78 2,498.88 Pup Joint - Casing 95/8 40.0 L-80 TXP 14.06 2,498.88 2,484.82 62 Casing 95/8 40.0 L-80 TXP 2,449.49 2884.82 35.33 Cuti2-Casing 95/S 40.0 L-80 TXP 8.93 35.33 26.40 Csg M. On Hook: 277.000 Type Float Collar. Comambonal No. Him to Ru?: 23 Csg M. On Slips: 145,000 Type of Shoe: Winces Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg X Yes_ No W Ft. Min. 95 PPG Fluid Description: Spud Mud X Yes —No Vol to Sort. 244 art In Place At Liner hanger Info(Makellucdel): Liner top Packer?. Yes No Liner hanger test pressure: TOC: Returns Floats Held X Yes No Centralizer Placement 2per on joint 1, l on joint 2,2 per on joint 3, l per on joints 4-25, 1 every Wherjdnts 25- 51, 1 Peron joint 104-118(5 belox ESICP and 10 above),1 ever other joints 120 -168. CEMENTING REPORT Shoe @ 6760 FC @ 61676M Top of Liner lush (Spacer) Clean Spacer Density (ppg) 10 Volume pumped (BBLs) I Slurry Type IN Sacks. 540 Yield: ity(ppg) 12 Volume pumped (BBLs) 225 Mixing/ Pumping Rate (bpm): flurry Class G Sacks: 447 Yield: ivy (ppg) 15.8 Volume pumped (BBLs) 92 Miring / Purrhoing Rate (bpm): Flush (Spacer) Density (ppg) Rate (bpm): Volume: acement- Spud Mud Density(ppg) 9.5 Rate(bpm): 3 Volume (actual I caiculabed): 507.9/503: ;psi): 900 Pump used for died.Rig Bump Plug? X Yes No Bump press 14 gRctated? _Yes X No Reciprocated? X Yes —No % Returns during job 100 int realms to surface? _Yes X No Spacer velums? Yes X No Vd to Surf: 0 int In Place At 0:57 Date: 2/13@019 Gwmwed TOC: 2,500 A Used To Determine TOC: Realms after opening stage collar le Collar @ 2498 Type ESICP Closure OK YES ish(Spacer) Clean Spacer Dereity (ppg) 10 Volume pumped (BBLs) 60 .. PennaBost'L' Sacks: 456 Yield illy (ppg) 10.7 Volume pumped (BBLs) 352 Mixing / Pumping Rate (bpm): Slurry Class G Sacks: 268 Yield: (ppg) 15.6 Volume pumped(BSLs) 56 Mixing/ Pumping Raw (bpm): ssh (Spacer) (ppg) Rate(bpm): Volume: Spud MW Density (ppg) 9.3 Rate (bpm): 45 Volume (actual / calculated): 189/189 (psi): 700 Pump used for disp: Rig Bump Plug? X Yes No Bump press 20 ig Robated? _Yes X No Reciprocated? _Yes X No % Realms during job 100 ant returns to surface? X Yes No Spacer returns? X Yes —No Vol to Sort. 244 art In Place At 13:15 Date: 2/1312019 Estimated TOC: 26 A Used To Determine TOC: Returns Post Job Calculations: Calculated Cmt Vd Q 0%excess: 400 Total Volume curt Pumped: 725 Cmt redhead to surface: 244 Calculated cement left in wellbore: 481 OH volume Calculated: 400 OH volume actual: 481 Actual % Washout: 20 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Saturday, March 23, 2019 2:53 PM To: Wallace, Chris D (DOA); Regg, James B (DOA) Cc: Darci Horner - (C); Alaska NS - Milne - Wellsite Supervisors; Taylor Wellman Subject: Newly Drilled Injector MPE-36 (PTD # 2190050) Ready For Injection 13 Newly drilled Milne Point water injection well MPE-36 (PTD # 2190050) had a passing Pre Injection MIT -IA on the rig on 3-2-19. The well is now ready to be put on injection for stabilization and compliance testing. Plan Forward - Milne Operations 1) Place well on injection. Use caution, annuli are fluid packed. 2) AOGCC MIT -IA once well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 7;785471 C: (509)670-£3001 1 wrivardithilcorp.com 3800 Lew erpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Monday, March 4, 2019 5:39 PM To:'Wallace, Chris D (DOA)'<chris.waIlace@alaska.gov>;'Brooks, Phoebe L (DOA)' <phoebe.brooks@alaska.gov>; 'Regg, James B (DOA)' <jim.regg@alaska.gov>;'doa.aogcc.prudhoe.bay@alaska.gov' <doa.aogcc.prudhoe. bay@alaska.gov> Cc: Darci Horner - (C) <dhorner@hilcorp.com>; Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-M ilne- Wellsite5upervisors@hilcorp.com>; Shane McLeod <smcleod@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com> Subject: MIT of MPE-36 (PTD # 2190050) 0 Newly drilled Milne Point water injection well MPE-36 (PTD # 2190050) had a passing Pre Injection MIT -IA on the rig on 3-2-19. The MIT was witness waived by Austin McLeod. Target test pressure was reduced from 3000 psi to 2500 psi following a completion change from 4-1/2" to 3-1/2" tubing (AOGCC approval attached). The MIT form is attached for reference. Please call with any questions. Thank You, WyattRivard I Well Integrity Engineer IHilcorpAlasku:, LLC 0: (907) 777-8547 1 C: (509)670-8001 1 wrivard0hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage:, AK 99503 SCANNED Ah R 0 12019 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.olaska.gov Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-36 Hilcorp Alaska, LLC Permit to Drill Number: 219-005 Surface Location: 3617' FSL, 1738' FEL, SEC. 25, TUN, R10E, UM, AK Bottomhole Location: 28' FSL, 876' FWL, SEC. 14, T13N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Hollis S. French Chair l DATED this 1 day of January, 2019. STATE OF ALASKA ALi.oKA OIL AND GAS CONSERVATION COMMIb_iON PERMIT TO DRILL 20 AAC 25.005 RECEIVED AN 0 8 2019 Ia. Type of Work: Proposed Well Class: Exploratory - Gas L1 Service - WAG F1 Service - Disp E]1 c. Specify if well is prop Drill E • Lateral ❑ 11b. Stratigraphic Test ❑ Development -Oil ❑ Service- Winj El • Single Zone 0 .dor: Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 • MPU E-36 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 14,488' ND: 4,413' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: o • Surface: 3617' FSL, 1738' FEL, Sec 25, T13N, R10E, UM, AK ADL025518 / ADL047437 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1967' FSL, 2549' FEL, Sec 24, T13N, RIDE, UM, AK LONS 94-017 1/23/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 28' FSL, 876' FWL, Sec 14, T13N, R10E, UM, AK 5120 8,439'to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 48.2' . 15. Distance to Nearest Well Open Surface: x-569407 y- 6016156 Zone -4 " GL / BF Elevation above MSL (ft): 21.7' • to Same Pool: 20' MPE-33 ' 16. Deviated wells: Kickoff depth: 280 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.2 degrees Downhole: 1934 Surface: 1495 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) Cord 20" - X-52 Weld 107' Surface Surface 107' 107' ±270113 12-114" 9-5/8" 40# L-80 TXP 6,598' Surface Surface 6,598' 4,398' Sig 1 L - 1262 ft3/ T - 458 ft3 Stg2L-1937 ft3/T-314 ft3 Tieback 4-1/2" 12.6# L-80 TXP-SR 6,448' Surface Surface 6,448' 4,385' N/A 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 8,040' 6,448' 4,385' 14,488' 4,413' Cementless Injection Liner w/ ICDs 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations) -sco It Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑� 20. Attachments: Property Plat O BOP Sketch Diverter Sketch Drilling Program Time v. Depth Plot 8 Seabed Report B Drilling Fluid Program B Shallow Hazard Analysis 20 AAC 25.050 requirementsB 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 priorwritten approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: 'en el a hIICOr .Com Authorized Title: Drilling Manager Contact Phone: 777-8395 Authorized Signature _ - Date: ZO 1 47 commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: Vq DOS 50- DZ 36 D - 00 O� Date: ( requirements. Conditions of approval : If box is checked, well may be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: IT /not Other: � �(/�Q a �` /.1� ,O �f•— !c -J 1� ' / Samples req'd: Yes ❑ No Mud lag req'd: Yes ❑ No R'• r2' HzS measures: Yes ❑ No Directional svy req'd: Yes [B'No ❑ r2' 4- W W -Fp pre_rei "r P :. Spacing exception req'd: Yes ❑ No LVT Inclination -only svy req'd: Yes ❑ No B- Qd 7-U 05 -F Post initial injection MIT mq'd: Yes W No El APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �(q n /1 Submit Forth and V ' , �jl `�otm 10-401 Revised 5/20n� This permit is valid©o 2µ�F+Gf f Ne of approval per 20 AAC 25.00 g) q chments in Duplicate V C� ` I ` I lJ 1 1 YYY '717 L`. . 0l (fOljq a c 0 06 025 N U �- O U v U J O J O Q Q Q z z z o E a E m U a o U Q u Q u f° u a v O a H c c 0 O O O d d ` r N u Y I U u u O. 0 0 t N d 0 O C s di u 0 E v w w rn a �� z z z V \\\ E t N Z Z Z m U V m vJi V u m W m W N N n p IA O v a m m m m v m o¢ v v v v -;t a a a F O m N m O ZD W C vl vl ti m io o m Oo v z z z J Q J v ? ces v~i a O n d d c d w Y Y t N J N j LL V N f0 O M a a 3 g Z> a 0 0 0 0 0 0 0 0 o O O O o 0 0 0 ti ti n FL rn rn ti ati °�' o o 0 mm N N N N N N N N N N N N N NN N O o 0 0 o O o 0 0 0 0 0 0 0 . N IA V1 Vl N Vl m N O N N V O N Ill Vf D N 00 C O C6 Ch N 00 00 F 00 Ol d '-I N N N N N N N B-18— _ g.q0_ B-11 s B-04A B-07 g_3 v A B-09 �. 1114 B-17 14 'N9� j37WP09 B-06 X41 L� . 0; /10 \ \ \C-41L1 � � MPE-36_WP08 ` \� E 03 ( I B-22 J HILCORP ALASKA LLC A-02 \ ��• • 02 �,,.. E-13B v v ( \ v • E-16 / AOR Map \ \ E-33 MILNE POINT FIELD \ � \ i v CFP-2 .� E-36 Injector (Proposed) MPE-38_WP07 FEET E-20A- • E-18 E-18 WELL SYMBOLS ® IN wm(WmrRwd) ' ..� E-19 �� / �� E-k IIyNecbt Gae wAux'i-�-fi" , E-26y . A x_ / E-3 REMARKS well msibP.&µm`luSaa. E-13 Bleck Bluff Heel — anEtoeloRrWeseBE-36Enllxell. G-19 - - Bc.rtdx 27, 2018 \ Hilcorp Alaska, LLC Milne Point Unit (MPU) E-36 Drilling Program Version 1 1/8/2019 Table of Contents 1.0 Well Summary .................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling / Completion Summary .....................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 R/U and Preparatory Work..........................................................................................................10 10.0 NIU 13-5/8115M Diverter Configuration.....................................................................................11 11.0 Drill 12-1/4" Hole Section.............................................................................................................13 12.0 Run 9-5/8" Surface Casing...........................................................................................................16 13.0 Cement 9-5/8" Surface Casing.....................................................................................................21 14.0 BOP N/U and Test.........................................................................................................................26 15.0 Drill 8-1/2" Hole Section...............................................................................................................27 16.0 Run 4-1/2" Injection Liner (Lower Completion)........................................................................31 17.0 Run 4-1/2" Tubing (Upper Completion).....................................................................................36 18.0 RDMO............................................................................................................................................37 19.0 Innovation Rig Diverter Schematic.............................................................................................38 20.0 Innovation Rig BOP Schematic....................................................................................................39 21.0 Wellhead Schematic......................................................................................................................40 22.0 Days Vs Depth................................................................................................................................41 23.0 Formation Tops & Information...................................................................................................42 24.0 Anticipated Drilling Hazards.......................................................................................................43 25.0 Innovation Rig Layout..................................................................................................................45 26.0 FIT Procedure................................................................................................................................46 27.0 Innovation Rig Choke Manifold Schematic................................................................................47 28.0 Casing Design.................................................................................................................................48 29.0 8-1/2" Hole Section MASP............................................................................................................49 30.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................50 31.0 Surface Plat (As Built) (NAD 27).................................................................................................51 32.0 Schrader Bluff OA Sand Offset MW vs TVD Chart ..................................................................52 33.0 Drill Pipe Information 5" 19.5# 5-135 DS -50 & NC50...............................................................53 N Hilcoip 1.0 Well Summary Milne Point Unit E-36 SB Injector Drilling Procedure Well MPU E-36 Pad Milne Point "E" Pad Planned Completion Type 4-1/2" Injection Tubing Target Reservoirs Schrader Bluff OA Sand Directional Plan WP08 Planned Well TD, MD / TVD 14,487' MD / 4,412' TVD PBTD, MD / TVD 14,477' MD / 4,412' TVD Surface Location (Governmental) 3617' FSL, 1738' FEL, Sec 25, T13N, R10E, UM, AK Surface Location (NAD 27) X= 569,407.52, Y= 6,016,156.74 Top of Productive Horizon Governmental 1967' FSL, 2549' FEL, Sec 24, TON, R10E, UM, AK TPH Location (NAD 27) X= 568,562.53 Y= 6,019,777.86 BHL (Governmental) 28' FSL, 876' FWL, Sec 14, TON, R10E, UM, AK BHL AD 27 X= 561,396 Y=6,023,056 AFE Number 1813045 AFE Drilling Das 18 days AFE Completion Das 7 days AFE Drilling Amount $4,574,853 AFE Completion Amount $1,471,701 AFE Facility Amount $591,000 Maximum Anticipated Pressure Surface 1495 psig Maximum Anticipated Pressure Downhole/Reservoir 1934 si Work String 5" 19.59 S-135 DS -50 & NC 50 KB Elevation above MSL: 26.5 ft + 21.7 ft = 48.2 ft GL Elevation above MSL: 21.7 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 2.0 Management of Change Information 11 Hilcorp Alaska, LLC ililorrP Changes to Approved Permit to Drill Date: 11812019 Subject: Changes to Approved Permit to Drill for MPU E-36 File #: MPU E-36 Drilling and Completion Program Any modifications to MPU E-36 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be ommt mcaied- !fie AOGCC. Sec Page Date Procedure Change Approved Approved By By Milne Point Unit E-36 SB Injector Hilco W -!U- Drilling Procedure 2.0 Management of Change Information 11 Hilcorp Alaska, LLC ililorrP Changes to Approved Permit to Drill Date: 11812019 Subject: Changes to Approved Permit to Drill for MPU E-36 File #: MPU E-36 Drilling and Completion Program Any modifications to MPU E-36 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be ommt mcaied- !fie AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Prepared: Drilling Engineer Page 3 3.0 Tubular Program: Milne Point Unit E-36 SB Injector Drilling Procedure IMP) OD W On) Drift in Conn OD in W _ #/ft , _ n Burst si Collapse si Tension k -lbs 20" 19.25" in (#/ft)Min(Max)(k-lbs) X-52 Weld 7Tb 9-5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 Production 4-1/2" 3.96" 3.795" 4.714" 13.5 L-80 H625 9020 8540 279 4-1/2" 3.958" 3.833" 5.250" 12.6 L-80 TXP-SR 8,430 7,500 288 4.0 Drill Pipe Information: ole OD ID (in) TJ H) TJ OD Wt Grade Conn M/U M/U Tension in in (#/ft)Min(Max)(k-lbs) Surface 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560klb Production 5" 4.276" 3.25" 6.625" 19.5 S-135 NC50 31,032 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 n Hilcorp £xrp Compmy 5.0 Internal Reporting Requirements Milne Point Unit E-36 SB Injector Drilling Procedure 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolinina hilcorp.com. mm eY rskhilcorp, ieneel@hilcorp.com and cdinger@hilcoEp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting • Health and Safety: Notify EHS field coordinator. • Environmental: Drilling Environmental Coordinator • Notify Drilling Manager & Drilling Engineer on all incidents • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyers(2hilcoM,com iengel@hilcoip.com and cdinger@hiIcoM.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers hilcorp.com 0engel@hilcorp.com and cdin erg r@ ilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 ien¢el@hilcorp.com Completion Engineer Taylor Wellman 907.777.8449 907.907.9533 twellman@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinaer@hilcorp.com Page 5 H Hilcotp 6.0 Planned Wellbore Schematic 11 Proposed Schematic Ilil..uy \I:nL,. IJ i. 958'r3 CsnerbQ t23aD rtO KB 6ev above NEL 48.7 W4 TD=14,488' (MD) / TD=4,413'OW PM=14,483'(MD)/PBTD=4,41Y(T ) Page 6 Milne Point Unit E-36 SB Injector Drilling Procedure Milne Point Unit Well: MPU E-36 PTD: TBD API: TBD TREE & WELLHEAD Tree I Cameron4l/16"SMw/41/16'SMCameron Wing Wellhead I Cameron 11`SKz i bottom, 2 2-1/I6"SKputs OPEN HOLE / CEMENT DETAIL 42" '270 ft3 12-1/4" Stg 1-1262 R3 Lead/458 ft3 Tail Top Stir 2-1937 113 Lead 314M Tail &1/2'ZMtq&lM lnrec on Liner in 8-1/2"h e CASING DETAIL SizeType Top MD Wt Grade/ Conn Drift ID Top B[m BPF 2D" Conductor N/A/%-52/Weld N/A Surtax 107 N/A XN Nipple profile:3.725"N Go/ 3.813 Packing Bore Surface a0/L-BD/DWC/C 8.75' 1 Surface I6,598' 3.960 D0758 41/2" 1 IJDer 13.5/L410/ 625 1 3.85' 1 6,490 1 14,988' 0.0149 TUBING DETAIL 412" 1 Tubing 126 L-80/T%P-58 I 3.83x' I Surf I6,446' 0.0152 WELL INCLINATION DETAIL KOp a 28D Max Hole Angle = 91.2° JEWELRY DETAIL No Top MD Rem ID Upper Completion 1 12,525' %Nipple 3.813 2 35,101" XN Nipple profile:3.725"N Go/ 3.813 Packing Bore 3.J25 3 16,43G 825'NOGOLomier on Tieback 6Mfl4J-1" Portetl Seal Stem) 3.960 4 16,448' Tieback Slwe &180 Lower Completion 4 +_6,446' liner Top Packer(Nk 4,365') 5 14,483' Wn/(Ball on Seat/Closed) pBTD - oeyrn Demi iw/swan yecker oe.ea MD ND [m and Smit Packer Devil TSD GENERAL WELL INFO APIC TBD Com leted by InnovaSon: Future 001/8/2019 7.0 Drilling / Completion Summary MPU E-36 is a grassroots injector planned to be drilled in the Schrader Bluff OA sand. E-36 is part of an - eight well program targeting the Schrader Bluff sand on E -Pad. The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. An 8.5" lateral section will then be drilled. A 4-1/2" ICD injection liner will be run in the open hole section. The Innovation Rig will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately Jan 23, 2019, pending rig schedule. Surface casing will be run to 6,598' MD / 4,398' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility. General sequence of operations: 1. MIRU Innovation to well site 2. N/U & Test 13-5/8" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing. 4. N/D diverter, N/U & test 13-5/8" x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 4-1/2" injection liner. 6. Run 4-1/2" tubing. 7. N/D BOP, N/U Tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 Milne Point Unit E-36 SB Injector HilcolTy UCompany Drilling Procedure 7.0 Drilling / Completion Summary MPU E-36 is a grassroots injector planned to be drilled in the Schrader Bluff OA sand. E-36 is part of an - eight well program targeting the Schrader Bluff sand on E -Pad. The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. An 8.5" lateral section will then be drilled. A 4-1/2" ICD injection liner will be run in the open hole section. The Innovation Rig will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately Jan 23, 2019, pending rig schedule. Surface casing will be run to 6,598' MD / 4,398' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility. General sequence of operations: 1. MIRU Innovation to well site 2. N/U & Test 13-5/8" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing. 4. N/D diverter, N/U & test 13-5/8" x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 4-1/2" injection liner. 6. Run 4-1/2" tubing. 7. N/D BOP, N/U Tree, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 Milne Pointr E-36 SB Injector Hile 2— Drilling Procedure rxr®Comyuy 5 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling and completion of MPU E-36. Ensure to provide AOGCC 24 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". o Ensure the diverter vent line is at least 75' away from potential ignition sources • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. • Notify the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). Record pressure test on 10-426 form and email to wrivardghilcorp.com for submission to AOGCC. • Hilcorp Alaska proposes to demonstrate isolation of the injected fluid as required under 20 AAC 25.412 (d) through cement job operational reports of a complete two stage cement job on the 9-5/8" surface casing. Planned surface cement volumes and cement returns to surface seen during both stages will indicate placement of cement in the entire surface casing annulus. A successful FIT after surface casing drill out will demonstrate isolation of injection fluid. AOGCC Regulation Variance Requests: Hilcorp Alaska LLC does not request any variances at this time. Page 8 Summary of BOP Equipment and Test Requirements Hole Section Equipment Milne Point Unit 12 1/4" • 13-5/8" 5M CTI Annular BOP w/ 16" diverter line Function Test Only E-36 SB Injector • 13-5/8" x 5M Control Technology Inc Annular BOP Hilco �w om Drilling Procedure Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12 1/4" • 13-5/8" 5M CTI Annular BOP w/ 16" diverter line Function Test Only • 13-5/8" x 5M Control Technology Inc Annular BOP Initial Test: 250/3000 • 13-5/8" x 5M Control Technology Inc Double Gate o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line 250/3000 • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.reggna alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz(c�r�alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loemi alaska.gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-xxx-xxxx / Email: melvin.rixse@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: hM://doa.alaska.gov/oizc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Milne Point Unit E-36 SB Injector Hilco Drilling Procedure �MT- 9.0 R/U and Preparatory Work 9.1 E-36 will utilize a newly set 20" conductor on E Pad Expansion. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4" nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Innovation Rig. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. ' 9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<800F). 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Ensure 5" liners in mud pumps. • White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. I/ Page 10 10.0 N/U 13-5/8" 5M Diverter Configuration Milne Point Unit E-36 SB Injector Drilling Procedure 10.1 N/U 13-5/8" CTI BOP stack in diverter configuration (Diverter Schematic attached to program). • N/U 20" x 13-5/8" DSA • N/U 13 5/8", 5M diverter "T". • NU Knife gate & 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. • Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the s e circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set wear bushing in wellhead. Page 11 Milne Point Unit E-36 SB Injector Hilco Drilling Procedure U� 10.5 Rig & Diverter Orientation: 13 ■ ■ 5 26 ■ ■ 30 9 ■ ■ 6 25 ■ ■ 21 11 ■ ■ 7 18 ■ ■ 1620 0 0 23 ��^—�♦ E-37 za ■ ■ 19 I ; t 14 ■ 12 E-36 1s ■ N 17 E-35 E-38 $E—.37 J E-39 E-36 E-41 E-35 75' Radius Clear of Ignition Sources Diverter Line MPU E Pad Expansion *Drawing Not To scale Page 12 Milne Point Unit E-36 SB Injector Hilco Drilling Procedure UMT 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub for wireline gyro • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135. • Run a solid float in the surface hole section. 11.2 5" Drill string, HWDP, and Jars will come from Weatherford. 11.3 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 12-1/4" hole section to section TD, in the Schrader OA sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. • Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. • Gas hydrates have been encountered on E -Pad, typically around 2100-2400' TVD (lust below permafrost). Be prepared for hydrates: • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD Page 13 1 • Monitor returns for hydrates, checking pressurized & non -pressurized scales • Past wells on E pad have increased MW to 9.8 ppg and added 1-1.5ppb of Lecithin & .5% lube. After drilling through hydrate sands, MW was cut back to normal • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. • Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. 11.5 12-1/4" hole mud program summary • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval MW (ppg) Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.8 (For Hydrates if need based on offset wells) MW can be cut once —500' below hydrate zone • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). Page 14 Milne Point Unit E-36 SB Injector Hilco-Tr Fn14—T Drilling Procedure • Monitor returns for hydrates, checking pressurized & non -pressurized scales • Past wells on E pad have increased MW to 9.8 ppg and added 1-1.5ppb of Lecithin & .5% lube. After drilling through hydrate sands, MW was cut back to normal • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. • Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. 11.5 12-1/4" hole mud program summary • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval MW (ppg) Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.8 (For Hydrates if need based on offset wells) MW can be cut once —500' below hydrate zone • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). Page 14 H Hilcorp System Type: 8.8 — 9.8 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Milne Point Unit E-36 SB Injector Drilling Procedure Section Density Viscosity Plastic Viscosity Yield Point API FL I pH I Tem Surface 8.8-9.8 75-175 20-40 25-45 <10 1 8.5-9.0 <_70F System Formulation: Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 15 - 20 ppb caustic soda 0.1 ppb (8.5 — 9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8 — 9.2 ppg PAC -L /DEXTRID LT if required for <10 FL ALDACIDE G 0.1 ppb 11.6 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. • This is to prevent washing out directional work to land the well 11.7 RIH t/ bottom, proceed to BROOH t/ HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5 —10 ft / minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.8 TOOH and LD BHA 11.9 No open hole logging program planned. , Page 15 H Hileorp Env ComT 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. Milne Point Unit E-36 SB Injector Drilling Procedure 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120' shoe track assembly consisting of: 9-5/8" Float Shoe 1 joint — 9-5/8" DWC, 2 Centralizers 10' from each end w/ stop rings 1 joint — 9-5/8" DWC, 1 Centralizer mid joint w/ stop ring 9-5/8" Float Collar w/ Stage Cementer Bypass Baffle 'Top Hat' 1 joint — 9-5/8" DWC, 1 Centralizer mid joint with stop ring 9-5/8" HES Baffle Adaptor • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 16 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No. Closing Sleeve No. Shear Pins Opening Sleeve No. Shear Pins ES Cementer Depth 11— Baffle Adapter (if used ID Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole To "Reference Casing Sales Rlanual Set,, 5 Page 17 "A NBrorp ESTI Runrtiay Order Milne Point Unit Overall Length B stud off Plug E-36 SB Injector Ma:.10 ARer Drtillour Hilco �� 4T- Drilling Procedure 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No. Closing Sleeve No. Shear Pins Opening Sleeve No. Shear Pins ES Cementer Depth 11— Baffle Adapter (if used ID Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole To "Reference Casing Sales Rlanual Set,, 5 Page 17 "A NBrorp ESTI Runrtiay Order Part No. Overall Length B stud off Plug Ma:.10 ARer Drtillour C OD Max, Tcol OD D OD 1�• 1 � Opening Sean ID E Shut-off Plug Closing Seat ID Plug Set NBrorp ESTI Runrtiay Order Part No. ES41 Cementer SO No. stud off Plug Closing Plug OD Opening Plug OD 1�• 1 � OD 5 Shut-off Plug OD Bypass Plug (if used) OD NBrorp ESTI Runrtiay Order ES41 Cementer stud off Plug Batik Adaper Box. mug 1�• 1 � 5 By Pass Raw Etat Collar Boat Shea H Hilc�or� Milne Point Unit E-36 SB Injector Drilling Procedure 12.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: Depth Interval Centralization e Shoe —1000' Above Shoe 1/'t r 1000' above Shoe — 2000' above Shoe 1/ 2 its i (jog of U nu fv depth of lowest Ugnu water sand for isolation with Geologist Utilize a collar clamp until weight is sufficient to keep slips set properly. Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES -II Stage tool so that it is positioned at least 100' TVD below the permafrost (— 2,500' MD). (Halliburton ESIPC with packer element may be used). • Install centralizers over couplings on 5 joints below and 10 joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to open at — 3000 psi. Reference ESIPC Procedure. 9-5/8" 40# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Page 18 TXP`J BTC Page 19 Milne Point Unit E-36 SB Injector Drilling Procedure ,..ae. 1110812018 Outside Diameter 9625In 64a MH 87.5% PERFORMANCE Teiti n ss binr YSd Stung Ih Grade Lao too bs Type 1 Compression snmirTli W.HThickness 0.395 n. Connection OD REGULAR lbs Option COUPLING Pipe BODY Eody Red 1st Band: Red Gatle L80 T pe 1- y Drift API Standard IT, Bard: Brown 2nd Band' 21.d rand: - Brown Type Casing 3rd Band: - 3rd 8and: - 4th Band: - a 1 1 GEOMETRY tkminal C9 9.625 in. tiomm.1 Wimught 40 bi One 8.679.. Nominal C 8.839.. War Tlckneas 0.395 m. Pbr. End Mghr 38,97 roatt OC Tesmce AS PERFORMANCE Body Yretd Sreaglh 916 X1000 ft Irnemal YeU 580 ps Std'rs 90000 psi Ccdapse 3090 psi L GEOMETRY Con,nectcn DC 10.625 in. Coupling L Th 10325 n. Cormecdon ID 8.823. make-up Loss 4.691 in. Thraads per n 5 Connection OD Option REGULAR PERFORMANCE Tension EMoienry 100.0% binr YSd Stung 916.000x1000 Intimal Pressure capacdym 5750.000 psi bs Ccmipression E9clencp 100 ,: Compression snmirTli 916,000 x1000 blas. Allmrble Sending 38 `+100 R lbs Exiemal Fxs ve Capaciry 3090.000 psi MAKE-UPTORQUES rA-imum. 18860ft-ID5 Optimum 20989h4i; bbximtaP 23069 eahs OPERATION LIMB TORQUES Operdfmg T;goi, 3560084ks Yrid Toryue 43400 No. Notes This connection is fully interchangeable with: TXP6 BTC - 9 625 in. - 36 143.5 147 153.5 158.4 lbslft [1] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 501 ISO 10400 - 2007. Datasheet is also valid for Special Bevel option when applicable - except toy Coupling Pace Load, which will be reduced. Please contact a local Tenans technical sales representative. n Hilcorp U �'m, Milne Point Unit E-36 SB Injector Drilling Procedure 12.8 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10' from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 20 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 RX cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the 1s` stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 11' Stage Total Cement Volume: Milne Point Unit Calculation Vol (bbl) Vol (ft3) E-36 SB Injector 12-1/4" OH x 9-5/8" Hilco U= Drilling Procedure 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 RX cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the 1s` stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 11' Stage Total Cement Volume: Page 21 %A'c 31 Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" � (5,598' - 2500') x .0558 bpf x 1.3 = 224.7 1261.7 J Casing Total Lead 224.7 1261.7 12-1/4" OH x 9-5/8" (6,598'-5,598')x.0558bpfx1.3= 72.5 407 Casing ~ 9-5/8" Shoe Track 120' x .0758 bpf = 9.1 51.09 Total Tail 81.6 458 Page 21 %A'c 31 H Hilcorp Envy C2,T Milne Point Unit E-36 SB Injector Drilling Procedure Cement Slurry Design (1St Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: ✓p 1 6,478' x .0758 bpf = 491 bbls 40 bbls of weighted spacer or water to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 Lead Slurry Tail Slurry System EXtendaCEM'"' System SwiftCEM'm System Density 11.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed Water 21.13 gal/sk 5.04ga1/sk 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: ✓p 1 6,478' x .0758 bpf = 491 bbls 40 bbls of weighted spacer or water to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 Milne Point Unit E-36 SB Injector Drilling Procedure 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not bold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. If ESIPC is ran, Increase pressure to 2090 psi to shift ESIPC sleeve and to begin inflating the packer. Inflate packer as per HEC rep. Reference ESIPC procedure. Once ESIPC packer is inflated, increase pressure to 3000 psi to open rupture disc / circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 23 No S� I S�' Gam �oc s a Second Stage Surface Cement Job: Milne Point Unit E-36 SB Injector Drilling Procedure 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. (If ESIPC is used and packer element inflated, CBU x minimum before pumping second stage). Hold pre job safety meeting. 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. 416ff1C Estimated 2"d Stage Total Cement Volume: Page 24 Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) SwiftCEM TM System (Hal Cem) 20" Conductor 9-5/8" Casing (110') x .26 bpf x 1= 28.6 161 a 12-1/4" CH x 9-5/8" Casing (2000'- 110') x .0558 6 f x 3 = 316.4 1776.3 Total Lead 345 1937 12-1/4" CH x 9-5/8" Casing (2500'- 2000') x .0558 bpf x 2 = 55.8 314 ~ Total Tail 55.8 314 Page 24 Cement Slurry Design (2nd stage cement job): Lead Slurry Tail Slurry System Permafrost L SwiftCEM TM System (Hal Cem) Density 10.7 lb/gal 15.8 lb/gal Yield 4.3279 ft3/sk 1.16 ft3/sk Mixed Water 21.405 gal/sk 5.08 gal/sk n Hilcorp E -W ��, Milne Point Unit E-36 SB Injector Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: olL 2500' x .0758 bpf = 190 bbls mud V/ 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1000 —1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8" final joint. L/D cut joint. Make final cut on 9-5/8". Dress off stump. Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As -Run" casing tally & casing and cement report to ienQeLghilcorp.com and cdingerghilcorp. com This will be included with the EOW documentation that goes to the AOGCC. Page 25 Milne Point Unit E-36 SB Injector Hileoyy Drilling Procedure E'u C2,T 14.0 BOP N/U and Test 14.1 N/D the diverter T, 16" knife gate, 16" diverter line & N/U 11" x 13-5/8" 5M casing spool. 14.2 N/U 13-5/8" x 5M CTI BOP as follows: • BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / 13- 5/8" x 5M mud cross / 13-5/8" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5.5" VBRs in top cavity, blind ram in bottom cavity. • Single ram should be dressed with 2-7/8" x 5.5" VBRs or 5" Solid Body Rams S • N/U bell nipple, install flowline. • Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1) manual valve & HCR valve on choke side of mud cross. (manual valve closest to mud cross) 14.3 Run 5" BOP test plug (if not installed previously). • Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. Confirm test pressures with PTD Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.4 R/D BOP test equipment 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.7 Set wearbushing in wellhead. 14.8 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.9 Ensure 5" liners in mud pumps. Page 26 U Hilcorp EoT MIT 15.0 Drill 8-1/2" Hole Section 15.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.220 PDM) Milne Point Unit E-36 SB Injector Drilling Procedure 15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool or ESIPC. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 R/U and test casing to 2500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC reg is 50% of burst = 6870 / 2 = —3500 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20' of new formation. 15.6 CBU and condition mud for FIT. 15.7 _Conduct FIT to 12 nne EMW. Chart Test. Ensure test is recorded on same chart as FIT. V Document incremental volume pumped (and subsequent pressure) and volume returned. 61 15.8 POOH & LD Cleanout BHA 15.9 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135 DS50 & NC50. • Run a ported float in the production hole section. 15.10 8-1/2" hole section mud program summary: Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. Page 27 U Hilco U nom,r.,,p Milne Point Unit E-36 SB Injector Drilling Procedure • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) sufficient hole cleanine • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9 — 9.5 ppg Baradrill-N drilling fluid Properties: Section Density Plastic Viscosity Yield Point Total Solids MBT HPHT Production 8.9-9.5 15-25 20-25 <10% <7 <110 System Form a ion: Baradrill-N Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N -VIS 1.0 — 1.5 ppb DEXTRID LT 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARACARB 50 2 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.015 ppb Page 28 H Bile otp E �.= 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid Milne Point Unit E-36 SB Injector Drilling Procedure 15.13 Begin drilling 8.5" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 15.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm • RPM: 120+ • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low • Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD, pump pressure & hookload trends for hole cleaning indication • Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Reservoir plan is to undulate between Schrader OA & OA3 lobes in 1000-1500' MD increments, and keeping DLS <3° when moving between lobes • Limit maximum instantaneous ROP to < 250 fph. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. • Target ROP is as fast as we can clean the hole without having to backream connections • Schrader Bluff OA Concretions: 5-10% of lateral • L-47:6%, L-50 9.5% • F-106: 6.1%, F-107: 4.7%, F-018: 9.9%, F-109: 10%, F-110: 10.1% • Injection Pressure from C-41 has been seen on E-35. Watch for higher than expected - pressure. Increase MW if needed. • E-35: 10.0ppg MW needed at TD to BROOH, 10.4 mud cap at shoe needed • A/C: E-33 is a close approach at 7,548 — 7,573' MD. E-33 is an abandoned SB Producer. The only risk to a collision is damage to the bit. 15.15 Reference: Open hole sidetracking practice: If a known fault is coming up, put a slight "kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. Attempt to lowside in a fast drilling interval where the wellbore is headed up. Page 29 H Hilcorp U Milne Point Unit E-36 SB Injector Drilling Procedure Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Once well has TD'd the production lateral swan to the completion AFE • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • Ensure mud has necessary lube % for running liner • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum 15.17 Monitor the retumed fluids carefully while conditioning the mud. After 4 (or more) BU, Perform production screen test (PST). The mud has been properly conditioned when the mud will pass the production screen test (x3 350ml samples passing through the screen in the same amount of time which will indicate no plugging of the screen). Reference PST Test Procedure • Injection Control Devices (ICDs) are wire wrapped, and require passing PST with 250µ Coupons • Circulate and condition mud as much as needed to pass the production screen test • If not passing after first test, call Completion Engineer 15.18 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (385 gpm max). • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe 15.19 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. • If necessary, increase MW at shoe for any higher than expected pressure seen 15.20 Monitor well for flow. Increase mud weight if necessary • Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise 15.21 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. 15.22 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted Page 30 16.0 Run 4-1/2" Injection Liner (Lower Completion) Milne Point Unit E-36 SB Injector Drilling Procedure 16.1. Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2" liner with ICD and swell packers, the following well control response procedure will be followed: • With ICD across the BOP: P/U & M/U the 5" safety joint (with 4-1/2" crossover installed on bottom, TIW valve in open position on top, 4-1/2" handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 4-1/2" liner. • With 4-1/2" solid joint across BOP: Slack off and position the 4-1/2" solid joint to MU the TIW valve. Shut in ram or annular on 4-1/2" solid joint. Close TIW valve. 16.2. Confirm VBR have been tested on 4-1/2" and 5" test joints to 250 psi low/3000 psi high. 16.3. In the event of an influx of formation fluids while running the 2-3/8" inner string inside the 4- 1/2" liner: • P/U & M/U the 5" safety joint (with 4-1/2" x 2-3/8" triple connect crossover installed on bottom, TIW valve in open position on top, 2-3/8" handling joint above TIW). M/U 2-3/8" and then 4-1/2" to triple connect. • This joint shall be fully M/U with crossovers and available prior to running the first joint • Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW valve. Proceed with well kill operations. 16.4. R/U 4-1/2" liner running equipment. • Ensure 4-1/2" Hydri1625 x DS -50 crossover is on rig floor and M/U to FOSV. • Ensure the liner has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 16.5. Run 4-1/2" injection liner. • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. Thread compound can plug the ICDs. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Use lift nubbins and stabbing guides for the liner run. • Fill 4-'/z" liner with PST passed mud (to keep from plugging ICDs with solids) • Install ICDs and swell packers as per the Running Order (Estimate 8 evenly spaced). • Do not place tongs or slips on swell packer elements or ICDs. • ICD and swell packer placement t40' • The ICD connection is 4-1/2" 13.5# Hydril 625 • Remove protective packaging on swell packers just prior to picking up • If liner length exceeds surface casing length, ensure centralizers are placed I Jt for each joint outside of the surface shoe. This is to mitigate difference sticking risk while running inner string. Page 31 H Hilcorp Milne Point Unit E-36 SB Injector Drilling Procedure • Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10 and 20 rpm 4-1/21113.5# L-80 Hydril 625 Casing OD Minimum Optimum Maximum Operating Tor ue Yield Torque 4.5" 8,000 ft -lbs 9,600 ft -lbs 12,800 ft -lbs 15,000 ft -lbs Page 32 H Hilcorp 6nZ Com2 For the latest performance data. always visit our wehsile: www.tenaris.com Wedge 625© Outside Diameter aSIB c Wall Thickness 0288 k. Grade LBO TypeV tlia Wall Thickness Connection OD OpSon Drift Type Milne Point Unit E-36 SB Injector Drilling Procedure PIPE BODY DATA eT.sx GEOMETRY I-) Grade LBB y 180.9 In. Type I A=n. REGULAR ASO Nprvnal waive[ 13.50 bs0 COUPLING PIPE BOGY Ns.d ID Body: RM IR Enid_ Rea API Standard Im Ban1 a'. 2nd Sand: CD Ttleance 2nd Band Broom Casing Band: - 3m Band: - PERFORMANCE at Ba d: - PIPE BODY DATA GEOMETRY 1711. Cmnxcten lD 180.9 In. IAakwp LOss A=n. Wmind 00 ASO Nprvnal waive[ 13.50 bs0 Drift 1795.. Ns.d ID =0 In Wad Thickness 0290.. Ren Eod Weight 13.05"" CD Ttleance APl ked YeW strengm M370a1000 Inkmal Presvre Capadry 9020.000 BY PERFORMANCE Ihs aPdy, Yxl6 strengen 307a10001he Ineme Yeld 9030 psi STAYS score Ps collapse 8510pv lbs :111ECTI DN DATA GEOMETRY cceveetim OD 1711. Cmnxcten lD 180.9 In. IAakwp LOss A=n. 5hiea^_sptsin 330 Cenneceec OD option REGULAR PERFORMANCE TetuanE clenz, IMM ked YeW strengm M370a1000 Inkmal Presvre Capadry 9020.000 BY Ihs Cprr{eeslon E4imry 913% Congression scengtli 290.115x1000 u""A0o1va0k Bending M-11JJ8 lbs Emmal Pesare capae, 8580.000 psi MAKE-UP TORQUES unimen 0000940s Co. 96009Jhs meeceen 1280D 0-16s OPERATION LIMIT TORQUES Operaeg 1a 12000kets Yeld Tmpx 15000 BJtis Notes For fuller infalmadon on concepts indicated in this datasheet, download the Datasheet Manual from wWw tBnanis Oom 16.6. Ensure that the liner top packer is set — 150' MD above the 9-5/8" shoe. • AOGCC regulations require a minimum 100' overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Ensure hanger/packer will not be set in a 9-5/8" connection. 16.7. R/U false rotary and run 2-3/8" 6.4#/ft inner string. Page 33 H Hilcorp Milne Point Unit E-36 SB Injector Drilling Procedure 16.8. Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.9. M/U Baker SLZXP liner top packer to inner string and 4-1/2" liner. Fill liner tieback sleeve with "Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 16.10. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. RIH w/ liner on DP no faster than 30 ft/min — this is to prevent buckling the liner and drill string. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. 16.12. The liner and inner string will prevent the DP from auto filling. Fill DP every 5 stands, more frequently if SOW trend indicates. 16.13. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.14. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.15. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.16. Rig up to pump down the work string with the rig pumps. 16.17. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.18. Rig up to pump down the work string with the rig pumps. 16.19. Break circulation and begin displacing wellbore to —9.2 ppg KCl/NaCl (adjust brine weight if needed). Note the large OD on the ICDs. Begin circulating at —1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. 16.20. Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the ICDs. Note all losses. Catch mud for future use if feasible. 16.21. Monitor the returned fluids carefully and when no more filter cake appears at the shaker begin pumping SAPP pill. 16.22. Mix and pump 3 tandem 40 bbl 10 ppb SAPP pills (120 bbl total SAPP pill) with 100 bbl in between. Keep circulation rate low to keep from packing off around the ICDs. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Page 34 16.23. Repeat pumping SAPP pills as needed until the wellbore is clean. Milne Point Unit E-36 SB Injector Drilling Procedure Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. Monitor the returned fluids to ensure as much mud and wall cake has been removed from the wellbore as possible so as to not impact wellbore injectivity. 16.24. Displace 1.5 OH & Liner volumes. 16.25. Shut down pumps. Drop setting ball down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. Pressure up to 1,500 psi to shift the wellbore isolation valve closed. 16.26. Continue pressuring up to 2700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the ZXP to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4100 psi to neutralize and release running tools. 16.27. Bleed DP pressure to zero, Pick up to expose Rotating Dog Sub and set down 50k4 without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k4 again, 16.28. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.29. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.30. Displace 2-3/8" x Liner, pump 2 circulations. 16.31. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. L/D 2-3/8" inner string. Rack back enough 5" drill pipe for liner top clean out run 16.32. Make up 3.5" wash tool & RIH on 5" DP to 4.5" liner top. 16.33. Flush liner top at max rate while displacing out well to clean brine. 16.34. POOH LD Remaining 5" DP. Page 35 H Hilc Eongy C2,Torp Milne Point Unit E-36 SB Injector Drilling Procedure 17.0 Run 4-1/2" Tubing (Upper Completion) 17.1 LofiL the AOGCC at least 24 hours in advance of the IA pressure test after running the completion as per 20 AAC 25.412 (e). Record pressure test on 10-426 form and email to wrivard@hilcoM.com for submission to AOGCC. 17.2 M/U injection assembly and RIH to setting depth. TIH no faster than 90 ft/min. • Ensure wear bushing is pulled. • Ensure 4-'/�" TXP-SR (or Buttress) x NC -50 crossover is on rig floor and M/U to FOSV. • Ensure all tubing has been drifted in the pipe shed prior to running. • Be sure to count the total # of joints in the pipe shed before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. • Monitor displacement from wellbore while RIH. 4-%" Upper Completion Running Order • 4-%z" Baker Ported Bullet Nose seal (stung into the tie back receptacle) • 3 joints (minimum, more as needed) 4-%2" 12.6#/ft, L-80 TXP-SR tubing • 4-'/z" "XN" nipple at 5,700' MD (less than 70° hole angle) • 4-'/z" 12.6#/ft, L-80 TXP-SR tubing • 4-'/2" "X" nipple at 2,500' MD • 4-'/2" 12.6#/ft, L-80 TXP-SR space out pups • 1 joint 4-'/2" 12.64/ft, L-80 TXP-SR tubing • Tubing hanger with 4-1/2" TXP-SR pin down 17.3 Locate and no-go out the seal assembly. Close annular and test to 400 psi to confirm seals engaged. 17.4 Bleed pressure and open annular. Space out the completion (+/- V to 2' above No -Go). Place all space out pups below the first full joint of the completion. 17.5 Makeup the tubing hanger and landing joint. 17.6 RIH. Close annular and test to 400 — 500 psi to confirm seals are engaged. Bleed pressure down to 250 psi. PU until ports in seal assembly exposed. 17.7 Reverse circulate the well with brine and I% corrosion inhibitor. 17.8 Freeze protect the tubing and IA to 3000' MD with ±210 bbl of diesel. Page 36 H Hilcorp F—W Campmy Milne Point Unit E-36 SB Injector Drilling Procedure 17.9 Land hanger. RILDs and test hanger. 17.10 Continue pressurizing the annulus to 3000 psi and test for 30 charted minutes i. Note this test must be witnessed by the AOGCC representative. 17.11 Set BPV, ensure new body seals are installed each time. ND BOPE and NU adapter flange and tree. 17.12 Pull BPV. Set TWC. Test tree to 5000 psi. 17.13 Pull TWC. Set BPV. Bullhead tubing freeze protect. 17.14 Secure the tree and cellar. 18.0 RDMO 18.1 RDMO Innovation Rig Page 37 H Hilcorp Em Company 19.0 Innovation Rig Diverter Schematic 3.118' Kih 13-% Technology Page 38 Milne Point Unit E-36 SB Injector Drilling Procedure :ontrol Technology 3 -ST SM Conlrol edmlogy, Double Ram -118' Choke Line Diverter Line 20.0 Innovation Rig BOP Schematic 3-1/8' Kill 9-518" DBL D Seal Casing 13-5/8" NOM 9-5/8' BTC Btm x 10.5" -4 SA Pin Top W/ Primary Seal Page 39 [PP] A C ?e] Milne Point Unit E-36 SB Injector Drilling Procedure X13-5/8" 5M Control Technology Annular BOP l C, 12- 13-5/8' 5M Control Technology Double Ram 3-1/8' Choke Line -----'� 13-5/8" 5M Control Technology Single Ram 13-5/8" x 5M —11" x 5M 2-1/16" x 5M x5M \.,— 2-1/16" x 5M 20' Casing -5/8" Casing H Hilcorp Ucoav�r 21.0 Wellhead Schematic Milne Point Unit E-36 SB Injector Drilling Procedure Page 40 H Hilcrp e.o .2T 22.0 Days Vs Depth 0 PI t -J4 9 fII r n v 0 8000 v m v tIO'8 9'4' 12000 14000 MPU E-36 SB OA Injector Days vs Depth Milne Point Unit E-36 SB Injector Drilling Procedure for 16000 0 5 10 15 20 25 30 Days Page 41 Milne Point Unit E-36 SB Injector Hilcorp Drilling Procedure Fmgy Comp.ny 23.0 Formation Tops & Information MPU E-36 Formations (wp08) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2216 1867 1915 842.6 8.46 SV1 3041 2457 2505 1102.2 8.46 LA3 4808 3711 3759 1653.96 8.46 Schrader Bluff NA 5764 4208 4256 1872.64 8.46 Schrader Bluff OA 6575 1 4348 1 4396 1934.24 8.46 sow GEOLOGICAL TVD FM LITH DESCRIPTION shower, ram me «nIV. SDI Spry • v . v Unconsdidated coarse to medium sand and met] gravel ells mYnor sflestane. Heavy gravel conmte gloerato 1100'. Wood Nagar encs throughout permafrost zone. Abundant pyme at!500,1 1,000• L Ind. df Bateperrnsfrost -40111 RUNNING GRAVELS 2,000' HYDRATESII Sagan anklutok C L Be prepared for HYDRATE gas cut mud tow to 2560• as (E -land E41 (plus --10,-11.-21 d -23,). ,E-,.. 30, •33 s -210. E42 HYDRATES. GAS CUT MUD A Predominantly clay to +e-3000' with lnterbeds o, sand, clays and alflsiones wIN occasional shows of coal. Y 3,000 Cangnued Imerbeds of sand, clays and slltstoaes wIN occasional shows or coal. Clay, arHstone and sand kiteme de, between 3D00 and 6000'. Lignite 3400.350011 SV i merv¢Is more ratty("muddier")than G` !hose In the Prudhoe Bay area. wasawas - A case r.1ae A lY>p 4,000 {A C'- {1ap•- ueaR,s SWABBING/STICKY UBnU: Thick package -200 m We D in some areas, mauly walw-fi1Md rd E -pad elavough some zones are filled with hydrocarbon. The Ugnu samum [mlerhedded nwlal sanmstoece and style)represems Dw Ir Ill Prilmdaddn daw Ugmr dERSIC SySlem over the underlying CLAYIGUMBO:E-20a.-28- shallow rrenne Schrader Blull session. Fluvial nersae can make it difficult to determine lap and base d individual units. Badaen bounding surtace d the entre Ugnu package Is bussed �2 8 -12. st Ne regional unconformly, WOO !see east Msands bHavy GAS CUT MUD E-24 AT 3996 MSands: Fluvial, dehalc channel sandstones progreded over the underlying she0ow TVD; E -13B Q 36,8 ted. marine sandstones of One Schrader Bluff, The MSands we subdh/ded Into three Mhastrahgra lose unas 1,1a. Mb. Me 1. top to bottom) Nal an as d ntimult to correlate due TIGHTlPACgNG OFF, E -25A, to Nell lkhal4HtelC nature. The%TVS narks the, lower most boundary. Bawd intervals, SuAatt oasis 9884 are typicallycwrsening upward packages of varying thicknesses, rare nglr m, 50-60'ttick. g All cores are highly unconsolldamol sandstones with porosyheei range an Ne 30-M%end for Schrader Bluff permeabllrnes reaching upwards d nic-Sn00 daM a conspeetlom. d. Each -sand lntervat acts as 3 t y" e >: B BC D V S .' L ( A 6 a d L sate c IF Yp • >+ J m sow TJ C Z hydraulically separate reservoir based on current understanding. N -Sands: The Nsantls are composed dsMrAe4 mDlne sharefate swdswrws Nov TIGHTiLEDGESICOAL) RUNNING SURFACE rs coarsen upwards from thin. silly, crudalanes "a IhN, low met-groaz very lira to medm u grainednd 8 NE sands e ere beatquality hal rock d dean. CASIHG. E-Zd, -33 8 -25. sastones. The NB_ NC ar high ner-gross Anel. medhamoralrei wrestode. Niamd polo iy raa gn loom ]2-354{an0 permeabad+es range from 100 -MOD mc, The NC S ND,iamds we me primary target with seconrsary targets In the FIB -sand. The more fmconsoldaled sames fyplraley Few NB, NC ND) tema to washout and Ne It. grand stry mudslodas can cause slow RDP. Each N-,antl arts as a hydmuhrally isolated separate reserver. Y E A .s G. {Sa5 q t uA y 0 -sands! TMD uchit Lon15te ,evingsausivaslower o trun wedlted. sands Nateclaim upwardsfrom Silly CAarriO(.andstYiingare 25)0Ninbedded, very Neetolen gralmed growl are 25-3o'trang ardtae OA,an is the primary Want or honmeue wells OBsdr 0 -sand Isrgel ler aui4 Fes airman Egad. mid-whorosNaa rangehemn the :aha pe reach only reedy upwards d 600 dad, whereas In OAsmed reach only In Ned. ,B N rp G m There chat t t d dal cornal de ze ilon the Ferman. 350 co There are urenodules an OB sells ( cause May contain light nodules end lenses Ueet cause mredimnal tlelkcflon (especially when hwizomal)ark slow ROP. Eedf Osand !thenal acts asa hydreukrahly lsdaetl reservoir yj C a8d0' N-100• 0 The nunwrous sub-ueismR 530 it faults and the lama] unacon0nu ty of the NBsands hake it essenbal for clear pick denbflcebon down through the Ugnu and N -sands. as well me careful geosteedng In horizontal we It.. Page 42 24.0 Anticipated Drilling Hazards Milne Point Unit E-36 SB Injector Drilling Procedure 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Gas hyrates have been seen on E Pad. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized mud scale. The non - pressurized scale will reflect the actual mud cut weight. Add 1.0 — 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti -Collison: There are a numb of wells in close proximity. Take directional surveys every stand, take additional surveysif sary. Continuously monitor proximity to offset wellbores and record any close 4pro—aches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No 1-12S events have been documented on drill wells on this pad. Page 43 H Hilo F ngy C IT Milne Point Unit E-36 SB Injector Drilling Procedure The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 300 gPm—� � (✓ � � �Li 25.0 Innovation Rig Layout Page 45 Milne Point Unit E-36 SB Injector Hiloo U4�7 Drilling Procedure 25.0 Innovation Rig Layout Page 45 H Hilcorp Evergy Compeny 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit E-36 SB Injector Drilling Procedure 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 46 Milne Point Unit E-36 SB Injector Hiko•{�y Drilling Procedure Eomp.ZT. 27.0 Innovation Rig Choke Manifold Schematic Page 47 H Hilcorp E" ,x Milne Point Unit E-36 SB Injector Drilling Procedure 28.0 Casing Design Hilco� Calculation & Casing Design Factors DATE: 11812019 WELL: MPU E-36 DESIGN BY: Joe Engel Desian Criteria: Hole Size 12-1/4" Mud Density: 9.2 ppg Hole Size 8-1/2" Mud Density: 9.2 ppg Hole Size Mud Density: Drilling Mode MASP: 1495 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1495 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/it) and the casing evacuated for the internal stress Page 48 Casing Section Calculation/Specification 1 1 2 3 4 Casing OD 9-518" 4-1/2" Top (MD) 0 6,598 Top (TVD) 0 4,398 Bottom (MD) 6,598 14,487 Bottom (TVD) 4,398 4,412 Length 6,598 7,869 Weight (ppf) 40 13.5 Grade L-80 L-80 Connection TXP H625 Weight w/o Bouyancy Factor (lbs) 263,920 106,502 Tension at Top of Section (lbs) 263,920 106,502 Min strength Tension (1000 Its) 916 279 Worst Case Safety Factor (tension) 3.47 C2.62 Collapse Pressure at bottom (Psi) rm 278 -o -- , 80Collapse CollapseResistance w/o tension (Psi) 3, 8, Worst Case Safety Factor (Collapse) 1.42 MASP (psi) 1, 1,495 Minimum Yield (psi) 5,7 9,0 it Worst case safety factor (Burst) 3.65 .03 Page 48 K Hilcorp 29.0 8-1/2" Hole Section MASP Milne Point Unit E-36 SB Injector Drilling Procedure Maximum Anticipated Surface Pressure Calculation Iiit 1 8-1/2" Hole Section mp MPU E-36 Milne Point Unit MD TVD Planned Top: 6598 4398 Planned TD: 14487 4412 Anticipated Formations and Pressures: 8.8-9.1 Surface 4125 Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sand 4,398 0 i Oil r #DIV/0! 1 0.440 Offset Well Mud Densities Well MW ranee Ton 1TVDI Rnttnm ITVnI nam L-50 8.8-9.1 Surface 4125 2015 L-49 9.0-9.2 Surface 4196 2015 L-48 8.9-9.2 Surface 4147 2015 L-47 8.8-9.0 Surface 4158 2015 L-46 9.0-9.3 Surface 4177 2015 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. . 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 4,398 (ft) x 0.78(psi/ft)= 3430.4 3430(psi)-[0.1(psi/ft)*4398(ft& 2991 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4398 (ft) x 0.44(psi/ft)= 1935 psi 1935(psi)-0.1(psi/ft)*4398(ft) 1495 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 49 �j H Hil e MT - 30.0 Spider Plot (NAD 27) (Governmental Sections) Milne Milne Point Unit E-36 SB Injector Drilling Procedure 11Milne Point Unit „ MPE-36 Well 0 1,200 2,400 wow=: "'C � 3 wp08 wmnmmmmmr====== Feet Page 50 31.0 Surface Plat (As Built) (NAD 27) Milne Point Unit E-36 SB Injector Drilling Procedure Page 51 84 elm -lug TRo 24 3■ ■e I w ■ >3 C ■ 2 27 0 a 32 1C ■ ■ 31 I ®{AD ` 28 ■ a 4 22 ■ ■ 1 251 • -I 111 S - TMPROJECT 1I 73 ■ 26■ •m ■ • I I -N- zs6 ■ VI CINI'iY.MAP I a 0 76 n■ 7 I n.TB. 0■ ■t6 1PU EGAD 20 ■ ■ 23 z. a a( s ,�� OF AZq to ■ ■ f7 I .�P: • S'f E- h:' 9 E -41 E-35 mothy ...ad 10200 (VOTES: LEGEMQ 1, l A STAT %AVE CNVOMAIE$ Mf ZNE 4. MID27. + As -8,147 CGwWTDR SURVEYOR'S CERTIEICATr 2. BASIS DF LDNTOM E MONUMENTS OR -3 AND E -L I HEREBY C£AY MAT I AM ■ EMSTNO EDMOvE PROFER4Y REGIS c1'ii ED AND LIMSM 5. BASS OF 6EmA" MUE PONT DAT3M M2 TD MA67X:E LAMD 6VRIEMNO N 4. DEIIEDL P=9 S ARE MID21. MIs 5. PAD MEAN s FA 15: a5669054 GRAPHIC SCALE n 13 as auLT SVIII A s.PAY 6. 6UR14m' DATE: MAY 31, 2676 A 1LY 1. MI6. m t6O 200 4OC MADE SY ME DR LrI MY DIRECT 5 CBYyON AMO MAT ,LLL 7. 14U MCE FdLD III K16 -OS FCS, 24-26 OUDIISOMS ANDAIM H636-0 P6$ 64-73 ( N FEET 1 CWWCT AS MAY �tAd NV 2D0 h 4CCA7.0 YATAIN PROTRACTED SEC. 25, T. 13 N., R. 10 L, UMIAT MERIDIAN, ALASKA WELL A.5 -P. PLANT GEDDET ETIC CELLAR SECTION NO. V CC96. NATES COORDINATES POSITICY4(DM$) POSITION(O.DD) 80% ELEV. OFFSETS Y=6.016,133.24' N-1.829.99' 70'2715.945"70454-4292* 217• 3,594'ESL E-35 X. 569.426,37' E= 1,45D.02' 749'26'00.438" 149.4334550' 1.720' FEL Y-6.016,156.74' N=1,Bfi0.92' 702716.778" 7D.4544939' 27.7 • 9.617 FSL E-36 %= 569 407.52' E= t.450.03- 149'26'00.984- 149.4334087 7.738' FEL Y'6.016,180.3T N=1.890.58' 770`27'16-412' 70.4545589- 21.7 3,841' ML E-37 X= 569 388.31' E. 1 444.Bb 144'26'01.542" 149.43}7677 1,757 FEL Y=6.016.OBi.G6' N-7,890.22' 702775.446" 70.4542906' 21'8 3.543`F5L E-38 X. 569.265.12' E=1,291.58' 14926'05.159' 149.4347747 1881 FELY=6.016.057.25' N.+1,859.75' 7027'75.210" 70.4542250' 27'7 3 579' FSL E-39 X. 589.264.93' E= 1.291.52' 14926'04.636' 149.4345271' 1,863' FEL Y=6,076.034.09' N-9,829,93' 70'2 14.981" 70.4541614' 21.8 3496'FSL E-41 X- 569.,)02,%V : 1,291,66' 149'26'04.091" 149.4344697 7, 844' FEL Aik�orpAlaska m+6 MILNE POINT, ALASKA 3t1t uM Ka>ei WP E -PAD, IMELLS M. 36. 37. 38, 39 @ 41 1 er t m mn AM, AIM,AIM, arou r �i� 4rm +• "amp CONDUCTOR AS -BUILT Page 51 H HilcoT EomgyCompm. Milne Point Unit E-36 SB Injector Drilling Procedure 32.0 Schrader Bluff OA Sand Offset MW vs TVD Chart Schrader Bluff OA Sand Offset MW vs TVD MW. PPB 8.5 8.7 8.9 9.1 9.3 9.5 9.7 9.9 10.110.310.5 0 T 11111 500 1000 1500 2000 O 2500 3000 3500 4000 4500 Page 52 -MPU L-46 (2015) -MPU L-47 (2015) -MPU L-48 (2015) MPU L-49 (2015) -MPU L-50 (2015) -MPU F-106 (2017) -MPU F-107 (2017) -MPU F-108 (2017) -MPU F-109 (2017) -MPU F-110 (2017) H Hilcorp ��R Milne Point Unit E-36 SB Injector Drilling Procedure 33.0 Drill Pipe Information 5" 19.5# 5-135 DS -50 & NC50 Drill Pipe Configuration Pipe Body OD m 5.ODD Pipe Body Wall T1licl e m 0.362 Pipe Body Grade 5-135 Drill Pipe Length Tool Joint SMYS Connection GPDS50 Tad Joint 00 6.625 Tod Joint to m 3250 Pin Tong 9 Box Torg m 12 80 %Inspection Class Nominal Nominal Weight Designation 19.50 Drill Pipe Approximate Length m131,5 SmodhEdge Height 4-) 13132 Rallied! Tool Joint SMYS (%,1120-000 ml-,74.100 Upset Type 56,100 0 Max Upset OD (DTE) n=15.725 124 Friction Factor 7.0 inam159.300 ... T.I. iW]en Nd1Ae nvbhcltq. Drill Pipe Performance DrilkPipe Length Rangel 100 100 Tms>on .._.._._.___............ 0.._.0 Tension Only 0 560.800 cmldrcvLNmm32.100 467.400 nNr oelelvoara NWlzu us.Nlmi. Nominal r \/ wile oml. W:z.1,lnrawez ¢R ¢ria esenai vie 1Wv.�`r a1: m qPe eNy nm emnme, enerNl Nvuc casno. amN eecxrs. Connection Performance GPDS50 ( 6.625 ml OD X 3.250 mr ID ) 120.000 <v.) Nck. Te m.0 ln¢e conneen'noperaernal lenile alJ`JLTi1-3i!C9MJEsi seoul]Ee aGLIkG Tpol Joint Torsional StrenpN ISJu1 71,800 Tod Joim Tensile 5lreflgth rout 1250.000 Elevator Shoulder Information Eley. SmoothEdge Height Nominal Tool JI 3132 Raised OD Box OD %16.812 6.625 Elevator Capadty aevi 1,658.000 11,440,200 fn: 5219 Nott Ekvalw cam an 1 Assumed Elevator Bore Diameter NUe:AraliN etvNvr oo 1. Pipe Body Slip Crushing Capacity Pipe Body Compo fiw r ,V Tool Joint Dimensions Balanced OD an 6.435 w.,11,e TeN Jun oae]rael 5.904 P1CmIwm mu en uranun Tea Junmex 5.93 c¢1.1mNrt ml 3132 Raised 6.612 <m VOmt06@Vel WantoMnTJODfor Oiamntrar AN Premium Class rvNm ewv c=a v.M all mom.Mc`wbM- 5 ml OD 0.362 rm Wall S-135) Pipe Bodv Performance Page 53 emmmen. Pipe Body Configuretim ( 5 (n) OD 0.362 r"> Well S-135) NIXe: NertMNl aulL o'ab¢tl al E).]'w NBW W10PI. Nominal 80 % Inman Class API Prer w.n class Pipe Temile Shen 11m171 IOD 560 560,600 Pipe Torsional Str ml-,74.100 58,100 56,100 TJ/PipeBody Torsional Ratio 0.97 124 124 80% Pipe Torsional Sire inam159.300 46,500 46,500 Burst rel 17,105 15,638 15,638 Collapse Iml 15.672 10.029 10.029 Pipe OD 1 5.11011 4. 4.855 Wail Thickness m10.362 0290 0.290 Nominal ID 4-14276 4276 4276 Cross Sectional Area of Pi Body<n•:1 5275 4.154 4.154 Cross Sectional Area of OD m•n 19.635 18.514 18.514 Cross Sectional Area d ID o 2, 14.360 14.360 14.360 Sed"ron lodukn w3i 5.708 4.476 4.476 Polar Section Modulus wm IIA15 8.953 8.953 NIXe: NertMNl aulL o'ab¢tl al E).]'w NBW W10PI. Milne Point Unit E-36 SB Injector Hilco Drilling Procedure U -22P 500204050016200 Weatherford 5" 19.50 Ib/ft S-135 w/ NC 50 6-5/8" OD x 3-1/4" ID Tool Joint DRILL PIPE SPECIFICATIONS Grade S-135 Connection NC 50 Interchangeable With 5' XH 8 4-1/2" IF Upset Type IEU Nominal Weight per Foot 19.50 lbs Adjusted Weight With Tool Joint per Foot 23.08 lbs TOOL JOINT DATA Outside Diameter 6-518' Inside Diameter 3-1/4' API Drift 3-1/8' Rabbit OD, Suggested 3-1/16' Minimum Make-up Torque 25.900 ft -lbs Maximum Recommend Make-up Torque 26.800 ft -lbs Torsional Yield Strength 51.700 ft -lbs Tensile Strength 1.269.000 lbs TUBE DATA New Premium Outside Diameter 5.000" 4.855" Inside Diameter 4.276" 4.276' Wall Thickness 0.362" 0.290' Cross Sectional Area 5.275 sq in 4.154 sq in Maximum Hook LoadfTensile Strength 712,000 lbs 560,800 Itis Slip Crushing f Slip Type (SDXL) 572,100 lbs 453,500 lbs Burst Pressure 17,100 psi 16,100 psi Collapse Pressure 15.700 psi 10.000 psi Torsional Yield Strength 74,100 ft -lbs 58.100 ft -lbs Capacity W/ Tool Joint 0.726 US oaVft 0.726 US gallft Displacement W/ Tool Joint 0.353 US gaVft 0.322 USgal/ft Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss, damage or injury resulting from the use of the information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. Page 54 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-36 M P E-36 Plan: MPE-36 wp08 Standard Proposal Report 12 November, 2018 HALLIBURTON Sperry Drilling Services H y g m 'r vai in o-i�aN� oai ro-0 r m N V_•tm'i •• 0o eomo�o�� a m'v f°a�o�mamc n _ ` y 0 00 0�0��❑ a ama g ta- Q m N W N W N W N W H a 6 a 2 U H u o 0 3 � � M m m w w w a a a "000-m�mm�nmmm �OOOmmONOYm]Cmlp� ......... O O O O N O O O m O m O n O m 0 1y O O Oe O� O e O N O m 0 r .......... O O O 000000000000 p oovi6eovo6o6o molnm�r mo -Nem �OO�mNVbOmtlAM 1� mOOfOO ienV�VImONNVN Z000viv �ldw m,c6o pommenVmormNm F OmnnNNmtmeeN N m e n O m M1 m O e e N mm`CCI tOe Cl t'le m o-o-o-o-eo- O O O N N O O m m N b �00 OOOmmOOmin 1�1� O O O N m O O N N m m eo- mmmmmm N N N N N N OO��te�ImOONNmm COOm[OCCmm��mm N O e V V m m m m m m ❑0000mommmrmN �v�000Noao-Mamm m000lommaim vion Nmmoo-mmmmm�m N Il10mmNmnVlne ammmmma m�Nmo-mmrmmofN m a eaNg�m Wm mm dampq m o6S$�SS �mNma`a p1my��bN (Np �,-NmNm �o t z 2ma 2mm mam pvm gm1: ooe 0 OOOft m m 00M 000U N $ � 0� m m 0 T' TT-r-� _.. o N 0 0 o O o L N N (ui/4sn 0091) 41da4 jevveA anal M1 m O 009" 2f d 000 LL o!y ss 0osm dO 9p U S �s�'�eJ .04eis 9 Fe 0006 � Ile2. oh s Syed' £'B9 0098 9. VP W'. W'. 'O(, Ogg V 0004 SO, OOSL E a, Off, IO�PiS' A. OWL �OOgL g 00 m `� � a g „ 0008 N W d � SSS � O 90 Z r as m m W S, S0 f S N $ � 0� m m 0 T' TT-r-� _.. o N 0 0 o O o L N N (ui/4sn 0091) 41da4 jevveA anal M1 m O F� O F W g o b C Y" O d L S o pl Ly O N � 4 0 a s (ul/ijsn OSZU (+)quom/(-)4lnoS g o b Y" O L HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-36 Wellbore: MPE-36 Design: MPE-36 wp08 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU E-36 TVD Reference: MPE-36 KBE @ 48.20usft ' MD Reference: MPE-36 KBE @ 48.20usft North Reference: True Survey Calculation Method: , Minimum Curvature roject Milne Point, ACT, MILNE POINT lap System: US State Plane 1927 (Exact solution) . System Datum: Mean Sea Level leo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 1 Using geodetic scale factor Site M Pt E Pad, TR -13-10 Site Position: From: Map Position Uncertainty: 0.00 usft Well Plan: MPU E-36 Well Position +N/ -S 0.00 usft +E/ -W 0.00 usfl Position Uncertainty 0.00 usft Wellbore MPE-36 Magnetics Model Name Northing: 6,013,798.68 usfl Latitude: Easting: 569,440.72usft Longitude: Slot Radius: 0.. Grid Convergence: Northing: 6,016,156.74 usfl • Latitude: Easting: 569,407.52 usfl Longitude: Wellhead Elevation: 0.00 usfl Ground Level: Sample Date Declination Dip Angle (') (') BGGM2018 9/17/2018 17.07 80.99 70' 26'52.982 N 149' 26'0.655 W 0.53' 70° 27' 16.178 N 149' 26'0.984 W 21.70 usfl Field Strength (nT) 57,454.38007099 Design MPE-36 wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 26.50 Vertical Section: Depth From (TVD) +N/S +E/ -W Direction (usfl) (usfl) (usft) (') 26.50 0.00 0.00 311.27 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +EI -W Rate Rate Rate Tool Face (usfl) (') (') (usft) usft (usft) (usft) ('/1o0usft) ('/100usft) ('1100usft) (^) 26.50 0.00 0.00 26.50 -21.70 0.00 0.00 0.00 0.00 0.00 0.00 280.00 0.00 0.00 280.00 231.80 0.00 0.00 0.00 0.00 0.00 0.00 550.00 8.10 40.00 549.10 500.90 14.60 12.25 3.00 3.00 0.00 40.00 1,000.00 26.10 40.00 977.44 92924 115.54 96.95 4.00 4.00 0.00 0.00 1,646.28 44.34 6.92 1,507.77 1,459.57 454.41 217.61 4.00 2.82 -5.12 -61.02 4,366.00 44.34 6.92 3,452.94 3,404.74 2,341.39 446.77 0.00 0.00 0.00 0.00 6,298.49 85.00 290.00 4,372.05 4,323.85 3,526.44 -529.04 4.00 2.10 -3.98 -84.10 6,598.49 85.00 290.00 4,39820 4,350.00 3,628.66 -809.88 0.00 0.00 0.00 0.00 6,766.39 91.20 292.59 4,403.77 4,355.57 3,689.58 -966.14 4.00 3.69 1.54 22.76 9,595.47 91.20 292.59 4,344.70 4,296.50 4,776.24 -3,577.52 0.00 0.00 0.00 0.00 9,710.95 89.18 296.75 4,344.32 4,29612 4,824.44 -3,682.44 4.00 -1.75 3.60 115.86 14,487.82 89.18 296.75 4,412.70 4,364.50 6,974.25 -7,947.65 0.00 0.00 0.00 0.00 11/12!2018 12:02:04PM Page 2 COMPASS 5000.15 Build 91 Planned Survey Halliburton HALLI B U RTO N Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well Plan: MPU E-36 Company: Hilcorp Alaska, LLC TVD Reference: MPE-36 KBE @ 48,20usft Project: Milne Point MD Reference: MPE-36 KBE @ 48.20usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-36 Survey Calculation Method: Minimum Curvature Wellbore: MPE-36 Map Design: MPE-36 wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +EI -W Northing Easting DLS Vert Section (usft) (^) (^) (usft) usft (usft) (usft) (usft) (usft) -21.70 26.50 0.00 0.00 26.50 -21.70 0.00 0.00 6,016,156.74 569,407.52 0.00 0.00 100.00 0.00 0.00 100.00 51.80 0.00 0.00 6,016,156.74 569,407.52 0.00 0.00 200.00 0.00 0.00 200.00 151.80 0.00 0.00 6,016,156.74 569,407.52 0.00 0.00 280.00 0.00 0.00 280.00 231.80 0.00 0.00 6,016,156.74 569,407.52 0.00 0.00 Start Dir 3-/100': 280' MD, 280'TVD 300.00 0.60 40.00 300.00 251.80 0.08 0.07 6,0163156.82 569,407.59 3.00 0.00 400.00 3.60 40.00 399.92 351.72 2.89 2.42 6,016,159.65 569,409.92 3.00 0.08 500.00 6.60 40.00 499.51 451.31 9.70 8.14 6,016,166.51 569,415.56 3.00 0.28 550.00 8.10 40.00 549.10 500.90 14.60 12.25 6,016,171.45 569,419.63 3.00 0.42 Start Dir 4°/100' : 550' MD, 549.1'TVD 600.00 10.10 40.00 598.47 550.27 20.65 17.33 6,015,177.55 569,424.66 4.00 0.60 700.00 14.10 40.00 696.23 648.03 36.71 30.80 6,016,193.73 569,437.98 4.00 1.06 800.00 18.10 40.00 792.29 744.09 57.95 48.62 6,016,215.13 569,455.60 4.00 1.67 900.00 22.10 40.00 886.18 837.98 84.27 70.71 6,016,241.65 569,477.43 4.00 2.43 1,000.00 26.10 40.00 977.44 929.24 115.54 96.95 6,0163273.17 569,503.38 4.00 3.34 1,100.00 28.24 32.59 1,066.43 1,018.23 152.34 123.84 6,016,310.21 569,529.93 4.00 7.39 1,200.00 30.73 26.22 1,153.49 1,105.29 195.21 147.88 6,016,353.30 569,553.56 4.00 17.60 1,300.00 33.48 20.75 1,238.21 1,190.01 243.94 168.95 6,016,402.22 569,574.17 4.00 33.91 1,400.00 36.44 16.05 1,320.17 1,271.97 298.30 186.94 6,016,456.74 569,591.65 4.00 56.24 1,500.00 39.56 11.98 1,398.98 1,350.78 358.01 201.77 6,016,516.58 569,605.92 4.00 84.48 1,600.00 42.80 8.42 1,474.24 1,426.04 422.80 213.36 63016,581.47 569,616.91 4.00 118.50 1,646.28 44.34 6.92 1,507.77 1,459.57 454.41 217.61 6,016,613.11 569,620.87 4.00 136.15 End Dir : 1646.28' MD, 1507.77' TVD 1,700.00 44.34 6.92 1,546.19 1,497.99 491.68 222.14 6,016,650.42 569,625.05 0.00 157.34 1,800.00 44.34 6.92 1,617.71 1,569.51 561.06 230.56 6,016,719.87 569,632.83 0.00 196.77 1,900.00 44.34 6.92 1,689.23 1,641.03 630.44 238.99 6,016,789.32 569,640.60 0.00 236.19 2,000.00 44.34 6.92 1,760.76 1,712.56 699.83 247.41 6,016,858.77 569,648.38 0.00 275.62 2,100.00 44.34 6.92 1,832.28 1,784.08 769.21 255.84 6,016,928.22 569,656.16 0.00 315.05 2,200.00 44.34 6.92 1,903.80 1,855.60 838.59 264.27 6,016,997.67 569,663.94 0.00 354.48 2,215.94 44.34 6.92 1,915.20 1,867.00 849.65 265.61 6,017,008.75 569,665.18 0.00 360.77 BPRF 2,300.00 44.34 6.92 1,975.32 1,927.12 907.97 272.69 6,017,067.12 569,671.72 0.00 393.91 23400.00 44.34 6.92 2,046.84 1,998.64 977.35 281.12 6,017,136.57 569,679.49 0.00 433.34 2,500.00 44.34 6.92 2,118.36 2,070.16 1,046.73 289.54 6,017,206.02 5693687.27 0.00 472.77 2,600.00 44.34 6.92 2,189.88 2,141.68 1,116.11 297.97 6,017,275.47 569,695.05 0.00 512.20 2,700.00 44.34 6.92 2,261.40 23213.20 1,185.49 306.39 6,017,344.92 569,702.83 0.00 551.63 2,800.00 44.34 6.92 2,332.92 2,284.72 1,254.88 314.82 6,017,414.37 569,710.61 0.00 591.06 2,900.00 44.34 6.92 2,404.44 2,356.24 1,324.26 323.25 6,017,483.82 569,718.39 0.00 630.49 3,000.00 44.34 6.92 2,475.96 2,427.76 1,393.64 331.67 6,017,553.28 569,726.16 0.00 669.92 3,040.88 44.34 6.92 2,505.20 2,457.00 1,422.00 335.12 6,017,581.66 569,729.34 0.00 686.03 SV1 3,100.00 44.34 6.92 2,547.49 2,499.29 1,463.02 340.10 6,017,622.73 569,733.94 0.00 709.35 3,200.00 44.34 6.92 23619.01 2,570.81 1,532.40 348.52 6,017,692.18 569,741.72 0.00 748.78 3,300.00 44.34 6.92 2,690.53 2,642.33 1,601.78 356.95 6,017,761.63 569,749.50 0.00 788.21 3,400.00 44.34 6.92 2,762.05 2,713.85 1,671.16 365.37 6,017,831.08 569,757.28 0.00 827.63 11/122018 12:02:04PM Page 3 COMPASS 5000.15 Build 91 Planned Survey Halliburton HALLIBURTON Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well Plan: MPU E-36 Company: Hilcorp Alaska, LLC TVD Reference: MPE-36 KBE @ 48.20usft Project: Milne Point MD Reference: MPE-36 KBE @ 48.20usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-36 Survey Calculation Method: Minimum Curvature Wellbore: MPE-36 Vertical Design: MPE-36 wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +EI -W Northing Easting DLS Vert Section (usft) 0 (^) (usft) usft (usft) (usft) (usft) (usft) 2,785.37 3,500.00 44.34 6.92 2,833.57 2,785.37 1,740.54 373.80 6,017,900.53 569,765.05 0.00 867.06 3,600.00 44.34 6.92 2,905.09 2,856.89 1,809.93 382.23 6,017,969.98 569,772.83 0.00 906.49 3,700.00 44.34 6.92 2,976.61 2,928.41 1,879.31 390.65 6,018,039.43 569,780.61 0.00 945.92 3,800.00 44.34 6.92 3,048.13 2,999.93 1,948.69 399.08 6,018,108.88 569,788.39 0.00 985.35 3,900.00 44.34 6.92 3,119.65 3,071.45 2,018.07 407.50 6,018,178.33 569,796.17 0.00 1,024.78 4,000.00 44.34 6.92 3,191.17 3,142.97 2,087.45 415.93 6,018,247.78 569,803.95 0.00 1,064.21 4,100.00 44.34 6.92 3,262.70 3,214.50 2,156.83 424.35 6,018,317.23 569,811.72 0.00 1,103.64 4,200.00 44.34 6.92 3,334.22 3,286.02 2,226.21 432.78 6,018,386.68 569,819.50 0.00 1,143.07 4,300.00 44.34 6.92 3,405.74 3,357.54 2,295.59 441.20 6,018,456.13 569,827.28 0.00 1,182.50 4,366.00 44.34 6.92 3,452.94 3,404.74 2,341.39 446.77 6,018,501.96 569,832.41 0.00 1,208.52 Start Dir 4°/100' : 4366' MD, 3452.94TVD 4,400.00 44.50 4.99 3,477.23 3,429.03 2,365.05 449.24 6,018,525.65 569,834.66 4.00 1,222.28 4,500.00 45.14 359.39 3,548.19 3,499.99 2,435.43 451.91 6,018,596.04 569,836.68 4.00 1,266.68 4,600.00 46.05 353.94 3,618.19 3,569.99 2,506.70 447.73 6,018,667.26 569,831.84 4.00 1,316.83 4,700.00 47.21 348.67 3,686.88 3,638.68 2,578.50 436.72 6,018,738.96 569,820.16 4.00 1,372.47 4,800.00 48.61 343.62 3,753.93 3,705.73 2,650.50 418.93 6,018,810.78 569,801.70 4.00 1,433.33 4,807.98 48.73 343.23 3,759.20 3,711.00 2,656.25 417.22 6,018,816.51 569,799.94 4.00 1,438.41 LA3 4,900.00 50.21 338.79 3,819.01 3,770.81 2,722.34 394.44 6,018,882.38 569,776.55 4.00 1,499.12 5,000.00 52.01 334.20 3,881.81 3,833.61 2,793.67 363.38 6,018,953.41 569,744.83 4.00 1,569.51 5,100.00 53.98 329.84 3,942.01 3,893.81 2,864.14 325.90 6,019,023.52 569,706.69 4.00 1,644.17 5,200.00 56.09 325.70 3,999.33 3,951.13 2,933.41 282.17 6,019,092.37 569,662.33 4.00 1,722.72 5,300.00 58.34 321.76 4,053.49 4,005.29 3,001.14 232.42 6,019,159.63 569,611.96 4.00 1,804.79 5,400.00 60.70 318.01 4,104.23 4,056.03 3,067.00 176.89 6,019,224.97 569,555.82 4.00 1,889.97 5,500.00 63.17 314.44 4,151.28 4,103.08 3,130.68 115.84 6,019,288.07 569,494.18 4.00 1,977.86 5,600.00 65.71 311.02 4,194.44 4,146.24 3,191.86 49.57 6,019,348.62 569,427.35 4.00 2,068.02 5,700.00 68.34 307.74 4,233.48 4,185.28 3,250.23 -21.59 6,019,406.33 569,355.66 4.00 2,160.01 5,763.96 70.05 305.70 4,256.20 4,208.00 3,285.97 -69.51 6,019,441.61 569,307.41 4.00 2,219.60 SB NA 5,800.00 71.02 304.58 4,268.21 4,220.01 3,305.53 -97.29 6,019,460.91 569,279.45 4.00 2,253.39 5,900.00 73.75 301.51 4,298.47 4,250.27 3,357.48 -177.18 6,019,512.10 569,199.09 4.00 2,347.69 6,000.00 76.53 298.54 4,324.12 4,275.92 3,405.82 -260.85 6,019,559.66 569,114.98 4.00 2,442.47 6,100.00 79.35 295.63 4,345.01 4,296.81 3,450.32 -347.91 6,019,603.35 569,027.52 4.00 2,537.26 6,200.00 82.19 292.77 4,361.06 4,312.86 3,490.77 -437.93 6,019,642.95 568,937.14 4.00 2,631.59 6,298.49 85.00 290.00 4,372.05 4,323.85 3,526.45 -529.04 6,019,677.77 568,845.70 4.00 2,723.62 End Dir : 6298.49' MD, 4372.05' TVD 6,300.00 85.00 290.00 4,372.19 4,323.99 3,526.96 -530.46 6,019,678.27 568,844.28 0.00 2,725.02 6,400.00 85.00 290.00 4,380.90 4,332.70 3,561.03 -624.07 6,019,711.47 568,750.37 0.00 2,817.85 6,500.00 85.00 290.00 4,389.62 4,341.42 3,595.10 -717.68 6,019,744.66 568,656.45 0.00 2,910.69 6,575.54 85.00 290.00 4,396.20 4,348.00 3,620.84 -788.40 6,019,769.74 568,585.51 0.00 2,980.82 SB OA 6,598.49 85.00 290.00 4,398.20 4,350.00 3,628.66 -809.88 6,019,777.36 568,563.95 0.00 3,002.12 StartDir 4°N 00' : 6598.49' MD, 4398.2'TVD -Start ESP Tangent -95/8" x 12 1l4" 6,600.00 85.06 290.02 4,398.33 4,350.13 3,629.18 -811.29 6,019,777.86 568,562.53 4.01 3,003.52 6,700.00 88.75 291.57 4,403.74 4,355.54 3,664.62 -904.62 6,019,812.43 568,468.89 4.00 3,097.05 11/12/2018 12:02:04PM Page 4 COMPASS 5000.15 Build 91 Halliburton HALLI BU RTON Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well Plan: MPU E-36 Company: Hilcorp Alaska, LLC TVD Reference: MPE-36 KBE @ 48.20usft Project: Milne Point MD Reference: MPE-36 KBE @ 48.20usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-36 Survey Calculation Method: Minimum Curvature Wellbore: MPE-36 Design: MPE-36 wp08 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (1 (') (usft) usft (usft) (usft) (usft) (usft) 4,355.57 6,766.39 91.20 292.59 4,403.77 4,355.57 3,689.58 -966.14 6,019,836.81 568,407.15 4.00 3,159.75 End Dir : 6766.39' MD, 4403.77' TVD 6,800.00 91.20 292.59 4,403.07 4,354.87 3,702.49 -997.16 6,019,849.43 568,376.01 0.00 3,191.58 6,900.00 91.20 292.59 4,400.98 4,352.78 3,740.90 -1,089.46 6,019,886.98 568,283.36 0.00 3,286.30 7,000.00 91.20 292.59 4,398.89 4,350.69 3,779.31 -1,181.77 6,019,924.52 568,190.71 0.00 3,381.01 7,100.00 91.20 292.59 4,396.80 4,348.60 3,817.72 -1,274.08 6,019,962.07 568,098.06 0.00 3,475.73 7,200.00 91.20 292.59 4,394.72 4,346.52 3,856.13 -1,366.38 6,019,999.61 568,005.41 0.00 3,570.44 7,300.00 91.20 292.59 4,392.63 4,344.43 3,894.54 -1,458.69 6,020,037.16 567,912.76 0.00 3,665.16 7,400.00 91.20 292.59 4,390.54 4,342.34 3,932.95 -1,550.99 6,020,074.70 567,820.11 0.00 3,759.87 7,500.00 91.20 292.59 4,388.45 4,340.25 3,971.36 -1,643.30 6,020,112.25 567,727.46 0.00 3,854.59 7,600.00 91.20 292.59 4,386.36 4,338.16 4,009.77 -1,735.60 6,020,149.79 567,634.81 0.00 3,949.30 7,700.00 91.20 292.59 4,384.28 4,336.08 4,048.18 -1,827.91 .6,020,187.34 567,542.16 0.00 4,044.02 7,800.00 91.20 292.59 4,382.19 4,333.99 4,086.60 -1,920.21 6,020,224.88 567,449.51 0.00 4,138.73 7,900.00 91.20 292.59 4,380.10 4,331.90 4,125.01 -2,012.52 6,020,262.43 567,356.86 0.00 4,233.45 8,000.00 91.20 292.59 4,378.01 4,329.81 4,163.42 -2,104.82 6,020,299.98 567,264.20 0.00 4,328.16 8,100.00 91.20 292.59 4,375.92 4,327.72 4,201.83 -2,197.13 6,020,337.52 567,171.55 0.00 4,422.87 8,200.00 91.20 292.59 4,373.84 4,325.64 4,240.24 -2,289.43 6,020,375.07 567,078.90 0.00 4,517.59 8,300.00 91.20 292.59 4,371.75 4,323.55 4,278.65 -2,381.74 6,020,412.61 566,986.25 0.00 4,612.30 8,400.00 91.20 292.59 4,369.66 4,321.46 4,317.06 -2,474.04 6,020,450.16 566,893.60 0.00 4,707.02 8,500.00 91.20 292.59 4,367.57 4,319.37 4,355.47 -2,566.35 6,020,487.70 566,800.95 0.00 4,801.73 8,600.00 91.20 292.59 4,365.49 4,317.29 4,393.88 -2,658.66 6,020,525.25 566,708.30 0.00 4,896.45 8,700.00 91.20 292.59 4,363.40 4,315.20 4,432.29 -2,750.96 6,020,562.79 566,615.65 0.00 4,991.16 8,800.00 91.20 292.59 4,361.31 4,313.11 4,470.70 -2,843.27 6,020,600.34 566,523.00 0.00 5,085.88 8,900.00 91.20 292.59 4,359.22 4,311.02 4,509.11 -2,935.57 6,020,637.88 566,430.35 0.00 5,180.59 9,000.00 91.20 292.59 4,357.13 4,308.93 4,547.52 -3,027.88 6,020,675.43 566,337.70 0.00 5,275.31 9,100.00 91.20 292.59 4,355.05 4,306.85 4,585.93 -3,120.18 6,020,712.98 566,245-05 0.00 5,370.02 9,200.00 91.20 292.59 4,352.96 4,304.76 4,624.34 -3,212.49 6,020,750.52 566,152.40 0.00 5,464.74 9,300.00 91.20 292.59 4,350.87 4,302.67 4,662.75 -3,304.79 6,020,788.07 566,059.75 0.00 5,559.45 9,400.00 91.20 292.59 4,348.78 4,300.58 4,701.16 -3,397.10 6,020,825.61 565,967.10 0.00 5,654.17 9,500.00 91.20 292.59 4,346.69 4,298.49 4,739.57 -3,489.40 6,020,863.16 565,874.45 0.00 5,748.88 9,595.47 91.20 292.59 4,344.70 4,296.50 4,776.24 -3,577.53 6,020,899.00 565,786.00 0.00 5,839.31 Start Dir 4°/100' : 9595.47' MD, 4344.7'TVD 9,600.00 91.12 292.76 4,344.61 4,296.41 4,777.99 -3,581.71 6,020,900.71 565,781.80 4.00 5,843.60 9,700.00 89.37 296.36 4,344.18 4,295.98 4,819.54 -3,672.64 6,020,941.41 565,690.49 4.00 5,939.35 9,710.95 89.18 296.75 4,344.32 4,296.12 4,824.44 -3,682.44 6,020,946.21 565,680.65 4.00 5,949.94 End Dir : 9710.95' MD, 4344.32' TVD 9,800.00 89.18 296.75 4,345.60 4,297.40 4,864.51 -3,761.95 6,020,985.54 565,600.78 0.00 6,036.14 9,900.00 89.18 296.75 4,347.03 4,298.83 4,909.52 -3,851.24 6,021,029.71 565,511.08 0.00 6,132.94 10,000.00 89.18 296.75 4,348.46 4,300.26 4,954.52 -3,940.53 6,021,073.87 565,421.39 0.00 6,229.74 10,100.00 89.18 296.75 4,349.89 4,301.69 4,999.53 -4,029.81 6,021,118.04 565,331.69 0.00 6,326.53 10,200.00 89.18 296.75 4,351.32 4,303.12 5,044.53 -4,119.10 6,021,162.21 565,241.99 0.00 6,423.33 10,300.00 89.18 296,75 4,352.75 4,304.55 5,089.54 -4,208.39 6,021,206.37 565,152.30 0.00 6,520.13 10,400.00 89.18 296.75 4,354.18 4,305.98 5,134.54 -4,297.68 6,021,250.54 565,062.60 0.00 6,616.92 10,500.00 89.18 296.75 4,355.62 4,307.42 5,179.55 -4,386.97 6,021,294.71 564,972.91 0.00 6,713.72 10,600.00 89.18 296.75 4,357.05 4,308.85 5,224.55 -4,476.26 6,021,338.87 564,88321 0.00 6,810.52 11/12/2018 12:02:04PM Page 5 COMPASS 5000.15 Build 91 Halliburton H A LL I B U R TO N Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well Plan: MPU E-36 Company: Hilcorp Alaska, LLC TVD Reference: MPE-36 KBE @ 48.20usft Project: Milne Point MD Reference: MPE-36 KBE @ 48.20usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-36 Survey Calculation Method: Minimum Curvature Wellbore: MPE-36 Design: MPE-36 wp08 Planned survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +EI-W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 4,310.28 10,700.00 89.18 296.75 4,358.48 4,310.28 5,269.56 -4,565.55 6,021,383.04 564,793.52 0.00 6,907.31 10,800.00 89.18 296.75 4,359.91 4,311.71 5,314.56 -4,654.84 6,021,427.21 564,703.82 0.00 7,004.11 10,900.00 89.18 296.75 4,361.34 4,313.14 5,359.56 -4,744.13 6,021,471.37 564,614.12 0.00 7,100.91 11,000.00 89.18 296.75 4,362.77 4,314.57 5,404.57 -4,833.42 6,021,515.54 564,524.43 0.00 7,197.71 11,100.00 89.18 296.75 4,364.20 4,316.00 5,449.57 -4,922.70 6,021,559.71 564,434.73 0.00 7,294.50 11,200.00 89.18 296.75 4,365.64 4,317.44 5,494.58 5,011.99 6,021,603.87 564,345.04 0.00 7,391.30 11,300.00 89.18 296.75 4,367.07 4,318.87 5,539.58 -5,101.28 6,021,648.04 564,255.34 0.00 7,488.10 11,400.00 89.18 296.75 4,368.50 4,320.30 5,584.59 -5,190.57 6,021,692.21 564,165.64 0.00 7,584.89 11,500.00 89.18 296.75 4,369.93 4,321.73 5,629.59 -5,279.86 6,021,736.38 564,075.95 0.00 7,681.69 11,600.00 89.18 296.75 4,371.36 4,323.16 5,674.60 -5,369.15 6,021,780.54 563,986.25 0.00 7,778.49 11,700.00 89.18 296.75 4,372.79 4,324.59 5,719.60 -5,458.44 6,021,824.71 563,896.56 0.00 7,875.28 11,800.00 89.18 296.75 4,374.22 4,326.02 5,764.61 -5,547.73 6,021,868.88 563,806.86 0.00 7,972.08 11,900.00 89.18 296.75 4,375.66 4,327.46 5,809.61 -5,637.02 6,021,913.04 563,717.16 0.00 8,068.88 12,000.00 89.18 296.75 4,377.09 4,328.89 5,854.62 -5,726.31 6,021,957.21 563,627.47 0.00 8,165.68 12,100.00 89.18 296.75 4,378.52 4,330.32 5,899.62 -5,815.59 6,022,001.38 563,537.77 0.00 8,262.47 12,200.00 89.18 296.75 4,379.95 4,331.75 5,944.63 -5,904.88 6,022,045.54 563,448.08 0.00 8,359.27 12,300.00 89.18 296.75 4,381.38 4,333.18 5,989.63 -5,994.17 6,022,089.71 563,358.38 0.00 8,456.07 12,400.00 89.18 296.75 4,382.81 4,334.61 6,034.64 -6,083.46 6,022,133.88 563,268.69 0.00 8,552.86 12,500.00 89.18 296.75 4,384.25 4,336.05 6,079.64 -6,172.75 6,022,178.04 563,178.99 0.00 8,649.66 12,600.00 89.18 296.75 4,385.68 4,337.48 6,124.65 -6,262.04 6,022,222.21 563,089.29 0.00 8,746.46 12,700.00 89.18 296.75 4,387.11 4,338.91 6,169.65 -6,351.33 6,022,266.38 562,999.60 0.00 8,843.25 12,800.00 89.18 296.75 4,388.54 4,340.34 6,214.66 -6,440.62 6,022,310.54 562,909.90 0.00 8,940.05 12,900.00 89.18 296.75 4,389.97 4,341.77 6,259.66 -6,529.91 6,022,354.71 562,820.21 0.00 9,036.85 13,000.00 89.18 296.75 4,391.40 4,343.20 6,304.67 -6,619.19 6,022,398.88 562,730.51 0.00 9,133.64 13,100.00 89.18 296.75 4,392.83 4,344.63 6,349.67 -6,708.48 6,022,443.04 562,640.81 0.00 9,230.44 13,200.00 89.18 296.75 4,394.27 4,346.07 6,394.67 -6,797.77 6,022,487.21 562,551.12 0.00 9,327.24 13,300.00 89.18 296.75 4,395.70 4,347.50 6,439.68 -6,887.06 6,022,531.38 562,461.42 0.00 9,424.04 13,400.00 89.18 296.75 4,397.13 4,348.93 6,484.68 5,976.35 6,022,575.55 562,371.73 0.00 9,520.83 13,500.00 89.18 296.75 4,398.56 4,350.36 6,529.69 -7,065.64 6,022,619.71 562,282.03 0.00 9,617.63 13,600.00 89.18 296.75 4,399.99 4,351.79 6,574.69 -7,154.93 6,022,663.88 562,192.33 0.00 9,714.43 13,700.00 89.18 296.75 4,401.42 4,353.22 6,619.70 -7,244.22 6,022,708.05 562,102.64 0.00 9,811.22 13,800.00 89.18 296.75 4,402.85 4,354.65 6,664.70 -7,333.51 6,022,752.21 562,012.94 0.00 9,908.02 13,900.00 89.18 296.75 4,404.29 4,356.09 6,709.71 -7,422.80 6,022,796.38 561,923.25 0.00 10,004.82 14,000.00 89.18 296.75 4,405.72 4,357.52 6,754.71 -7,512.08 6,022,840.55 561,833.55 0.00 10,101.61 14,100.00 89.18 296.75 4,407.15 4,358.95 6,799.72 -7,601.37 6,022,884.71 561,743.86 0.00 10,198.41 14,200.00 89.18 296.75 4,408.58 4,360.38 6,844.72 -7,690.66 6,022,928.88 561,654.16 0.00 10,295.21 14,300.00 89.18 296.75 4,410.01 4,361.81 6,889.73 -7,779.95 6,022,973.05 561,564.46 0.00 10,392.01 14,400.00 89.18 296.75 4,411.44 4,363.24 6,934.73 -7,869.24 6,023,017.21 561,474.77 0.00 10,488.80 14,487.82 , 89.18 296.75 4,412.70 ' 4,364.50 6,974.25 -7,947.65 6,023,056.00 561,396.00 0.00 10,573.81 Total Depth: 14487.82' MD, 4412.7' TVD 11/122018 12:02:04PM Page 6 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-36 Wellbore: MPE-36 Design: MPE-36 wp08 Targets Target Name - hit/miss target Shape Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Dip Angle Dip Dir. TVD +N/ -S (1) M (usft) (usft) Halliburton Standard Proposal Report Well Plan: MPU E-36 MPE-36 KBE @ 48.20usft MPE-36 KBE @ 48.20usft True Minimum Curvature +EI -W Northing (usft) (usft) MPE-36 wp07 Toe 0.00 0.00 4,412.70 6,974.25 -7,947.65 - plan hits target center Depth - Circle (radius 50.00) Name MPE-36 wp08 Heel - updated 0.00 0.00 4,398.20 3,581.42 -623.27 - plan misses target center by 48.97usft at 6594.93usft MD (4397.89 TVD, 3627.45 N. -806.55 E) - Circle (radius 50.00) Formations '.. - _ MPE-36 wp07 CPI 0.00 0.00 4,344.70 4,776.24 -3,577.52 - plan hits target center Depth Depth Depth SS - Point (usft) (usft) Casing Points Measured Vertical Vertical Depth Depth Depth (usft) (usft) Name 6,598.49 4,398.20 9 5/8" x 12 1/4" 14,487.82 4,412.70 6 5/8" x 8 1/2" Formations '.. - _ .... Measured Vertical Vertical 0.00 Depth Depth Depth SS 550.00 (usft) (usft) Name 4,807.98 3,759.20 LA3 6,575.54 4,396.20 S8_OA 3,040.88 2,505.20 SV1 2,215.94 1,915.20 8PRF 5,763.96 4,256.20 SB NA Plan Annotations 3,526.45 Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) 280.00 280.00 0.00 0.00 550.00 549.10 14.60 12.25 1,646.28 1,507.77 454.41 217.61 4,366.00 3,452.94 2,341.39 446.77 6,298.49 4,372.05 3,526.45 -529.04 6,598.49 4,398.20 3,628.66 -809.88 6,766.39 4,403.77 3,689.58 -966.14 9,595.47 4,344.70 4,776.24 -3,577.53 9,710.95 4,344.32 4,824.44 -3,682.44 14,487.82 4,412.70 6,974.25 -7,947.65 Comment 6,023,056.00 6,019,730.00 6,020,899.00 Easting (usft) 561,396.00 Casing Hole Diameter Diameter 35/8 12-1/4 6-5/8 8-1/2 568,551.00 565,786.00 Dip Dip Direction Lithology (") (") StartDir 3°/100' : 280' MD, 280'TVD StartDir 4°/100' : 550' MD, 549.1'lVD End Dir : 1646.28' MD, 1507.77' TVD Start M46/100': 4366' MD, 3452.94'TVD End Dir : 6298.49' MD, 4372.05' TVD Start Dir 4°/100' : 6598.49' MD, 4398.2T7D -Start ESP Tangent End Dir : 6766.39' MD, 4403.77' TVD Start Dir 4°/100' : 9595.47' MD, 4344.7'TVD End Dir : 9710.95' MD, 4344.32' TVD Total Depth : 14487.82' MD, 4412.7' TVD 11/122018 12:02:04PM Page 7 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-36 MPE-36 MPE-36 wp08 Sperry Drilling Services Clearance Summary Anticollision Report 12 November, 2018 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 Well Coordinates: 6,016,156.74 N, 569,407.52 E (70° 27' 16.18" N, 149° 26' 00.98" W) Datum Height: MPE-36 KBE @ 48.20usft Scan Range: 26.50 to 6,598.49 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: GLOBAL FILTER APPLIED. All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Plan: MPU E-36 - MPE-36 wp08 Closest Approach 30 Proximity Scan on Current Survey Data (North Reference) 5,192.38 Reference Design: M Pt E Pad - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 5,192.38 Scan Range: 26.50 to 6,598.49 usft. Measured Depth. MPCFP-2 - MPCFP-2 - MPCFP-2 Scan Radius Is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,000.00 usft Measured Minimum @Measured Ellipse Site Name Depth Distance Depth Separation Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) M Pt A Pad Centre Distance M Pt C Pad 7I"41 MPCFP-2 - MPCFP-2 - MPCFP-2 5,192.38 605.40 5,192.38 545.32 MPCFP-2 - MPCFP-2 - MPCFP-2 5,551.50 671.05 5,551.50 603.31 M Pt E Pad Pass - 625.61 65.059 Centre Distance MPE-02 - MPE-02 - MPE-02 5,401.50 189.56 5,401.50 28.41 MPE-02 - MPE-02 - MPE-02 5,426.50 179.53 5,426.50 27.50 MPE-02 - MPE-02 - MPE-02 5,569.61 147.78 5,569.61 76.17 MPE-03 - MPE-03 - MPE-03 624.29 600.83 624.29 591.59 MPE-03 - MPE-03 - MPE-03 701.50 601.25 701.50 590.93 MPE-03 - MPE-03 - MPE-03 1,876.50 754.24 1,876.50 735.57 MPE-04 - MPE-04 - MPE-04 1,563.13 198.56 1,563.13 177.06 MPE-04 - MPE-04 - MPE-04 1,576.50 198.83 1,576.50 177.04 MPE-04 - MPE-04 - MPE-04 1,626.50 204.76 1,626.50 181.80 MPE-05 - MPE-05 - MPE-05 1,281.57 260.47 1,281.57 241.22 MPE-05 - MPE-05 - MPE-05 1,376.50 265.58 1,376.50 245.56 MPE-06 - MPE-06 - MPE-06 1,374.98 225.51 1,374.98 205.63 MPE-06 - MPE-06 - MPE-06 1,376.50 225.51 1,376.50 205.62 MPE-06 - MPE-06 - MPE-06 1,451.50 227.93 1,451.50 207.49 MPE-07 - MPE-07 - MPE-07 673.41 204.98 673.41 193.01 MPE-07 - MPE-07 - MPE-07 726.50 205.39 726.50 192.48 MPE-07 - MPE-07 - MPE-07 901.50 216.14 901.50 200.58 MPE-08 - MPE-08 - MPE-08 2,027.43 297.85 2,027.43 271.88 MPE-08 - MPE-08 - MPE-08 2,076.50 299.24 2,076.50 273.04 MPE-12 - MPE-12 - MPE-12 261.59 89.89 261.59 85.10 Hileorp Alaska, LLC Milne Point @Measured Clearance Summary Based on Depth Factor Minimum Separation Warning usft 4,438.10 10.076 Ellipse Separation Pass - 4,606.01 9.906 Clearance Factor Pass - 5,211.47 1.176 Clearance Factor Pass - 5,230.01 1.181 Ellipse Separation Pass - 5,330.45 2.064 Centre Distance Pass - 625.61 65.059 Centre Distance Pass - 697.01 58.248 Ellipse Separation Pass - 1,568.20 40.401 Clearance Factor Pass - 1,617.45 9.235 Centre Distance Pass - 1,626.30 9.126 Ellipse Separation Pass - 1,658.33 8.919 Clearance Factor Pass - 1,305.89 13.526 Ellipse Separation Pass - 1,386.76 13,262 Clearance Factor Pass - 1,399.58 11,344 Centre Distance Pass - 1,401.06 11.337 Ellipse Separation Pass - 1,472.46 11.152 Clearance Factor Pass - 680.09 17.134 Centre Distance Pass - 731.65 15.904 Ellipse Separation Pass - 897.90 13.887 Clearance Factor Pass - 2,038.39 11.469 Ellipse Separation Pass - 2,082.06 11.418 Clearance Factor Pass - 270.74 18.768 Centre Distance Pass - 12 November, 2018 - 11:49 Page 2 of 8 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-36 - MPE-36 wp08 Hilcorp Alaska, LLC Milne Point Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 Scan Range: 26.50 to 6,598.49 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,000.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft MPE-12 - MPE-12 - MPE-12 426.50 90.55 426.50 83.50 433.28 12.834 Ellipse Separation Pass - MPE-12 - MPE-12 - MPE-12 2,801.50 405.31 2,801.50 355.49 2,792.28 8.136 Clearance Factor Pass - - MPE-14 - MPE-14 - MPE-14 225.87 181.55 225.87 178.50 235.37 59.485 Centre Distance Pass - MPE-14 - MPE-14 - MPE-14 301.50 181.75 301.50 177.77 310.52 45.722 Ellipse Separation Pass - MPE-14 - MPE-14 - MPE-14 801.50 246.34 801.50 236.24 802.91 24.393 Clearance Factor Pass - MPE-14 - MPE-14A- MPE-14A 225.87 181.55 225.87 178.78 235.37 65.523 Centre Distance Pass - MPE-14 - MPE-14A- MPE-14A 301.50 181.75 301.50 178.05 310.52 49.204 Ellipse Separation Pass - MPE-14 - MPE-14A- MPE-14A 801.50 246.34 801.50 236.52 802.91 25.092 Clearance Factor Pass - MPE-14 - MPE-14AP131 - MPE-14APB1 225.87 181.55 225.87 178.50 235.37 59.485 Centre Distance Pass - MPE-14 - MPE-14APB1 - MPE-14APB1 301.50 181.75 301.50 177.77 310.52 45.722 Ellipse Separation Pass - MPE-14-MPE-14APB1-MPE-I4APB1 801.50 246.34 801.50 236.24 802.91 24.393 Clearance Factor Pass - MPE-15 - MPE-15 - MPE-15 101.50 169.14 101.50 167.25 107.20 89.466 Centre Distance Pass - MPE-15 - MPE-15 - MPE-15 276.50 170.80 276.50 165.49 279.56 32.121 Ellipse Separation Pass - MPE-15 - MPE-15 - MPE-15 776.50 243.55 776.50 228.42 768.57 16.096 Clearance Factor Pass - MPE-16 - MPE-16 - MPE-16 1,676.77 143.77 1,676.77 126.41 1,666.26 8.281 Ellipse Separation Pass - MPE-16 - MPE-16 - MPE-16 1,726.50 144.82 1,726.50 127.20 1,712.23 8.221 Clearance Factor Pass - MPE-17 - MPE-17 - MPE-17 697.44 41.74 697.44 32.67 704.85 4.605 Centre Distance Pass - MPE-17 - MPE-17 - MPE-17 701.50 41.74 701.50 32.63 708.88 4.581 Ellipse Separation Pass - MPE-17 - MPE-17 - MPE-17 751.50 43.50 751.50 33.76 758.22 4.466 Clearance Factor Pass - MPE-19 - MPE-19 - MPE-19 210.93 119.66 210.93 116.78 221.28 41.607 Centre Distance Pass - MPE-19 - MPE-19 - MPE-19 326.50 120.58 326.50 116.30 334.81 28.180 Ellipse Separation Pass - MPE-19 - MPE-19 - MPE-19 776.50 147.82 776.50 137.99 767.54 15.044 Clearance Factor Pass - MPE-20 - MPE-20 - MPE-20 281.27 217.15 281.27 213.20 289.34 54.908 Centre Distance Pass - MPE-20 - MPE-20 - MPE-20 326.50 217.38 326.50 212.86 334.97 48.152 Ellipse Separation Pass - MPE-20 - MPE-20 - MPE-20 801.50 270.02 801.50 259.65 798.21 26.060 Clearance Factor Pass - MPE-20 - MPE-20A - MPE-20A 281.27 217.15 281.27 213.44 291.89 58.449 Centre Distance Pass - MPE-20 - MPE-20A- MPE-20A 326.50 217.38 326.50 213.10 337.52 50.850 Ellipse Separation Pass - MPE-20 - MPE-20A - MPE-20A 801.50 270.02 801.50 259.89 800.76 26.676 Clearance Factor Pass - MPE-20 - MPE-20AL1 - MPE-20AL1 281.27 217.15 281.27 213.57 291.89 60.571 Centre Distance Pass - MPE-20 - MPE-20AL1 - MPE-20AL1 326.50 217.38 326.50 213.23 337.52 52.448 Ellipse Separation Pass - 12 November, 2018 - 11:49 Page 3 of 8 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU E-36 - MPE-36 wp08 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 Scan Range: 26.50 to 6,598.49 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft MPE-20 - MPE-20AL1 - MPE-20AL1 801.50 270.02 801.50 260.02 800.76 27.024 Clearance Factor Pass - MPE-20 - MPE-20ALIPBI - MPE-20AL1PB1 281.27 217.15 281.27 212.92 291.89 51.325 Centre Distance Pass - MPE-20 - MPE-20ALlPBI - MPE-20AL1PB1 326.50 217.38 326.50 212.59 337.52 45.377 Ellipse Separation Pass - MPE-20 - MPE-20ALIPBI - MPE-20AL1PB1 801.50 270.02 801.50 259.38 800.76 25.383 Clearance Factor Pass - MPE-21 - MPE-21 - MPE-21 964.72 217.89 964.72 207.35 988.72 20.683 Ellipse Separation Pass - MPE-21 - MPE-21 - MPE-21 1,076.50 222.44 1,076.50 211.43 1,089.68 20.215 Clearance Factor Pass - MPE-23 - MPE-23 - MPE-23 654.76 142.12 654.76 132.56 659.51 14.867 Centre Distance Pass - MPE-23 - MPE-23 - MPE-23 701.50 142.52 701.50 132.29 705.16 13.931 Ellipse Separation Pass - MPE-23 - MPE-23 - MPE-23 851.50 152.70 851.50 140.54 848.65 12.553 Clearance Factor Pass - MPE-24 - MPE-24 - MPE-24 219.49 197.91 219.49 194.92 228.39 66.028 Centre Distance Pass - MPE-24 - MPE-24 - MPE-24 276.50 198.10 276.50 194.41 284.14 53.705 Ellipse Separation Pass - MPE-24 - MPE-24 - MPE-24 726.50 266.77 726.50 257.65 699.55 29.256 Clearance Factor Pass - MPE-24 - MPE-24A - MPE-24A 219.49 197.91 219.49 195.03 224.99 68.528 Centre Distance Pass - MPE-24 - MPE-24A - MPE-24A 276.50 198.10 276.50 194.52 280.74 55.346 Ellipse Separation Pass - MPE-24 - MPE-24A- MPE-24A 726.50 266.77 726.50 257.76 696.15 29.611 Clearance Factor Pass - MPE-24 - MPE-24AL1 - MPE-24AL1 219.49 197.91 219.49 195.13 224.99 71.092 Centre Distance Pass - MPE-24 - MPE-24AL1 - MPE-24AL1 276.50 198.10 276.50 194.62 280.74 57.005 Ellipse Separation Pass - MPE-24 - MPE-24ALI - MPE-24AL1 726.50 266.77 726.50 257.86 696.15 29.957 Clearance Factor Pass - MPE-31 - MPE-31 - MPE-31 2,052.96 51.26 2,052.96 34.04 1,996.61 2.977 Centre Distance Pass - _ MPE-31 - MPE-31 - MPE-31 2,076.50 52.64 2,076.50 33.31 2,016.96 2.724 Ellipse Separation Pass - MPE-31 - MPE-31 - MPE-31 2,126.50 63.47 2,126.50 38.22 2,060.16 2.514 Clearance Factor Pass - MPE-31 - MPE-31 PBI -MPE-31 PB1 2,052.96 51.26 2,052.96 34.04 1,996.61 2.977 Centre Distance Pass - MPE-31 - MPE-31 PBI - MPE-31 P131 2,076.50 52.64 2,076.50 33.31 2,016.96 2.724 Ellipse Separation Pass - MPE31-MPE-3I PBI -MPE-31 PB1 2,126.50 63.47 2,126.50 38.22 2,060.16 2.514 Clearance Factor Pass - MPE-32 - MPE-32 - MPE-32 1,739.02 337.70 1,739.02 321.75 1,703.89 21.166 Ellipse Separation Pass - MPE-32 - MPE-32 - MPE-32 1,801.50 339.70 1,801.50 323.57 1,755.68 21.058 Clearance Factor Pass - MPE-32-MPE-321-1-MPE-321-1 1,739.02 337.70 1,739.02 321.75 1,703.89 21.166 Ellipse Separation Pass - MPE-32 - MPE-321-1 - MPE-321-1 1,801.50 339.70 1,801.50 323.57 1,755.68 21.058 Clearance Factor Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 1,739.02 337.70 1,739.02 321.75 1,703.89 21.166 Ellipse Separation Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 1,801.50 339.70 1,801.50 323.57 1,755.68 21.058 Clearance Factor Pass - 12 November, 2018 - 11:49 Page 4 of 8 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU E-36 - MPE-36 wp08 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-36. MPE-36 - MPE-36 wp08 Scan Range: 26.50 to 6,596.49 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft MPE-33 - MPE33 - MPE-33 26.50 539.93 26.50 539.19 33.51 729.654 Centre Distance Pass - MPE-33 - MPE33 - MPE33 376.50 541.56 376.50 536.85 372.95 114.916 Ellipse Separation Pass - - MPE-33-MPE-33-MPE-33 6,598.49 822.91 6,598.49 639.48 6,603.76 4.486 Clearance Factor Pass - Plan: MPU E-35 - MPU E-35 - MPU E-35 wp09 276.50 30.13 276.50 26.14 276.50 7.552 Centre Distance Pass - Plan: MPU E-35 - MPU E-35 - MPU E-35 wp09 601.50 31.24 601.50 23.22 602.45 3.898 Ellipse Separation Pass - Plan: MPU E-35 - MPU E-35 - MPU E-35 wpo9 676.50 33.42 676.50 24.46 677.25 3.728 Clearance Factor Pass - Plan: MPU E-37 - MPE-37 - MPE-37 wp07 551.37 30.44 551.37 20.35 550.51 3.018 Centre Distance Pass - Plan: MPU E-37 - MPE-37 - MPE-37 wp07 601.50 30.85 601.50 19.87 600.00 2.810 Ellipse Separation Pass - Plan: MPU E-37 - MPE-37 - MPE-37 wp07 701.50 34.06 701.50 21.30 698.46 2.667 Clearance Factor Pass - Plan: MPU E-38 - MPE-38 - MPE-38 WP07 873.65 152.55 873.65 140.69 929.06 12.861 Centre Distance Pass - Plan: MPU E-38 - MPE-38 - MPE-38 WP07 876.50 152.56 876.50 140.68 931.63 12.838 Ellipse Separation Pass - Plan: MPU E-38 - MPE-38 - MPE-38 WP07 901.50 153.07 901.50 141.01 954.18 12.692 Clearance Factor Pass - Plan: MPU E-40 - MPE-401- MPE-40 wp01 276.50 169.06 276.50 165.21 275.50 43.826 Centre Distance Pass - Plan: MPU E-40 - MPE40i - MPE40 wp01 301.50 169.18 301.50 165.02 301.50 40.616 Ellipse Separation Pass - Plan: MPU E-40 - MPE40i - MPE40 wp01 701.50 224.44 701.50 215.46 685.94 25.010 Clearance Factor Pass - Plan: MPU E-41 - MPE41 - MPE41 wp01 276.50 160.88 276.50 156.89 276.50 40.329 Centre Distance Pass - Plan: MPU E-41 - MPE41 - MPE41 wp01 301.50 161.00 301.50 156.71 301.50 37,468 Ellipse Separation Pass - Plan: MPU E-41 - MPE41 - MPE41 wp01 651.50 207.70 651.50 199.24 632.55 24.550 Clearance Factor Pass - Prelim Duall-atPlan: MPU E-39 - MPU E -39i - MPU E-: 276.50 158.52 276.50 154.66 276.50 41.093 Centre Distance Pass - Prelim Duall-atPlan: MPU E-39 - MPU E -39i - MPU E-; 301.50 158.64 301.50 154.47 301.50 38.084 Ellipse Separation Pass - Prelim Duall-atPlan: MPU E-39 - MPU E391 - MPU E-: 601.50 197.18 601.50 189.47 581.42 25.556 Clearance Factor Pass - 12 November, 2018 - 11:49 Page 5 of 8 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-36 - MPE-36 wpo8 Survey tool oroaram From (usft) 26.50 600.00 6,600.00 To (usft) 800.00 MPE-36 wp08 6,600.00 MPE-36 wp08 14,487.81 MPE-36 wp08 Survey/Plan Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 2_Gyro-SR-GSS 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point 12 November, 2018 - 11,49 Page 6 of 8 COMPASS WALLIBURTON Sperry Orllling I Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-36 Wellbore: MPE-36 Plan: MPE-36 wp06 Ladder / S.F. Plots SHO of 2) C nllnale (ME) Referemz: Wal Pun- MPU E46, Tme Norm Vedual (TVD) Reference: MPE46 KBE @ 46,Wwft Measured Depth Rulcm x: MPEJB KBE @ 48.20uett Foo,� calculation Mum : Minimum CuNaWre SURVEY PROGRAM Date:2018-09-1M13:00:00 Velidated:Yes Version: Dapth From Depth To Survey/Plan Tool 26.50 BOOnO MPE-36 wp08 (MPE-36) 2_Gyro-SR-GSS 800.00 6600.00 MPE-36 wP08(MPE-36) 2_MWD+IFR2+MS+Seg 6600.00 1448T.B1 MPE-36 wpD8(MPE-36) 2_MWD+IFR2+MS+Sag WELL DETMLS:Plan: MPU E-36 NAD 1927(NADCON CONUS) Alaskiiam,04 Ground Level 21.70 +V -M' Northing Easling Latinude Lmiitudn 0.00 6016156.74 569407.52 70° 27' 16.178 N 149° 26'0.984 W GLOBAL FILTER APPLIED: All wellpaths wdhin 200'+ IDOM 000 of reference 26.50 To 14487.82 CASING DETAILS TVD TVDSS MD Sim Namc 4398.20 4350.00 6598.49 9-5/8 9 5/8" z 12 1/4" Measured Depth (700 usfUin) Measured Depth Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-36 MPE-36 MPE-36 wp08 Sperry Drilling Services Clearance Summary Anticollision Report 12 November, 2018 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 Well Coordinates: 6,016,156.74 N, 569,407.52 E (70° 27' 16.18" N, 149" 26' 00.98" W) Datum Height: MPE-36 KBE @ 48.20usft Scan Range: 6,598.49 to 14,487.82 usft. Measured Depth. Scan Radius Is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,000.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: GLOBAL FILTER APPLIED. All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Plan: MPU E-36 - MPE-36 wp08 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E-36 - MPE-36 - MPE-36 wp08 Scan Range: 6,598.49 to 14,487.82 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft M Pt A Pad MPA -01 - MPA -01 - MPA -01 MPA -01 - MPA -01 - MPA -01 MPA -01 - MPA -01 - MPA -01 MPA -03 - MPA -03 - MPA -03 MPA -03 - MPA -03 - MPA -03 MPA -03 - MPA -03 - MPA -03 M Pt C Pad MPU C-41 - MPC -41 L2 - MPC -41 L2 MPU C-41 - MPC -41 L2 - MPC -411.2 M Pt CFP MPCFP-2 - MPCFP-2 - MPCFP-2 M Pt E Pad MPE-02 - MPE-02 - MPE-02 MPE-03 - MPE-03 - MPE-03 MPE-03 - MPE-03 - MPE-03 MPE-03 - MPE-03 - MPE-03 MPE-33 - MPE-33 - MPE-33 MPE-33 - MPE-33 - MPE-33 MPE-33 - MPE-33 - MPE-33 Plan: MPU E-35 - MPU E-35 - MPU E-35 wp09 Plan: MPU E-35 - MPU E-35 - MPU E-35 wp09 Plan: MPU E-37 - MPE-37 - MPE-37 wp07 Plan: MPU E-37 - MPE-37 - MPE-37 wp07 Plan: MPU E-37 - MPE-37 - MPE-37 wp07 Hilcorp Alaska, LLC Milne Point Separation Warning 11,411.16 3.604 847.24 Pass - _. 11,411.16 6.736 674.91 Pass - 4,365.14 6.861 4.916 Centre Distance Pass - 11,423.49 Centre Distance 847.33 11,423.49 674.65 - 4,365.11 4.913 Ellipse Separation Pass - 11,448.49 728.07 10,525.31 848.06 Centre Distance 11,448.49 678.72 14,565.14 675.35 Clearance Factor 4,365.05 831.76 9,517.51 4.910 Clearance Factor Pass - 12,012.46 6.746 1,223.15 Pass - 12,012.46 3.448 1,006.74 Pass - 4,640.14 5.652 Centre Distance Pass - 12,048.49 1,223.68 12,048.49 1,005.80 4,642.99 5.616 Ellipse Separation Pass - 12,173.49 1,233.64 12,173.49 1,011.79 4,652.86 5.561 Clearance Factor Pass - 11,598.49 477.87 11,598.49 37.61 13,850.00 1.085 Clearance Factor Pass - 11,679.99 470.87 11,679.99 48.98 13,850.00 1.116 Centre Distance Pass - 6,598.49 1,397.02 6,598.49 1,309.12 4,615.14 15.893 Clearance Factor Pass - 6,598.49 943.25 6,598.49 8,548.49 720.54 8,548.49 8,673.49 710.49 8,673.49 8,707.65 710.04 8,707.65 \ 10,413.02 964.44 10,413.02 14,487.82 1,109.43 14, 487.82 8,494.37 970.09 8,494.37 8,623.49 973.05 8,623.49 13,048.49 1,179.65 13,048.49 681.55 5,738.42 3.604 Clearance Factor Pass - _. 613.58 6,943.28 6.736 Clearance Factor Pass - 606.93 7,006.94 6.861 Ellipse Separation Pass - 607.68 7,029.20 6.936 Centre Distance Pass - IIIIIIIII� _ - - IIIIIIIIII� - - - 728.07 10,525.31 4.080 Centre Distance Pass - 678.72 14,565.14 2.576 Clearance Factor Pass - 831.76 9,517.51 7.013 Centre Distance Pass - 828.80 9,600.00 6.746 Ellipse Separation Pass - 837.51 13,943.34 3.448 Clearance Factor Pass - 12 November, 2018 - 12:05 Page 2 of 5 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-36 - MPE-36 wp08 From (ustt) 26.50 800.00 6,600.00 To (usft) 800.00 MPE-36 wp08 6,600.00 MPE-36 wp08 14,487.81 MPE-36 wp08 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Survey/Plan Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 2_GyroSR-GSS 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point 12 November, 2018 - 12:05 Page 3 of 5 COMPASS NALLIBUiaiON REFERENCE INFORMATION WELLDEfAILS:PIen:MPUE-36 NAD1927(NADCONCONUS) Alaska Zone04 Project: Milne Point Coadinele(ME) Relemnce: Well Plan: MPU EBB, True NOM Site: MPtEPad Gmund Level: 21.70 13penny 0,18x, V.1.1DVO) Ream- MPES6 KBE@o0.20us, Well: Plan: MPU E-36 Measured Depth Reference: MPE-36 KBE Q 48,20usX +NAS +F/ -W Northing Easlin6 latnmde Longitude Wellbore: MPE-36 calculation Mstlrod wrimum Curvftue 0.00 0.00 6016156.74 569407.52 70"27'16.178N 14V 26'0.984W Plan: MPE-36 wpO8 SURVEY PROGRAM GLOBAL FILTER APPLIED. All wellpaths, within 200'+ 100/1000 of reference Em Data: 2018-09-17T00:00:00 Validated: Yes Version: 26.50 To 14487.82 Depth From Depth To Survey/Plan Tool CASING DETAILS Ladder/S.F. Plots 26.50 600.00 MPE-36 wp08(MPE-36) 2_Gym-SR-GSS TVD TVDSS MD Sm Nnme 800.00 6600.00 MPE-36 wp08(MPE-36) 2 MWD+IFR2+MS+Seg PH(2of2) 6600.00 14487.81 MPE-36wp08(MPE-36) 2_MWD+IFR2+MS+Seg 4398.20 4350.00 6598.49 9-5/8 95/8"x721/4" 4412.70 4364.50 14487.82 6-5/8 6 5/8" x 8 1/2" 180.00 C_ 1150.00 0 0 0 c 0 C6 090.00-- .90.00rn U) d 66.00 - ----- U 0 m MPE-33 30.00 _ U 0.00 6800 7225 7650 8075 8500 8925 9350 9775 10200 10625 11050 11475 11900 12325 12750 13175 13600 14025 14450 Measured Depth (850 usfUin) s0 4.50- 0 o 3.00 LL C EO a Collision Risk Procedures Rq. � m - - Collision Avoidance Req. No -Go Zone -Stop Drilling 0.00- 6750 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 12150 12600 13050 13500 13950 14400 14850 Measured Depth Schwartz, Guy L (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Wednesday, January 16, 2019 2:58 PM To: Schwartz, Guy L (DOA) Cc: Taylor Wellman; Monty Myers Subject: RE: [EXTERNAL] E-36 MPU SB injector (PTD 219-005) Hello Guy — Thanks for the questions. Responses are below: 1. The inner string triple connect for well control is listed in step 16.3 2. E-33 is an abandoned SB producer, with cement in the liner except the last 5' of the heel. Where the close approach occurs with E-36, there is cement isolating it from surface and there are no reservoir pressure risks with collision. The only risk is damage to the bit. Our mitigation will be to control drill past and watch for magnetic interference. Regarding the long term plan for E-33, a cement down squeeze is planned with a TOC of 4,500' MD, to occur in ` 1 month. 3. C-411_1 & L2 P&As have been completed. Final pressure tests are occurring in the near future (planned for today). Thank you for your time. Please let me know if you have any questions. Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 [ Cell: 805.235.6265 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, January 16, 2019 8:58 AM To: Joe Engel <jengel@hilcorp.com> Subject: [EXTERNAL] E-36 MPU SB injector (PTD 219-005) Joe, A couple comments on PTD application: 1. Step 16.7 should include having the triple x -over ready to be deployed in casing of a well control issue while deploying the inner string. 2. What are your mitigation plans for drilling past E-33? 3. What is the status of the P & A's for C -41L1 and L2 laterals. (PTD 201-079 and PTD 201-122) Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.aovl. Transform Points Source coordinate system Target coordinate system State Plane 1927 - Alaska Zone 4 Albers Equal Area (150) Datum: Datum: NAD 1927 - North America Datum of 1927 (Mean) NAD 1927 - Noah America Datum of 1927 (Mean) Ffype valuesinto the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to loopy and Ctd+Vto paste. Then dick on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: M P a E 1-3 PTD: 119- 00-57 Development V Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: tA h PD t K+ POOL: 5G V 0.4 y D ufie 0I 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 (If last two digits No. , API No. 50 - Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- _-_� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are fust 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 l 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 da s after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 — Well Name: M11 NE PT UNIT E-36 Program SER Well bore seg ❑ PTD#: 2190050 Company HILCORP ALASKA LLC Initial Class/Type SER 1 PEND GeoArea $90 Unit ]1328 On/Off Shore On Annular Disposal ❑ Administration 1 Permitfeeattached. . .. _ - - - - . . ............ . .NA 2 Lease number appropriate- - - -- - - - - - - - - - - - - -------- - - - - - - - - - - - - Yes - - - - - - - - - 3 Unique well name and number . . . .......... . . . . . . . . ..... . . . . .. . . Yes 4 Well located in a. defined pool ........ . . . . . . - - - - _ .. - ... Yes .. - - - - - . - - - - - - - - 5 Well located proper distance from drilling unit -boundary -- - - - ----- - - - - - - - - - - - - - Yes ...... Milne Point Schrader Bluff Oil Pool (525140), governed by. CO 477, amended by CO 477,05, - 6 Well Jocated proper distance from other wells. - - - - - - - - - - Yes - _ - - CO 477.05 specifies:. "There are no restrictions as to well spacing except that no pay shall - - 7 Sufficient acreage available in drilling unit- - - - _ - - _ - _ - - - - .. Yes ... - be openedina well closer than 500 feel from the exterior boundary of the affected area."- - - 8 If deviated, is wellbore plat included - - - - - - ..... - - - - - - Yes _ - Area Injection Order No.. 10-6 - - - - - - 9 Operator only affected part'... - - - - - - - - - .. - .. Yes 10 Operator has appropriate bond in force - - - _ - - - - - - - - _ - _ Yes 11 Permit can be issued without conservation order.... - - _ - - - -- - - - - - - - - - - Yes Appr Date 12 Permit can be issued without administrative approval .. - - - - - - - .... - Yes - - - 13 Can permit be approved before 15 -day wait. - - - - ..... - - - - Yes - - - - - - - - - - - - - - - - - - DLB 1/10/2019 14 .Well located within area and strata authorized by -Injection Order # (put 10# in. comments) (For- Yes - _ - Area Injection Order No. 10-B ............- 15 All wells -within 14 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 Nonoonven. gas -conforms to AS31.05.03oQ.1.A),G.2.A-D) - - - - - - - - - --- - - - - - - - - NA_ - - - ...... - ................ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 18 Conductor stringprovided------- - - - - - - - - - - .... - - - - - - - - - - - ..... Yes Conductor set at 107 ft. - _- Engineering 19 Surface.casing-protects all known USDWs ....... - - - - - - _ - - .NA - Permafrost area.., no aquifers. -- '20 CMT vol adequate to circulate on conductor& surf cog - - - _ - - - -- - - - - - - - - - - Yes . Using 2. stage cement., ES at 2500 ff.- - 21 C.MT. vol adequate to fie -in long string to surf cs9- - . . . . . . . . ........... Yes 22 CMT will cover all knownproductivehorizons- - - _ - - Yes .... Swell packers and ICD will be used in lateral. injection zone. 23 Casing designs adequate for C, T, B 8 -permafrost - - - - - - - .... - _ _ - - _ - Yes - - - ..... .. - - - 24 Adequate tankage. or reserve pit _ _ - - _ - - - - - - - - . . ........ . . . . Yes _ - - - _ _ Rig has steel pits, - - ... - - - - - - - - - - _ - .. - .......... . 25 If a -re -drill, has -a 10-403 for abandonment been approved - - - - - - - - - - - - - - -- - - - - NA- --------------- 26 Adequate wellbore separation proposed - _ - - ....... . . . . . . . .. . Yes - - Close. crossing with E-33 at 7500 ff. Reservoir is P & Ad with cement. 27 If diverter required, does it meet regulations - ... - _ . . . . . . . . . ........ Yes _ - _ - - Innovation rig has 16" diyerter.. Uses DOPE for annular- Appr Date 28 Drilling fluid. program schematic & equip list adequate- - - - --- - - - - - - - - - - - - .. Yes ... - .. Max form pressure =-1934 psi ( 8.6ppg EMW )- drilling with 8.8 - 9.5 ppg mud - GLS 1/16/2019 29 DOPEs,.do they meet regulation ... - - _ - - - - - - - - - Yes - - - - - .. . 30 DOPEpressrating appropriate; test to (put psig in comments)- - - - - --- - - - - - - - Yes - - - - MASP = 1495 -psi. Will test BOPE to 3000 psi - - - - - - - - - - - - - _ - - - - - - .. _ _ - - - . 31 Choke.manifold complies. w/API RP -53 (May 84). - - - - - - - - - - - ---- - - - - - Yes 32 Work will occur without operation shutdown- . ...... ..... . . . . . . . . . . . . . Yes . - . - .. - _ - - - -- 33 Js presence of H2$ gas probable ----------- - --------- ------- --------Yes -...................--..--..-..-------... --..- 34 -Mechanical condition of wells within AOR verified (For service well only) ............ . . Yes _ _ . _ . _ _ 1/4 mile review completed ( C-41 L2. recently P & Rd-)- - - - _ - - - _ , - _ _ _ - - , _ . _ - - - - - .. - .. - . 35 Permit can be issued w/o hydrogen sulfide measures ...... - . . . . . ... . ...... Yes .. _ - - _ _ H2S not anticipated from drilling of offset wells; however, dg will have )12S sensors and alarms. Geology 36 Data presented on potential overpressure zones - - - - - - - - - - - - - - -Yes .. - . - - - - - - - - - .. - . - - . - _ _ _ _ - _ _ _ - _ _ _ - _ _ _ _ _ _ .. _ _ _ - _ - _ .. _ - - . - . - . - . - . _ -- _ - - - - . - . - Appr Date 37 Seismic analysis of shallow gas zones . . . . .... . .. . . . . . ......... . . . . . . . NA - - _ - _ - - _ - _ - - - - - - - - - _ - - - - - - _ .... - - - - - - _ DLB 1/10/2019 38 Seabed condition survey (if off -shore) - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ - _ - - ........... 39 Contact name/phone for weekly.prggress reports [exploratory only] . . . . . .......... NA... Geologic Engineering Public Water injection well for Schrader Bluff pool. Using ICD and swell packers. GIs Commissioner: Date: Co missio�nef: Date Commissioner Date