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Home My WebLink About219-044MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC E-40 MILNE PT UNIT E-40 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 E-40 50-029-23626-00-00 219-044-0 W SPT 4385 2190440 1500 375 394 375 392 4YRTST P Adam Earl 9/4/2023 4-year MIT IA mono-bore 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-40 Inspection Date: Tubing OA Packer Depth 527 1718 1671 1659IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230905124839 BBL Pumped:2.5 BBL Returned:2.2 Tuesday, October 17, 2023 Page 1 of 1            CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: MPE-40 (PTD# 2190440) Return to Injection Date:Tuesday, August 29, 2023 8:51:32 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, August 25, 2023 3:32 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: OPERABLE: MPE-40 (PTD# 2190440) Return to Injection Mr. Wallace – PWI well MPE-40 (PTD# 2190440) was made Not Operable in June 2023 after missing its 4 year MIT- IA due to not being online. We will be bringing this well back on injection. The well will now be re-classified as OPERABLE and an AOGCC witnessed MIT-IA will be scheduled once on stable injection. Please respond with any questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Thursday, June 29, 2023 3:14 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPE-40 (PTD# 219-044) Missed AOGCC Witnessed MIT-IA Mr. Wallace – PWI well MPE-40 (PTD# 219-044) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well will now be classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPE-40 (PTD# 219-044) Missed AOGCC Witnessed MIT-IA Date:Monday, July 3, 2023 12:20:14 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, June 29, 2023 3:14 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPE-40 (PTD# 219-044) Missed AOGCC Witnessed MIT-IA Mr. Wallace – PWI well MPE-40 (PTD# 219-044) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well will now be classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 Cord 10/24/2019 E-36 Milne Point 50029236200000 2190050 Surface 15 Topof Cond 10/24/2019 E-38 Milne Point 50029236260000 2190440 Surface 20 Topof Cond 30/24/2019 E-39 Milne Point 50029236400000/60-00 2190960 Surface 20 Top of Cord 10/24/2019 E-40 Milne Point 50029236260000 2190440 Surface 25 Topof 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 Cord 10/25/2019 M-18 Milne Point 50029236320000 2190700 3 50 Top of Cord 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 1 to 3'd own from the top of the conductor DEC 0 6 2019 DATA SUBMITTAL COMPLIANCE REPORT 8/19/2019 Permitto Drill 2190440 Well Name/No. MILNE PT UNIT E-40 Fz Operator Hilcorp Alaska LLC API No. 50-029-23626-00-00 MD 12900 TVD 4411 Completion Date 5/12/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes REQUIRED INFORMATION / Mud Log No ,� Samples No ✓ Directional Survey Yes DATA INFORMATION List of Logs Obtained: ROP/ABG/DGR/EWR/ADR 2"/5" MD/PB1 .... ABG/DGR/EWR/ADR 2"/5" TVD/PB1 Well Log Information: Logl Electr Data Digital Dataset Log Log Run Interval Type Med/Frmt Number Name Scale Media No Start Stop ED C 30840 Digital Datai 105 12900 ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data ED C 30840 Digital Data Log C 30840 Log Header Scans 6970 12862 0 0 (from Master Well Data/Logs) OH/ CH Received Comments 5/24/2019 _ Electronic Data Set, Filename: MPU E-40 DGR ABG EWR ADR.Ias 5/24/2019 Electronic Data Set, Filename: MPU E-40 ADR Quadrants All Curves.las 5/24/2019 Electronic File: MPU E-40 LWD Final MD.cgm 5/24/2019 Electronic File: MPU E40 LWD Final TVD.cgm 5/24/2019 Electronic File: MPU E40 Definitive Survey Report.pdf 5/24/2019 Electronic File: MPU E -40i GIS.txt 5/24/2019 Electronic File: MPU E-40—Definitive Survey Report.txt 5/24/2019 Electronic File: MPU E-40 LWD Final MD.emf 5/24/2019 Electronic File: MPU E-40 LWD Final TVD.emf 5/24/2019 Electronic File: EMFView3_1.zip 5/24/2019 Electronic File: Readme.txt 5/24/2019 Electronic File: MPU E-40 Geosteedng.dlis 5/24/2019 Electronic File: MPU E40 Geosteering.ver 5/24/2019 Electronic File: MPU E-40 LWD Final MD.pdf 5/24/2019 Electronic File: MPU E-40 LWD Final TVD.pdf 5/24/2019 Electronic File: MPU E-40 LWD Final MD.tif 5/24/2019 Electronic File: MPU E-40 LWD Final TVD.tif 2190440 MILNE PT UNIT E-40 LOG HEADERS AOGCC Page 1 of Monday. August 19,2019 DATA SUBMITTAL COMPLIANCE REPORT 8/19/2019 Permit to Drill 2190440 Well Name/No. MILNE PT UNIT E-40 Operator Hilcorp Alaska LLC API No. 50-029-23626-00-00 MD 12900 TVD 4411 Completion Date 5/12/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes Log C 30841 Log Header Scans 0 0 2190440 MILNE PT UNIT E-40 PB1 LOG HEADERS ED C 30841 Digital Data 105 9422 5/24/2019 Electronic Data Set, Filename: MPU E-40 PB1 DGR ABG EW R ADR.Ias ED C 30841 Digital Data 6970 9384 5/24/2019 Electronic Data Set, Filename: MPU E40 PB1 ADR Quadrants All Curves.las ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E-40 PB1 LWD Final MD.cgm ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E-40 PB1 LWD Final TVD.cgm ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E-40PB1 Definitive Survey Report.pdf ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E40PB1_Definitive Survey Report.txt ED C 30841 Digital Data 524/2019 Electronic File: MPU E-40PB1 GIS.txt ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E-40 PB1 LWD Final MD.emf ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E40 P81 LWD Final TVD.emf ED C 30841 Digital Data 5/24/2019 Electronic File: EMFViev13_1.zip ED C 30841 Digital Data 524/2019 Electronic File: Readme.bd ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E-40 P81 Geosteering.dlis ED C 30841 Digital Data 524/2019 Electronic File: MPU E40 PB1 Geosteering.ver ED C 30841 Digital Data 524/2019 Electronic File: MPU E40 PB1 LWD Final MD.pdf ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E-40 PB1 LWD Final TVD.pdf ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E-40 PB1 LWD Final MD.tif ED C 30841 Digital Data 5/24/2019 Electronic File: MPU E-40 PB1 LWD Final TVD.tif Well CoreslSamples Information: Sample Interval Set Name Start Slop Sent Received Number Comments AOGCC Page 2 of 3 Monday, August 19, 2019 DATA SUBMITTAL COMPLIANCE REPORT 8/19/2019 Permit to Drill 2190440 Well Name/No. MILNE PT UNIT E-40 Operator Hilcorp Alaska LLC MD 12900 TVD 4411 INFORMATION RECEIVED Completion Report O Production Test Information Y NA Geologic Markers/Tops O COMPLIANCE HISTORY Completion Date: 5/12/2019 Release Date: 4/10/2019 Description Comments: Completion Date 5/12/2019 Completion Status 1WINJ Current Status 1WIN.. Directional / Inclination Data G Mud Logs, Image Files, Digital Data Ya Mechanical Integrity Test Information/Y / NA Composite Logs, Image, Data FilesO Daily Operations Summary Cuttings Samples Y /(9 Date Comments API No. 50-029-23626-00-00 UIC Yes Core Chips Y //Iva/) Core Photographs Y NA Laboratory Analyses Y'�J Compliance Reviewed ByDate: �' /19 AOGCC Page 3 of 3 Monday, August 19, 2019 m -U [177\►1T11�1 TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 27, 2019 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC E-40 MILNE PT UNIT E40 Src: Inspector Reviewed By: P.I. Suprvj50-- Comm Well Name MILNE PT UNIT E-40 API Well Number 50-029-23626-00-00 Inspector Name: Austin McLeod Permit Number: 219-044-0 Inspection Date: 6/13/2019 - Insp Num: mitSAM190613205504 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-40 Typelnj +' "PVD Tubing s;; 8il - 833 xa? PTDj 2190440 TypeTest si,i 'rest Psi M) 1A i Isis - 1748 1729 BBL Pumped: 3 "BBL Returned: OA Interval INITAL P/F ✓ Notes: Monobore. P01 5-17-19 ./ Thursday, June 27, 2019 Page I of I Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, June 12, 2019 10:57 AM To: Wallace, Chris D (CED) Subject: MPU E-4021212190440) Late MIT -IA Attachments: MIT MPU E-40 5-11-19.xlsx; 9.625 x 3.5 annulus.pdf; MPU E-40 Definitive Survey Report.pdf; MPE-40 Schematic 6-11-19.doc Chris, Milne Point water injection well MPE-40 (PTD # 2190440) was drilled and completed in May. The well had a passing, witness waived, Pre -Injection MIT -IA to 2000 psi on the rig on 5-11-19. The MIT form, chart and schematic are attached for reference. The well was put on injection on 5/16/19 but did not receive a follow-up, injecting, MIT -IA within the normal 2 week stabilization period. We will submit notification today for a witnessed MIT -IA to be performed tomorrow. We will review our MIT process for new injection wells and provide additional follow-up on why this MIT was not performed within the normal stabilization period. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 I C: (509)(570-80011 wrivard@hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION ECENED JUN 11 2019 WELL COMPLETION OR RECOMPLETION REPORT AN Ia. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended[_] 1b. Well Class: 20AAC 25.105 20MC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ Q WAGE] WDSPL ❑ No. of Completions: -I Service Q Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Hilcorp Alaska, LLC Aband.: 5/12/2019 219-044 ' 3. Address: 7. Date Spudded: 15. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 April 16, 2019 50-029-23626-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: + Surface: 3472' FSL, 1825' FEL, Sec 25, T13N, R10E, UM, AK May 3, 2019 MPU E-40 Top of Productive Interval: 9. Ref Elevations: KB: 48.4' r 17. Field / Pool(s): Milne Point Field 1800' FNL, 1574' FWL, Sec 30, T13N, R11 E, UM, AK GL: 21.6' BF: 21.6' Schrader Bluff Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1699' FNL, 2101' FEL, Sec 19, T13N, R11 E, UM, AK 1 12,895' MD / 4,411' TVD ADL025518, ADL028231, ADL047438 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 569322 y- 6016010 ' Zone- 4 . 12,900' MD / 4,411' TVD LONS 94-017 TPI: x- 572721 y- 6016049 - Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MDfFVD: Total Depth: x- 574213 y- 6021445 Zone- 4 N/A 2,066' MD / 1,783' TVD 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ROP/ABG/DGR/EWR/ADR 2"/5" MD / PB1 ABG/DGR/EWR/ADR 275" TVD / PB1 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT SETTING DEPTH MD SETTING DEPTH TVD AMOUNT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 215# X-52 Surface 107' Surface 107' 42" ±270 ft3 9-5/8" 40# L-80 Surface 6,984' Surface Stg 1 L - 585 sx / T - 400 sx 4,393' 12-1/4" Stg 2 L - 500 sx / T - 270 sx 75 bbls 3-1/2" 9.2# L-80 Surface 6,808' Surface 4,386' Tieback Tieback Tubing 4-1/2" 13.5# L-80 6,791' 12,900' 4,385' 4,411' 8-1/2" Injection Liner w/ [CDs & Swell Packers 24. Open to production or injection? Yes ❑' No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): 3-1/2" 6,808' 6,791' MD / 4,385' TVD " Please see attached schematic for ICD/Swell Packer Detail" Liner Top Packer Cementless Injection Liner Run on 5/8/19 COMPLETION TE 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No -4a 0(9 VERIFI [) Per 20 AAC 25.283 (1)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A N/A ' Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate --p� Form 10-407 Revised 5/2017 CONTINUE ON PAGE 2 Submit ORIGINIAL only ftP&Jzs/iq c-�(� 6�1Y(�19 M07 94-611-M RBDMS-I�wJUN 13 2019 (fit 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MDTFVD, FromrFo), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 2,066' 1,783' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval SB NB 7,250' 4,390' information, including reports, per 20 AAC 25.071. SV5 1,989' 1,730' SV1 3,128' 2,478' Ugnu LA3 5,119' 3,816' SB NA 6,636' 4,370' SB NB 6,788' 4,385' Formation at total depth: SB NB 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Defintive Directional Surveys, Csg and Cmt Report, OH Sidetrack Summary 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: Drilling Manager Contact Email: CdID er hllCor .Corti Authorized Contact Phone: 777-8389 / Signature: Date: INSTRUCTIONS General: This 7f, d the required attachments p ' e a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Milne Point Unit Well: MPU E-40 Schematic PTD: 219-044 Hilcaro Alaska, LLC API: 50-029-23626-00-00 KB Elev above MSL: 48.4' TD= 12,900'(MD)/TD=4,411'(TVD) PBTD =12,895 (MD) / PBTD = 4,411'(TVD) TREE & WELLHEAD Tree Cameron3 1/16" 5M w/3-1/16" SM Cameron Wing Wellhead Cameron 11" 5K x sliplock bottom w/ (2) 2-1/16" SK outs OPEN HOLE / CEMENT DETAIL 42" -270 ft3 12-1/4" Stg l-585 sx Lead /400 sx Tail Top Stg 2 - 500 sx Lead / 270 sx Tail (75 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 4,393' 0.0758 4-1/2" Liner 13.5 / L-80 / Hyd 625 3.85" 6,791' 12,900' 0.0149 TUBING DETAIL 3-1/2" Tubing 9.2/L-80/EUE 2.992" 1 Surf 1 6,808' 1 0.0152 WELL INCLINATION DETAIL KUP E231! Max Hole Angle = 95.5" GENERAL WELL INFO API#: 50-029-23626-00-00 Completed by Innovation: 5/12/19 JEWELRY DETAIL No Top MD Item ID Upper Completion 1 2,487' X Nipple 2.813 2 5,828' XN Nipple profile: 2.725" No Go / 2.813 Packing Bore 2.725 3 6,795' 8.25" No -Go Locater on Tieback Assy ([4] - 1" Ported Seal Stem) 2.992 4 6,808' Tieback Shoe 6.180 Lower Completion 4 6,791' Liner To Packer(TVD=4,385') Tendeka Water Swell Packer 5 12,895' W IV (Ball on Seat/ Closed) PBTD - Depth MD Depth WD ICD/Swell Packer Detail 7,107' 4,391' Tendeka Water Swell Packer 7,251' 4,390' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 7,480' 4,375' Tendeka Water Swell Packer 7,782' 4,356' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wed 7,930' 4,355' Tendeka Water Swell Packer 8,797 4,358' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 8,983' 4,369' Tendeka Water Swell Packer 9,084' 4,378' Teadeka- ICD w/ 250L mesh, Sliding Sleave 13.59 bxp 625 Wedge 9,152' 4,383' Tendeka Water Swell Packer 9,490' 4,393' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.54 bxp 625 Wedge 9,836' 4,401' Tendeka Water Swell Packer 9,936' 4,406' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.59 bxp 625 Wedge 10,044' 4,414' Tendeka Water Swell Packer 10,184' 4,424' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.59 bxp 625 Wedge 10,572' 4,432' Tendeka Water Swell Packer 10,870' 4,431' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 11,139' 4,426' Tendeka Water Swell Packer 11,199' 4,424' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.59 bxp 625 Wedge 11,267' 4,421' Tendeka Water Swell Packer 11,368' 4,415' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 11,437' 4,412' Tendeka Water Swell Packer 11,537' 4,406' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 11,605' 4,402' Tendeka Water Swell Packer 11,987' 4,391' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge 12,295' 4,390' Tendeka Water Swell Packer 12,715' 4,406' Tendeka- ICD w/ 250L mesh, Sliding Sleave 13.5# bxp 625 Wedge CJD 6/11/2019 U Well Name: MP E-40 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): API #: 50-029-23626-00-00 Spud Date: 4/16/2019 Job Name: 19109400 MPE-40 Drilling Contractor AFE #: AFE $: Hilcorp Energy Company Composite Report I ; '; Ops Summary _. 4/13/2019 Bridle up and scope down derrick. Blow down water and steam. Swap from high line to gen power at 09:30. Move beyond energy choke house. Rig down sub outriggers. Scope cattel chute adn prep pip shed. Disconnect all remaining interconnects. Disconnect and move break shack. Prep all walkways,;Iandings and roof for move.;RDMO E-41. Split rig modules apart and stage allowing access for roads and pads to level pad around E-40. Level pad. Assemble mud pumps. Lay out herculite and set rig mats.;Continue setting rig mats. Spot sub on mats. Pull rear tires off sub due to clearance with E-41. Spot wellhead equipment behind rig. Walk sub over MP E-40. 4/14/2019 Stage speed head, diverter T, well head and RCD behind sub base. Spot sub base over MP -00. Pull forward to allow production access to E-41 to lubricate BPV and re -orientate tree. Set rig mats for mud module and gen module. Clear snow and stage gen mod.;Spot sub -base over E-40. Rig up out riggers. Lay rig mats. Spot pipe skate and pipe shed. Conductor was noted to be 4" short. Begin adding section to conductor.;Spot mud mod, gen mod and cuttings box and berm up. Spot Beyond choke skid. Rig up steam, air, and water lines in interconnect. Rig up mud lines. Plug in electrical and swap from cold start to gen power at 21:00. Continue adding extension on conductor.;Spot and hook up break shack. Scope up derrick and bridle down. Start rig acceptance checklist. Finish extension on conductor, install speed head as per NOS. Grease crown, inspect derrick. Tighten drag chain. Fill pit with water and circulate around muds stem. Install rotary drain and bolt. 4/15/2019 Ria accepted at 06:00 N/U diverter system. Install DSA, diverter'T', annular and bell nipple and torque all connections. Install knife valve, and diverter line. Install chain binders to BOP and center stack. Remove bridge cranes. Change out air boots and install riser.;Continue processing 5" drill pipe in shed. Load pits with spud mud.;Test starter head void to SDO psi. Continue to torque flanges and make up diverter line. Change out top drive upper frame extend pin bushings. Quadco rep calibrate and certify all gauges for mud pumps, stand pipe, accumulator and tongs. Continue processing 5" drill pipe. Test gas alarms.;Continue making up diverter vent line. Make up accumulator lines to annular and knife valve. Continue to change out bushings on TD extend frame, While re -installing ODS pin, keeper slot on pin broke. Weld in 2" containment in cellar doorways.;PJSM remove wash pipe. Change out wash pipe stem liner and re -install while fabricating stop plate for ODS pin on extend frame.;Test diverter system, AOGCC right to witness waived by Bob Noble. Install joint of 5" drill pipe. Knife valve open in 7 seconds, annular close in 10 seconds. Accumulator drawdown: starting pressure 2950 psi, final 1950 psi. 200 psi recharge in 17 seconds, full recharge 54 seconds.;6 N2 bottles with 2241 psi average.;PJSM Rig up to pick up drill pipe. Install mouse hole, change out tongs. Drift, pick UD and rack back 71 stands of drill pipe. 4/16/2019 Cont. P/U M/U 5" NC50 5-135 19.5# DP F/ Pipe Shed racking back in Derrick. Drift 3.125" ID. 111 stands in Derrick.;PJSM P/U 17 Jnts 5" HWDP NC50 and n 6.5" SLB Hydra Jars and rack back in Derrick. Bring up Tongs, BHA Subs and X/O's.;PJSM Grease Blocks, Top Drive, Elevators and Drawworks.;PJSM P/U r M/U 12.25" Kymera Bit, Mud Motor and X/O. RIH W. 5" HWDP tag at 80' MD. Fill surface Equip and hole W/ H2O.:PJSM PT mud lines to 3,000 PSI, good. C/O 4" conductor ball valve due to leak. Hold Pre Spud meeting with crew and 3rd party.;PJSM Drill F/ 80' to 220' MD. 400 GPM, 660 PSI, 40 RPM, TRQ ON I 2.2K, TRQ OFF 1 K. WOB 3K. Rig on high line @ 15:OO.;PJSM POOH on elevators F/ 220' to 30' MD. Blow down.;PJSM P/U M/U remaining BHA #1, 8" DM, V' B" DGR, 8" EWR-P4, 8" PWD, 8" HCIM, 8" TM, 8" NM UBHO, 2 as 8" NM FC, X70 and 5" HWDP to 220' MD. Download MWD SIMOPS R/U Gyro sheave and tools. Measure RFO = 1431811 = 63.48", orientate UBHO.;Rotate and slide 12.25" Surface F/ 220' to 413' MD Total 193' (AROP 32.2')450 GPM, 1,100 PSI, 40 RPM, TRQ On 3K, TRQ Off 1 K, WOB 10K. Max Gas 14U, ECD 9.6 ppg, P/U 58K, SLK 58K, ROT 57K. Run Gyro every stand.;Rotate and slide 12.25" Surface F/ 413'to 950' MD Total 537' (AROP 89.5')450 GPM, 1,200 PSI, 40 RPM, TRQ On 5.5K, TRQ Off 2K, WOB 17-18K. Max Gas OU, ECD 9..84 ppg, P/U 74K, SLK 72K, ROT 75K. Stopped using Gyro at 588' MD. Build 4'/100' after 480' MD. H2O 40 BPH, 9.0 ppg MW.;Distance to WP #4: 9.18', 0.35' Low, 9.17' Right;Hauled 249 bbls Fluid to MP G&I total = 249 bbls Hauled 100 bbls H2O from L -Pad Lake total = 800 bbis Lost 0 bbls to formation Total fluid lost = 0 bbls 4/17/2019 Drill 12.25" Surface F/ 950' to 1477' MD Total 527' (AROP 87.8') 500 GPM, 1,590 PSI, 60 RPM, TRQ On 4.6K, TRQ Off 3.5, WOB 8-12K. Max Gas OU, ECD 9..84 ppg, P/U 85K, SLK 76K, ROT 77K. H2O 40 BPH, 9.0 ppg MW. Back Ream Full Side. Cont. Build 4°/109.;Drill 12.25" Surface F/ 147T to 2,040' MD Total 563' (AROP 93.8') 550 GPM, 1,730 PSI, 80 RPM, TRQ On 4.2K, TRQ Off 3.8, WOB 8-12K. Max Gas 3U, ECD 10.4 ppg, P/U 90K, SLK 74K, ROT 82K . H2O 40 BPH, 9.1 ppg MW. Back Ream Full Stds.;End 4°/100' Build @ 1727'. Start Tangent f/1727'. Control drill @ 100-150 FPH and allow hole to clean up. ECD @ 11.0. Seeing lots of clays @ shaker.;Rotate and slide 12.25" Surface F/ 2,040' to 2,586' MD (TVD 2,121) Total 546 (AROP 91')535 GPM, 1,600 PSI, 80 RPM, TRQ On 6.8K, TRQ Off SK, WOB 5-8K. Max Gas 1740U, ECD 10.4 ppg, P/U 104K, SLK 70K, ROT 89K. H2O 40-50 BPH, 9.3 ppg MW. Back ream ea stand.; Encountered base of permafrost at 2,066 MD (1,782' TVD).;Rotale and slide 12.25" Surface F/ 2,586' to 3,188' MD (TVD 2,515) Total 602' (AROP 100.3')520 GPM, 1,630 PSI, 80 RPM, TRQ On 8K, TRQ OR 6.8K, WOB 4-10K. Max Gas 1,781 U, ECD 10.22 ppg, P/U 112K, SLK 81 K, ROT 96K. H2O 40-50 BPH, 9.4 ppg MW. Back ream ea stand.;Gas hydrates encountered in two sands around the top of the SV2,at 2,745' MD (2,225' TVD) Max Gas 1,781 U. Sliding HRS 4.13, ROT HRS 6.92 Distance to WP #4: 9.87', 2.05' Low, 9.37' Right.;Hauled 981 bbls Fluid to MP G&I total = 1,230 bbis Hauled 1,070 bbls H2O from L -Pad Lake total = 1,870 blots Lost 0 We to formation Total fluid lost = 0 bbls 4/1 B/2019 Rotate and slide 12.25" Surface F/ 3188'to 3759' MD (TVD 2693) Total 571' (AROP 96) 500 GPM, 1,560 PSI, 80 RPM, TRO On 9K, TRQ Off 9K, WOB 2- 10K. Max Gas 298U, ECD 10.15 ppg, P/U 132K, SLK 85K, ROT 102K. H2O 40-50 BPH, 9.4 ppg MW. Back ream ea stand. Drilling Tangent w/Maintenance Slides.;Rotate and slide 12.25" Surface F/ 3759' to 3943' MD (TVD 3014') Total 184' (AROP 92') 600 GPM, 2075 PSI, 80 RPM, TRQ On 9K, TRQ Off 8.5K, WOB 9K. Max Gas 3000, ECD 10..0 ppg, P/U 132K, SLK 85K, ROT 102K. H2O 40-50 BPH, 9.4 ppg MW. Back ream ea stand. End Tangent @ 3947' MD (3,017' TVD).;Take Survey. Pump 35 bbl Hi Vis Sweep, 600 GPM, 80 RPM, 1980 PSI, 8.5 Tq. Sweep back 12 bbls early. 10% increase sand and clay. Circulate additional BU.;Rotate and slide 12.25" Surface F/ 3,94Y to 4,120' MD (TVD 3,136') Total 177' (AROP 70.8') 600 GPM, 2,040 PSI, 80 RPM, TRQ On 10.5K, TRQ Off 10K, WOB 3K. Max Gas 45U, ECD 9.8 ppg, P/U 146K, SLK 85K, ROT 109K. H2O 40-50 BPH, 9.25 ppg MW. Back ream ea stand. Maintain 4.3°/100.;Rotate and slide 12.25" Surface F/ 4,120' to 4„459' MD (TVD 3,372') Total 339' (AROP 56.5') 600 GPM, 2,115 PSI, 80 RPM, TRQ On 10-12K, TRQ Off 11-16K, WOB 4-8K. Max Gas 53U, ECD 9.79 ppg, P/U 155K, SLK 88K, ROT 111 K. H2O 40-50 BPH, 9.25 ppg MW. Back ream ea stand. Maintain 4.3°/100.;Rotate and slide 12.25” Surface F/ 4,459'to 4,813' MD (TVD 3,611) Total 354' (AROP 59') 600 GPM, 2,240 PSI, 80 RPM, TRQ On 12-14K, TRQ Off 12-15K, WOB 8-14K. Max Gas 314U, ECD 9.88 ppg, P/U 159K, SLK 90K, ROT 112K. H2O 40-50 BPH, 9.25 ppg MW. Back ream ea stand.;Pumped 50 bbl 300+ Vis sweep at 4,522' MD returned 12 bels late W/ 10% increase of sand at Shakers. Maintain 4.3°/100 Sliding HRS 4.94, ROT HRS 5.38 Distance to WP #4: 0.62', 0.55' High, 0.6' Left.;Hauled 981 bbis Fluid to MP G&I total = 2,221 bels Hauled 1,290 bbis H2O from L-Pad Lake total = 3,160 bbis Lost 0 bbis to formation Total fluid lost = 0 bbis 4/19/2019 Rotate and slide 12.25" Surface F/ 4813' to 5221" MD (TVD 3,890') Total 408' (AROP 68') 600 GPM, 2,130 PSI, 80 RPM, TRQ On 13-14K, TRQ Off 13-16K, WOB SK. Max Gas 45u, ECD 10 ppg, P/U 164K, SLK 90K, ROT 122K. H2O 40-50 BPH, 9.3 ppg MW. Back ream ea stand. Maintain 4.3°/100.;Production Shut in El 1 & 22 @ 4900' f/close approach mitigations.;Rotate and slide 12.25" Surface F/ 5221' to 5,602' MD (TVD 4,081') Total 381' (AROP 58.6') 600 GPM, 1,740 PSI, 80 RPM, TRQ On 14.2K, TRQ Off 16.6K, WOB 10K. Max Gas 180U, ECD 9.9 ppg, P/U 175K, SLK 91K, ROT 123K. H2O 40-50 BPH, 9.3 ppg MW. Back ream ea stand. Maintain 4.3°1100.;On bottom Press. loss observed at 5,498' MD F/ 2,130 PSI to 1,750 PSI. Stayed consistent to 5,602' MD. Suspected unplugged jet. Production bring E-11 & E22 back on line @ 5300'.;At 5,602' MD rotate and reciprocate string, Pump 45 bbl 9.3 ppg 300+ Vis sweep. 600 GPM, 1,585 PSI, 80 RPM, TRQ 16K, Sweep back on time with 10% increase sand. Check surface Equip for Press. loss. SPR at 5,602' MD (4,081' TVD) MW 9.3 ppg MP # 1 32-260, 48-305 MP #2 32-265, 49-312.;Rotate and slide 12.25" Surface F/ 5,602' to 5,637' MD (TVD 4,099') 600 GPM, 1,740 PSI on, 1,580 PSI off, 80 RPM, TRQ On 14.2K, TRQ Off 16.6K, WOB 10K. Max Gas 180U, ECD 9.8 ppg, P/U 174K, SLK 93K, ROT 122K. Maintain 4.3*/100.;At 5,637'MD stalled out bit to 2,139 PSI, P/U lost 100 PSI off bottom Press. F/ 1,580 PSI to 1,480 PSI. Decision was made to pump out of hole looking for hole in DP.;PJSM Pump out of hole looking for hole F/ 5,637'to 4,395' MD, 500 GPM, 1,150 PSI. P/U 162K, SLK 82K.;PJSM Pump out of hole looking for hole F/ 4,395' to 2,046' MD, 500 GPM, 850 PSI.;Started BROOH F/ 2,046'to 1,919' MD, 500 GPM, 815 PSI. 80 RPM, 6.4K TRQ, P/U 79K, SLK 62K.;Sliding HRS 5.23, ROT HRS 1.70. Distance to WP #4: 7.2', 2.23' High, 6.85' Right.;Hauled 808 bels Fluid to MP G&I total = 3,029 bbis Hauled 1,040 bbis H2O from L-Pad Lake total = 4,200 bels Lost 0 bbis to formation Total fluid lost = 0 bbis 4/20/2019 Cont BROOH looking for wash out f/l920' to 338'. 500 gem, 480 psi, 80-40 rpm. Hole started unloading @ 700'. Slow pulling speed to 7 fpm and allow hole to clean up. Pulled to Jars and observed ports below Jar Mandrel spewing mud. Kelly up and bring on charge pump and saw circulation through ports.;PJSM UD bad Jar and replace with spare. Shallow pulse test MWD was unable to read tool. 600 GPM, 1,275 PSI.;PJSM Rack Back 5" HWDP and NM FC. Found two small stones on top of pulsar. Attempted to down load logs and was unable to do so. Decision was made to UD remaining BHA and inspect Mud Motor and Bit.;PJSM UD remaining BHA as per DD and MWD onsite. Drain Mud Motor and inspect. Mud Motor lower sleeve stab showed slight wear on upper portion of blades and Bit showed no signs of wear and in gauge.;Clean and clear rig floor. UD TM Collar stage new TM Collar. Remove bad RLL from Pipe Shed and set new Combo Jars in Pipe Shed. Prep shed and rig floor for P/U BHA #2.;PJSM P/U M/U new BHA #2 as per DD/MWD onsite. RIH W/ re run motor and bit, new DGR Collar, EWR-P4 Collar, PWD, HCIM and TM HOC. RIH W/ 5" HWDP to 325' MD. Shallow hole test MWD, good. 440 GPM, 830 PSI. C/O Jars to Combo Jars. Cont. to RIH F/ 325' to 560' MD. Set down 4K and started washing down.;Wash down 5" D.P. F/ 560' to 960' MD. 440 GPM, 1,125 PSI. P/U 76K, SLK 72K. Heavy sand seen at Shakers during washing down.;Cont wash down 5" D.P. F/ 960' to 2,161' MD. 400 GPM, 1,040 PSI. P/U 76K, SLK 72K. Heavy sand seen at Shakers during washing down.;RIH on Elevators F/ 2,161' to 2,978' MD. Set down 25K.;At 2,978' worked drill string pulling tight, 30K over. Broke Circ. staging pumps up F/ 250 GPM, 260 PSI to 400 GPM 1,350 PSI, . Drill string packing off with 35% flow returns, injected -30 bbls. Started rotation at 20 RPM, TRQ 14.9K to 9.3K. Pulled up to 2,922' MD.;Injected 60 bbis. Hole unloaded over Shakers about -30 bbl returned back to surface. CBU Rotate and reciprocate F/ 2,916' to 2,976' MD. 400 GPM, 56% FR, 1,170 PSI, 40 RPM, 9K TRQ P/U 124K, SLK 66K, ROT 96K.;Wash down F/ 2,916" to 3,115' MD 400 GPM, 1,150 PSI. P/U 128K, SLK 77K.;Hauled 404 bbis Fluid to MP G&I total = 3,433 bible Hauled 440 bels H2O from L-Pad Lake total = 4,640 bels Lost 80 bbis to formation Total fluid lost = 80 bbis 4/21/2019 Wash down F/ 3,115" to 3,295 MD 400 GPM, 1,150 PSI. Cont. RIH on elevators F/ 3,295'to 5,596' MD P/U 195K, SLK 105K.;CBU Rotate and reciprocate at 5,596'. Stage up to 600 GPM, 2,150 PSI, 61% RF, 80 RPM, 14-ISK TRQ, ROT 127K.;Rotate and slide 12.25" Surface F/ 5,637' to 5,790' MD (TVD 4,171') 153' Total (AROP 27.8') 550 GPM, 2,000 PSI on, 1,875 PSI off, 80 RPM, TRQ On 16.5K, TRQ Off 16.8K, WOB 6-10K. Max Gas 19U, ECD 9.7 ppg, P/U 180K, SLK 94K, ROT 126K. Build Turn 4.5°/100.;Rotate and slide 12.25" Surface F/ 5,790'to 6,090' MD (TVD 4,285') 300' Total (AROP 50') 550 GPM, 2,070 PSI on, 1,880 PSI off, 80 RPM, TRQ On 16-19K, TRQ Off 18-19K, WOB 8-10K. Max Gas 81U, ECD 9.8 ppg, P/U 188K, SLK 90K, ROT 127K. Build Turn 4.5°1100.;At 5,922' MD encountered slight pack off while sliding., suspected fault. Pulled 20K over, start rotation 80 RPM, 23K TRQ and ream area. Cont. to slide again. Fault #1, approximately 40' DTN at 5885 MD.;Rotate and slide 12.25" Surface F/ 6,090' to 6,549' MD (TVD 4,359') 459 Total (AROP 76.5) 550 GPM, 2,164 PSI on, 1,950 PSI off, 80 RPM, TRQ On 16-17K, TRQ Off 17K, WOB 18K. Max Gas 71 U. ECD 9.8 ppg, P/U 198K, SLK 82K, ROT 121K. Water 40 BPH, 9.35 ppg MW.;Finish directional build/ turn at 6,350' MD and maintain 85° Inc per Geology, running -25' low, anticipate casing point may be around 6900' MD. Pad Operator shut in Well E-23 at 6,500' MD. Sliding HRS 1.7, ROT HRS 6.2. Distance to WP #4:17.6', 13.74' High, 11.0' Right.;Hauled 577 bbis Fluid to MP G&I total = 4,010 bbis Hauled 470 bbls H2O from L-Pad Lake total = 5,110 bbis Lost 0 bible to formation Total fluid lost = 80 bels 4/22/2019 Rotate and slide 12.25" Surface F/ 6549' [0 6,992' MD (TVD 4,392) 443' Total (AROP 63') 550 GPM, 1,85 PSI on, 1,810 PSI off, 80 RPM, TRQ On 16-17K, TRQ Off 19.5K, WOB 7K. Max Gas 56U, ECD 10 ppg, P/U 188 K, SLK 75K, ROT 115K. Water 40 BPH. 9.35 ppg MW.;Take Final Survey and Rack Back 2 Stands f/6992' to 686T. Last survey at 6952.03' MD, 4393' TVD, 90.45°inc, 21.52°az Showed us 11.1' from plan, 0' high, 11.1' RighL:Rot & Recip F 6,867' to 6,792" MD 550 GPM,1,860 PSI, 80 RPM, 16-18K TRQ, Max Gas 50U. CBU 4.5 X. ROT 115K. Circulate 1/2 BU and pump 9.35 ppg 300+ Hi Vise Sweep, back on time with little brought back over Shakers. Continue to circulate and condition mud for casing run. Lower YP to -25.; PJSM Wash down F/ 6,867' to 6,992' MD. 550 GPM, 1,810 PSI, 80 RPM, 16-17K TRQ, Monitor well for 10 Min, static. C/O Shaker screens and suction screens.;SPR @ 6,992' MD ( 4,392' TVD) 9.35 ppg MW MP #1 32-230,48-270 MP #2 32-235, 48-280.;PJSM BROOH F/ 6,992' to 5,723' MD. 550 GPM, 1,700 PSI, 80 RPM, 18-19K TRQ, P/U 190K, SLK 85K, ROT 125K. Max Gas 51 U. Pull speed 10-15 ft/min. Work thru high TRQ areas as needed.;PJSM BROOH F/ 5,723' to 3,993' MD. 550 GPM, 1,475 PSI, 80 RPM, 10.51K TRQ, P/U 152K, SLK 80K, ROT 105K. Max Gas 32U. Pull speed 15-20 fUmin.;Rotate and reciprocate F/ 3,993' to 3,875' MD. 550 GPM, 1,500 PSI, 80 RPM, 10-11K TRQ. Pump 50 bbl 9.35 ppg 300+ Vis sweep at end of tangent section. Sweep back on time with 0% at Shakers.;Pad Operator restarted Well E-23 at 6,750' MD. Sliding HRS 1.19, ROT HRS 3.35. Distance to WP #4: 11.1', Y High, 11.1' Right.;Hauled 750 bbis Fluid to MPG&I total = 4,760 bbis Hauled 830 bbis H2O from L-Pad Lake total = 5,940 bels Lost 0 bbis to formation Total fluid lost = 80 bbIs 4/23/2019 Continue BROOH F/ 3,939'- T/ 1,215' MD. 550 gpm, 1378 psi, 57% flow, 80 rpm, 9-10k tq. 20-30 ft/min pulling speed. Saw slight to moderate tq spikes and packing off issues while backreaming. Wiped clean past all trouble areas.;Conlinue BROOH F/ 1216- T/ 390' MD. Reduced rate F/ 550 to 470 gpm, 860 psi, 55% flow, reduce rpm F/ 80 to 40 while pulling thru initial build section. Saw slight to moderate tq and psi spikes while backreaming. Wiped all trouble areas clean. Attempt to pull on elevators @ 510' wl 30k over.;Continued backreaming from 510' t0 390' before being able to pull on elevators without significant overpulls or tq up issues.; PJSM RID DP Tongs, R/U BHA Tongs. Clean and clear rig floor. Prep for UD BHA #2. Well static.;PJSM UD BHA #2 F/ 390' MD as per DDI MWD onsite. Down load MWD tool. Bit Grade 1-1-C1-F-1-CT, TD. Motor stab was worn substantially more on the trailing edge than it was when after the previous run.; PJSM UD BHA components F/ rig floor. UD BHA Tongs. Clean and clear rig floor. Prep for cut and slip. Load Pipe Shed Shoe Track and 9 5/8" Joints.;PJSM Inspect drilling line. RIH 1 stand 5" HWDP, hang Blocks. Cut and slip 69'. Check Brakes, un hang Blocks and calibrate. Grease Top Drive, Block, Crown and Spinners. SIMOPS Stage Weatherford tools and Equip.;P/U Csg. Equip, stage 73 Centralizers on rig floor. RID 5" hydraulic elevators.;PJSM Cont. R/U Weatherford, Volant, bail Ext, Power Tongs and handing Equip.;PJSM W/ rig crew, Weatherford and Halliburton ES. PIU M/U 9 5/8" Shoe Track to 166' MD (Bakerloc). Halliburton set By Pass on top of FC. Check Floats, good. Cont. RIH 9 5/8" 40# TXP BTC L-80 F/ 166' to 562 MD as per tally. P/U 50 K, SLK 50K. Torque to 21K. Filling every 5 joints.;Calc. displacement 5.8 bbis, actual 5.8 bbis. No Iosses.;Hauled 346 bbls Fluid to MPG&I total = 5,106 bbis Hauled 570 bbis H2O from L-Pad Lake total = 6,510 bbis Lost 0 bbls to formation Total fluid lost = 80 bbis 4/24/2019 Continue run 9-5/8", TXP BTC, 409, L-80 casin F/ 562'- T/ 2179' MD. 21k M/U tq. 115k up, 78k dn. Fill every 5 jts, record displacement every 10 jts. Changed out #a 20 & 21 due to damaged threads on box/pin. Washed down it @ 1520' MD, stg up to 6 bpm, 120 psi w/ no issues.;Continue run 9-5/8", TXP BTC, 40#, L-80 casing F/ 2179' - TI 3205' MD. 21k M/U tq. 178k up, 78k dn. Fill every 5 its, record displacement every 10 its. 18 bbl loss to this point in csg run.;Circulate and condition mud 1x csg volume while reciprocating pipe 320T MD. Stage pumps up to 6.1 bpm, 160 psi, 36% flow. No notable gas count @ I up.;Continue run 9-5/8', TXP BTC, 40#, L-80 casing F/ 32D5'- T/ 3589' MD. 21 k M/U tq. 178k up, 78k dn. Fill every 5 its, record displacement every 10 its.;Continue run 9-5/8", TXP BTC, 40#, L-80 casing on elevators F/ 3,589'- T/ 3,774' MD. Slacked off to 45K, pulled over 60K. PIU 180K, SLK 75K. Fill every 5 Jnts, record displacement every 10 Jnts.;CBU at 5 bpm, 200 PSI, Engage Volant Tool working Csg F. 3,802' to 3,774' and set Max TRQ to 17.7K. Max RPM achieved 6 RPM, down stroke 2 RPM. Slight packing off, lost 10 bbis. PIU 225K, SLK 60K.;Wash and ream down 9 5/8" Csg. F/ 3,802' to 4,380' MD. 5 bpm, 165 PSI, Stall TRQ set 17,7K. 31% FR, RPM 2-4 on down stroke. P/U 225K, SLK 80K. Reduced flow F/ 5 bpm to 4 bpm due to pushing fluid away. Calc Disp 29.2 bbl, Actual 15 bbl, lost 14.2 bbls.;Circ. 9 5/8" Csg volume prior to M/U ES Cementer. staging pumps up F/ 3 to 6 bpm, 165 to 185 PSI, Working pipe FI 4,380'to 4,369' MD Stall TRQ 18K, 2-4 RPM on down stroke. Max pull 280K. PIU 245K, SLK 83K, Dynamic loss rate about 5 BPH. Max Gas 33U.;PJSM P/U M/U ES Cementer (Bakerloc) RIH on elevators F/ 4,380'to 4,460' MD. Set down 35K. Engage Volant Tool wash and ream down F/ 4.469to 5,008' MD. 4 bpm, 170 PSI, Stall TRQ set 17,9K. 36% FR, RPM 1-2 on down stroke. PIU 280 K, SLK 90K. Max Gas 22U. Run speed 15-20 f /min.;Calc Djsp 29.2 bbl, actual 19 bbls. Lost 10.2 bbls. Fill every 5 Jnts, record displacement every 10 Jnts. Dynamic loss about 5 BPH.;CBU at end of build/turn F/ 5,006' MD to 4,998' MD stage pumps up to F/ 3 bpm to 6 bpm, 225 PSI, 42% RF, P/U 250K, SLK 100K. RPM 1-2 on down stroke, TRQ stall at 17.9K. Pulling 290K at 4,998' MD. Max Gas 46U.;Wash down FI 5,008' to 5,217MD 4 bpm, 170 PSI, 34.9 % FR, P/U 280K, SLK 89K Max Gas 137U. Make up torque 21 K. Filling every 5 stands Run speed 15-20 ft/min. Calc Disp 5.7 bbl, actual 3.6 bbl. Lost 2.1 bbl.;Hauled 173 bbis Fluid to MP G&I total = 5,279 bbls Hauled 280 bbis H2O from L-Pad Lake total = 6,790 bible Lost 40 bbis to formation Total fluid lost = 120 bbis 4/25/2019 Continue wash and ream 9-5/8" TXP BTC, 40#, L-80 casing down F/ 5,217- T/ 6,984'. 21k tq connection. 17k max tq when having to ream down (2-5 rpm). Wash do @4-6 BPM, 30-40% flow out, 127 max gas. 9.4 bbl loss for trip.; Rot and Recip 9-5/8" casing F/ 6984' up to 6970' MD. Unable to pull up past 6970' (pulled 430k). Continue recip/rot F/ 6970' down to 6986' MD. 17k max tq, 2-5 rpm, stg up to 6.5 bpm, 250 psi, 44% flow w/ negligible gas. 335k up, 101 k do .,� with slight rotation (2-5 rpm). RID Weatherford equip.;Blow down TDS & Cmt lines to CRT. Troubleshoot plugged cmt line. Found plug valve to have residual G cmt plugging valve. Clean and clear lines and valves. Clean suctions on both mud pumps. PJSM, stg up pumps circulating via cmt line, CRT. 6.5 bpm, 520 psi.;HAL fill lines W/ 5 bbl H2O PT 925 PSI low, 2,600 PSI stall, 3,909 PSI high. HAL mix and pump 55 bbl 10.0 ppg Clean Spacer W/ Red Dye and 0.5 ppb f Pol-E-Flake at 3 BPM, 20O PSI 28% FR. Pump 247 bbl (585 sx) 12.0 ppg Type I/ll Lead at 5 bpm, 380 PSI. Pump 82.6 bbl (400 sx) 15.8 ppg Type /ll Tail 7 at;3.8 BPM, 580 P51 39.9 % FR. Shut down disengage Volant and drop Shut Off Plug. Engage Volant and HAL pump 20 bbl H2O 5.3 bpm, 298 P51, 21.1°k FR. Switch to Rig, pump 274.2 bbis 9.4 ppg Spud Mud at 7 bpm slowing to 6 bpm, 400 PSI, 36.1 % FR. HAL pump 80 bbl H2O 5 bpm, 690 PSI, 39.6%.;Started seeing slight losses about 40 bbis into pumping, lost 10 bbis. Rig pumped 425.8 bbl 9.4 ppg Spud Mud at 6 bpm, 785 PSI, 39.6% FR. Staging pumps down to 2 bpm due losses. FCP 800 PSI Plug pumped 5.6 bbl passed calculated. Inc Press to 1,300 PSI, bleed down 3.3 bbl returned. Check Floats good.;CIP at 22:10.;Press up and ES Cementer shifted open at 2,810 PSI at 2 bpm, pumped 5 bbls. Increase rate to 6 bpm, 565 PSI. Pump 31 bbl Hi Vis �7 sweep on the fly. Started seeing Poly-E-Flake about 20 bbis into pumping. Started dumping Spacer about 122 bbls into pumping. Dumped 108 bbis mostly Spacer with trace;amount cement. Started taking returns back to Pits. Sweep back 52 bbis early, started dumping. Dumped 163 bbl mostly coagulated mud with trace amounts of cement. Reduced pumps to 4 bpm 167 PSI seeing stringers of coagulated mud with trace amounts of cement.;Cont. Circ at 4 bpm, 240 PSI. seeing coagulated mud stingers at surface. Prep for second stage cement job. Shut down pumps disconnect Knife Valve and drain Stack. Fill Stack W/ Block Water and work Bag 3X. Perform flush 2X. Drain Stack and reconnect Knife Valve.;Cont. Circ. at 4 bpm, 250 PSI. SIMOPS Heat rig water (700 bbls) to 80'. Reduce surface volume. Buils Black Water pills. Process 5" D.P. in Pipe Shed.;PJSM for 2nd stage cement job. Blow down water and cement lines. Check Volant release. HAL start mixing spacer. Circ. at 4 bpm, 263 PSI.;Hauled 457 bbls Fluid to MP G&I total = 5,736 bbls Hauled 650 bbis H2O from L-Pad Lake total = 7,440 bbis Lost 70 bbis to formation Total fluid lost = 190 bbis 2% sv- f 4/26/2019 Perform 2nd stage cement job as follows PJSM, Wet lines w/ 5 bbls H2O, PIT lines 4k (fail). C/O low tq valve on mud manifold and retest 4k (test good). 60 bbls 109 Clean Spacer w/ (4#) red dye & .51b/bbl poly flake in first 10 bbls, 2.2 bpm, 160 psi;393 bbls 147# Perm "L" lead cmt / 4.407 yld 150 sxs. 4 bpm, 350 psi 56 bbls 15.8# Tail cement 11.169 yld 1270 sxs. 2.9 bpm, 440 psi Drop closing plug Pump displacement HES pump 20 bbls Fresh water (clean and clear lines) Turnover to rig MP#1;175.2 bbls 9.4 spud mud @ 3.5 bpm, FCP @ 624 psi. Calc stks 2831, Bump @ 2825 stks. Psi up to 1520 before seeing good indication of stage tool shifting (pipe jump along w/ hold psi on csg @ 1620 psi). Held psi 5 min. Bleed off 1.25 bbls. No flow @ 9-5/8" casing stump. CIP @ 10:00 hrs;Had to adjust flow rate F/ 5 to final rate of 3.5 bpm due to coagulated cement plugging off flowline and attempting to packoff surface equipment with medium to large pieces of mildly setup cmt returns (presumable from tat job. No losses noted for 2nd stage job. 5 Overboard returns @ 400 bbls into lead; Return 75 bbls 10.7 lead cement back to surface.,R/D and UD Volant CRT. BID cmt line, disconnect knife valve, drain Q stack while flushing with black water. Function bag 3x flushing with black water. Open inspection hatches on flowline and clean same.;Vac out fluid from inside landing jt. R/U cranes to stack. UD mousehole, remove diverter section from knife valve. N/D diverter stack. Sym Ops - Clean pits.;Lift stack and center 9-5/8" casing. Set "E" slips w/ 150k string wt on slips as per wellhead rete (Mike Gilroy / Johnny Morrow). Make rough cut on 9 5/8" Csg joint. (28.03' p Cut Jnt);AOGCC BOP witness notification sent @ 13:31 him for upcoming BOP lest. Will update in the morning as requested.;PJSM Set Stack down and hot bolt. Re install Knife Valve. Top rinse and Johnny Week Stack. Set Stack back. UD Diverter'T'. Attempt to pull Starter Head. Had to break down into 2 pieces to be able to manipulate slip segments.;PJSM Install T-103 Slip Lock, Make final cut on 9 518" Csg. UD 9 5/8" handling Equip, surface riser and master bushings. Bring up split bushing. Cameron T-103 was for 10 3/4". Have discussion with town about options. Decision was made to use FMC sytem. Remove T-103 and Equip from cellar.;Hauled 1,555 bbls Fluid to MP G&I total = 7,291 bbls Hauled 980 bbls H2O from L -Pad Lake total = 8,420 bbls Lost 0 bbls to formation Total fluid lost = 190 bbis 4/27/2019 Mobilize FMC wellhead equipment to location. Install 11", 5M FMC slip lock wellhead for 9-5/8" casing. Psi test packoff 500 low, 2480 high (good).;Tq wellhead flange, Install 11" x 13-5I8" DSA. Prep MPD head, BOP flanges.;Tq connections on wellhead flanges and DSA. Bring wellhead equipment to rig floor. Perform EAM on TDS, Drawworks and inspect electrical connections for TDS.; Remove master bushings. Install MPD studs. Stage MPD rotating head directly below Floor. Mob BOP stack in place and set same. Set MPD head on BOP stack. Tq all flanges on BOP stack. Hookup MPD lines, Choke and Kill lines. Center stack and "4" point. Install flow riser.;PJSM M/U Test sub to Top Drive. M/U 5" lest Jnt to side entry Sub, TIW, Dart Valve, and test plug. Flood lines and workout air. Function Equip. Shell test 300 PSI low and 3,000 PSI high, good.; PJSM Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Perform BOPE test W/ 3.5" & 5" to 300 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 1-15, 5" Dart, 5" TIW, Dart, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke,;Upper and lower VRB Rams (2,875' X 5.5") Blind Rams, Annular W/ 3.5" test Jnt. Koomey draw drown Initial System 3,000 PSI, Manifold 1,450 PSI, Annular 1,325 PSI, after System 1,500 PSI, Man 1,500 PSI, Annular 1,400 PSI. 200 PSI increase n 24 Sec, full charge 92 sec. Nitrogen 6 bottle average 2,333 PSI;Witnessed by AOGCC Rep Matt Henrera.;PJSM RID test Equip. Wear Ring 38", 9" ID, 10.75" A. RILDS.;PJSM Remove riser. Re install test plug. Fill stack W/ H2O. Install MPD plug. Shut MPD valve and PT Beyond MPD system to 350 PSI low and ;000 PSI high (Good) charted. Re position Stack. Clean riser profile and re install.R/D test Equip.;PJSM P/U WU Clean Out BHA #3 RR 8.5" Smith XR+PS Tricone, 6 3/4" SperryDrill Lobe,6 Jnts 5" HWDP, 6 1/4" Combo Jars,11 Jnts 5" HWDP to 592.71' MD.;Hauled 258 bbls Fluid to MP G&I total = 7,549 bbls Hauled 210 bbls H2O from L -Pad Lake total = 8,630 bola ` Lost 0 bbls to formation Total fluid lost = 190 bbls 4/28/2019 Adinct MPD w,uioment_ Install drip pan and re -install MPD lines.. Single in w/ 8.5" cleanout assy F/ 592' - T/ 1210' MD. Continue trip out of derrick to 2500' MD. 152k up, 60k dn.;Wash down F/ 2500' - T/ tag depth @ 2571' MD. Drill cmt F/ 2571' - 2580'. Drill ESII stage tool @ 2580' past to 2582' (on depth). 300 gpm, 330 psi, 40 rpm, 6.6k tq, 44% flow. Trip thru clean F/ 2563' -T/2627' (3x).;Continue trip in FI 2,627' - T/ 4,723' MD. 151 k up, 71 k dn.;Continue trip in F/ 4,723'- T/ 6735' MD. 210k up, 64k on. Took wt @ 6735' MD. Set do 20k.;Kelly up and wash down F/ 6735'- T/ 6818' MD. 550 gpm, 1400 psi, 40 rpm. Did not take wt while washing down to 6818' MD. Probably took wt @ 6735' from debris that was pushed to bottom after drilling stage tool.;Circulate and condition mud while working pipe F/ 6818 - up to 6760' MD. 550 gpm, 1400 psi. 40 rpm. Saw small amount of drill cmt @ btms up.;R/U and test 9-5/8", 40#, qG� L-80 casing to 2,500 psi w/ 30 min hold. Pumped 5 bbls @ 1/2 bpm. Bled back 5 bbls. RID and B/D lest equipment. Chart and record same.;PJSM Drill (A) cement and Shoe Track F/ 6,818' to BFA at 6,859', FC at 6,901' and Shoe at 6,984' MD. PIU working single drill to 7,012' MD. 550 GPM, 1,550 PSI, 40 RPM, 18.5K TRQ, WOB 4K, 250 ROP, 60% FR, ROT 123K.;Re ream thru 3X thru FC and Shoe at 350 GPM, 630 PSI, 40 RPM, 18.5K TRQ with no issues. Max Gas 1,213U at BU.;PJSM Rot and Ree F/ 7,012'to 6,935' 550 GPM, 1,000 PSI, 40 RPM, 15.5K TRQ, 56% RF, Max Gas 11U. Displace 9.2 ppg Spud Mud W/ 8.9 ppg Baridril. Pump 45 bbl Hi Vis Sweep, 488 bbl 8.9 ppg Baridril. Sweep back on time. Monitor well for 15 Min. UD working Single and rack back 1 stand to 6,946' MD.;PJSM R/U test Equip. Close Upper Pipe Rams and fluid pack lines. Perform FIT at 0.5 bpm to 700 PSI 12 ppq EMW. Pumped 4.5 bbls and bled back 1.3 bbls. Press fell F/ 700 PSI to 483 PSI in 13 Min. Checked surface Equip and circ. thru surface Equip again. Suspected aerated mud.;Perform FIT again at 1 bpm to 712 PSI, 12 ppg EWM, pumped 1.86 bbls, bled back 1.69 bbls. Press fell F/ 712 PSI to 522 PSI after 16 Min with linear line on chart. Blow down Choke Manifold, Choke and Kill Line. RID Test Equip.;PJSM POOH 5" D.P. on elevators F/ 6,946'to 4,859' MD. Pull 5 stands off bottom monitor well, falling. PIU 204K, SLK 93K. Calc Disp 13.9 bbl, actual 13.9 bbl.;PJSM POOH 5" D.P. on elevators F/ 4,859' to 592' MD. PIU 62KK, SLK 60KK. Calc Disp 13.9 bbl, actual 13.9 bbl.;UD 14 Jnts 5" HWDP. Rack back 1 stands of 5" HWDP and Jar stand. UD Mud Motor and Bit. Bit Grade 1-1-WT- A-E-Y-TD;PJSM PIU M/U BHA #4 as per DD/MWD onsite. M/U 8.5" NOV SK616MJl D PDC, 8.5" NRP, 7 5/8" Geo Pilot 7600.6 314 ADR/HCIM, 6 3/4" ILS, 6 3/4" DGR, 6 3/4" DM Collar, 6 3/4"TM Collar to 83.63' MD.;Hauled 934 bbls Fluid to MP G&I total = 8,483 bbls Hauled 450 bbls H2O from L -Pad Lake total = 9,080 bbls Lost 0 bbls to formation Total fluid lost = 190 bbls 4/29/2019 Finish uploading MWD. RIH w/ HWDP and jars. Shallow pulse test (good). Break in Geo Pilot range from 10-40. Corrosion ring installed on top of NM fle)fs.;Single in F/ 275'- T/ 6901' MD w/ 5", NC-50, 19.5#, S-135 drill pipe. Drift = 3.126'.;PJSM W/ Beyond. Pull Riser and install Bearing Assy into RCD body as per Beyond Rep onsite. Monitor well, static.;PJSM Service and inspect Top Drive and floor Equip. Trouble shot Top Drive proximity sensor.;PJSM Wash down F/ 6,901'to 7,012' MD 400 GPM, 740 PSI, 40 RPM, 13.81K TRO, ROT 177K. No issue going thru Shoe Track. SPR at 6,965' MD (4,393' TVD) W/ 8.9 ppg MW MP #1 32-190, 48-227 MP #2 32-194, 48-225;PJSM Drill 8.5" hole F/ 7,012' to 7,281' MD Total 296' (AROP 67.3') 460 GPM, 970 PSI, 125 RPM, TRQ On 15K, TRQ Off 13.81K, WOB 3K. Max Gas 1,476U, ECD 9..9 ppg, P/U 166K, SLK 73K, ROT 111 K. Maintain 90" thru NB Sand. Contacted Operations about close approach to MP E- 32 & 32L. Did not shut in well.;Will clear E-32 at 8,250' MD. At 7,043' MD flooded MPD system to monitor weight and flow out during drilling. MPD surface equipment friction 90 PSI, EMW is 9.3 ppg W/ 8.9 ppg MW. Maintain 170 R/hr ROP thru close approach to E-32 in case we encounter unforeseen concretion.; PJSM Drill 8.5" hole F17,281'to 7,978' MD Total 697' (AROP 1162) 460 GPM, 1,125 PSI, 125 RPM. TRQ On 17.6K, TRQ Off 17K, WOB 1-3K. Max Gas 1,490U, ECD 10.2 ppg, PIU 174K, SLK 63K, ROT 110K. Maintain 90° thru NB Sand.;increase flow rate F/ 450 GPM to 500 GPM at 7,655' MD as Shakers will allow. At 7,800' MD increased MPD system to 90 PSI for a 9.3 ppg EMW W/ 8.9 ppg MW Due to 600-8000 BGG with peaks up 1,490U. Drilled close approach at 7,782' MD E-32PB1 24' CTC,7,791' MD CTC 24'& 7,789.5' MD at 24' CTC.;Encountered magnetic interference at 7,845' MD. Encountered Fault #1 at 7,534' MD 5' throw DN still in NB Sand. Distance to Well Plan (#06) 10.74', 10.69' low, 1.04' right Still in NB Sand.;Hauled 78 bbis Fluid to MP G&I total = 8,561 bbis Hauled 170 bbis H2O from L-Pad Lake total = 9,25 bbls Lost 0 bbls to formation Total fluid lost = 0 bbis 4/30/2019 PJSM Drill 8.5" hole F/ 7,978' to 8,591' MD Total 613' (AROP 102fph) 515 GPM, 1,465 PSI, 125 RPM, TRQ On 17.6K, TRQ Off 17K, WOB 14K. Max Gas 1,490U, ECD 10.7 ppg, P/U 185K, SLK 41 K, ROT 107K.;PJSM Drill 8.5" hole F/ 8,591'to 9,310' MD Total 719' (AROP 120 fph) 530 GPM, 1,560 PSI, 120 RPM, TRQ On 21K, TRQ Off 21K. WOB 12K. Max Gas 2,460U, ECD 10.9 ppg, P/U 220K, ROT 110K.;Dhll 8.5" hole F/ 9,310' to 9,421' MD Total 111' (AROP 111 fph) 530 GPM, 1,670 PSI, 120 RPM, TRQ On 21K, TRQ Off 21.5K, WOB 12K. Max Gas 450U, ECD 11.0 ppg, P/U 228K, ROT 108K. While dropping angle to 85` towards ND sand to compensate for a fault at -9,600', gamma and;resistivity data indicates the wellbore has been in the ND sands, and not the NB sands, since the fault crossed at 7,534'; exiting the base of the ND sands at 8,965'.;Circulate annular volume, 530 gpm/1670 psi, 120 rpms/21 Kft-lbs reciprocating pipe. Flow check, static.;Pump out of hole from 9,421' to 9,119; 5 bpm, 420 psi. Tight at 9150' (20K), and 9115' (30-40K without breaking over). Establish rotary at 80 rpms/21 Kft-lbs. BROOH from 9,115' to 7076; 80 rpmsJ20Kft-lbs, 450 gpm/1200 psi. PUW 220K, ROTW 110K. Stalled out with slight packoff at 9,000', and;TQ spike with slight packoff at 8835'.;Trough x 5 from 7,075'to 7,090' 400 gpm/840 psi, 40 rpms/16.7Kft-lbs, 250fph. Sidetrack well bore Drilling from 7,090' to 7,154' 450 gpm/1000 psi, 100 rpms/17Kf-lbs, ROP 10 -30 fph with initial tool face 160° with 100% deflection, staging up to 90'R after 20' and difference of 1.85° ABI.;Work through sidetrack point with pumps/rotary, with pumps, and without pumps/rotary with no issues going into new hole.;Dri[I 8.5" hole F/ 7,154' to 7,344' MD Total 190' (AROP 95 fph) 475 GPM, 1,173 PSI, 120 RPM, TRQ On 18.9K, TRQ Off 19K, WOB 10K. Max Gas 1,666U, ECD 10.3 ppg, P/U 198K, SOW 55K, ROT 107K.;1 PB drilled so far (7090'-9421') Distance to Well Plan (#06) 16.04', 12.22' low, 10.46' right;Hauled 635 bbls Fluid to MP G&I total = 9,196 bbis Hauled 910 bbis H2O from L-Pad Lake total = 10,160 bbis Lost 0 bbis to formation Total fluid lost = 0 bbl 5/1/2019 Continue Drill 8.5" lateral F/ 7,344'- T/ 7,788' MD Total 444' (AROP 74 fph). 500 gpm, 1307 psi, 12k wob, 120 rpm, 19k tq on, 17.5k tq off, 1.172u Max Gas, 10.4 ECD. 204k up, 55k on, 107k rot. SPR @ 7,766'1 4,351' TVD. MP#1-32/48 spm, 275/318 psi / MP#2-32/48 spm, 271/315 psi.; PJSM Drill 8.5" hole F/ 7,788' to 8,164' MD Total 376 (AROP 63 fph) 500 GPM, 1,305 PSI, 120 RPM, TRQ On 22K, TRQ Off 20K, WOB 8-12K. Max Gas 2,51 BU, ECD 10.4 ppg, P/U 21 UK, S/O 46K ROT 107K. Backream 30' every stand.; PJSM Drill 8.5" hole F/ 8,164' to 8,676' MD Total 512' (AROP 85 fph) 515 GPM, 1,410 PSI, 120 RPM, TRQ On 21.5K, TRQ Off 20K, WOB 12K. Max Gas 2,3000, ECD 10.5 ppg, P/0 221 K. ROT 108K, lost SOW at 8296'. Backream 30' every stand.;PJSM Drill 8.5" hole F18,676' to 9,173' MD Total 497' (AROP 83 fph) 515 GPM, 1,576 PSI, 120 RPM, TRQ On 21.5K, TRQ Off 20K, WOB 12K. Max Gas 1,755U, ECD 10.9 ppg, P/U 208K, ROT 106K, lost SOW at 8296'. Backream 30' every stand.;I PB drilled so far (7090'-9421'). 1 fault crossed at 7552' 31 concretions drilled so far for a total footage of 218' (10.6%) 1,842' drilled in NB sands.;Hauled 461 bbis Fluid to MP G&I total = 9,657 bbls Hauled 650 bbls H2O from L-Pad Lake total = 10,810 bbls Lost 35 bbls to formation Total fluid lost lateral = 59 bbis Distance to Well Plan (#06) 26.04', 21.64' high, 15.13' right 5/2/2019 Drill 8.5" hole F/ 9 173'to 9 693' MD Total 520'(A OF 87 fph) 510 GPM, 1,600 PSI, 120 RPM, TRQ On 25K, TRQ Off 21K, WOB 12-14K. Max Gas 2,124U, ECD 10.8 ppg, P/U 212K, ROT 108K, Backream 30' every stand.;Drill 8.5" hole F/ 9,693' to 10,391' MD Total 698' (AROP 116 fph) 515 GPM, 1,720 PSI, 120 RPM, TRQ On 23K, TRQ Off 24.5K, WOB 10K. Max Gas 2,1000, ECD 11.1 ppg, P/U 220K, ROT 107K. Backream 30' every stand.; Drill 8.5" hole F/ 10,391' to 11,120' MD Total 729' (AROP 122 fph) 515 GPM, 1,830 PSI, 120 RPM, TRQ On 25K, TRQ Off 26K, WOB 12K. Max Gas 1,8741.1, ECD 11.0 ppg, P/U 215K, ROT 107K. Increase lube concentration from 2.8%to 3.3% at 10700' with no impact on torque. Tandem Sweep a 11,090.;Continue to circulate out tandem low vislwt and high vis/wt sweep at 515 gpm/1,830 psi 120 rpms/23-25Kft-lbs reciprocating pipe. No increase in cuttings, sweep back on time. Minimal decrease in ECD (0.1 ppg), no impact on torque and drag.;Drill 8.5" hole F/ 11,120' to 11,680' MD Total 560' (AROP 93 fph) 515 GPM, 1,800 PSI, 120 RPM, TRQ On 24K, TRQ Off 24.5K, WOB 10K, Max Gas 2,116U, ECD 11.2 ppg with 9.2 ppg drilling fluid. P/U 191K, ROT 106K. Backream 30' every stand.; Increase lube concentration to 3.8% at 11,280'.;1 PB drilled so far (7090' -9421'). 3 faults crossed at 7552', 9756', and 11,220'. 51 concretions drilled so far for a total footage of 302' (6.5%). 1852' drilled in NB sands, 1097' in NC, and 856' in ND.; Hauled 577 bbls Fluid to MP G&I total= 10,234 bbis Hauled 780 bbis H2O from L-Pad Lake total = 11,590 bbis Lost 0 bbls to formation Total fluid lost lateral = 59 bbis Distance to Well Plan (#06) 32.72', 31.28' low, 9.58' left 5/3/2019 Drill 8.5" hole F/ 11,680'to 12,298' MD Total 618' (AROP 103 fph) 515 GPM, 1,850 PSI, 120 RPM, TRQ On 26.5K, TRQ Off 26.5K, WOB 6K. Max Gas 1,966U, ECD 11.2 ppg with 9.2 ppg drilling fluid. P/U 190K, ROT 108K. Backream 30' every stand.;Start Increase Lube to 4%.. Start tightening up screens 12,100' w/200s/170s.;Drill 8.5" hole F/ 12,298! to 12,900' MD Total 602' (AROP 100 fph) 515 GPM, 1,810 PSI, 120 RPM, TRO On 27K, TRQ Off 28.5K, WOB 12K. Max Gas 1,2730, ECD 11.05 ppg with 9.2 ppg drilling fluid. P/U 205K, ROT 108K. Backream 30' every stand.;Both Shakers screened up to 2005 12,700'.;Circulate hole clean 3 x BU; staging up to 550gpm/1890 psi, 160 rpms/27.5Kft-lbs. Reciprocate pipe, rack one stand back every bottoms up. Screen shakers up to all 270 on shaker 1 and 270/200 on shaker 2; circulate hole volume staging up to 550 gpm/ 1800 psi, 40 rpms/18.5Kft-Ibs.;obtain passing PST. Finish screening both shakers up to 270's. CBU, unable to stage pumps up past 415 gpm without losing significant mud over shakers. Replace screen on end with 200 and finish full circulation at 550 gpml20 rpms, while working pipe to bottom. Obtain 2 more;passing PST's (5.94, 6.16, 6.49). Obtain SPR's.;UD working single. BROOH from 12,900' to 11,900' at 15-22 fph. 500 gpm/1520 psi, 120 RPM/18-21.5Kft-lbs. ROTW 107, PUW 153K, SOW 55K. Max gas 182U.;1 PB drilled so far (7090'-9421'). 3 faults crossed at 7552', 9756', and 11,220'. 66 concretions drilled so far for a total footage of 350'(5.9%) 2704' drilled in NS sands, 111 Tin INC, and 794' in ND.;Hauled 807 bbis Fluid to MP G&I total = 11,041 bbls Hauled 910 bbls H2O from L -Pad Lake total = 12,500 bbis Lost 0 bbls to formation Total fluid lost lateral = 59 bbls Distance to Well Plan (#06) 24.6', 23.06' low, 8.57' left 5/4/2019 BROOH from 11,900' to 11,675' at 15-22 fph. 400.500 gpm/1520 psi, 120 RPM/18-21.5Kft-lbs. ROTW 111, PUW 165K, SOW 55K. Max gas 169U. Battle trying to keep mud on shakers. Had to slow to 375GPM. Decision made to perform clean up cycle.;CBU attempting to establish higher flow rate over shakers. 200/270 mesh screens. 270 mesh screens blinding off with fines. Could not achieve higher than 350 gpm with out losing fluid over shakers.;Shut down pumps. Flow Check well .Well Static. R/U and remove MPD Bushing while changing all shaker screens to 200s. Pull MPD Element, C/O air boot and Install Riser. Well static with 9.2 MW.;Establish circulation with 200 mesh screens on both shakers. Circulate STS volume + active pit volume staging pumps up as shakers allowed from 350 gpm to 550 gpm. Obtain Passing PST Test on Flow Line and under shakers.; BROOH from 11,675'to 9700' at 15-30 fph. 515 gpm/1500 psi, 120 R PM/1 9Kft-lbs. ROTW 110, PUW 178K, SOW 69K. ECD 10.31 ppg EMW. Work though tight spot with slight pack -off at 11,030'.;Cont. BROOH from 9,700' to 7,851' 515 gpm/1500 psi, 120 RPM/17Kft-lbs. ROTW 115, PUW 178K, SOW 69K. ECD 9.9-10.7 ppg EMW. Work though multiple tight spots with pack -offs at formation changes: 10,970', 8520', 8295', 8080', 8520'; slowing puling speed and allowing hole to cleanup.;Cont. BROOH from 7,851' to 6,965515 gpm/1285 psi, 120 RPM/18Kft-lbs. PUW 150K, SOW 95K, ROTW 114k. ECD 9.84 ppg EMW. Work though multiple tight spots with pack -offs at formation changes: 7,534', 7,450'. slow pulling speed and allowing hole to cleanup.;Flow check, static. Circulate hole clean 3 x BU, 515 gpm/1155 psi, 75 rpms/14.5Kft-lbs. ECD's 9.79 ppg EMW. PUW 150K, SOW 95K, ROTW 114K. Obtain passing PST at flowline and under shakers.;Flow, check, static. B/D top drive and Geo -span. M/U TIW. Slip and out 72' drilling Iine.;Hauled 577 bible Fluid to MP G&I total= 11,618 bbis Hauled 520 bbis H2O from L -Pad Lake total = 13,020 bbis Lost 0 bbis to formation Total fluid lost lateral = 59 bbls 5/5/2019 Continue to slip and out 72' of drill line. check brake tolerance -good. Calibrate blocks and elevator stops.; POOH from 6965' to 6456MD laying down drill pipe observe well swabbing.;Circulate surface to surface at 515 gpm/1185 psi, 20 rpms/14K-ftlbs. Attempt to POOH, still swabbing.;Pump out of the hole from 6455' to 5745' 125 gpm/190 psi laying down drill pipe. Attempt to pull on elevators multiple times, continues to swab. PUW 155K, SOW 98K.;Continue to Pump out of the hole from 5745' to 4760' 125 gpm/160 psi racking back drill pipe. PUW 136K, SOW 91 K.;Circulate 20 bbis at 550 gpm/1050 psi, 100 rpms/ 8.8Kft-lbs to attempt and clear BHA. POOH laying down drill pipe from 4760' to 3200'.;Ddll pipe wiper rubber fell downhole. Attempt to circulate out. Drain stack and check flowline. Cont. to Circulate 600 gpm/1300 psi, 20 rpms/4700 ft -lbs while building and pumping high viscosity sweep. Downlink to shut down MWD and stage pumps up to 700 gpm/1570 psi.;Shut down, drain stack. Rubber observed on top of wear bushing. Fished out. B/D top drive.;POOH from 3200' to 275' laying down drill pipe. Calculated fill.;Lay down drill collars, Jars. Plug in and download MWD. Continue UD BHA. Bit grade 2-3-BT-A-X-I-CT- TD.;Clean and clear rig Floor of BHA components.;Service rig. Grease crown, TD, drawworks.;Rig up to RIH with liner. M/U triple connect to safety XO. Pick up and rig up Weatherford power tongs and Baker tools.;Hauled 230 bbls Fluid to MPG&I total= 11,848 bbis Hauled 360 bbis H2O from L -Pad Lake total = 13,380 bible V Lost 0 bbls to formation Total fluid lost lateral = 59 bbis 5/6/2019 Continue to bring Baker tools to rig floor and rig up Weatherford. SimOps: clean pill pits in preparation for brine displacement.; PJSM. Pick up float shoe, WIV, and drilliable packoff.RIH with 4-1/213.5# 625 Wedge L-80 liner with swell packers and ICD's as per tally to 3147'. centralizer on every joint. Observe calculated displacement.;Cont. to RIH with 4-1/2" 13.5# 625 Wedge L-80 liner with swell packers and ]CD's as per tally from 3147'to 6082'. Centralizer on everyjoint. Observe calculated displacement. PUW 98K, SOW 72K.;Rig up false table. Change out pipe handling equipment for innerstring.;M/U slick stinger with No -Go, ball seat sub and rupture disc. Pickup drift and RIH with 2-3/8" inner string to 4920'.;Discovered 4-1/2" liner was incorrectly torque'd (5,000 ft -lbs) Min torque 8,000ft-lbs. POOH with inner string from 4920' to 3300'. PUW 61K, SOW 43K.;Conlinue to POOH with inner string from 3300' to surface.;Rig up and POOH with 4-1/2" 13.5# 625W from 6082' to 5626' liner checking breakout torque. First two joints broke out at 50 -lbs, 3.50 -lbs. Bump third joint up to optimum torque at 9.6Kft-Ibs, observe pipe spinning at 53008 -lbs. Continue POOH with 4.5Kft-lbs average to break out.;Hauled 348 bbis Fluid to MP G&I total = 12,196 bbls Hauled 0 bbis H2O from L -Pad Lake total = 13,380 bbls Lost 0 bbis to formation Total fluid lost lateral = 59 bbis 5/7/2019 Continue POOH UD 4.5" Hyd 625, 13.5# Lower completion f/5626' to WIV/Shoe easy. Use slabbing guide pulling out of box. Check Box and Pin ends before UD. Check OD on all swell Packers Elements (8.25"-8.20") Torque Jt on top of Shoe Track to 9,600 %Ibs. No Issues encountered UD Llner.;RIH with 4-1/2" 13.5# 625 Wedge L-80 liner with swell packers and ICD's as per tally to 6082', centralizer on every joint. Observe calculated displacement. PUW 99K, SOW 73K.;Rig up false table. Change out pipe handling equipment for innerstring.;M/U slick stinger with No -Go, ball seat sub and rupture disc. Pick up drift and RIH with 2-3/8" inner string to 4929. (END OF NPT).;Continue to pick up, drift and RIH with 2-318" inner string it 4920' to 6061' Tag No -Go with 5K on depth. PUW 65k, SOW 47k.;Space out innerstring 6.8' off No -Go with 8.03' stung in. UD partial and full joint. Pick up 3 pups total 22.34'. M/U crossover. Rig down false rotary table. C/O pipe handling equipment. M/U swivel and Liner top packer/hanger. Rig down power tongs. RIH one stand. Circulate liner volume at;1 bpm/350 psi, 2 bpm/590 psi, 3 bpm/950 psi. PUW 127K, SOW 90k. Blow down top drive.;RIH from 6183' to 6984' with liner on drill pipe from derrick, drifting (2.75"). Obtain parameters prior to entering open hole 2 bpm/590 psi. 5 rpm/7600ft-Ibs, 10 rpms/8400ft-Ibs, 20 rpms/8900 ft-Ibs PUW 135K, SOW 90k.;Hauled 0 bbis Fluid to MP G&I total= 12,196 bbis Hauled 0 bbls H2O from L -Pad Lake total = 13,380 bbis Lost 0 bbis to formation Total fluid lost lateral = 59 bbl Continue to RIH from 6,984' to 10,711' with 4-1/2" lower completion. RIH with DP drilling (2.75" OD) out of derrick to 9,167', pickup drift (2.75" OD) and single in with HWDP to 10,711'. PUW 195K, SOW 100K. Increase lube concentration in surface volume to 6%. Fill pipe every 15 stands breaking;circulation with 20 bbls. 60fpm running speed.;Conl. to RIH from 10,711'to 12.320', pick drift (2.75"OD) and single in with HWDP to 11,649, RIH with DP out of derrick the rest of the way. Set down at 12,320'. Attempt to work past, unable to.; Establish circulation and stage up to 3 bpm/1400 psi. Set torque limiter to 13Kft-lbs. No free rotation but able to rotate 2040 rpms while working pipe. PUW 200K, SOW 100K. Slack off to 35K while working pipe, picks up with 10-20K overpull. Work pipe down from 12,320' to 12,464'.;Continue working pipe from 12,464`, varying parameters 2-3.2 bpm, 5-30 rpms while working. Unable to work past. Consult with town. Increase torque limiter to 18Kft-lbs. Pump 20% lube pill. Slow rate to 1 bpm/730psi when pill exits shoe; Observe 30K drop in PUW, and more consistent rotary.;Work down to 12,658', where we were able to rotate and pump casing down to TD at 12,900'. Pick up to PUW and set in tension. PUW 212K, SOW 110K.;PJSM. Prep pits while staging pumps up to 3.7bpm/1684 psi (limiter set at 1700 psi as per Baker rep). Displace to brine and cleanup wellbore: 40 bbls high viscosity spacer, 500 bbis 9.2 ppg Brine, SAPP chem train consisting of (3) 40 bbls SAPP pills each followed by 50 bbls of brine. Slow rate to;3 bpm/1660 psi. Go to closed loop system once clean brine is at surface and continue circulating out SAPP chem train. Loss rate 10 bph.;Hauled 587 bbls Fluid to MP G&I total = 12,783 bbls Hauled 0 bbls H2O from L -Pad Lake total = 13,380 bbls Lost 0 bbis to formation Total Fluid lost lateral = 59 bbls UHilcorp Energy Company Composite Report Well Name: MP E-40 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): API #: 50-029-23626-00-00 Spud Date: 4/16/2019 Job Name: 1910940C MPE-40 Completion Contractor AFE #: AFE $: 5/9/2019 Continue to Displace Annulus to clean Brine pumping SAPP Pills to Surface @ 3 bpm/1660 psi. Go to closed loop system when we observed clean brine at surface, and continue circulating out SAPP chem train. Loss rate 10 bph.Note 10 BPH Loss Rate @ end of Circulation., Drop 1.25' phenolic ball down 5" D.P. Pump 1.25" Ball down to WIV at 2 BPM, 875 PSI for 94.8 bbis. Slow pumps to 1.5 BPM. Pressure up to 2,650 PSI and Shear pins on Pusher tool, increase Press to 3,000 PSI for 5 Min. Slack off to 45K Hook Load ensure Packer set. Pressure up to 4,400 PSI to release HRD running tool with W IV/Shoe @ 12,900' & TOL @ 6791'.,P/U to 200K Hook Load and test PKR/IA to 1500 psi for 10 min. All charted and witnessed by Baker and CO Rep.,Un-Sting f/ Pack off, Break Circ. at 4 bpm, 2750 PSI. Circ. Displace 4.5" x 2 3/8' Liner Volume x 2 with clean 9.3 ppg Brine. Monitor well for 10 Min, static.,Pump Dry Job and chase with Fresh Water to rinse ID of Pipe. B/D TDS. POOH Racking Back 5" DP from 12,900' to 12,476'.,Continue to POOH from 12,496'to 6119' racking back 5" OF. 7 bbis lost during trip.,UD liner running tool. Change out pipe handling equipment. Rig up Weatherford power tongs. Rig up safety joint.,POOH laying down 2- 3/8" inner string to surface. Calculated hole fill 16 bbls, actual 29 bbls.,Lay down slick stick. Rig down handling equipment, and safety joint. Monitor hole on trip tank: static loss rate 4 bph.,Make up 3.5" wash tool with 8.4" OD No -Go. Rig down Weatherford tongs. Change out cobra head cable., RIH from 28' to 6822' (mule shoe depth) and tag No -Go on liner top with 5K on depth. Calculated displacement 58.3 bbls, actual 43.9 bbls. PUW 148K, SOW 101 K., Establish circulation staging up to 8 bpm/230 psi slowly pulling out of liner top to 6776, increase rate to 10 bpm/325 psi. Circulate 2 x annular volume. loss rate = 24 bph.,Hauled 1,944 bbis Fluid to MP G&I total = 14,727 bbls Hauled 260 bbis H2O from L -Pad Lake total = 13,640 bbls Lost 120 bbis brine to formation Total brine lost lateral = 120 bbis Total drilling Fluid lost lateral = 59 bbls 5/10/2019 Displace 9-5/8" casing to clean 9.2 ppq brine at 7 b m 220 psi. Monitor well, initially slight Flow slowing down to at 2.2 bph static loss rate.,inspect drilling line. Cut and slip 120'. Check brake tolerance - good. Calibrate blocks and elevator stops.,Service rig. Grease crown, blocks, wash pipe, TO, IBOP, Tongs, Elevators, spinners. Perform derrick inspection. Loss rate 2.2 bph.,POOH to surface laying down drill pipe. Calculated displacement 62.2 bbls, actual 96.7 bbls.,RIH with remaining 9 stands of drill pipe, calc displacement 4.4 bbls, actual 1.7 bbls.,POOH laying down drill pipe. Calc displacement 4.4 bbis, actual 10.1 bbls.,Pull wear ring. Clean and clear rig Floor. Rig up to RIH with upper completion, change out pipe handling equipment. Stage SLB ]-wire spool, cannon clamps on rig Floor. Rig up Weatherford Power tongs. Stage jewelry in pipe shed. Static loss rate 6.6 bph.,Pick up bullet seal assembly with NO-GO. RIH on 3-1/2" EUE 8rd L-80 9.3# tubing to 609. MUT 3200 ft -lbs PUW38K, SOW 38K. Simops: Test metal to metal seal from gauge cable had to gauge to 5000 psi for five minutes - good.,Continue to RIH from 600'to 3724' with lower completion on 3-1/2" EUE 8rd, L-80, 9.39 tubing as per tally. 'XN' nipple after J joint 31, gauge carrier after joint 33. Install gauge and I -wire and test to 5000 psi for 5 minutes - good. Install cannon clamps everyjoint after for 20 joints then every other joint. Continuously monitoring gauge wire., Hauled 684 bbls Fluid to MP G&I total = 15,411 bbis Hauled 130 bbis H2O from L -Pad Lake total = 13,770 bible Lost 105 bbis brine to formation Total brine lost lateral = 225 bbls Total drilling fluid lost lateral = 59 bbis 5/1 112 01 9 Continue to RIH from 3724' to 6809' with lower completion on 3-1/2" EUE 8rd, L-80, 9.3# tubing as per tally. Tag up and No -Go with 12K down. Space out 1.66' off No -Go. PUW 78K, SOW 57K. Install cannon clamps every joint 1st 20 past gauge and then every other joint. Continuous monitoring downhole tom, gauge.,Change out elevators, pick up landing joint. Make up hanger. Terminate I -wire for gauge. RIH and engage seals. Close annular and PT to 400 psi - r good. Strip out of hole until 1" ports on seals are exposed.,Line up establish reverse circulation at 3 bpm/92 psi with significant losses; 5 min loss rate= 72 bph. Reverse in 275 bbls of corrosion inhibited brine and 191 bbis diesel down back side. 3 bpm/375 psi.,Strip in hole until seals are engaged. Bleed off pressure and open annular. Land hanger. R/U and PT 9-518" x 3.5" annulus to 2000 psi for 30 minutes - good test. Pumped 4 bible bled back 4 bbls. Rig down test \ equipment., Pull landing joint. Break out X/O's and UD. Clean and clear rig floor while monitoring well - slight flow, breathing. Fill stack to monitor on trip tanks and observe well go on slight losses. Set BPV. R/U and flush surface equipment with fresh water. SimOps: Prep E-38, set herculite. Lay rig mats.,Blow down choke and kill lines. Pull riser. Install bushing plug in MPD. Disconnect choke and kill lines. De -energize accumulator and disconnect lines. Disconnect drain hoses and remove drip pan. Pull rotating head off stack. Break out studs on BOPE. SimOps: Finish cleaning pits. Disconnected pits interconnect. Stage equipment behind E-38.,Hauled 399 bbis Fluid to MP G&I total= 15,810 bbis Hauled 230 bbis H2O from L -Pad Lake total = 14,000 bbls Lost 52 bbls brine to formation Total brine lost lateral = 277 bbls Drilling mud lost lateral = 59 bbis N/0 BOPE: Stand back BOPE on pedestal. L/d rotating head. Remove DSA, Penetrate I-wire. Install plug in BPV. N/U tree and test tubing hanger void 500psi/5min, 5000 psi/15 min -good. Rig up to test tree. Pull speed head and rotating head out of cellar. Swap to Gen power at 07:00. B/D water and steam lines. Disconnect and move cuttings tank, environvac and break shack. R/D tongs. Bridle up. Scope down derrick,Test tree 500psi/5min, 5000/15 min - good. Pull plug and BPV, install BPV. LRS freeze protect tubing bullheading 27 bbls of diesel at 1.5 bpm ICP 118 psi, FCP 727 psi. Raise beaver slide. Scope back cattle chute. Finis R/D steam, water and air at interconnects. Set starting head and diveter'T' on E-38. Split and stage Gen, Pit, pipe shed and catwalk mods. Finish prepping pits, pump room. Walk sub off E-40.,Install sub rear tires. Stage sub. Set matting boards. Re-Stage Pit and Gen mods. Remove suction screen pods on mud pumps and weld on new cap nut. Reinstall same. Open and inspect fluid end on mud pump #1.,Spot and level sub over MP E-38. Remove jeep from sup. Spot diverter line. Back drag and level pad in front of sub. Set rig mats. Spot catwalk. SimOps: Change out idler bearings on drag chain.,Last report for MP E-40.,Hauled 307 bbls Fluid to MP G&I total = 16,117 bbls Hauled 0 bbls H2O from L-Pad Lake total = 14,000 bbls Lost bbls brine to formation Total brine lost lateral = 277 bbis Drilling mud lost lateral = 59 bbls Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E -40i 500292362600 Sperry Drilling Definitive Survey Report 09 May, 2019 HALLIBURTON Sporry Drilling Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-40 Wellbore: MPU E -40i Design: MPU E -40i Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-40 MPU E-40 Actual RKB @ 48.44usft MPU E-40 Actual RKB @ 48.44usft True Minimum Curvature NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU E-40 Well Position +N/ -S +E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: 6,016,010.71 usfl 569,322.23 usfl 0.00 usfl Latitude: Longitude: Ground Level: 70° 27' 14.7492 N 149` 26'3.5298 W 21.60 usft Wellbore MPU E -40i Map Map Vertical MD Magnetics Model Name Sample Date Declination +NIS Dip Angle Field Strength Easting DLS Section (usft) (I (I (nT) (usft) BGGM2018 4/1/2019 (ft) 16.77 80.97 57,434.24620471 Design MPU E-401 0.00 26.84 -21.60 0.00 0.00 Audit Notes: 569,322.23 0.00 0.00 UNDEFINED 100.00 0.44 238.32 Version: 1.0 Phase: ACTUAL Tie On Depth: 7,082.38 Vertical Section: -0.27 2_Gym-NS-GC_Drill collar (1 Depth From (TVD) +NIS +EI -W Direction 120.56 -0.51 -0.75 (usft) (usft) (usfl) -0.89 2_Gyro-NS-GC_Drill collar (1 (`) 1.17 236.99 26.84 0.00 0.00 -1.55 42.27 Survey Program Date 5/9/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 481.00 MPU E-40PBI Gyro (MPU E-40PB1) 2_Gyro-NS-GC_Drill colt; H029Ga: North seeking single shot in drill colla 04/09/2019 546.47 6,952.03 MPU E-40PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +se 0 4/1 712 01 9 7,020.67 7,082.38 MPU E-40PB1 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec& multi -station analysis +sa 04/30/2019 7,090.00 7,090.00 MPU E-40 Blind Survey (MPU E -40i) 2_Blind A026Ua: Blind drilling - no survey data 05/09/2019 7,146.41 12,831.29 MPU E-40 MWD+IFR2+MS+Sag (4) (MF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 04/30/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usfl) (ft) (ft) (°1100') (ft) Survey Tool Name 26.84 0.00 0.00 26.84 -21.60 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 UNDEFINED 100.00 0.44 238.32 100.00 51.56 -0.15 -0.24 6,016,010.56 569,321.99 0.60 -0.27 2_Gym-NS-GC_Drill collar (1 169.00 0.61 232.25 169.00 120.56 -0.51 -0.75 6,016,010.19 569,321.48 0.26 -0.89 2_Gyro-NS-GC_Drill collar (1 231.00 1.17 236.99 230.99 182.55 -1.06 -1.55 6,016,009.64 569,320.69 0.91 -1.82 2_Gyro-NS-GC_Dn1l collar (1 294.00 2.37 245.13 293.96 245.52 -1.96 -3.27 6,016,008.72 569,318.98 1.94 -3.65 2_Gym-NS-GC_Drill collar (1 356.00 3.76 230.49 355.87 307.43 -3.79 -6.00 6,016,006.87 569,316.27 2.56 -6.84 2_Gyro-NS-GC_Dn1l collar (1 419.00 4.70 222.50 418.70 370.26 -7.01 -9.34 6,016,003.62 569,312.96 1.76 -11.47 2_Gym-NS-GC Dnll collar (1 481.00 6.23 210.06 480.41 431.97 -11.79 -12.74 6,015,998.80 569,309.60 3.11 -17.29 2_Gyro-N8GC_Dn1l collar it 546.47 8.07 191.03 545.38 496.94 -19.38 -15.40 6,015,991.19 569,307.01 4.54 -24.70 2_MWD+IFR2+MS+Sag (2) 609.19 9.33 178.74 607.38 558.94 -28.78 -16.13 6,015,981.78 569,306.37 3.57 -32.15 2_MWD+IFR2+MS+Sag (2) 59/2019 4:23:14PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E40 Project: Milne Point TVD Reference: MPU E-40 Actual RKB @ 48.44usft Site: M Pt E Pad MD Reference: MPU E-40 Actual RKB @ 48.44usft Well: MPU E-40 North Reference: True Wellbore: MPU E-401 Survey Calculation Method: Minimum Curvature Design: MPU E -40i Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-1100') (ft) Survey Tool Name 671.81 11.17 163.57 669.01 620.57 -39.68 -14.30 6,015,970.90 569,308.30 5.19 -38.98 2_MWD+IFR2+MS+Sag(2) 735.63 12.75 150.98 731.46 683.02 -51.77 -9.13 6,015,958.86 569,313.58 4.77 -44.45 2_MWD+IFR2+MS+Sag(2) 799.97 16.03 145.00 793.77 745.33 -65.26 -0.59 6,015,945.45 569,322.24 5.59 -48.69 2_MWD+IFR2+MS+Sag(2) 862.51 18.30 142.46 853.52 805.08 -80.12 10.34 6,015,930.70 569,333.32 3.82 -52.33 2_MWD+IFR2+MS+Sag (2) 926.58 21.28 142.61 913.80 865.36 -97.34 23.54 6,015,913.61 569,346.67 4.65 -56.20 2_MWD+IFR2+MS+Sag(2) 989.00 22.85 139.98 971.65 923.21 -115.62 38.21 6,015,895.46 569,361.51 2.97 -59.86 2_MWD+IFR2+MS+Sag (2) 1,052.06 24.54 137.94 1,029.39 980.95 -134.72 54.86 6,015,876.52 569,378.33 2.98 -62.79 2_MWD+IFR2+MS+Sag (2) 1,118.12 26.70 138.02 1,088.96 1,040.52 -155.94 73.98 6,015,855.48 569,397.65 3.27 -65.64 2_MWD+IFR2+MS+Sag (2) 1,182.08 30.12 138.24 1,145.20 1,096.76 -178.60 94.28 6,015,83301 569,418.16 5.35 -68.74 2_MWD+IFR2+MS+Sag(2) 1,245.82 33.78 137.60 1,199.28 1,150.84 -203.62 116.69 6,015,808.20 569,441.00 5.77 -72.06 2_MWD+IFR2+MS+Sag (2) 1,307.04 36.32 137.49 1,249.39 1,200.95 -229.56 140.62 6,015,782.49 569,464.97 4.15 -75.29 2_MWD+IFR2+MS+Sag (2) 1,372.74 38.22 135.23 1,301.68 1,253.24 -258.34 168.08 6,015,753.97 569,492.69 3.56 -78.11 2_MWD+IFR2+MS+Sag (2) 1,436.68 40.31 134.76 1,351.18 1,302.74 -286.94 196.70 6,015,725.64 569,521.58 3.30 -80.03 2_MWD+IFR2+MS+Sag (2) 1,499.71 42.60 132.72 1,398.42 1,349.98 -315.78 226.86 6,015,697.09 569,551.99 4.22 -81.08 2_MWD+IFR2+MS+Sag (2) 1,562.41 45.12 131.86 1,443.62 1,395.18 -345.00 259.00 6,015,668.17 569,584.40 4.13 -81.09 2_MWD+IFR2+MS+Sag (2) 1,624.13 46.90 131.24 1,486.49 1,438.05 -374.45 292.23 6,015,639.03 569,617.90 2.97 -80.53 2_MWD+IFR2+MS+Sag (2) 1,689.00 48.07 131.92 1,530.33 1,481.89 -406.18 327.99 6,015,607.63 569,653.96 1.96 -79.95 2_MWD+IFR2+MS+Sag(2) 1,751.92 47.81 132.94 1,572.48 1,524.04 -437.70 362.47 6,015,576.44 569,688.73 1.27 -80.08 2_MWD+IFR2+MS+Sag(2) 1,815.35 48.90 132.48 1,614.63 1,566.19 -469.85 397.30 6,015,544.62 569,723.85 1.80 -80.44 2_MWD+IFR2+MS+Sag(2) 1,878.29 48.77 132.67 1,656.06 1,607.62 -501.91 432.20 6,015,512.89 569,759.04 0.31 -80.70 2_MWD+IFR2+MS+Sag(2) 1,942.13 47.82 133.09 1,698.53 1,650.09 -534.34 467.12 6,015,480.79 569,794.26 1.57 -81.20 2_MWD+IFR2+MS+Sag(2) 2,003.53 46.93 131.28 1,740.11 1,691.67 -564.68 500.59 6,015,450.77 569,828.01 2.61 -81.14 2_MWD+IFR2+MS+Sag(2) 2,068.09 47.56 132.83 1,783.94 1,735.50 -596.43 535.78 6,015,419.35 569,863.49 2.01 -80.97 2_MWD+IFR2+MS+Sag(2) 2,131.91 46.39 131.43 1,827.48 1,779.04 -627.73 570.38 6,015,388.37 569,898.37 2.44 -80.86 2_MWD+IFR2+MS+Sag(2) 2,195.13 47.74 133.54 1,870.55 1,822.11 -658.99 604.50 6,015,357.43 569,932.78 3.24 -81.04 2_MWD+IFR2+MS+Sag(2) 2,258.44 49.77 132.77 1,912.29 1,863.85 -691.55 639.23 6,015,325.21 569,967.81 3.33 -81.77 2_MWD+IFR2+MS+Sag(2) 2,321.14 48.00 131.53 1,953.51 1,905.07 -723.25 674.24 6,015,293.83 570,003.11 3.19 -81.68 2_MWD+IFR2+MS+Sag(2) 2,385.46 50.80 132.51 1,995.37 1,946.93 -755.94 710.51 6,015,261.48 570,039.68 4.50 -81.47 2_MWD+IFR2+MS+Sag(2) 2,449.67 51.27 134.04 2,035.75 1,987.31 -790.17 746.86 6,015,227.60 570,076.34 1.99 -82.35 2_MWD+IFR2+MS+Sag(2) 2,513.41 51.35 132.92 2,075.59 2,027.15 -824.40 782.96 6,015,193.71 570,112.75 1.38 -83.40 2_MWD+IFR2+MS+Sag(2) 2,577.28 49.65 134.26 2,116.22 2,067.78 -858.37 818.66 6,015,160.07 570,148.76 3.12 -84.53 2_MWD+IFR2+MS+Sag (2) 2,640.70 49.13 134.22 2,157.50 2,109.06 -891.96 853.15 6,015,126.81 570,183.56 0.82 -86.19 2_MWD+IFR2+MS+Sag (2) 2,704.29 49.18 134.93 2,199.09 2,150.65 -925.72 887.42 6,015,093.37 570,218.14 0.85 -88.12 2_MWD+IFR2+MS+Sag(2) 2,767.91 48.02 134.28 2,241.16 2,192.72 -959.23 921.39 6,015,060.18 570,252.42 1.98 -90.07 2_MWD+IFR2+MS+Sag(2) 2,831.09 47.21 134.56 2,283.75 2,235.31 -991.90 954.72 6,015,027.83 570,286.05 1.32 -91.82 2_MWD+IFR2+MS+Sag(2) 2,892.55 49.58 132.56 2,324.56 2,276.12 -1,023.55 988.03 6,014,996.49 570,319.64 4.56 -92.84 2_MWD+IFR2+MS+Sag(2) 2,957.86 49.81 132.85 2,366.81 2,318.37 -1,057.33 1,024.63 6,014,963.06 570,356.55 0.49 -93.22 2_MWD+IFR2+MS+Sag(2) 3,020.88 49.22 132.07 2,407.72 2,359.28 -1,089.69 1,059.99 6,014,931.03 570,392.21 1.33 -93.38 2 MWD+IFR2+MS+Sag(2) 3,084.20 49.08 133.80 2,449.14 2,400.70 -1,122.31 1,095.05 6,014,898.74 570,427.57 2.08 -93.93 2_MWD+IFR2+MS+Sag(2) 3,147.39 48.75 133.91 2,490.67 2,442.23 -1,155.31 1,129.40 6,014,866.07 570,462.22 0.54 -95.25 2 MWD+IFR2+MS+Sag(2) 57912019 4:23:14PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU E-40 Project: Milne Point TVD Reference: MPU E-40 Actual RKB @ 48.44usft Site: M Pt E Pad MD Reference: MPU E-40 Actual RKB @ 48.44usft Well: MPU E-40 North Reference: True Wellbore: MPU E-401 Survey Calculation Method: Minimum Curvature Design: MPU E -40i Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI•W Northing Easting DLS Section (usft) (`) (1) (usft) (usft) (usft) (usft) (ft) (ft) ('1700') (ft) Survey Tool Name 3,210.35 49.02 131.22 2,532.07 2,483.63 -1,187.39 1,164.33 6,014,834.32 570,497.44 3.25 -95.49 2_MWD+IFR2+MS+Sag(2) 3,273.76 48.64 130.94 2,573.81 2,525.37 -1,218.75 1,200.31 6,014,803.29 570,533.71 0.69 -94.50 2_MWD+IFR2+MS+Sag(2) 3,336.78 48.70 130.31 2,615.43 2,566.99 -1,249.56 1,236.23 6,014,772.82 570,569.91 0.76 -93.14 2_MWD+IFR2+MS+Sag(2) 3,400.12 48.20 131.17 2,657.44 2,609.00 -1,280.50 1,272.14 6,014,742.22 570,606.11 1.29 -91.87 2_MWD+IFR2+MS+Sag (2) 3,463.44 48.91 132.06 2,699.36 2,650.92 -1,312.02 1,307.62 6,014,711.03 570,641.88 1.54 -91.33 2_MWD+IFR2+MS+Sag (2) 3,525.33 48.83 130.54 2,740.07 2,691.63 -1,342.79 1,342.64 6,014,680.60 570,677.18 1.85 -90.54 2_MWD+IFR2+MS+Sag (2) 3,591.55 48.66 132.32 2,783.74 2,735.30 -1,375.73 1,379.97 6,014,648.01 570,714.81 2.04 +39.81 2_MWD+IFR2+MS+Sag (2) 3,654.54 49.63 130.95 2,824.94 2,776.50 -1,407.37 1,415.58 6,014,616.70 570,750.70 2.25 -89.28 2_MWD+IFR2+MS+Sag (2) 3,718.06 48.14 132.09 2,866.71 2,818.27 -1,439.09 1,451.41 6,014,585.32 570,786.83 2.71 -88.65 2_MWD+IFR2+MS+Sag (2) 3,781.62 50.01 131.90 2,908.34 2,859.90 -1,471.22 1,487.10 6,014,553.53 570,822.81 2.95 -88.42 2_MWD+IFR2+MS+Sag (2) 3,844.87 49.56 131.84 2,949.18 2,900.74 -1,503.46 1,523.07 6,014,521.63 570,859.07 0.72 -88.08 2_MWD+IFR2+MS+Sag (2) 3,905.93 47.95 132.30 2,989.44 2,941.00 -1,534.22 1,557.15 6,014,491.19 570,893.43 2.70 -87.92 2_MWD+IFR2+MS+Sag (2) 3,972.67 47.36 130.15 3,034.39 2,985.95 -1,566.72 1,594.24 6,014,459.03 570,930.83 2.54 -87.02 2_MWD+IFR2+MS+Sag (2) 4,035.23 46.05 128.58 3,077.30 3,028.86 -1,595.61 1,629.44 6,014,430.48 570,966.29 2.78 -84.72 2_MWD+IFR2+MS+Sag (2) 4,100.57 45.38 125.65 3,122.92 3,074.48 -1,623.83 1,666.72 6,014,402.61 571,003.83 3.37 -80.53 2_MWD+IFR2+MS+Sag (2) 4,162.98 45.48 121.85 3,166.73 3,118.29 -1,648.52 1,703.68 6,014,378.27 571,041.01 4.34 -73.94 2_MWD+IFR2+MS+Sag (2) 4,228.29 45.74 115.54 3,212.44 3,164.00 -1,670.90 1,744.58 6,014,356.27 571,082.11 6.91 -62.99 2_MWD+IFR2+MS+Sag (2) 4,291.44 46.43 113.71 3,256.24 3,207.80 -1,689.85 1,785.93 6,014,337.71 571,123.64 2.36 -49.20 2_MWD+IFR2+MS+Sag (2) 4,354.68 46.03 110.78 3,299.99 3,251.55 -1,707.14 1,828.19 6,014,320.81 571,166.05 3.40 -33.57 2_MWD+IFR2+MS+Sag(2) 4,418.20 46.10 105.83 3,344.08 3,295.64 -1,721.50 1,871.59 6,014,306.86 571,209.58 5.61 -15.00 2_MWD+IFR2+MS+Sag (2) 4,481.86 47.47 100.75 3,387.68 3,339.24 -1,732.13 1,916.72 6,014,296.65 571,254.80 6.20 7.48 2_MWD+IFR2+MS+Sag (2) 4,545.47 47.51 97.23 3,430.67 3,382.23 -1,739.46 1,963.02 6,014,289.76 571,301.16 4.08 33.21 2_MWD+IFR2+MS+Sag(2) 4,608.82 47.94 93.27 3,473.30 3,424.86 -1,743.74 2,009.68 6,014,285.91 571,347.85 4.67 61.42 2_MWD+IFR2+MS+Sag (2) 4,672.00 47.33 89.26 3,515.88 3,467.44 -1,744.78 2,056.33 6,014,285.30 571,394.51 4.79 92.03 2_MWD+IFR2+MS+Sag(2) 4,735.24 47.16 85.03 3,558.82 3,510.38 -1,742.47 2,102.69 6,014,288.04 571,440.84 4.92 124.92 2_MWD+IFR2+MS+Sag (2) 4,799.00 47.69 80.69 3,601.97 3,553.53 -1,736.63 2,149.25 6,014,294.32 571,487.34 5.08 160.57 2_MWD+IFR2+MS+Sag(2) 4,861.72 47.03 77.69 3,644.46 3,596.02 -1,727.98 2,194.56 6,014,303.38 571,532.57 3.67 197.44 2_MWD+IFR2+MS+Sag (2) 4,926.35 46.42 74.85 3,688.77 3,640.33 -1,716.82 2,240.27 6,014,314.97 571,578.16 3.34 236.44 2_MWD+IFR2+MS+Sag (2) 4,990.14 47.66 71.77 3,732.25 3,683.81 -1,703.41 2,284.97 6,014,328.80 571,622.73 4.03 276.44 2_MWD+IFR2+MS+Sag (2) 5,053.19 49.72 68.75 3,773.87 3,725.43 -1,687.39 2,329.53 6,014,345.22 571,667.13 4.86 318.25 2_MWD+IFR2+MS+Sag (2) 5,115.69 51.53 64.48 3,813.53 3,765.09 -1,668.21 2,373.84 6,014,364.82 571,711.26 6.02 362.26 2_MWD+IFR2+MS+Sag (2) 5,180.32 53.18 63.31 3,853.00 3,804.56 -1,645.68 2,419.79 6,014,387.76 571,757.00 2.93 409.83 2_MWD+IFR2+MS+Sag (2) 5,243.68 53.57 61.61 3,890.81 3,842.37 -1,622.17 2,464.87 6,014,411.69 571,801.86 2.24 457.56 2_MWD+IFR2+MS+Sag (2) 5,307.70 55.35 58.35 3,928.02 3,879.58 -1,596.10 2,509.96 6,014,438.18 571,646.69 4.99 507.17 2_MWD+IFR2+MS+Sag (2) 5,370.47 56.85 56.68 3,963.03 3,914.59 -1,568.12 2,553.90 6,014,466.57 571,890.37 3.25 557.44 2_MWD+IFR2+MS+Sag (2) 5,434.52 58.41 53.70 3,997.33 3,948.89 -1,537.23 2,598.30 6,014,497.86 571,934.47 4.62 610.16 2_MWD+IFR2+MS+Sag (2) 5,497.95 59.22 51.31 4,030.18 3,981.74 -1,504.20 2,641.35 6,014,531.29 571,977.21 3.47 663.55 2_MWD+IFR2+MS+Sag (2) 5,561.32 60.40 48.51 4,062.05 4,013.61 -1,468.93 2,683.24 6,014,566.95 572,018.76 4.25 717.83 2_MWD+IFR2+MS+Sag (2) 5,617.45 61.22 44.72 4,089.43 4,040.99 -1,435.27 2,718.84 6,014,600.93 572,054.04 6.07 766.68 2_MWD+IFR2+MS+Sag (2) 5,681.69 61.22 40.75 4,120.37 4,071.93 -1,393.93 2,757.03 6,014,642.62 572,091.85 5.42 822.97 2_MWD+IFR2+MS+Sag (2) 592019 4:23: 14PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU E-40 Project: Milne Point TVD Reference: MPU E-40 Actual RKB @ 48.44usft Site: M Pt E Pad MD Reference: MPU E-40 Actual RKB @ 48.44usft Well: MPU E-40 North Reference: True Wellbore: MPU E-40i Survey Calculation Method: Minimum Curvature Design: MPU E-40i Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/.W Northing Easting DLS Section (usft) (') (') (usft) (usft) (usft) (usft) (ft) (ft) (°I100-) (ft) Survey Tool Name 5,745.43 62.16 36.72 4,150.61 4,102.17 -1,350.16 2,792.13 6,014,686.71 572,126.54 5.76 878.96 2_MWD+IFR2+MS+Sag(2) 5,809.07 62.44 33.43 4,180.19 4,131.75 -1,304.06 2,824.50 6,014,733.11 572,158.47 4.60 934.85 2_MWD+IFR2+MS+Sag(2) 5,872.48 64.91 32.78 4,208.31 4,159.87 -1,256.45 2,855.54 6,014,781.00 572,189.06 4.00 990.95 2_MWD+IFR2+MS+Sag(2) 5,935.87 66.25 32.36 4,234.52 4,186.08 -1,207.81 2,886.61 6,014,829.92 572,219.68 2.20 1,047.84 2 MWD+IFR2+MS+Sag(2) 6,000.17 70.12 29.59 4,258.41 4,209.97 -1,156.64 2,917.30 6,014,8B1.37 572,249.89 7.23 1,106.36 2 MWD+IFR2+MS+Sag(2) 6,064.46 74.20 26.61 4,278,11 4,229.67 -1,102.66 2,946.10 6,014,935.61 572,278.18 7.73 1,165.67 2_MWD+IFR2+MS+Sag(2) 6,127.79 76.59 25.37 4,294.08 4,245.64 -1,047.58 2,972.95 6,014,990.93 572,304.52 4.22 1,224.49 2_MWD+IFR2+MS+Sag(2) 6,189.79 79.66 23.06 4,306.84 4,258.40 -992.25 2,997.83 6,015,046.49 572,32B.87 6.15 1,282.16 2_MWD+IFR2+MS+Sag (2) 6,254.93 79.06 22.89 4,318.86 4,270.42 -933.31 3,022.82 6,015,105.65 572,353.31 0.96 1,342.59 2_MWD+IFR2+MS+Sag (2) 6,318.24 81.54 22.21 4,329.53 4,281.09 -875.68 3,046.74 6,015,163.50 572,376.70 4.06 1,401.33 2_MWD+IFR2+MS+Sag(2) 6,381.93 83.16 21.58 4,338.01 4,289.57 -817.11 3,070.28 6,015,222.27 572,399.69 2.73 1,460.50 2_MWD+IFR2+MS+Sag (2) 6,445.55 82.79 21.59 4,345.79 4,297.35 -758.40 3,093.51 6,015,281.20 572,422.37 0.58 1,519.57 2_MWD+IFR2+MS+Sag(2) 6,508.42 82.54 21.86 4,353.82 4,305.38 -700.47 3,116.59 6,015,339.33 572,444.91 0.58 1,577.96 2_MWD+IFR2+MS+Sag (2) 6,571.82 82.69 21.96 4,361.96 4,313.52 -642.14 3,140.05 6,015,397.87 572,467.82 0.28 1,636.91 2_MWD+IFR2+MS+Sag(2) 6,635.24 83.20 21.01 4,369.75 4,321.31 -583.57 3,163.10 6,015,456.64 572,490.33 1.69 1,695.75 2_MWD+IFR2+MS+Sag(2) 6,698.84 83.19 22.00 4,377.29 4,328.85 -524.82 3,186.25 6,015,515.61 572,512.93 1.55 1,754.80 2 MWD+IFR2+MS+Sag (2) 6,762.55 85.94 20.45 4,383.32 4,334.88 465.70 3,209.21 6,015,574.93 572,535.33 4.95 1,813.98 2_MWD+IFR2+MS+Sag (2) 6,826.34 85.18 20.34 4,388.26 4,339.82 -406.09 3,231.37 6,015,634.74 572,556.94 1.20 1,873.00 2_MWD+IFR2+MS+Sag (2) 6,890.21 87.60 21.01 4,392.28 4,343.84 -346.46 3,253.88 6,015,694.57 572,578.88 3.93 1,932.27 2_MWD+IFR2+MS+Sag (2) 6,952.03 90.45 21.52 4,393.34 4,344.90 -288.86 3,276.29 6,015,752.37 572,600.76 4.68 1,989.96 2_MWD+IFR2+MS+Sag (2) 7,020.67 90.50 20.86 4,392.77 4,344.33 -224.87 3,301.10 6,015,816.59 572,624.97 0.96 2,054.01 2_MWD+IFR2+MS+Sag (3) 7,082.38 91.73 20.89 4,391.57 4,343.13 -167.22 3,323.09 6,015,874.43 572,646.42 1.99 2,111.45 2_MWD+IFR2+MS+Sag (3) 7,090.00 91.49 21.11 4,391.35 4,342.91 -160.11 3,325.82 6,015,881.56 572,649.08 4.27 2,118.55 2_Blind (4) 7,146.41 89.75 22.70 4,390.74 4,342.30 -107.78 3,346.86 6,015,934.08 572,669.63 4.18 2,171.43 2_MWD+IFR2+MS+Sag (5) 7,210.06 90.37 24.57 4,390.67 4,342.23 -49.47 3,372.38 6,015,992.62 572,694.60 3.10 2,231.74 2_MWD+IFR2+MS+Sag (5) 7,273.03 91.30 26.12 4,389.76 4,341.32 7.43 3,399.33 6,016,049.76 572,721.02 2.87 2,291.97 2_MWD+IFR2+MS+Sag(5) 7,335.88 93.46 26.95 4,387.15 4,338.71 63.61 3,427.38 6,016,106.20 572,748.55 3.68 2,352.41 2_MWD+IFR2+MS+Sag(5) 7,399.86 95.51 26.94 4,382.14 4,333.70 120.47 3,456.28 6,016,163.31 572,776.91 3.20 2,413.92 2_MWD+IFR2+MS+Sag(5) 7,461.75 95.31 26.39 4,376.31 4,327.87 175.53 3,483.93 6,016,218.62 572,804.05 0.94 2,473.27 2 MWD+IFR2+MS+Sag (5) 7,524.41 95.06 25.28 4,370.65 4,322.21 231.69 3,511.13 6,016,275.03 572,830.72 1.81 2,533.12 2_MWD+IFR2+MS+Sag (5) 7,586.86 94.07 23.75 4,365.68 4,317.24 288.33 3,536.95 6,016,331.91 572,856.01 2.91 2,592.40 2_MWD+IFR2+MS+Sag (5) 7,650.99 94.08 22.48 4,361.12 4,312.68 347.16 3,562.07 6,016,390.96 572,880.57 1.98 2,652.83 2_MWD+IFR2+MS+Sag (5) 7,715.66 91.47 22.24 4,357.99 4,309.55 406.89 3,586.64 6,016,450.91 572,904.59 4.05 2,713.56 2_MWD+IFR2+MS+Sag(5) 7,780.12 91.17 21.67 4,356.50 4,308.06 466.66 3,610.73 6,016,510.90 572,928.12 1.00 2,773.99 2_MWD+IFR2+MS+Sag(5) 7,843.17 90.86 20.07 4,355.39 4,306.95 525.56 3,633.19 6,016,570.00 572,950.03 2.58 2,832.68 2_MWD+IFR2+MS+Sag (5) 7,906.60 89.99 20.03 4,354.92 4,306.48 585.15 3,654.93 6,016,629.78 572,971.22 1.37 2,891.40 2_MWD+IFR2+MS+Sag(5) 7,970.10 88.45 20.56 4,355.78 4,307.34 644.70 3,676.96 6,016,689.53 572,992.68 2.56 2,950.28 2_MWD+IFR2+MS+Sag(5) 8,033.54 88.70 19.70 4,357.36 4,308.92 704.24 3,698.78 6,016,749.27 573,013.95 1.41 3,009.02 2_MWD+IFR2+MS+Sag(5) 8,096.44 88.82 20.35 4,358.72 4,310.28 763.33 3,720.31 6,016,808.54 573,034.93 1.05 3,067.23 2_MWD+IFR2+MS+Sag(5) 8,160.02 89.88 19.27 4,359.44 4,311.00 823.14 3,741.86 6,016,868.55 573,055.92 2.38 3,125.98 2_MWD+IFR2+MS+Sag(5) 5792019 4:23: 14PM Page 5 COMPASS 5000.15 Build 91 Company: Hiicorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-40 Wellbore: MPU E -40i Design: MPU E -40i Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Survey Map MD Inc Azi TVD TVDSS +NIS +E/ -W Northing (usft) (') (1) (usft) (usft) (usft) (usft) (ft) 8,224.00 91.30 18.50 4,358.78 4,310.34 883.67 3,762.57 6,016,929.26 8,287.73 90.24 18.15 4,357.92 4,309.48 944.16 3,782.60 6,016,989.93 8,351.42 90.12 17.66 4,357.72 4,309.28 1,004.77 3,802.18 6,017,050.71 8,414.82 90.18 17.58 4,357.56 4,309.12 1,065.19 3,821.37 6,017,111.31 8,478.01 90.55 18.69 4,357.16 4,308.72 1,125.24 3,841.04 6,017,171.53 8,541.25 90.30 18.12 4,356.69 4,308.25 1,185.24 3,861.01 6,017,231.71 8,604.26 89.50 18.76 4,356.80 4,308.36 1,245.02 3,880.94 6,017,291.66 8,667.57 89.94 19.20 4,357.11 4,308.67 1,304.88 3,901.53 6,017,351.71 8,731.11 89.63 20.47 4,357.34 4,308.90 1,364.65 3,923.09 6,017,411.67 8,794.45 88.76 21.88 4,358.23 4,309.79 1,423.71 3,945.96 6,017,470.93 8,857.70 87.77 21.39 4,360.15 4,311.71 1,482.48 3,969.27 6,017,529.91 8,919.90 85.42 20.11 4,363.84 4,315.40 1,540.53 3,991.27 6,017,588.16 8,983.05 85.43 20.44 4,368.88 4,320.44 1,599.58 4,013.08 6,017,647.41 9,048.97 84.80 19.94 4,374.49 4,326.05 1,661.22 4,035.75 6,017,709.25 9,112.29 84.99 20.06 4,380.13 4,331.69 1,720.49 4,057.32 6,017,768.71 9,174.75 86.23 20.28 4,384.91 4,336.47 1,778.95 4,078.80 6,017,827.36 9,238.18 87.90 19.63 4,388.16 4,339.72 1,838.49 4,100.41 6,017,887.09 9,301.70 89.82 18.72 4,389.42 4,340.98 1,898.47 4,121.27 6,017,947.26 9,365.96 86.26 17.92 4,390.50 4,342.06 1,959.46 4,141.47 6,018,008.43 9,429.21 88.58 16.25 4,392.24 4,343.80 2,019.89 4,160.04 6,018,069.03 9,493.16 89.19 17.39 4,393.49 4,345.05 2,081.10 4,178.54 6,018,130.39 9,557.74 88.39 18.35 4,394.85 4,346.41 2,142.54 4,198.35 6,018,192.02 9,621.17 88.89 20.37 4,396.36 4,347.92 2,202.37 4,219.37 6,018,252.03 9,684.94 88.26 20.39 4,397.94 4,349.50 2,262.13 4,241.58 6,018,311.99 9,748.50 88.51 21.54 4,399.73 4,351.29 2,321.45 4,264.31 6,018,371.52 9,812.06 89.57 21.90 4,400.80 4,352.36 2,380.49 4,287.83 6,018,430.77 9,875.12 87.15 22.22 4,402.60 4,354.16 2,438.91 4,311.50 6,018,489.39 9,938.47 85.67 21.56 4,406.57 4,358.13 2,497.57 4,335.07 6,018,548.27 10,001.09 85.79 21.36 4,411.23 4,362.79 2,555.69 4,357.92 6,018,606.59 10,065.69 85.86 20.18 4,415.93 4,367.49 2,615.93 4,380.76 6,018,667.04 10,128.53 86.04 18.71 4,420.37 4,371.93 2,675.04 4,401.63 6,018,726.33 10,191.62 87.53 17.83 4,423.91 4,375.47 2,734.85 4,421.38 6,018,786.32 10,255.46 89.20 16.68 4,425.73 4,377.29 2,795.79 4,440.30 6,018,847.42 10,319.30 89.57 15.97 4,426.42 4,377.98 2,857.05 4,458.25 6,018,908.84 10,382.62 88.70 15.21 4,427.37 4,378.93 2,918.03 4,475.26 6,018,969.98 10,446.14 88.39 13.33 4,428.99 4,380.55 2,979.57 4,490.91 6,019,031.65 10,510.03 88.08 12.07 4,430.95 4,382.51 3,041.87 4,504.95 6,019,094.07 10,573.62 89.63 11.76 4,432.23 4,383.79 3,104.07 4,518.08 6,019,156.39 10,636.88 91.05 10.98 4,431.85 4,383.41 3,166.09 4,530.55 6,019,218.51 10,700.23 90.80 11.22 4,430.83 4,382.39 3,228.24 4,542.74 6,019,280.77 Well MPU E-40 MPU E-40 Actual RKB @ 48.44usft MPU E-40 Actual RKB @ 48.44usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (=1100.) (ft) Survey Tool Name 573,07606 2.52 3,184.70 2_MWD+IFR2+MS+Sa9 (5) 573,095.53 1.75 3,242.94 2_MWD+IFR2+MS+Sag (5) 573,114.54 0.79 3,300.95 2_MWD+IFR2+MS+Sag (5) 573,133.17 0.16 3,358.58 2_MWD+IFR2+MS+Seg (5) 573,152.27 1.85 3,416.24 2_MWD+IFR2+MS+Sag (5) 573,171.68 0.98 3,474.07 2_MWD+IFR2+MS+Sag (5) 573,191.05 1.63 3,531.71 2_MWD+IFR2+MS+Sag (5) 573,211.08 0.98 3,589.86 2_MWD+IFR2+MS+Sag (5) 573,232.08 2.06 3,648.59 2_MWD+IFR2+MS+Sag (5) 573,254.41 2.62 3,707.68 2 MWD+IFR2+MS+Sag (5) 573,277.16 1.75 3,766.84 2_MWD+IFR2+MS+Sag(5) 573,298.62 4.30 3,824.60 2_MWD+IFR2+MS+Sag(5) 573,319.88 0.52 3,882.96 2_MWD+IFR2+MS+Sag(5) 573,341.97 1.22 3,943.83 2_MWD+IFR2+MS+Sag(5) 573,362.99 0.35 4,002.19 2_MWD+IFR2+MS+Sag(5) 573,383.91 2.02 4,059.89 2_MWD+IFR2+MS+Sag (5) 573,404.97 2.82 4,118.49 2_MWD+IFR2+MS+Sag(5) 573,425.27 3.34 4,176.91 2_MWD+IFR2+MS+Sag (5) 573,444.90 2.73 4,235.62 2_MWD+IFR2+MS+Sag (5) 573,462.91 2.69 4,292.84 2_MWD+IFR2+MS+Sag (5) 573,480.84 2.02 4,350.57 2_MWD+IFR2+MS+Sag (5) 573,500.07 1.93 4,409.37 2_MWD+IFR2+MS+Sag (5) 573,520.53 3.28 4,467.77 2_MWD+IFR2+MS+Sag (5) 573,542.18 0.99 4,526.93 2_MWD+IFR2+MS+Sag (5) 573,564.35 1.85 4,586.12 2_MWD+IFR2+MS+Sag (5) 573,587.32 1.76 4,645.62 2_MWD+IFR2+MS+Sag(5) 573,610.44 3.87 4,704.77 2_MWD+IFR2+MS+Sag(5) 573,633.47 2.56 4,764.04 2_MWD+IFR2+MS+Sag(5) 573,655.77 0.37 4,822.41 2_MWD+IFR2+MS+Sag(5) 573,678.05 1.82 4,882.36 2_MWD+IFR2+MS+Sag(5) 573,698.37 2.35 4,940.13 2_MWD+IFR2+MS+Sag(5) 573,717.55 2.74 4,997.67 2_MWD+IFR2+MS+Sag(5) 573,735.91 3.18 5,055.50 2_MWD+IFR2+MS+Sag(5) 573,753.28 1.25 5,112.90 2_MWD+IFR2+MS+Sag(5) 573,769.73 1.82 5,169.47 2_MWD+IFR2+MS+Sag (5) 573,784.80 3.00 5,225.53 2_MWD+IFR2+MS+Sag(5) 573,798.26 2.03 5,281.07 2_MWD+IFR2+MS+Sag(5) 573,810.81 2.49 5,335.93 2_MWD+IFR2+MS+Sag(5) 573,822.70 2.56 5,390.21 2_MWD+IFR2+MS+Sag(5) 573,834.31 0.55 5,444.41 2_MWD+IFR2+MS+Sag(5) 5192019 4:23 14PM Page 6 COMPASS 5000.15 Build 91 Survey Halliburton Definitive Survey Report Map Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU E-40 Project: Milne Point ND Reference: MPU E40 Actual IRKS @ 48.44usft Site: M Pt E Pad MD Reference: MPU E40 Actual RKB @ 48.44usft Well: MPU E-40 North Reference: True Wellbore: MPU E -40i Survey Calculation Method: Minimum Curvature Design: MPU E -40i Database: NORTH US+CANADA Survey Checked By: Chelsea Wright ---.=Z--- Approved By: Mitch Laird Date: 05-09-2019 5492019 4:23:14PM Page 7 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (`) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,764.28 90.24 11.00 4,430.25 4,381.81 3,291.09 4,555.08 6,019,343.72 573,846.07 0.94 5,499.22 2_MWD+IFR2+MS+Sag (5) 10,828.46 89.31 10.37 4,430.50 4,382.06 3,354.16 4,566.98 6,019,406.89 573,857.38 1.75 5,553.89 2_MWD+IFR2+MS+Sag (5) 10,892.04 89.63 10.22 4,431.09 4,382.65 3,416.71 4,578.35 6,019,469.54 573,868.16 0.56 5,607.82 2_MWD+IFR2+MS+Sag (5) 10,955.23 90.25 11.04 4,431.15 4,382.71 3,478.81 4,590.00 6,019,531.75 573,879.24 1.63 5,661.62 2_MWD+IFR2+MS+Sag (5) 11,018.81 91.67 11.49 4,430.09 4,381.65 3,541.16 4,602.42 6,019,594.20 573,891.07 2.34 5,716.10 2_MWD+IFR2+MS+Sag (5) 11,082.66 92.04 10.60 4,428.02 4,379.58 3,603.79 4,614.65 6,019,656.94 573,902.71 1.51 5,770.67 2_MWD+IFR2+MS+Sag (5) 11,146.41 92.22 9.59 4,425.65 4,377.21 3,666.51 4,625.81 6,019,719.75 573,913.29 1.61 5,824.60 2_MWD+IFR2+MS+Sag (5) 11,209.23 92.28 8.54 4,423.18 4,374.74 3,728.50 4,635.70 6,019,781.82 573,922.61 1.67 5,877.12 2_MWD+IFR2+MS+Sag (5) 11,273.16 92.97 8.49 4,420.26 4,371.82 3,791.66 4,645.16 6,019,845.06 573,931.47 1.08 5,930.21 2_MWD+IFR2+MS+Sag(5) 11,336.09 92.78 8.55 4,417.10 4,368.66 3,853.81 4,654.47 6,019,907.30 573,940.21 0.32 5,982.47 2_MWD+IFR2+MS+Sag(5) 11,400.08 92.78 9.75 4,414.00 4,365.56 3,916.91 4,664.63 6,019,970.48 573,949.78 1.87 6,036.00 2_MWD+IFR2+MS+Sag(5) 11,464.22 93.52 10.11 4,410.47 4,362.03 3,980.00 4,675.68 6,020,033.66 573,960.24 1.28 6,090.11 2_MWD+IFR2+MS+Sag(5) 11,527.38 93.33 10.86 4,406.70 4,358.26 4,041.99 4,687.15 6,020,095.75 573,971.13 1.22 6,143.70 2_MWD+IFR2+MS+Sag(5) 11,591.55 93.33 10.66 4,402.97 4,354.53 4,104.93 4,699.11 6,020,158.79 573,982.50 0.31 6,198.32 2_MWD+IFR2+MS+Sag(5) 11,654.27 93.21 10.82 4,399.39 4,350.95 4,166.45 4,710.78 6,020,220.41 573,993.60 0.32 6,251.69 2_MWD+IFR2+MS+Sag(5) 11,718.27 91.23 11.63 4,396.91 4,348.47 4,229.17 4,723.23 6,020,283.24 574,005.46 3.34 6,306.48 2_MWD+IFR2+MS+Sag(5) 11,782.33 91.35 11.11 4,395.47 4,347.03 4,291.96 4,735.85 6,020,346.14 574,017.50 0.83 6,361.43 2_MWD+IFR2+MS+Sag(5) 11,845.58 91.48 11.71 4,393.91 4,345.47 4,353.94 4,748.36 6,020,408.23 574,029.43 0.97 6,415.71 2_MWD+IFR2+MS+Sag(5) 11,908.77 91.60 12.13 4,392.21 4,343.77 4,415.75 4,761.41 6,020,470.14 574,041.90 0.69 6,470.22 2_MWD+IFR2+MS+Sag(5) 11,971.59 90.36 11.23 4,391.14 4,342.70 4,477.25 4,774.12 6,020,531.76 574,054.04 2.44 6,524.29 2 MWD+IFR2+MS+Sag(5) 12,035.32 90.24 11.01 4,390.80 4,342.36 4,539.79 4,786.42 6,020,594.40 574,065.75 0.39 6,578.83 2_MWD+IFR2+MS+Sag (5) 12,098.87 90.12 11.77 4,390.60 4,342.16 4,602.08 4,798.97 6,020,656.81 574,077.72 1.21 6,633.37 2_MWD+IFR2+MS+Sag(5) 12,162.58 90.74 11.50 4,390.13 4,341.69 4,664.48 4,811.81 6,020,719.32 574,089.99 1.06 6,688.19 2_MWD+IFR2+MS+Sag (5) 12,224.71 90.74 10.15 4,389.32 4,340.88 4,725.50 4,823.48 6,020,780.43 574,101.08 2.17 6,741.19 2_MWD+IFR2+MS+Sag (5) 12,287.70 88.63 9.67 4,389.67 4,341.23 4,787.55 4,834.32 6,020,842.57 574,111.35 3.44 6,794.39 2_MWD+IFR2+MS+Sag (5) 12,353.29 87.40 10.32 4,391.94 4,343.50 4,852.10 4,845.70 6,020,907.22 574,122.12 2.12 6,849.81 2_MWD+IFR2+MS+Sag (5) 12,417.02 86.97 10.08 4,395.07 4,346.63 4,914.75 4,856.97 6,020,969.97 574,132.81 0.77 6,903.75 2_MWD+IFR2+MS+Sag (5) 12,479.99 88.02 9.95 4,397.82 4,349.38 4,976.70 4,867.91 6,021,032.01 574,143.17 1.68 6,956.95 2_MWD+IFR2+MS+Sag (5) 12,544.51 87.65 9.85 4,400.26 4,351.82 5,040.21 4,879.00 6,021,095.62 574,153.66 0.59 7,011.41 2_MWD+IFR2+MS+Sag (5) 12,608.08 88.02 9.97 4,402.66 4,354.22 5,102.79 4,889.93 6,021,158.29 574,164.01 0.61 7,065.07 2_MWD+IFR2+MS+Sag(5) 12,671.57 88.27 10.09 4,404.72 4,356.28 5,165.27 4,900.98 6,021,220.87 574,174.48 0.44 7,118.74 2_MWD+IFR2+MS+Sag(5) 12,734.90 87.71 10.25 4,406.94 4,358.50 5,227.57 4,912.15 6,021,283.26 574,185.07 0.92 7,172.35 2_MWD+IFR2+MS+Sag (5) 12,799.52 88.58 10.47 4,409.03 4,360.59 5,291.10 4,923.77 6,021,346.89 574,196.10 1.39 7,227.18 2_MWD+IFR2+MS+Sag(5) 12,831.29 88.64 10.86 4,409.80 4,361.36 5,322.32 4,929.65 6,021,378.15 574,201.68 1.24 7,254.23 2_MWD+IFR2+MS+Sag (5) 12,900.00 88.64 10.86 4,411.43 4,362.99 5,389.78 4,942.59 6,021,445.73 574,214.00 0.00 7,312.85 PROJECTED to TD Checked By: Chelsea Wright ---.=Z--- Approved By: Mitch Laird Date: 05-09-2019 5492019 4:23:14PM Page 7 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-40PB1 500292362670 Sperry Drilling Definitive Survey Report 09 May, 2019 HALLIBURTON Sporry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E40 Project: Milne Point TVD Reference: MPU E40 Actual IRKS @ 48.44usft Site: M Pt E Pad MD Reference: MPU E-40 Actual RKB @ 48.44usft Well: MPU E-40 North Reference: True Wellbore: MPU E-40PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-40PB1 Database: NORTH US + CANADA Project 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-40 Well Position +N/S +EI -W Position Uncertainty Wellbore MPU E-40PB1 Magnetics Model Name 0.00 usft Northing: 6,016,010.71 usfl 0.00 usft Easting: 569,322.23 usfl 0.00 usft Wellhead Elevation: 0.00 usfl Sample Date Declination M BGGM2018 4/1/2019 16.77 Design MPU E-40PB1 +EI -W Audit Notes: (usft) V) Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/ -S TVDSS (usft) (usft) Northing 26.84 0.00 Latitude: 70° 27' 14.7492 N Longitude: 149° 26'3.5298 W Ground Level: 21.60 usft Dip Angle Field Strength (") (nT) 80.97 57,434.24620471 Tie On Depth: 26.84 +EI -W Direction (usft) V) 0.00 42.27 Survey Program Date 5/6/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 481.00 MPU E-40PB1 Gyro (MPU E-40PB1) 2_Gyro-NS-GC_Drill coll; H029Ga: North seeking single shot in drill colla 04/09/2019 546.47 6,952.03 MPU E-40PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 04/17/2019 7,020.67 7,780.20 MPU E-40PB1 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 04/30/2019 7,843.20 7,843.20 MPU E-40PB1 MWD_Interp Azi+Sag (1) 2_MWD_Interp Azi+Sag H003Mb: Interpolated azimuth +sag correctior 04/30/2019 7,906.85 9,302.38 MPU E-00PB1 MWD+IFR2+MS+Sag (3) 2_MWD+IFR2+MS+Sag A0131\4b: IIFR dec & multi -station analysis +as 04/30/2019 Survey Map Vertical Easting DLS Section (ft) Map MD Inc Azi TVD TVDSS +NIS +E/ -W Northing (usft) (') (1) (usft) (usft) (usft) (usft) (ft) 26.84 0.00 0.00 26.84 -21.60 0.00 0.00 6,016,010.71 100.00 0.44 238.32 100.00 51.56 -0.15 -0.24 6,016,010.56 16900 0.61 232.25 169.00 120.56 -0.51 -0.75 6,016,010.19 231.00 1.17 236.99 230.99 182.55 -1.06 -1.55 6,016,009.64 294.00 2.37 245.13 293.96 245.52 -1.96 -3.27 6,016,008.72 356.00 3.76 230.49 355.87 307.43 -3.79 -6.00 6,016,006.87 419.00 4.70 222.50 418.70 370.26 -7.01 -9.34 6,016,003.62 481.00 6.23 210.06 480.41 431.97 -11.79 -12.74 6,015,998.80 546.47 8.07 191.03 545.38 496.94 -19.38 -15.40 6,015,991.19 609.19 9.33 178.74 607.38 558.94 -28.78 -16.13 6,015,981.78 Map Vertical Easting DLS Section (ft) (°1100') (ft) Survey Tool Name 569,322.23 0.00 0.00 UNDEFINED 569,321.99 0.60 -0.27 2_Gyro-NS-GC_Dnll collar (1 569,321.48 0.26 -0.89 2_Gyro-NS-GC_Drill collar (1 569,320.69 0.91 -1.82 2_Gyro-NS-GC_Drill collar (1 569,318.98 1.94 -3.65 2_Gyro-NS-GC_Drill collar (1 569,316.27 2.56 -6.84 2_Gyro-NS-GC_D411 collar (1 569,312.96 1.76 -11.47 2_Gyro-NS-GC_Drill collar (1 569,309.60 3.11 -17.29 2_Gyro-NS-GC_Drill collar (1 569,307.01 4.54 -24.70 2_MWD+IFR2+MS+Sag(2) 569,306.37 3.57 -32.15 2_MWD+IFR2+MS+Sag(2) 5192019 4:25: 48PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-40 Project: Milne Point TVD Reference: MPU E-40 Actual RKB @ 48.44usft Site: M Pt E Pad MD Reference: MPU E-40 Actual RKB @ 48.44usft Well: MPU E-40 North Reference: True Wellbore: MPU E-40PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-40PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (-1100-) (ft) Survey Tool Name 671.81 11.17 163.57 669.01 620.57 -39.68 -14.30 6,015,970.90 569,308.30 5.19 -38.98 2_MWD+IFR2+MS+Sag (2) 735.63 12.75 150.98 731.46 683.02 -51.77 -9.13 6,015,958.86 569,313.58 4.77 -44.45 2_MWD+IFR2+MS+Sag (2) 799.97 16.03 145.00 793.77 745.33 -65.26 -0.59 6,015,945.45 569,322.24 5.59 48.69 2_MWD+IFR2+MS+Sag (2) 862.51 18.30 142.46 853.52 805.08 -80.12 10.34 6,015,930.70 569,333.32 3.82 -52.33 2 MWD+IFR2+MS+Sag (2) 926.58 21.28 142.61 913.80 865.36 -97.34 23.54 6,015,913.61 569,346.67 4.65 -56.20 2_MWD+IFR2+MS+Sag (2) 989.00 22.85 139.98 971.65 923.21 -115.62 38.21 6,015,895.46 569,361.51 2.97 -59.86 2_MWD+IFR2+MS+Sag (2) 1,052.06 24.54 137.94 1,029.39 980.95 -134.72 54.86 6,015,876.52 569,378.33 2.98 -62.79 2_MWD+IFR2+MS+Sag (2) 1,118.12 26.70 138.02 1,088.96 1,040.52 -155.94 73.98 6,015,855.48 569,397.65 3.27 -65.64 2_MWD+IFR2+MS+Sag (2) 1,182.08 30.12 138.24 1,145.20 1,096.76 -178.60 94.28 6,015,833.01 569,418.16 5.35 -68.74 2_MWD+IFR2+MS+Sag (2) 1,245.82 33.78 137.60 1,199.28 1,150.84 -203.62 116.89 6,015,808.20 569,441.00 5.77 -72.06 2_MWD+IFR2+MS+Sag (2) 1,307.04 36.32 137.49 1,249.39 1,200.95 -229.56 140.62 6,015,782.49 569,464.97 4.15 -75.29 2_MWD+IFR2+MS+Sag (2) 1,372.74 38.22 135.23 1,301.68 1,253.24 -258.34 168.08 6,015,753.97 569,492.69 3.56 -78.11 2_MWD+IFR2+MS+Sag (2) 1,436.68 40.31 134.76 1,351.18 1,302.74 -286.94 196.70 6,015,725.64 569,521.58 3.30 -80.03 2_MWD+IFR2+MS+Sag (2) 1,499.71 42.60 132.72 1,398.42 1,349.98 -315.78 226.86 6,015,697.09 569,551.99 4.22 -81.08 2_MWD+IFR2+MS+Sag (2) 1,562.41 45.12 131.86 1,443.62 1,395.18 -345.00 259.00 6,015,668.17 569,58440 4.13 -81.09 2_MWD+IFR2+MS+Sag(2) 1,624.13 46.90 131.24 1,486.49 1,438.05 -374.45 292.23 6,015,639.03 569,617.90 2.97 -80.53 2_MWD+IFR2+MS+Sag (2) 1,689.00 48.07 131.92 1,530.33 1,481.89 -406.18 327.99 6,015,607.63 569,653.96 1.96 -79.95 2_MWD+IFR2+MS+Sag (2) 1,751.92 47.81 132.94 1,572.48 1,524.04 437.70 362.47 6,015,576.44 569,688.73 1.27 -80.08 2_MWD+IFR2+MS+Sag (2) 1,815.35 48.90 132.48 1,614.63 1,566.19 469.85 397.30 6,015,544.62 569,723.85 1.80 -80.44 2_MWD+IFR2+MS+Sag (2) 1,878.29 48.77 132.67 1,656.06 1,607.62 -501.91 432.20 6,015,512.89 569,759.04 0.31 -80.70 2_MWD+IFR2+MS+Sag(2) 1,942.13 47.82 133.09 1,698.53 1,650.09 -534.34 467.12 6,015,480.79 569,794.26 1.57 -81.20 2_MWD+IFR2+MS+Sag(2) 2,003.53 46.93 131.28 1,740.11 1,691.67 -564.68 500.59 6,015,450.77 569,828.01 2.61 -81.14 2_MWD+IFR2+MS+Sag(2) 2,068.09 47.56 132.83 1,783.94 1,735.50 -596.43 535.78 6,015,419.35 569,863.49 2.01 -80.97 2_MWD+IFR2+MS+Sag(2) 2,131.91 46.39 131.43 1,827.48 1,779.04 -627.73 570.38 6,015,388.37 569,898.37 2.44 -80.86 2_MWD+IFR2+MS+Sag(2) 2,195.13 47.74 133.54 1,870.55 1,822.11 -658.99 604.50 6,015,357.43 569,932.78 3.24 -81.04 2_MWD+IFR2+MS+Sag(2) 2,258.44 49.77 132.77 1,912.29 1,863.85 -691.55 639.23 6,015,325.21 569,967.81 3.33 -81.77 2_MWD+IFR2+MS+Sag(2) 2,321.14 48.00 131.53 1,953.51 1,905.07 -723.25 674.24 6,015,293.83 570,003.11 3.19 -81.68 2_MWD+IFR2+MS+Sag(2) 2,385.46 50.80 132.51 1,995.37 1,946.93 -755.94 710.51 6,015,261.48 570,039.68 4.50 -81.47 2_MWD+IFR2+MS+Sag(2) 2,449.67 51.27 134.04 2,035.75 1,987.31 -790.17 746.86 6,015,227.60 570,076.34 1.99 -82.35 2 MWD+IFR2+MS+Sag(2) 2,513.41 51.35 132.92 2,075.59 2,027.15 -824.40 782.96 6,015,193.71 570,112.75 1.38 -83.40 2_MWD+IFR2+MS+Sag(2) 2,577.28 49.65 134,26 2,116.22 2,067.78 -858.37 818.66 6,015,160.07 570,148.76 3.12 -84.53 2_MWD+IFR2+MS+Sag(2) 2,640.70 49.13 134.22 2,157.50 2,109.06 -891.96 853.15 6,015,126.81 570,183.56 0.82 -86.19 2_MWD+IFR2+MS+Sa9(2) 2,704.29 49.18 134.93 2,199.09 2,150.65 -925.72 887.42 6,015,093.37 570,218.14 0.85 -88.12 2_MWD+IFR2+MS+Sag (2) 2,767.91 48.02 134.28 2,241.16 2,192.72 -959.23 921.39 6,015,060.18 570,252.42 1.98 -90.07 2_MWD+IFR2+MS+Sag (2) 2,831.09 47.21 134.56 2,283.75 2,235.31 -991.90 954.72 6,015,027.83 570,286.05 1.32 -91.82 2_MWD+IFR2+MS+Sag (2) 2,892.55 49.58 132.56 2,324.56 2,276.12 -1,023.55 988.03 6,014,996.49 570,319.64 4.56 -92.84 2_MWD+IFR2+MS+Sag (2) 2,957.86 49.81 132.85 2,366.81 2,318.37 -1,057.33 1,024.63 6,014,963.06 570,356.55 0.49 -93.22 2_MWD+IFR2+MS+Sag (2) 3,020.88 49.22 132.07 2,407.72 2,359.28 -1,089.69 1,059.99 6,014,931.03 570,392.21 1.33 -93.38 2_MWD+IFR2+MS+Sag(2) 3,084.20 49.08 133.80 2,449.14 2,400.70 -1,122.31 1,095.05 6,014,898.74 570,427.57 2.08 -93.93 2_MWD+IFR2+MS+Sag(2) 3,147.39 48.75 133.91 2,490.67 2,442.23 -1,155.31 1,129.40 6,014,866.07 570,462.22 0.54 -95.25 2_MWD+IFR2+MS+Sag(2) 5/92019 4: 2548P Page 3 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-40 Wellbore: MPU E-40PB1 Design: MPU E-40PB1 Survey Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +NIS +El -W Northing (usft) (1) 0 (usft) (usft) (usft) (usft) (ft) 3,210.35 49.02 131.22 2,532.07 2,483.63 -1,187.39 1,164.33 6,014,834.32 3,273.76 48.64 130.94 2,573.81 2,525.37 .1,218.75 1,200.31 6,014,803.29 3,336.76 48.70 130.31 2,615.43 2,566.99 -1,249.56 1,236.23 6,014,772.82 3,400.12 48.20 131.17 2,657.44 2,609.00 -1,280.50 1,272.14 6,014,742.22 3,463.44 48.91 132.06 2,699.36 2,650.92 -1,312.02 1,307.62 6,014,711.03 3,525.33 48.83 130.54 2,740.07 2,691.63 -1,342.79 1,342.64 6,014,680.60 3,591.55 48.66 132.32 2,783.74 2,735.30 -1,375.73 1,379.97 6,014,648.01 3,654.54 49.63 130.95 2,824.94 2,776.50 A.407.37 1,415.58 6,014,616.70 3,718.06 48.14 132.09 2,866.71 2,818.27 -1,439.09 1,451.41 6,014,585.32 3,781.62 50.01 131.90 2,908.34 2,859.90 -1,471.22 1,487.10 6,014,553.53 3,844.87 49.56 131.84 2,949.18 2,900.74 -1,503.46 1,523.07 6,014,521.63 3,905.93 47.95 132.30 2,989.44 2,941.00 -1,534.22 1,557.15 6,014,491.19 3,972.67 47.36 130.15 3,034.39 2,985.95 -1,566.72 1,594.24 6,014,459.03 4,035.23 46.05 128.58 3,077.30 3,028.86 -1,595.61 1,629.44 6,014,430.48 4,100.57 45.38 125.65 3,122.92 3,074.48 -1,623.83 1,666.72 6,014,402.61 4,162.98 45.48 121.85 3,166.73 3,118.29 -1,648.52 1,703.68 6,014,378.27 4,228.29 45.74 115.54 3,212.44 3,164.00 -1,670.90 1,744.58 6,014,356.27 4,291.44 46.43 113.71 3,256.24 3,207.80 A.689.85 1,785.93 6,014,337.71 4,354.68 46.03 110.78 3,299.99 3,251.55 -1,707.14 1,828.19 6,014,320.81 4,418.20 46.10 105.83 3,344.08 3,295.64 -1,721.50 1,871.59 6,014,306.86 4,481.86 47.47 100.75 3,387.68 3,339.24 -1,732.13 1,916.72 6,014,296.65 4,545.47 47.51 97.23 3,430.67 3,382.23 -1,739.46 1,963.02 6,014,289.76 4,608.82 47.94 93.27 3,473.30 3,424.86 -1,743.74 2,009.68 6,014,285.91 4,672.00 47.33 89.26 3,515.88 3,467.44 -1,744.78 2,056.33 6,014,285.30 4,735.24 47.16 85.03 3,558.82 3,510.38 -1,742.47 2,102.69 6,014,288.04 4,799.00 47.69 80.69 3,601.97 3,553.53 -1,736.63 2,149.25 6,014,294.32 4,861.72 47.03 77.69 3,644.46 3,596.02 -1,727.98 2,194.56 6,014,303.38 4,926.35 46.42 74.85 3,688.77 3,640.33 -1,716.82 2,240.27 6,014,314.97 4,990.14 47.66 71.77 3,732.25 3,683.81 -1,703.41 2,284.97 6,014,328.80 5,053.19 49.72 68.75 3,773.87 3,725.43 -1,687.39 2,329.53 6,014,345.22 5,115.69 51.53 64.48 3,813.53 3,765.09 -1,668.21 2,373.84 6,014,364.82 5,180.32 53.18 63.31 3,853.00 3,804.56 -1,645.68 2,419.79 6,014,387.76 5,243.68 53.57 61.61 3,890.81 3,842.37 -1,622.17 2,464.87 6,014,411.69 5,307.70 55.35 58.35 3,928.02 3,879.58 -1,596.10 2,509.96 6,014,438.18 5,370.47 56.85 56.68 3,963.03 3,914.59 -1,568.12 2,553.90 6,014,466.57 5,434.52 58.41 53.70 3,997.33 3,948.89 -1,537.23 2,598.30 6,014,497.86 5,497.95 59.22 51.31 4,030.18 3,981.74 -1,504.20 2,641.35 6,014,531.29 5,561.32 60.40 48.51 4,062.05 4,013.61 -1,468.93 2,683.24 6.014.566,95 5,617.45 61.22 44.72 4,089.43 4,040.99 -1,435.27 2,718.84 6,014,600.93 5,681.69 61.22 40.75 4,120.37 4,071.93 -1,393.93 2,757.03 6,014,642.62 Well MPU E-40 MPU E-40 Actual RKB @ 48.44usft MPU E40 Actual RKB @ 48.44usft True Minimum Curvature NORTH US + CANADA Map Easting DLS (ft) (°I700-) 570,497.44 3.25 570,533.71 O69 570,569.91 0.76 570,606.11 1.29 570,641.88 1.54 570,677.18 1.85 570,714.81 2.04 570,750.70 2.25 570,786.83 2.71 5701822.81 2.95 570,859.07 570,893.43 570,930.83 570,966.29 571,003.83 571,041.01 571,082.11 571,123.64 571,166.05 571,209.58 571,254.80 571,301.16 571,347.85 571,394.51 571,440.84 571,487.34 571,532.57 571,578.16 571,622.73 571,667.13 571,711.26 571,757.00 571,801.86 571,846.69 571,890.37 571,934.47 571,977.21 572,018.76 572,054.04 572,091.85 0.72 2.70 2.54 2.78 3.37 4.34 6.91 2.36 3.40 5.61 6.20 4.08 4.67 4.79 4.92 5.08 3.67 3.34 4.03 4.86 6.02 2.93 2.24 4.99 3.25 4.62 3.47 4.25 6.07 5.42 Vertical Section (ft) Survey Tool Name -95.49 2_MWD+IFR2+MS+Sag(2) -94.50 2_MWD+IFR2+MS+Sag (2) -93.14 2_MWD+IFR2+MS+Sag(2) -91.87 2 MWD+IFR2+MS+Sag (2) -91.33 2_MWD+IFR2+MS+Sag (2) -90.54 2 MWD+IFR2+MS+Sag(2) -89.81 2 MWD+IFR2+MS+Sag(2) -89.28 2_MWD+IFR2+MS+Sag(2) -88.65 2_MWD+IFR2+MS+Sag (2) .88.42 2_MWD+IFR2+MS+Sag (2) -88.08 2_MWD+IFR2+MS+Sag (2) -87.92 2 MWD+IFR2+MS+Sag (2) -87.02 2 MWD+IFR2+MS+Sag(2) -84.72 2_MWD+IFR2+MS+Sag(2) -80.53 2_MWD+IFR2+MS+Sag(2) -73.94 2_MWD+IFR2+MS+Sag(2) -62.99 2_MWD+IFR2+MS+Sag (2) -49.20 2 MWD+IFR2+MS+Sag (2) -33.57 2_MWD+IFR2+MS+Sag (2) -15.00 2 MWD+IFR2+MS+Sag (2) 7.48 2_MWD+IFR2+MS+Sag (2) 33.21 2_MWD+IFR2+MS+Sag (2) 61.42 2_MWD+IFR2+MS+Sag(2) 92.03 2_MWD+IFR2+MS+Sag(2) 124.92 2_MWD+IFR2+MS+Sag (2) 160.57 2 MWD+IFR2+MS+Sag (2) 197.44 2_MWD+IFR2+MS+Sag (2) 236.44 2 MWD+IFR2+MS+Sag (2) 276.44 2_MWD+IFR2+MS+Sag (2) 318.25 2_MWD+IFR2+MS+Sag(2) 362.26 2_MWD+IFR2+MS+Sag (2) 409.83 2_MWD+IFR2+MS+Sag (2) 457.56 2 MWD+IFR2+MS+Sag (2) 507.17 2_MWD+IFR2+MS+Sag (2) 557.44 2_MWD+IFR2+MS+Sag (2) 610.16 2_MWO+IFR2+MS+Sag(2) 663.55 2_MWD+IFR2+MS+Sag(2) 717.83 2 MWD+IFR2+MS+Sag(2) 766.68 2_MWD+IFR2+MS+Sag (2) 822.97 2 MWD+IFR2+MS+Sag(2) 5/92019 4.25.48PM Page 4 COMPASS 5000.15 Build 91 552019 4:25:48PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-40 Project: Milne Point TVD Reference: MPU E-40 Actual RKB @ 48.44usft Site: M Pt E Pad MD Reference: MPU E-40 Actual RKB @ 48.44usft Well: MPU E-40 North Reference: True Wellbore: MPU E-40PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-40PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 5,745.43 62.16 36.72 4,150.61 4,102.17 -1,350.16 2,792.13 6,014,686.71 572,126.54 5.76 878.96 2_MWD+IFR2+MS+Sag(2) 5,809.07 62.44 33.43 4,180.19 4,131.75 -1,304.06 2,824.50 6,014,733.11 572,158.47 4.60 934.85 2_MWD+IFR2+MS+Sag(2) 5,872.48 64.91 32.78 4,208.31 4,159.87 -1,256.45 2,855.54 6,014,781.00 572,189.06 4.00 990.95 2_MWD+IFR2+MS+Sag(2) 5,935.87 66.25 32.36 4,234.52 4,186.08 -1,207.81 2,886.61 6,014,829.92 572,219.68 2.20 1,047.84 2_MWD+IFR2+MS+Sag (2) 6,000.17 70.12 29.59 4,258.41 4,209.97 -1,156.64 2,917.30 6,014,881.37 572,249.89 7.23 1,106.36 2_MWD+IFR2+MS+Sag (2) 6,064.46 74.20 26.61 4,278.11 4,229.67 -1,102.66 2,946.10 6,014,935.61 572,278.18 7.73 1,165.67 2_MWD+IFR2+MS+Sag (2) 6,127.79 76.59 25.37 4,294.08 4,245.64 -1,047.58 2,972.95 6,014,990.93 572,304.52 4.22 1,224.49 2_MWD+IFR2+MS+Sag(2) 6,189.79 79.66 23.06 4,306.84 4,258.40 -992.25 2,997.83 6,015,046.49 572,328.87 6.15 1,282.16 2_MWD+IFR2+MS+Sag (2) 6,254.93 79.06 22.89 4,318.86 4,270.42 -933.31 3,022.82 6,015,105.65 572,353.31 0.96 1,342.59 2_MWD+IFR2+MS+Sag (2) 6,318.24 81.54 2221 4,329.53 4,281.09 -875.68 3,046.74 6,015,163.50 572,376.70 4.06 1,401.33 2_MWD+IFR2+MS+Sag (2) 6,381.93 83.16 21.58 4,338.01 4,289.57 -817.11 3,070.28 6,015,222.27 572,399.69 2.73 1,460.50 2_MWD+IFR2+MS+Sag (2) 6,445.55 82.79 21.59 4,345.79 4,297.35 -758.40 3,093.51 6,015,281.20 572,422.37 0.58 1,519.57 2_MWD+IFR2+MS+Sag (2) 6,508.42 82.54 21.86 4,353.82 4,305.38 -700.47 3,116.59 6,015,339.33 572,444.91 0.58 1,577.96 2_MWD+IFR2+MS+Sag (2) 6,571.82 82.69 21.96 4,361.96 4,313.52 -642.14 3,140.05 6,015,397.87 572,467.82 0.28 1,636.91 2_MWD+IFR2+MS+Sag(2) 6,635.24 83.20 21.01 4,369.75 4,321.31 -583.57 3,163.10 6,015,456.64 572,490.33 1.69 1,695.75 2_MWD+IFR2+MS+Sag(2) 6,698.84 83.19 22.00 4,377.29 4,328.85 -524.82 3,186.25 6,015,515.61 572,512.93 1.55 1,754.80 2_MWD+IFR2+MS+Sag(2) 6,762.55 85.94 20.45 4,383.32 4,334.88 -465.70 3,209.21 6,015,574.93 572,535.33 4.95 1,813.98 2_MWD+IFR2+MS+Sag(2) 6,826.34 85.18 20.34 4,388.26 4,339.82 -406.09 3,231.37 6,015,634.74 572,556.94 1.20 1,873.00 2_MWD+IFR2+MS+Sag(2) 6,890.21 87.60 21.01 4,392.28 4,343.84 -346.46 3,253.88 6,015,694.57 572,578.88 3.93 1,932.27 2_MWD+IFR2+MS+Sag (2) 6,952.03 90.45 21.52 4,393.34 4,344.90 -288.86 3,276.29 6,015,752.37 572,600.76 4.68 1,989.96 2_MWD+IFR2+MS+Sag (2) 7,020.67 90.50 20.86 4,392.77 4,344.33 -224.87 3,301.10 6,015,816.59 572,624.97 0.96 2,054.01 2_MWD+IFR2+MS+Sag (3) 7,082.38 91.73 20.89 4,391.57 4,343.13 -167.22 3,323.09 6,015,874.43 572,646.42 1.99 2,111.45 2_MWD+IFR2+MS+Sag (3) 7,145.60 91.98 19.83 4,389.52 4,341.08 -107.98 3,345.07 6,015,933.86 572,667.85 1.72 2,170.08 2_MWD+IFR2+MS+Sag (3) 7,209.48 90.05 19.61 4,388.39 4,339.95 47.86 3,366.62 6,015,994.18 572,688.83 3.04 2,229.06 2_MWD+IFR2+MS+Sa9 (3) 7,273.35 89.93 20.38 4,388.40 4,339.96 12.16 3,388.46 6,016,054.39 572,710.11 1.22 2,288.16 2_MWD+IFR2+MS+Sag (3) 7,336.56 89.87 20.19 4,388.51 4,340.07 71.45 3,410.38 6,016,113.88 572,731.47 0.32 2,346.78 2_MWD+IFR2+MS+Sag (3) 7,399.39 90.18 20.28 4,388.48 4,340.04 130.40 3,432.11 6,016,173.02 572,752.65 0.51 2,405.02 2_MWD+IFR2+MS+Sag(3) 7,462.64 89.62 20.13 4,388.59 4,340.15 189.76 3,453.95 6,016,232.58 572,773.94 0.92 2,463.63 2_MWD+IFR2+MS+Sag (3) 7,526.22 89.44 21.27 4,389.11 4,340.67 249.23 3,476.42 6,016,292.25 572,795.86 1.82 2,522.76 2_MWD+IFR2+MS+Sag(3) 7,589.41 90.00 20.53 4,389.42 4,340.98 308.26 3,498.97 6,016,351.48 572,817.85 1.47 2,581.60 2_MWD+IFR2+MS+Sag (3) 7,653.04 89.13 20.69 4,389.91 4,341.47 367.82 3,521.36 6,016,411.24 572,839.69 1.39 2,640.74 2_MWD+IFR2+MS+Sag (3) 7,716.23 89.57 21.02 4,390.62 4,342.18 426.86 3,543.86 6,016,470.48 572,861.63 0.87 2,699.56 2_MWD+IFR2+MS+Sag (3) 7,780.20 89.75 21.51 4,391.00 4,342.56 486.48 3,567.06 6,016,530.31 572,884.27 0.82 2,759.28 2_MWD+IFR2+MS+Sag(3) 7,843.20 89.38 21.63 4,391.48 4,343.04 545.06 3,590.22 6,016,589.10 572,906.88 0.62 2,818.21 2_ MWD_Interp Azi+Sag(4) 7,906.85 90.25 21.75 4,391.69 4,343.25 604.21 3,613.74 6,016,648.45 572,929.85 1.38 2,877.80 2_MWD+IFR2+MS+Sag (5) 7,97005 91.79 22.25 4,390.56 4,342.12 662.79 3,637.41 6,016,707.25 572,952.98 2.56 2,937.07 2_MWD+IFR2+MS+Sag(5) 8,034.04 92.59 21.83 4,388.12 4,339.68 722.06 3,661.41 6,016,766.74 572,976.42 1.41 2,997.07 2_MWD+IFR2+MS+Sag(5) 8,097.52 92.59 21.65 4,385.25 4,336.81 780.97 3,684.90 6,016,825.85 572,999.35 0.28 3,056.46 2 MWD+IFR2+MS+Sag(5) 8,161.18 91.91 21.00 4,382.75 4,334.31 840.22 3,708.03 6,016,885.31 573,021.93 1.48 3,115.86 2_MWD+IFR2+MS+Sag(5) 8,225.54 91.85 20.55 4,380.64 4,332.20 900.37 3,730.84 6,016,945.66 573,044.18 0.71 3,175.72 2_MWD+IFR2+MS+Sag(5) 552019 4:25:48PM Page 5 COMPASS 5000.15 Build 91 Survey Map MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing lush) (°) (°) (usft) (usft) (usft) (usft) (ft) 8,288.80 91.35 20.18 4,378.87 4,330.43 959.65 3,752.85 6,017,005.14 8,351.46 90.67 20.29 4,377.77 4,329.33 1,018.43 3,774.52 6,017,064.12 8,414.01 88.70 20.18 4,378.11 4,329.67 1,077.12 3,796.15 6,017,122.99 8,477.14 87.28 19.71 4,380.32 4,331.88 1,136.42 3,817.67 6,017,182.49 8,540.94 88.33 21.70 4,382.77 4,334.33 1,196.05 3,840.21 6,017,242.33 8,604.39 88.58 20.44 4,384.48 4,336.04 1,255.24 3,863.01 6,017,301.71 8,667.33 88.20 20.73 4,386.25 4,337.81 1,314.14 3,885.14 6,017,360.81 8,730.53 87.96 21.56 4,388.36 4,339.92 1,373.05 3,907.92 6,017,419.93 8,793.30 88.52 21.98 4,390.29 4,341.85 1,431.31 3,931.19 6,017,478.40 8,857.30 86.91 21.46 4,392.84 4,344.40 1,490.72 3,954.85 6,017,538.02 8,920.69 85.61 21.78 4,396.98 4,348.54 1,549.52 3,978.16 6,017,597.03 8,983.43 84.86 22.33 4,402.19 4,353.75 1,607.47 4,001.64 6,017,655.19 9,047.85 85.18 22.44 4,407.78 4,359.34 1,666.81 4,026.08 6,017,714.75 9,110.87 85.18 22.18 4,413.08 4,364.64 1,724.91 4,049.92 6,017,773.06 9,175.69 85.36 21.82 4,418.42 4,369.98 1,784.80 4,074.12 6,017,833.17 9,238.95 85.67 22.35 4,423.37 4,374.93 1,843.24 4,097.83 6,017,891.82 9,302.38 85.49 22.84 4,428.26 4,379.82 1,901.63 4,122.12 6,017,950.43 9,421.00 85.49 22.84 4,437.59 4,389.15 2,010.61 4,168.03 6,018,059.82 Map Vertical East(ng DIS Section (R) (°1100') (ft) Survey Tool Name 573,065.64 0.98 3,234.38 2_MWD+IFR2+MS+Sag (5) 573,086.75 1.10 3,292.46 2_MWD+IFR2+MS+Sag (5) 573,107.84 3.15 3,350.44 2_MWD+IFR2+MS+Sag(5) 573,128.80 2.37 3,408.80 2_MWD+IFR2+MS+Sag (5) 573,150.79 3.52 3,468.08 2_MWD+IFR2+MS+Sag (5) 573,173.03 2.02 3,527.22 2_MWD+IFR2+MS+Sag(5) 573,194.60 0.76 3,585.68 2_MWD+IFR2+MS+Sag(5) 573,216.84 1.37 3,644.60 2_MWD+IFR2+MS+Sag(5) 573,239.56 1.11 3,703.36 2_MWD+IFR2+MS+Sag(5) 573,262.67 2.64 3,763.24 2_MWD+IFR2+MS+Sag(5) 573,285.43 2.11 3,822.43 2_MWD+IFR2+MS+Sag (5) 573,308.36 1.48 3,881.10 2_MWD+IFR2+MS+Sag (5) 573,332.25 0.53 3,941.45 2_MWD+IFR2+MS+Sag (5) 573,355.54 0.41 4,000.48 2_MWD+IFR2+MS+Sag (5) 573,379.18 0.62 4,061.08 2_MWD+IFR2+MS+Sag(5) 573,402.34 0.97 4,120.27 2_MWD+IFR2+MS+Sag(5) 573,426.10 0.82 4,179.82 2_MWD+IFR2+MS+Sag (5) 573,470.98 0.00 4,291.34 PROJECTEDto TD Checked By: Chelsea Wright ° w m.. Approved By: Mitch Laird -- Date: 05-09-2019 592019 4:25:46PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E40 Project: Milne Point TVD Reference: MPU E40 Actual RKB @ 48.44usft Site: M Pt E Pad MD Reference: MPU E-40 Actual RKB @ 48.44usft Well: MPU E-40 North Reference: True Wellbore: MPU E-40PB1 Survey Calculation Method: Minimum Curvature Design: MPU E40PB1 Database: NORTH US+CANADA Survey Map MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing lush) (°) (°) (usft) (usft) (usft) (usft) (ft) 8,288.80 91.35 20.18 4,378.87 4,330.43 959.65 3,752.85 6,017,005.14 8,351.46 90.67 20.29 4,377.77 4,329.33 1,018.43 3,774.52 6,017,064.12 8,414.01 88.70 20.18 4,378.11 4,329.67 1,077.12 3,796.15 6,017,122.99 8,477.14 87.28 19.71 4,380.32 4,331.88 1,136.42 3,817.67 6,017,182.49 8,540.94 88.33 21.70 4,382.77 4,334.33 1,196.05 3,840.21 6,017,242.33 8,604.39 88.58 20.44 4,384.48 4,336.04 1,255.24 3,863.01 6,017,301.71 8,667.33 88.20 20.73 4,386.25 4,337.81 1,314.14 3,885.14 6,017,360.81 8,730.53 87.96 21.56 4,388.36 4,339.92 1,373.05 3,907.92 6,017,419.93 8,793.30 88.52 21.98 4,390.29 4,341.85 1,431.31 3,931.19 6,017,478.40 8,857.30 86.91 21.46 4,392.84 4,344.40 1,490.72 3,954.85 6,017,538.02 8,920.69 85.61 21.78 4,396.98 4,348.54 1,549.52 3,978.16 6,017,597.03 8,983.43 84.86 22.33 4,402.19 4,353.75 1,607.47 4,001.64 6,017,655.19 9,047.85 85.18 22.44 4,407.78 4,359.34 1,666.81 4,026.08 6,017,714.75 9,110.87 85.18 22.18 4,413.08 4,364.64 1,724.91 4,049.92 6,017,773.06 9,175.69 85.36 21.82 4,418.42 4,369.98 1,784.80 4,074.12 6,017,833.17 9,238.95 85.67 22.35 4,423.37 4,374.93 1,843.24 4,097.83 6,017,891.82 9,302.38 85.49 22.84 4,428.26 4,379.82 1,901.63 4,122.12 6,017,950.43 9,421.00 85.49 22.84 4,437.59 4,389.15 2,010.61 4,168.03 6,018,059.82 Map Vertical East(ng DIS Section (R) (°1100') (ft) Survey Tool Name 573,065.64 0.98 3,234.38 2_MWD+IFR2+MS+Sag (5) 573,086.75 1.10 3,292.46 2_MWD+IFR2+MS+Sag (5) 573,107.84 3.15 3,350.44 2_MWD+IFR2+MS+Sag(5) 573,128.80 2.37 3,408.80 2_MWD+IFR2+MS+Sag (5) 573,150.79 3.52 3,468.08 2_MWD+IFR2+MS+Sag (5) 573,173.03 2.02 3,527.22 2_MWD+IFR2+MS+Sag(5) 573,194.60 0.76 3,585.68 2_MWD+IFR2+MS+Sag(5) 573,216.84 1.37 3,644.60 2_MWD+IFR2+MS+Sag(5) 573,239.56 1.11 3,703.36 2_MWD+IFR2+MS+Sag(5) 573,262.67 2.64 3,763.24 2_MWD+IFR2+MS+Sag(5) 573,285.43 2.11 3,822.43 2_MWD+IFR2+MS+Sag (5) 573,308.36 1.48 3,881.10 2_MWD+IFR2+MS+Sag (5) 573,332.25 0.53 3,941.45 2_MWD+IFR2+MS+Sag (5) 573,355.54 0.41 4,000.48 2_MWD+IFR2+MS+Sag (5) 573,379.18 0.62 4,061.08 2_MWD+IFR2+MS+Sag(5) 573,402.34 0.97 4,120.27 2_MWD+IFR2+MS+Sag(5) 573,426.10 0.82 4,179.82 2_MWD+IFR2+MS+Sag (5) 573,470.98 0.00 4,291.34 PROJECTEDto TD Checked By: Chelsea Wright ° w m.. Approved By: Mitch Laird -- Date: 05-09-2019 592019 4:25:46PM Page 6 COMPASS 5000.15 Build 91 Lease 8 Well No. County Hilcorp Energy Company CASING & CEMENTING REPORT MP E40 Dale Run 24 -Apr -19 State Alaska Supv. SBarber /O Amend CASING RECORD Surface � onm Csg Wt. On Hook: Type Float Collar: Standard No. Hrs to Run: 3/ Csg Wt. On Slips: 100,000 Type of Shoe: Standard Casing Crew: Weatherford Rotate Csg Yes No Recip Csg _ Yes No 3 Ft. Min. 9.45 PPG Fluid Description: Spud Liner hanger Info (MakelModel): Liner hanger test pressure: Centralizer Placement: Emergency Liner top Packer?: Floats Held CEMENTING REPORT _Yes X No X Yes No Shoe @ 6984 FC @ 6,901.00 Casing (Or Liner) Detail lush (Spacer) Selling Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top 1 Shoe 95/8 sity (ppg) 12 Volume pumped (BBLs) DWC/C DHE 1.58 6,984.00 6,982.42 2 Casing 95/8 40.0 L-80 DWC/C Tenaris 81.11 6,982.42 6,901.31 1 Float Collar 95/8 Density (ppg) DWC/C Rate(bpm): Volume: 1.29 6,901.31 6,900.02 1 Casing 95/8 40.0 L-80 DWC/C Tenaris 40.48 6,900.02 6,859.54 1 Baffle Adapter 95/8 X No Spacerretums? X Yes DWC/C tent In Place At: 2210 1.47 6,859.54 6,858.07 110 Casing 95/8 40.0 L-80 DWC/C Tenaris 4,258.18 6,858.07 2,599.89 1 Pup 95/8 40.0 L-80 DWC/C 18.34 2,599.89 2,581.55 1 ESC 95/8 40.0 L-80 DWC/C 3.102,581.55 2,578.45 1 Pup 95/8 40.0 L-80 DWC/C 17.60 2,578.45 2,560.85 65 Casing 95/8 40.0 L-80 DWC/C Tenaris 2,560.85 2,560.85 26.40 Csg Wt. On Hook: Type Float Collar: Standard No. Hrs to Run: 3/ Csg Wt. On Slips: 100,000 Type of Shoe: Standard Casing Crew: Weatherford Rotate Csg Yes No Recip Csg _ Yes No 3 Ft. Min. 9.45 PPG Fluid Description: Spud Liner hanger Info (MakelModel): Liner hanger test pressure: Centralizer Placement: Emergency Liner top Packer?: Floats Held CEMENTING REPORT _Yes X No X Yes No Shoe @ 6984 FC @ 6,901.00 Top of Liner lush (Spacer) .. Clean Spacer Density(ppg) 10 Volume pumped (BELS) 55 J Slurry .. Type 141 Sacks: 585 Yield: 2.35 sity (ppg) 12 Volume pumped (BBLs) 247 Mixing / Pumping Rate (bpm): 5 Slurry E Type Al1 Sacks: 400 Yield: 1.16 airy (ppg) 15.8 Volume pumped (BBLs) 82.6 Mixing / Pumping Rale (bpm): 3.8 t Flush (Spacer) Density (ppg) Rate(bpm): Volume: Nacement: Spud Mud Density (ppg) 9A5 Rale (bpm): 6 Volume (actual / calculated): 425.8/420.2 !(psi): 800 Pump used for disp: Rig Bump Plug? X Yes _No Bump press 780 ing Rotated? _Yes X No Reciprocated? _Yes X No % ReT.mduring lob 95 tent returns to surface? _Yes X No Spacerretums? X Yes _No Vol to Surf: tent In Place At: 2210 Date: 4/26/2019 Estimated TOC: 2,581 wd Used To Determine TOC: Returns to Sud Stage Collar@ 2581 Type ES Closure OK yes re0ush(Spacer) Me: Clean Spacer Density(ppg) 10 Volume pumped (BBLs) .ad Slu my Penn L Sacks: 500 Yield: 4.41 ty (ppg) 10.7 Volume pumped (BBLs) 393 Mixing / Pumping Rate (bpm): 4 Murry Type 141 Sacks: 270 Yield: 1.17 try, (ppg) 15.6 Volume pumped (BBLs) 56 Mixing / Pumping Rate (bpm): 2.9 Flush (Spacer) Rate (bpm): Volume: Spud Mud Density (ppg) 9.4 Rate (bpm): 3.5 Volume (actual / calculated): 17' (psi): 624 Pump used for disp: Rig Bump Plug? X Yes _No Bump press ig Rotated? _Yes X No Reciprocated? _Yes X No % Returns during job ti ant returns to surface? X Yes m _No Spacer retus?_Yes X No Vol to Surf: 75 ant In Place At: 1010 Date: 427/2019 Estimated TOC: od Used To Determine TOC: Surface Post Job Calculations: Calculated Cmt Vol @ 0% excess: 412.5 Total Volume cmt Pumped: 778.6 Girt returned to surface: 75 Calculated cement left in wellbore: 703.6 OH volume Calculated: 383.6 OH volume actual: 693.6 Actual % Washout: 55 www.weliez.net WellEz Information Management LLC ver_04818br MPU E-40 OH Sidetrack Summary PBI TD 9,421' MD / 4,438' TVD KOP 7,090' MD Date 4/30/2019 PTD: 219-044 / API: 50-029-23626-00-00 rGk•�,q, �In.La, t.t.c DATE: 5/24/2019 21 904'f De—ra Oudean Hilcorp Alaska, LLL h p 4 0 AK_GeoTech 3800 Centerpoint Drive, Suite 1400 U V 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-40 PTD 219-044 MPU E-40 PB1 CD: HALLIBURTON 13 May 2019 FEB 2019 E-40 ROP DGR ABG EWR ADR MD & TVD E-40 PB1 ROP DGR ABG EWR ADR MD & TVD Please acknowledge receipt lay signing hand returning one copy of this Received By: /�� \ / Date: U NM or FAX to 907 777.8510 DATE: 5/24/2019 -Z19O44 Deure Oudean Hilcorp Alaska, LLC 2 O ^ 8 fM 1 AK_GeoTech 3800 Centerpoint Drive, Suite 1400 J 1 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-40 PTD219-044 MPU E-40 PB1� CD: HALLIBURTON 13 May 2019 FEB 2019 E-40 ROP DGR ABG EWR ADR MD & TVD E-40 PB1 ROP DGR ABG EWR ADR MD & TVD MA y F ,yT� V -10 <'0l9 Please acknowledge refeipt 41y signing hand returning one copy of this Received By: W/////1 // //� � \ / Date: 11 L ( l or FAX to 907 777.8510 THE STATL °fALASKA 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 www.aogcc.olaskci.gov Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-40 Hileorp Alaska, LLC Permit to Drill Number: 219-044 Surface Location: 3472' FSL, 1825' FEL, SEC. 25, TUN, R10E, UM, AK Bottomhole Location: 534' FNL, 2045' FEL, SEC. 19, T13N, Rl IE, 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, / �i off- l, Jessieelowski Commissioner DATED this L day of April, 2019. STATE OF ALASKA ALk%oKA OIL AND GAS CONSERVATION COMMlbsION PERMIT TO DRILL 90 AAC 95 nnR MAR 15 2,159 D 1a. Type of Work: ib. Proposed Well Class: Exploratory -Gas LJ Service- WAG LJ Service - Disp ❑ 1c. Specify if well is proposed for: Drill ❑✓ • Lateral ❑ Stratigraphic Test ❑ Development -Oil ❑ Service - Winj ❑✓ • Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory- Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑✓ . Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 • MPU E-40 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 14,050' TVD: 4,400' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3472' FSL, 1825' FEL, Sec 25, T13N, R10E, UM, AK • ADL025518, ADL028231, ADLO47438 1y'5 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 233T FNL, 1339' FWL, Sec 30, T13N, R1 1E, UM, AK LONS 94-017 4/8/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 534' FNL, 2045' FEL, Sec 19, T13N, R1 1E, UM, AK 7659 8167'to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 48.1 15. Distance to Nearest Well Open Surface: x-569322 y- 6016010 Zone -4 GL / BF Elevation above MSL (ft): 21.6. to Same Pool: 40'to MPE;40 3Z 16. Deviated wells: Kickoff depth: 280 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 1899 11 2� 1 Surface: 1487 /'4, '�- / 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length I MD TVD MD TVD (including stage data) Cond 20" - X-52 Weld 107' Surface Surface 107' 107' ±270113 12-1/4" 9-5/8" 40# L-80 TXP 6,626' Surface Surface Sig 1 L- 1273 ft3 / T - 458 ft3 6,626' 4,373' Stg 2 L- 1937 ft3 / T - 314 ft3 Tieback 3-1/2" 9.2# L-80 ELIE 8rd 6,476' Surface Surface 6,476' 4,360' Tieback Tubing 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 7,574' 6,476 4,400' Cementless Liner w/ ICDs & Swell Pkrs 19. PRESENT WELL CONDITION SUMMARY (To be completed forrill and Re- MG perations) Total Depth MD (ft): Total Depth TVD (11): Plugs (measured): Effect. Depth MD (ft)3 Effect. Depth TVD (11): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (11): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑✓ 20. Attachments: Property Plat BOP Sketch B Drilling Progrpam Diverter Sketch ✓ Seabed Re ort e Time v. Depth Plot a Shallow Hazard Analysise Drilling Fluid Program ✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: 'en el hilCor .COm Authorized Title: illing Manager Contact Phone: 777-8395 FoQ morvTY /t'1YL`RS Authorized Signature: Date: 3%1S�ly Commisslon Use Only Permit to Drill k / _l �U API Number: Permit Approval See cover letter for other Number: 7 50- 07-7 Z— ��--iY>—Zfk:D Date: 1 requirements. Conditions of approval : If box is checked, well may not be used to explore for, lest, or produce coalbed metha e, gas hydrates, or gas contained in shale / Other: •x 3" pS L �a ,O S /, Samples req'd: Yes ❑ ,No ['✓ Mud log req'd: YU I{7]'A. I T/J HzS `y massspyLas: yYyw No—/ Directional svy req'd: Y Cl Spacing exceptionreq'11: Yes 1—I No[v Inclination-onlysvyreq'd: Yttt❑�� gZCCOYY�cL 1 (39 Post injection MIT req'd: YID to (^� tiinitial APPROVED BY Approved by: �C ��(/�--`_ COMMISSIONER THECOMMISSION ON Date: Submit Foran and Foran 1 01 Revised 5/2017 This permit is valid for 2 m o of Ovd1 per 20 C 2 (g) Attachment in Duplicate t OiNoA ,yam _�� , y ,4 Milne Point Unit E-40 SB Injector Hileo Drilling Procedure �Z 6.0 0 Planned Wellbore Schematic Proposed Schematic nx V.11n•la.l l KB FEVab ' M!L: 461' Milne Point Unit Well: MPU E-40 PTD: TBD API: TBD TREE & WELLHEAD OPEN HOLE / CEMENT DETAIL 42" -270N3 12u4„ Seg 1- 1273 113 Lmd/ 459 F0 Tal Top Stg2 -1937 k31vd / 314 fLi Taf &17' to ecdon Liner in8- YMIe CASING DETAIL Size Type +rt /&adei 0— OfdS ID Top Btm SPF 20' EOn3K1af N/A/X-521 WM WA Sudan 7Q7' NIA 9-5/8' Surface 40/L-W/DWCX 8.75" Surtam 6,626' aw58 4-1W I Omer I 13.57L-80 625 I 3.85" I r,,476' I 14,OSkT I Q.0149 TUBING DETAIL 3-02' 1 Tubin 9.2/L-W/EIIE 1 2992' 1 Sud 1 6,476' 1 0.04870 WELL INCLINATION DETAIL XOP @ 260' Max IlokAngle e91.Y JEWELRY DETAIL N0 Top MD Item ID upper Camp eaan 1 32.325' XNpge 2.813 2 35,301' XN Ni le fib: 2724'No Ga/2813 ftcidna Bae 2.723 3 36,464' 8.25'NoGa lncamranTiebockpyX(I4-1"Ported5ml5teml 2992 4 1 36,476' I Tinbxk Shoe 6.180 IAMrer Comp on 4 36,476' liner Top Mker ITVD=TBD 5 14,045' WV (Bat an Seal Cbdk PSTD - D=4,4 lT P6TC=13,015' Iii /FBCD=4/lOD'ITVDI Pa -e 6 a.P�F a.y�h KnfSwllwG.. aua MQ Ya ICa mJ tieell Peer Dmil FXD GENERAL WELL INFO API4 TBD Completed Innvwtbrc Future H Hileorp Bac Company 3.15.2019 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7'h Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill MPU E40 Dear Commissioner, Joe Engel Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 Email: jengel@hilcorp.com Hilcorp Alaska, LLC hereby submits for review and approval for a Permit to Drill an onshore injector well at Milne Point'E' Pad, well slot 40. Drilling operations are expected to commence approximately April 8, 2019, pending rig schedule. MPU E-40 is a grassroots injector planned to be drilled in the Schrader Bluff NB sand. E-40is part of an Pight 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 NB 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. Please find attached the Form 10-401, Application For Permit to Drill per 20 AAC 25.005 (a) and the drilling program for MPU E-40, which includes information required by 20 AAC 25.005 (c). If you have any questions, or require further information, please do not hesitate to contact myself (Joe Engel) at 777-8395 or jengel@hilcorp.com or Monty Myers at 777-8431 or mmyers@hilcorp.com. Sincerely, Joe Engel Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 HILCORP ALASKA LLC MILNE POINT FIELD AOR Map E40 InIec r(PmIaweE) %mm60 00 FEET MSTEO WELL MTA YM • E-02 • CFP -2 E-16 E-07 E-14 0 B-12 B-11 D;3304 hylNp�� %yl� B-29JB-o B-05 B -04A • • B-03-16 I \ B-177 B-01 • B-30 • • I \ B -05A /A • I / IB-13 B-21 B-11 • / B-06 • 4 / •0 I It B-22-27 E-30 E- I E -30A E-30AL1 / E-12 / • E-32 /E -0'8 O / • E-06 / � / E-4:?o`// 04 \ / / -21 • \ / 1 E-05 E-23 E-40 wp04 E110 \ v9 E-17 fiu -ete MPE-40 AOR Table CBL Top of CBL Top of Top of SB Top of SB Cement Cement Schrader NB PTD API WELL STATUS NB (MD) NB (TVD) (MD) (TVD) status Zonal Isolation Surface casing run to 190-081 50-029-22058-00-00 MPE-05 Kuparuk WAG 5,302' 4,363' Surface Surface Closed 5,671' MD/4,639' TVD and cemented to surface. - 70 bbls of cement pumped thru ES Cementer on 7" 195-094 50-029-22570-00-00 MPE-23 Kuparuk WAG 5,949' 4,375' 3,467' 3,255' Closed casing at 6,566' MD. TOC @ ±3,467' MD/3,255' TVD. Surface casing run to 5,961' MD / 4,768' TVD 198-115 50-029-22894-00-00 MPE-21 Schrader Susp 5,316' 4,352' Surface Surface Closed and cemented to surface. Well was perl"d below the NB sands. Surface casing run to 191-050 50-029-22156-00-00 MPE-08 Kuparuk Shut In 5,547' 4,325' Surface Surface Closed 5,947' MD / 4,590' TVD and cemented to surface. 7" Casing run to 6,761' MD / 4,461' TVD and cemented 205-067 50-029-23262-00-00 MPE-12 Schrader WAG 6,299' 4,330' 3,661' 2,895' Closed back to 3,661' MD/ 2,895' TVD (Calc) . Well open in ND, NC and OA sands. 7-5/8" casing run to 6,502' MD/4,384' TVD and 205-072 50-029-23263-00-00 MPE-31 Schrader Producer 6,468' 4,375' 4,149' 3,170' Closed cemented back to 4,149' MD / 3,170' TVD (Calc). Surface casing run to 185-093 50-029-21348-00-00 MPB-13 Kuparuk WINJ 5,620' 4,390' Surface Surface Closed 6,127' MD / 4,674' TVD and cemented to surface. NB was opened and never cased/cemented. Well was 182-105 50-029-20772-00-00 MPB-05 P&A'd 5,544' 4,455' N/A N/A Open later sidetracked. See below. 7" Casing run to 9,370' MD 185-148 50-029-20772-01-00 MPB-05A KuparukWINJ 5,525' 4,436' 7,900' 6,213' Open /7,310'TVD. Pumped 115.4 bbls CBL TOC is at 7,900' MD/6,213' TVD. Surface casing run to 201-011 50-029-22903-03-00 MPE-30A Schrader Shut In 6,553' 4,349' Surface Surface Closed 6,738' MD/4,462' TVD and cemented to surface. 7-5/8" casing run to 6,299' MD/4,385'TVD and 205-065 50-029-23261-00-00 MPE-32 Schrader Producer 4,892' 4,327' 2,482' 2,404' Closed cemented back to 2,482' MD / 2,404' TVD(calc). ,/ 9-5/8" Surface Casing run to 5,741' MD / 4,579' TVD 190-005 50-029-21997-00-00 MPE-04 Kuparuk Producer 5,437' 4,359' Surface Surface Closed and cemented back to surface. 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O O U U d v 1p rA N' Q p p m u m t N CO V Z N to N Zn ZD m M m n m a v v v v V ' in M N Lq � � v v 1 v _ c v u Z ++ � -p 3 � O a` a 3 ro N 01 3 L Y u L o Q � m m a a w w a a a 0 0 0 0 0 0 0 0 0 0 0 0 N N tt1 'i O N O N N N m N T N Ol N Ol N Ol N O O O O O O O O Ifl 00 r1 In e0 00 O O N N N N Hilcorp Alaska, LLC Milne Point Unit (MPU) E-40 Drilling Program Version 1 3/15/2019 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 N/U 13-5/8" 5M 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 NIU 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 3-1/2" Tubing (Upper Completion).....................................................................................36 18.0 RDMO............................................................................................................................................38 19.0 Innovation Rig Diverter Schematic.............................................................................................39 20.0 Innovation Rig BOP Schematic....................................................................................................40 21.0 Wellhead Schematic......................................................................................................................41 22.0 Days Vs Depth................................................................................................................................42 23.0 Formation Tops & Information...................................................................................................43 24.0 Anticipated Drilling Hazards.......................................................................................................44 25.0 Innovation Rig Layout..................................................................................................................47 26.0 FIT Procedure................................................................................................................................48 27.0 Innovation Rig Choke Manifold Schematic................................................................................49 28.0 Casing Design.................................................................................................................................50 29.0 8-1/2" Hole Section MASP............................................................................................................51 30.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................52 31.0 Surface Plat (As Built) (NAD 27).................................................................................................53 32.0 Schrader Bluff NB Sand Offset MW vs TVD Chart ..................................................................54 33.0 Drill Pipe Information 5" 19.5# S-135 DS -50 & NC50...............................................................55 1.0 Well Summary Milne Point Unit E-40 SB Injector Drilling Procedure Well MPU E-40 Pad Milne Point "E" Pad Planned Completion Type 3-1/2" Injection Tubing Target Reservoir(s) Schrader Bluff NB Sand Directional Plan WP04 Planned Well TD, MD / TVD 14,050' MD / 4,400' TVD • PBTD, MD / TVD 14,045' MD / 4,400' TVD Surface Location (Governmental) 3472' FSL, 1825' FEL, Sec 25, T13N, RI OE, UM, AK Surface Location (NAD 27) X= 569,322.2, Y= 6,016,010.7 Top of Productive Horizon (Governmental) 2337' FNL, 1339' FWL, Sec 30, T13N, RI 1E, UM, AK TPH Location AD 27 X= 572,491.3 Y= 6,015,511.2 BHL (Governmental) 534' FNL, 2045' FEL, Sec 19, TON, RI 1E, UM, AK BHL AD 27) X= 574,253.3 Y=6,022,611.6 AFE Number 1910940 AFE Drilling Das 20 days AFE Completion Das 4 days AFE Drilling Amount $4,313,099 AFE Completion Amount $1,133,942 AFE Facility Amount $591,000 Maximum Anticipated Pressure Surface 1487 psig Maximum Anticipated Pressure Downhole/Reservoir 1899 psig Work String 5" 19.5# S-135 DS -50 & NC 50 KB Elevation above MSL: 26.5 ft + 21.6 ft = 48.1 ft GL Elevation above MSL: 21.6 ft BOP Equipment 13-5/8" x 5M Annular, 3) ea 13-5/8" x 5M Rams Page 2 Milne Point Unit E-40 SB Injector Hilcorp Drilling Procedure W 22 2.0 Management of Change Information 11 Hilcorp Alaska, LLC Hilcoo, Changes to Approved Permit to Drill Date: 3/162019 Subject: Changes to Approved Permit to Drill for MPU E-40 File #: MPU Edo Drilling and Completion Program Any modifications to MPU E-40 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be ocmffirunieatedt4the AOGCC� �y ��L l �•/ Approval: Drilling Manager Prepared: Drilling Engineer Page 3 Date Date H Hilcorp &.W ��, 3.0 Tubular Program: Milne Point Unit E-40 SB Injector Drilling Procedure 4.0 Drill Pipe Information: All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 D (in) ID in D onn OD - in Wt (#/ft)psi), Grade Conn Burst Collapse , si Tension (k -lbs) 78-1/72"4-1/2" 20" 19.25" - - - X-52 Weld -5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 3.96" 3.795" 4.714" 13.5 L-80 H625 9020 8540 279 -1/2" 2.992" 2.897" 4.5" 9.3 L-80 TxP-sa 9,289 7,399 163 4.0 Drill Pipe Information: All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 Milne Point Unit E-40 SB Injector Hilcorp Drilling Procedure �� 2 5.0 Internal Reporting Requirements 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 pmazzolini@hilcorp com mmers hileo_pr jengel@a)hilcgM.com and cdinger@hilcoM.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 hilcorp,com jeneel(a hilcorp.com and cdingerah ilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hilcom.com ieneelghilcorp.com and cdin er ,hilcoM.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 ieneel@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 kfleminQ@hilcorp.com EHS Manager Carl Jones 907.777.8327 1 907.382.4336 c1 ones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdineer@hilcorp.com Page 5 n Hilcorp 7.0 Drilling / Completion Summary eight well program Milne Point Unit E-40 SB Injector Drilling Procedure to be drilled in the Schrader Bluff NB sand. E-40 is part of an 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 NB 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 April 8, 2019, pending rig schedule. Surface casing will be run to 6,626' MD / 4,373 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 n Hilcorp UMT Milne Point Unit E-40 SB Injector Drilling Procedure 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-40. 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 wrivard hilcorp.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 Milne Point Unit Test Pressure(psi)_ E-40 SB Injector Hilcorp ceme.�.r 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.reggi7n alaska.eov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz@alaska.gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loepp@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.Inspectorsnalaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/oac/forfns/TestWitnessNotif btml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 9.0 RX and Preparatory Work 9.1 E-40 will utilize a newly set 20" conductor on E Pad Expansion. Ensure to review attached surface plat and make sure ri¢ 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 NX 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. Page 10 Milne Point Unit E-40 SB Injector Hilcorp Drilling Procedure 9.0 RX and Preparatory Work 9.1 E-40 will utilize a newly set 20" conductor on E Pad Expansion. Ensure to review attached surface plat and make sure ri¢ 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 NX 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. Page 10 H Hilcorp 10.0 N/U 13-5/8" 5M Diverter Configuration Milne Point Unit E-40 SB Injector Drilling Procedure 10.1 N/U 13-5/8" CTI BOP stack in diverter configuration (Diverter Schematic attached to program). • NIU 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 same 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 I 1 Milne Point Unit E-40 SB Injector Hil.corp Drilling Procedure e� C�p.or 10.5 Rig & Diverter Orientation: *Orientation may differ on location 41 E-40 `9 ■ ■ v6 25 ■ ■ 21 11 ■ ■ 7 18 ■ ■ 16 20 ■ ■ 23 24 ■ ■ 19 14 ■ 34 1 15 ■ 17 38 ■ ■ 37 39 ■ ■ 36 41 ■ ■ 35 E-40 + 75' Radius Clear of Ignition Sources Diverter tine MPU E Pad Expansion `Drawing Not To Scale Page 12 n Hil U�=— corp 11.0 Drill 12-1/4" Hole Section Milne Point Unit E-40 SB Injector Drilling Procedure 11.1 PX 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 TEA 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 NB 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 F — below permafrost). Be prepared for hydrates: • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD Page 13 H Hilcorp Milne Point Unit E-40 S8 Injector 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 ".1) highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg �and �tf� TD with 9.2+ pg. $' Depth Interval 0 Page 14 • 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). MW 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). System Type: 8.8 - 9.8 ppg Pre -Hydrated Aquaget/freshwater spud mud Prnnerfies Milne Point Unit E-40 SB Injector Drilling Procedure Section Densltv I Viscosity Plastic Viscosi Yield Point API FL pH Tem Surface 1 8.8-9,8.1 75-175 1 20-40 25-45 :<l 0 8.5 - 9.0 <_ 70 F 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 Hilcorp 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. Milne Point Unit E-40 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 W • 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 Closing Sleeve No. Shear Pins Opening Sleeve No. Shear Pins ES Cementer Depth Baffle Adapter (it used) ID Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole TD "Reference Casing Sales Manual S:.5 Page 17 «A overall Length 8 Min. ID After Drilbut C Max. Tool OD D opening Seat ID E closing Seat O Plug Set Part No. SO No. Closing Plug OD Opening Plug OD- OD- Shut-off DOD Shut-off Plug OD Bypass Plug (d used) OD Milne Point Unit E-40 SB Injector Drilling Procedure Rikorp E541 sunrdng Order ESTI Cementer Shut Off Plug suffix Adapter �dt�I V 1 i By -Rio Plug By Dass Baffle Float Collar Float Shce H Hilcorp ft� � Milne Point Unit E-40 S8 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: • Verify depth of lowest U 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). !C� • Install centr rzaI a 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 p� open at -- 3000 psi. Reference ESIPC Procedure. 9-5/8" 40# L-80 TXP Make Up Torques: to inflate at — 2080 psi, and the tool to Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Depth Interval Centralization Shoe —1000' Above Shoe 1/jt 1000' above Shoe — 2000' above Shoe 1/ 2 its (Top of Ugnu) Page 18 Milne Point Unit E-40 SB Injector Hilcolp Drilling Procedure ee.� ��, TXP® BTC Outside Diameter 9.625 in. Min. Wall 87.541 COUPLING PIPE BOOy Thickness 1st Band: Red Wall Thickness 0395m. Connection OD REGULAR 3rd Band. - 3m Band: - Optbon 4th Bane - Grade LBO Type V Drift API Standard Type Casing Page 19 �wae. 11108/2018 (') Grade L80 dos Type 1 COUPLING PIPE BOOy eody'. Red 1st Band: Red 1st Band- Broom 2nd Band: 2nd Bard-- Brown 3rd Band. - 3m Band: - 4th Bane - GEOMETRY I Nominal 0.- Nominal 1D 9.625 in. 8.835 in. Nominal Weight Way Thickness 40 1b.1 0.395 m. Drift Plain End Weight 9.679 in. 33.971bs,tt OC Tederence AN PERFORMANCE Body tied Strength 916 XI000it's Internal relt 5750 ps, SIdYS 90000 Ps' Collapse 3090 psi GEOMETRY Connection OD Make-up Loss 10.625 in. 0.891 in, Coupling Length Threads per in 10.9250 5 Connection ID Connection OD Option 8 823 in. REGULAR PERFORMANCE I Tension Elftienry 100.0% b m yasu strength ✓ 916.000 x1000 Internal Pressure Capacity P1 5750.000 psi ✓ Ibs Cwnpression Efficiency 100% Compression strength 916000x1000 Max. Allowable Bending 38`i1000 his Exams] Plese Pa Capacity 3090.000 pat ,✓ MAKE-UPTORQUES I klranum 18860 Robs Optimum 20960 h-Ibs Maximum 23060 Miss OPERATION LIMIT TORQUES Operating Tons. 356000 -Ts Yield Torque 43400 hobs Notes This connection is fully interchangeable with: TXP® BTC - 9.625 in. - 36 143.5 147 / 53.5 15&4 WSM 11] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C3 / ISO 10400 - 2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced. Please contact a local Tenads technical sales representative. H Hilcorp Z= Milne Point Unit E-40 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 ff Hilcorp Evngy Co 2 13.0 Cement 9-5/8" Surface Casing Milne Point Unit E-40 SB Injector Drilling Procedure 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 R/U 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 I" 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 lsi Stage Total Cement Volume: Page 21 X -1 ('S K 3gY5X Section Calculation Vol (bbl) Vol (ft3) � 12-1/4" OH x 9-5/8" (5,626' - 2500') x .0558 bpf x 1.3 = 226.7 1273 9 Casing Total Lead 226.7 1273 12-1/4" OH x 9-5/8" (6,626'-5,626')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 X -1 ('S K 3gY5X n Hil ncorp G _02 Milne Point Unit E-40 SB Injector Drilling Procedure Cement Slurry Design (V 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: / 6,506' x.0758 bpf = 493 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, f4.5 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 TM 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 5.04 gal/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: / 6,506' x.0758 bpf = 493 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, f4.5 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 H Hilcorp Milne Point Unit E-40 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 hold, 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 H Hilcorp Second Stage Surface Cement Job: Milne Point Unit E-40 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 x1 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 2"d 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. Estimated 2nd Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) SwiftCEM "" System (Hal Cem) 20" Conductor x 9-5/8" Casing (110') x .26 bpf x 1= 28.6 161 J 12-1/4" OH x 9-5/8" Casi n (2000'- 110') x .0558 bpf x 3 = 316.4 1776.3 Total Lead 345 1937 12-1/4" OH x 9-5 8" Casin (2500'- 2000') x .0558 bpf x 2 = 55.8 314 ~ Total Tail 55.8 314 Cement Slurry Design (2nd stage cement job): Page 24 Lead Slurry Tail Slurry System Permafrost L SwiftCEM "" 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 Page 24 n Hilcorp Milne Point Unit E-40 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: 2500' x.0758 bpf = 190 bbls mud 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 ieWe1khi1corp.com and cdinverghilcw�vcom This will be included with the EOW documentation that goes to the AOGCC. Page 25 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 • 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 Milne Point Unit E-40 SB Injector Hileorp Drilling Procedure �� cams 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 • 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 Milne Point Unit E-40 SB Injector Hil Drilling Procedure 15.0 Drill 8-1/2" Hole Section 15.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.22° PDM) 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. �f \ 15.7 Conduct FIT to 12 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 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/J 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 n Hilcorp MZT. Milne Point Unit E-40 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) for sufficient hole cleaning • 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 Densi lostic Viscosit Yield Point Total Solids MOT HPHT Productio 8.9-9.5 ' 15-25 1 20-25 <10% 1 <7 <11.0 System F�muJnti6n: 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 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Displace wellbore to 8.9 Page 28 Baradrill-N drilling fluid Milne Point Unit E-40 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. • 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 NB Concretions: 3-5% of lateral • Abnormal Pressure maybe seen on E-40 as we cross faults. Monitor pressure on connections with MPD if necessary 30W.W E-32 is a close approach at 7,558 — 8,000' MD. E-32 is an active SB OA & CD Producer. E-40 is an UliWeclor and will not be in this reservoir. Monitor MWD for magnetic interference throughout this interval. E-12 is a clsot approach at -- 9,000-9250' MD. E-12 is a S/I SB OA & CD Injector. -E-40 is an NB,inj,�or and will not be in this reservoir, onitor MWD for magnetic interference throughout this interval. pig (� A :S-A-uD 15.15 Reference: Open hole sidetracking practice: p r • 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. • 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. Page 29 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, swap 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 returned 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 (0 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 • If abnormal pressure is seen, utilize MPD to close chokes on connections while BROOH 15.19 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. Perform production screen test (PST). The mud has been properly conditioned when the mud will pass the production screen test on the return fluids (0 350ml samples passing through the screen in the same amount of time which will indicate no plugging of the screen). Reference PST Test Procedure • 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. Page 30 Milne Point Unit E-40 SB Injector Hilcorp Drilling Procedure 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, swap 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 returned 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 (0 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 • If abnormal pressure is seen, utilize MPD to close chokes on connections while BROOH 15.19 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. Perform production screen test (PST). The mud has been properly conditioned when the mud will pass the production screen test on the return fluids (0 350ml samples passing through the screen in the same amount of time which will indicate no plugging of the screen). Reference PST Test Procedure • 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. Page 30 H Hilcorp b eW<��, Milne Point Unit E-40 SB Injector Drilling Procedure Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted 16.0 Run 4-1/2" Injection Liner (Lower Completion) 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 3-1/2" 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" Hydril 625 x DS -50 crossover is on rig floor and NIX 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, Operations Engineer to provide confirmation of set depths). • Do not place tongs or slips on swell packer elements or ICDs. • ICD and swell packer placement f40' Page 31 H Hilcorp Milne Point Unit E-40 SB Injector Drilling Procedure • 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 1/jt for each joint outside of the surface shoe. This is to mitigate difference sticking risk while running inner string. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10 and 20 rpm 4-1/2" 13.5# L-80 Hydril 625 Casing OD Minimum Optimum MaximumYield Operating Tor ue Torque 4.5" 8,000 ft -lbs 9,600 ft -lbs 12,800 ft -lbs 15,000 ft -lbs Page 32 H Hileorp =T Milne Point Unit E-40 SB Injector Drilling Procedure For the latest performance data. always visit our website: www.tenaris.com Wedge 6250 ._ 12J04n017 Ou We Diameter 4500 r.. Yin. WaB 97.5% GEOMETRY Thickness MGr LW hk 100 A.5O0 iL Norrcnal Weipe 1]50IhsMl Type 1 3]%n Wall Thidness 0290 r, Conner Go REGULAR Ham Er Weigle 13.0Dsm CO Tolerance A% ppbon EoUPlY1G RPE BODY PERFORMANCE Body Rel to eand. RM Grade LBO Type f Drift API Standard 1st Band: B.� 2nd Band' Colla CLO pi 9d Band:- Brown CONNECTION DATA T,P Casino 3b sand:- 3rd sand. GEOMETRY am Band -- PIPE BODY DATA GEOMETRY hk 100 A.5O0 iL Norrcnal Weipe 1]50IhsMl [AiR 3]%n Ndminal lD 19Wa WaL Thinness 0190 n. Ham Er Weigle 13.0Dsm CO Tolerance A% PERFORMANCE Baily Yc SO gm W1 atOW lbs m2 yl d Mir psi 3MYS WOOD psi Colla CLO pi CONNECTION DATA GEOMETRY Conne 00 4.714n cm, to 3.94.9::. Mao- Loss aaWa Thre Perin Val Lonnesln OD Opti REGULAR PERFORMANCE Tmsan Efioiency 9A% domM�J5 nph 27937071000 IMemal P� Capadty W20.000" lbs CmrAess..emd % 94.5% Cmryressian sn-vg 090.115a10D1 LLii Abxabk Bending 717'0039 lbs FiSen.YTesvue CapadN LLO.OW psi MAF -UP TORQUES Min'u.slm 9000 ft 1 0". 9Wg 9Jbs hlav'rmen 12M 941,s OPERATION LIMIT TORQUES DasrmTmwe 12000 nm YWd Tor.pre 15()40 ftm Notes For further infannation on concepts indicated in this datasheet, download the Datitshest Manual from www tenans.00m 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-40 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 packof. . 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 KCI NaCI (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 n Hilcorp Energy.2,9 16.23. Repeat pumping SAPP pills as needed until the wellbore is clean. Milne Point Unit E-40 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 50k# without pulling sleeve packoff. Contingency (if suspected not released from running tool) - Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k# 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 Milne Point Unit EA0 SB Injector Hilcorp Drilling Procedure 17.0 Run 3-1/2" Tubing (Upper Completion) 17.1 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 wrivardnn hilcorp.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 3-'/�" EUE 8RND 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. 3-'/2" Upper Completion Running Order • 7.30" Baker Ported Bullet Nose seal (stung into the tie back receptacle, crossed over to 3-1/2 9.3# EUE 8RND) • 3 joints (minimum, more as needed) 3-%" 9.3# EUE 8RND tubing • 3-'/z" "XN" nipple at 5,700' MD (less than 70° hole angle) • 2 joints 3-'/2" 9.3# EUE 8RND tubing • 3-1/2" Baker gauge mandrel o Cross collar clamps: Every joint for first 10 joints, every other joint beyond this to surface • 3-'/2" 9.3# EUE 8RND tubing • 3-'/z" "X" nipple at 2,500' MD • 3-'/z" 9.3# EUE 8RND space out pups • 1 joint 3-'h" 9.3# EUE 8RND tubing • Tubing hanger with 3-1/2" EUE 8RND pin down Page 36 TOOLS 00: ID: Weight: Grade: Tube Wan: Tubing Length: Milne Point Unit E-40 SB Injector Drilling Procedure Tubing Specification Sheet 3-1/27 9.30#7 L80, EUE 8RD, R2 3.500 in Connection: 2.992 In Coupling OD: 9.30 1bal t Tool Joint ID: L80 - ._ Drilt. 0.254 in R2 Thread Compound Friction Factor. Maximum MUT: RBW: 0.203 in Optimal MUT: Tube Tensile: _ 163,178 M ft Minimum MUT: Tube Collapse: 7,399 psi Tube Internal Burst: 9,289 psi Displacement Estimate: 0.00339 bbls/N g11521 Toa"a_._._.___-. Capacity Estimate. 0.00870 bblslft 3-112' EUE 8RD 4.500 in 2.992 in 2.897 in 1.0 4,000 ft -lbs 3,200 ft -lbs 2,400 ft -lbs 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 (+/- 1' 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 17.9 Land hanger. RILDs and test hanger. Page 37 Milne Point Unit E-40 SB Injector Hilc4T Drilling Procedure en� 17.10 Continue pressurizing the annulus to 2,000 i. Note this test must be win 30 charted minutes. . )resentative. 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. 1 L (J 17.14 Secure the tree and cellar. 18.0 RDMO 18.1 RDMO Innovation Rig Page 38 il-,~ 2,-� 44C �S.iItZ (L) ff Hilcom 19.0 Innovation Rig Diverter Schematic 3.118' 13 Technol Page 39 Milne Point Unit E-40 SB Injector Drilling Procedure eQbd TKhnology l,5V 5M Control echnobgy Double Ram W Choke Line —1 OiveRer Urce I U Hie= 20.0 Innovation Rig BOP Schematic 3-118" Kill 9-518" DBL D Casing Hanger S-22 13-518" NOM 9-518" BTC Btm x 10.5"-4 SA Pin Top W/ Primary Seal Page 40 W, R C U Milne Point Unit E-40 SB Injector Drilling Procedure 13-518" 5M Control Technology Annular BOP 13-518" 5M Control Technology Double Ram -----�3-118" Choke Line -518" x 5M 11"x5M x5M 13-5/8"x 5M \— 2-1/16" x 5M Casing " Casing —13-518" 5M Control Technology Single Ram H Hilcorp U Milne Point Unit E-40 SB Injector Drilling Procedure 21.0 Wellhead Schematic CAMERON 11" 5K A4BS A Schlumberger Company 4-111V' SK o a:a lj f 3 •' - �I B-0195 � 12-12-17 Im�n rmd® Page 41 Milne Point Unit E-40 SB Injector Hi1mT Drilling Procedure ��r 22.0 Days Vs Depth 4000 6000 MPU E-40 Days vs Depth 12000 14000 16000 Page 42 J 0 5 10 15 20 25 Days ff HiIcorp �� 23.0 Formation Tops & Information Milne Point Unit E-40 SB Injector Drilling Procedure MPU E-40 Formations (wp04) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2128 -1787 1835 807.4 8.46 LA3 4505 -3738 3787 1666.28 8.46 Schrader Bluff NB 6225 -4269 4318 1899.92 8.46 GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL TVD FM LITH DESCRIPTION MI carr. mor, argent Gubl Unconsolidated coarse to mecum sand and small gravel with r.1ao•. 600 minor aalaane. 1,0011, • Heavy gravel conglomerate to 1400'. Wood fragments E1.amee Ntoughout permafrost zone. Abundant pyrite at 1500 n. ease RUNNING GRAVELS 17gg. permafrost 2,000' Be prepared lot HYDRATE gas cut HYDRATESI! srg a nlrktok C mu tl 2000th 2500' es 1E-]antl E3) (plus --10.-11.-228-231). (E-01,30, -40m L -ssa-tt). E,12- HYDRATES! GAS CUT MUD A Predominantly Nay to ef- 3000 with Interbeds o1 sand. clays and slitstmes wim occasional shows of coal. Y 3,000 Confined Inswiceds of sand, clays and shistones with occasional shows of teal. Clay. smstme and land Interbeds between 3000 and 6000'. Lignite 3400-3500 R SV intervals mere rany("muddier")than those in the Prudhoe Bay area. ME, UG4lN15 SWABBINGISTICKY ' L r.1 A Ugnu: Thick package -200 to 300 H in some areas. maty water -/filled at Egad. ehhwugh e a someaoros are IHled with trydrocartcon The Ugnu sac0m (InterDetldeC fluvial sandslEne A R and sl We) represents the know! piogmm0on or me Ugnu deltaic system over the underlying CLAY/GUMBO: E -20a.-28. C G I— shallow marine Schrader Bluff section- Fluvial nature can make k diffieW to determine top anti base o mNWduel un b- BOHoan bounding surface N the ensue Ugnu packAp Is prxad -32 8 -12. A Y ' at me regional unoononnly W. OS lsee me N -sands IrI GAS CUT MUD E-24 AT 3996 M -Sands: Flit' lel. denaic chain m sandstones prograded over me underlying shadow TVD; E-138 @ 3618 tvd. a 4,000 marine sandstones of me Schrader Bluff. The M -Sends are subdivided into three TIGH-TTPACHING OFF, E -25A., A klhosbiWgraphc units {Ma. Mb, Mc Iran top to scrams) mat can be difficult to consists due arm la des IhMBA4Nt81C mature. Tne mros marks the Itlner, .1 boundary. MSM! bderast9 6aliaEe easing Seat. B am typloaily co,;eningupaard packages of varying tnEknesses,rar ngfrgn 50.80-1Hak for Schrader Bluff Carom, 1' C Alt aeneS sae RlgiflyuKonsPlidalrad sandstones wim porosities range Infhe 30->8%Md completion. i pe mrabll saes reaMing upwartls N2000-5000 mol. Eachktsandlntervalactsaae hydreubrally separate, ervov based m cunren sande standh g. L cr' O TIGHVLEDGES(COAL) N -Sands: The N -amid -are composed ol-backed, panne shoelace sandstones that RUNNING SURFACE a A p ry coarsen upwards f soh min. SI rtwdstones Into gun, low nelgross very fine to ml ral CASING. E-24, -33 A -25. The NC N6sands the hest reservoir rock oftleat Yar C p gramed sandsha es. NB. i are quality hagh a grow fine to medlun gained sandstone. N --and pE25(ty ranges from 12-3614 and m permsabiloes range from 100-3000 m0. The NC 8 NDsaM5 are the pnmuy target. with j= E secondary targets in dare NB -seed. The more, unwnsol.0eted earrds IyPlealy the NB, NC 8 0 ND) tend to sisal and the flow grained slay arudslones can cause slow ROP. / Each N -sand acts as a hydrudicalfy Isolated separate re-ervoir. 451] aSiT A Eonsister MadNed.tO'M+othinlaceed. marine et O-siandsu"ardsr: ar eyMtl to flneron upwardhes-Thly mudstoneY (Intervening very egrained aidy mand.dst re25-tothlnbetlded. wrdis primary DASMdis sandstones. These GAa"O-fiiO res are25-30'mang von thern1 ff laget[orhand Osandporid, range lydmn pereachrinly y 0 the Qand realwellsa[E-pad. ma reach upwards of Egg en4 whereas In me reach only that correlate a "on 3'A rnd. There are lrwedylrg OB seeds (OBb-0B4)11W correlate over me radon. 3 d, Them a6 fill (e-Axiallywhen hordonaQ eM Slow ROP. Each 0 -sand Interval acts rasa hydrauurally btHmetl reurvdr. hocionsallnho slow OP.endlensestialcause acts" a hydraulically The numerous suh-seisow, S 0 H laults and the lateral dkscoMlnWy of the NBsvwtls make H w/ D essentlal for clear pick idenullcMbn down through the Ugnu and N -seeds, as well as careful 4800' N-IOD geosteenng in homt.rlul wells. Page 43 24.0 Anticipated Drilling Hazards Milne Point Unit E-40 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 number of wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches 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 H2S events have been documented on drill wells on this pad. Page 44 Milne Point Unit E-40 SB Injector Hilcorp Drilling Procedure a� Com, 1, The AOGCC will be notified within 24 hours if H2S 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. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 45 Milne Point Unit E-40 SB Injector Hilcorp Drilling Procedure 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 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. Faulting: ✓ There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for 1-12S. No 1-12S events have been documented V on drill wells on this pad. 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 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Abnormal pressure has been seen on E -Pad. Utilize MPD to mitigate any abnormal pressure seen. Anti -Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Page 46 I Milne Point Unit E-40 SB Injector HilmDrilling Procedure il�am�, 25.0 Innovation Rig Layout Page 47 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit E-40 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 48 Milne Point Unit E-40 SB Injector Hilcox Drilling Procedure 27.0 Innovation Rig Choke Manifold Schematic Page 49 n Hilcrp �2,T 28.0 Casing Design n HilmrP Calculation & Casing Design Factors DATE: 3/15/2019 WELL: MPU E-40 DESIGN BY: Joe Engel Desian Criteria: Milne Point Unit E-40 SB Injector Drilling Procedure 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: 1487 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1487 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 50 Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 4-1/2" Top (MD) 0 6,476 Top (TVD) 0 4,315 Bottom (MD) 6,626 14,050 Bottom (TVD) 4,373 4,400 Length 6,626 71574 Weight (ppf) 40 13.5 Grade L-80 L-80 Connection TXP H625 Weight w/o Bouyancy Factor (lbs) 265,040 102,249 Tension at Top of Section (Ibs) 265,040 102,249 Min strength Tension (1000 lbs) 916 279 Worst Case Safety Factor (Tension) 3.46✓ 2.73 Collapse Pressure at bottom (Psi) 2,160 2,174 Collapse Resistance w/o tension (Psi) 3,090 8,540 Worst Case Safety Factor (Collapse) 1.43 ✓ 3.93 MASP (psi) 1,487 1,487 Minimum Yield (psi) 5,750 9,020 Worst case safety factor (Burst) 3.87 ✓ 6.07 Page 50 Milne Point Unit E-40 SB Injector Drilling Procedure 29.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 11 8-1/2' Hole Section Hilcorp MPU E-40 Milne Point Unit MD TVD Planned Top: 6626 4373 Planned TD: 14050 4400 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sandi 4,373 1900 I Oil 8.36 0.440 Offset Well Mud Densities Well MW ranee Ton17VDI Bottom(TVD) Date MPU L-52 &B-9.35 Surface 3952 2017 MPU L-51 8.9.9.3 Surface 3930 2017 MPU L-53 9-9.25 Surface 3891 2017 MPUJ-27 9-9.3 Surface 3666 2015 MPUJ-28 9-9.3 Surface 3617 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 forthe 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: 4,373 (ft) x 0.78(psi/ft)= 3411 3411(psi)-[0.1(psi/ft)*4373(ft)]= 2973 psi MASP from pore pressure (complete evacuation of wellbore to gas from 4373 (ft) x 0.44(psi/ft)= 1924 psi 1924(psi) - 0.1(psi/ft)*4373(ft) 1487 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore togas at 0.1 psi/ft. Page 51 Milne Point Unit E-40 SB Injector Hilcorp Drilling Procedure e ll ��> 30.0 Spider Plot (NAD 27) (Governmental Sections) ---- - -- -- -- JE E.,. 1A.y qYu: ylyXlt9 Page 52 ]3LT1 f TPH = _ Sec. 30 Legend • MPE-40i_SHL X MPE-40i_TPH T MPEADi_BHL • Other Surface Holes (SHL) Other Bottom Holes (BHL) - Other Well Paths Q Oil and Gas Unit Boundary Pad Footprint Milne Point Unit MPE-40 Well 0 1.0oo 2.000 wp04 IFeet E, o' 1 I � ♦" � 25 ADL'028 31 Lt • ggY+gq ♦ ♦ I ♦ ♦ ]3LT1 f TPH = _ Sec. 30 Legend • MPE-40i_SHL X MPE-40i_TPH T MPEADi_BHL • Other Surface Holes (SHL) Other Bottom Holes (BHL) - Other Well Paths Q Oil and Gas Unit Boundary Pad Footprint Milne Point Unit MPE-40 Well 0 1.0oo 2.000 wp04 IFeet H HilmEnvy «P., 31.0 Surface Plat (As Built) (NAD 27) Milne Point Unit E-40 SB Injector Drilling Procedure Page 53 ,1 IL cRD 70'2Tta.749" 70.4540969' 21.8' 24 E-40 X- 569 322.25' E- T 292.10' 1x9'28'03.830" ta9.a3s3139' ,C ■ 13 28. ^^//y� I u■ i i � d I la ■ ■ a THS PROiIECI' 13 ■ r 16 ■ ■ 10 V' –N– 2s ■ ■ 10 I � I1 ■ ■ ] VICINITY MAP N,ls ■16 WU P." AD10■ 2A ■ ■ I3 10 ■ ■ 19 1s ■ ' 15 ■ i] s9■ �n SF.�F•ACA S a ■ ■ x �P•.•= E_40+ 1 °i:' 9 '•e Aro m� f+ �. — — — r GRAPHIC SCALE IFOFNn �•7.0•��200 .......py. 0 106 10D 100 + AS-BI14T C UcTm (M FEET) ■ mms CMOUCTOR 1 ad, - 200 a S IRVEYOR'c CERTWICATE I NOKW OD4KY TUT I AN RICFIIIT REW61E1.7:8 MO 1X my N m P$TIM LANG ARANO NOTES: *rE sTATE 0[ A:A9(A AND T A B. A Sk TOS Avy RUWER 1. XA9(A STAE PUYE ECMOXAIE$ AEE ITE A. MN122. T N.YE aT ME M 1166A MY OIIE4'T WE C w E MIO THAT ALL 2 BA4i 6 LOCATOI 5 YOR6YJ60 EM -3 MD E"1. M W SONS 3 8042 W BEVAMN It11E PPRT MA NA cmRCT As S PgoE v 51 201m 1 OE6xn6 POPW ARE N021. E PM MEM YJIY FK 5: 6901663/ 6 %R1 6AIL x014 m A =41 i PS[LPdtf PF1L BOOM 16:16-61 PP. 62-61 LOCATED WITHIN PROTRACTED SEC. 25, t 13 K. R. 10 E., UMIA7 MERIDIAN, ALA9CA WELL ASP. PLANT GEODETIC GEOOE77C CELLAR SECTION NO. COQRDINA7E5 COORDINATES POSITION(DMS) POSITION(C.DD) BOX ELEV. OFFSETS Y -6.016,010.71 -IN -1.799-59-1 JA Hitcorp Alaska v e MILNE POINT, ALASKA m ccu UP E -PAD, 40 AL Ra..rvs> AS-WELU CONDUCTOR AS-9ULL7 1' 1 Page 53 70'2Tta.749" 70.4540969' 21.8' S 472' PSL E-40 X- 569 322.25' E- T 292.10' 1x9'28'03.830" ta9.a3s3139' 1,825' FEL H Hilcox Milne Point Unit E-40 SB Injector Drilling Procedure 32.0 Schrader Bluff NB Sand Offset MW vs TVD Chart Page 54 SB NB Offset MW vs MD EMW, ppg 8.5 9.5 10.5 11.5 12.5 0 • ••• 4000 WON -J-27 (2015) J-28 (2015) -L-53 (2017) - L -S2 (2017) - L-51(2017) H Hilcorp ..,, e2,T Milne Point Unit E-40 SB Injector Drilling Procedure 33.0 Drill Pipe Information 5" 19.5# S-135 DS -50 & NC50 Drill Pipe Configuration Pipe Body OD m 5.000 Pqe Body Wan TNckriss" m 0.362 Pipe Body Grade S-135 Drill Pipe Length 31.5 Connection GPDS50 Tod Jolm OD 5.625 Tod Joint ID m 3250 Pin Tong 9 Box Tong m 12 80 % Inspection Class Nominal Weight Designation API Prenman class 19.50 Drill Pipe Approximate Length ins 31.5 SmoothEdge Height ms 3732 Raised Tool Joint SMYS �w�t 120.000 Upset Type Ell Max Upset OD (DTE) tme 5.125 Friction Factor 11.0 N. T.I. w[¢ mr m[e.a¢ nvmaaca. Drill Pipe Performance Drill -Pipe Length Range2 Performance of Drill Pioe with Pioe Body at 80 % Inspection Class 100 Connection Performance A ., Tension Only 10 560.800 Drib Size cs^s 3.125 cw mrke -s 32.100 1467,400 1Nd2-. ou neu omN N 1m 4z reek: ami Pa aaemnr raw[Y, as s[ss [mmarca sae a.+r „a<ya� a cm¢ Dear nni mkrurm. nn[.mi Nwn[wmmo. me onKr rser_ GPDSW ( 6.625 mt OD X 3.250 mt ID ) 120,000 w.n ryW. T...........etlM WeMonL knsR. a N^Jt Rsl • 3i TCO inAtsrsssuk Ee a{{ILY Tool Joint Torsional StrengN moat 71,800 Tod Jd d Tensile Strendh mat 12513000 Elevator Shoulder Information Smooth Edge Heigh 3132 Raised Box OD ��^� 6.812 Elevator CapeCl naxc 1,658,000 Assumed Elevator Bore Diameter fn,15-219 Pipe Body Slip Crushing Capacity No tq Sli Crushin Ca M-41498 3D 19/ Assumed Sib Le th M)116-9- Transverse Load Factor (K) 42 Pipe Body Performance I K'i � Grant 111 Page 55 Tool Joint Dimensions Balanced OD m46.435 aarenVnTwl Awn ao ex APi 5.930 PICTtM CS s[ M r.Nnkn Tod Awnmear 5.93 [cu�trsD r¢ 0^ Elevator OD 3132 Raised Trsar.rN^7 No1¢: Ekvaly [apaYy .- i[[umeQ Ekvaka Ear¢,n Ytzlv.aM [mCtl W[ss Or 1f0, 10Cps1. Nof[: A oo fvlxM LL`Yabr OO IwNSIZ ekYat[+[.iaxry vtl1m1 alRcinO mike.m bipue. Pipe Body Configurafim ( 5 wt OD 0.362(-) Wall S-135) minol I 80 % Inspection Class API Premium Class eArr. Deo- tiro aoo<ovro NQS%waraec.m r¢y.r+krAna Nuu m.avAv eceeo-u Pm raNnn eroaeramen, i=seum¢aaemanawmans.¢mmQmma von ao a trrte�a�m oQr. tie wmrQ �mknxcrme�¢ao Q�a^a^aN'aae•. axQnenaenm. marowimvc. mrea sr. mn x¢w Newco nnw>,. re anrcxns. cemuwmnrwnennxa:rsm moil Pipe Bwty C.nfigureban ( 5 (m> OD 0.362 cw Wall S-135) NIX "m Mi Bum cgwlM m V51 Pala er.aPi. Nominal 80% Inspection Class API Prenman class Pipe Tensile titre ew 71 100 560.800 560,000 Pipe Torsional Strength l^+nt 74AOD 58.100 56.100 TJfiYqeBody Torsional Ratio 0.97 124 124 80% Pipe Torsional S ts+wr 59.300 46-500 46,500 Burst 17,105 15.638 15.638 Cdla se Imi 15.672 10.029 10,029 Pipe OD cros 5.0130 4.855 4.855 Wall Thickness m, 0.362 0290 0.290 Norninal Pipe ID nmc 4276 4276 4276 Cross Sectional Area of Pipe Boil m-115275 4 154 4.154 Cross Sectorial Area of OD<m•zr 19.635 18.514 78.514 Gross Sectional Area of ID 4.360 114.360 14.360 Sedan mmuhu (ws)5.706 14476 4.476 Polar Section Modulus m'sr 11-415 18953 8.953 NIX "m Mi Bum cgwlM m V51 Pala er.aPi. Milne Point Unit E-40 SB Injector Hilcorp Drilling Procedure 500204050016200 Weatherford 5" 19.50 Ib/ft S-135 w/ NC 50 6-5/8" OD x 3-114" ID Tool Joint DRILL PIPE SPECIFICATIONS Grade I S-135 Connection NC 50 Interchangeable With 5' XH & 4-12" IF Upset Type IEU Nominal Weight per Foot 1 19.50 lbs Adjusted Weight With Tool Joint per Foot 1 23.08 lbs TOOL JOINT DATA Outside Diameter 6-5/8' Inside Diameter 3-1/4' API Drift 3-1/8' Rabbit OD, Suggested 3-1/16' Minimum Make-up Torque 25.900 ft-Ibs Maximum Recommend Make-up Torque 26.800 ft -lbs Torsional Yield Strength 51.700 ft -lbs Tensile Strength 1,269,000 Itis TUBE DATA New Premium Outside Diameter 5.000' 4.855' Inside Diameter 4.276" 4276" Wall Thickness 0.362" 0.290' Cross Sectional Area 5.275 sq in 4.154 sq in Maximum Hook Load(rensile Strength 712,000 lbs 560,800 lbs Slip Crushing / 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 Stren th 74.100 ft -lbs 58.100 ft-Ibs Capacity W/ Tool Joint 0.726 US gattft 0.726 US QaVft Displacement W/ Tool Joint 0.353 US oaVft 0.322 US clalfft 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 56 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-40 M P E -40i Plan: MPU E-40 wp04 Standard Proposal Report 27 February, 2019 HALLIBURTON Sperry Drilling Services MALLIBURTON S,o-v, CIHIH.g SECTION DETAILS So. MID AN WD +NI -S 4El-W Dleg Waco VSRc Target 1 26.50 0.00 0.00 26.50 0.00 DOD 0.00 0.00 000 2 20DDO 000 GAS 280.00 000 000 0.00 0.00 0,00 3 480.00 6.00 210.00 479.63 -9.06 323 3,00 210.00 -10.38 4 1674.12 48.81 132.62 1520.09 J89 61 312,83 4.00 -82,66 -120.10 5 3950.34 48.81 132.62 3027,21 -1549.34 1573.32 000 0.00 -27938 6 6455.63 050 17.35 4350.30 -76150 301 420 -110.99 1267.67 7 6625.63 85.0 17.35 4373,20 -599.85 3142.55 080 0.00 1426.87 MPE-Kayser ND Hoot 8 6749.37 09.95 17.31 437665 -481.80 3179.37 4A0 -0441543.03 9 1102234 0995 17.31 430.10 4361.27 4600.99 0.00 0.00 631083 MPE-Ko,or NS CPI ANnota110n Starz Dir YAW : 280' MD, 260'N1) Stan Dir 4.110:460' MD, 479.63'WD End Dir :16]4.12' MD, 1528.09' WD Stan Dir 4 2110:3950.31' MD, 3027.21'00 End Dir :6455.63' MD, 435898' WD Stan Dir 4°1100':662563' MD. 4373,2T 1) End Dir :67483T M0, 4370.65 WD 10 12000.16 09.95 17.31 4303.26 4531,03 1711.91 0,00 0.0 6477.]4 Stan DO 3°1100': 12000.18'MD, 438326'ND Project: Wine Point 11 12110.56 8995 14.00 4303.35 4637.33 4771.70 3.00 -90.00 6580.36 End Dir :12110.59' MD, 4303.35' TW Site: MPtEPad 12 12650.02 09.95 14AO 4383.82 5160.75 4902.20 0.00 0.0 7075.83 Slav Dir 3-110P: 12650.0' MD. 4383.62WD 0160; Plan: MPU E-40 13 13050.78 09.20 2A0 4386.81 5556 88 4957.88 3.00 -93.61 7424.]0 Entl Dir :13050]8' MD, 4385.81' TYl 14 14050.00 09.29 2.00 4400.76 655639 4992.74 0.00 0.90 6240A8 Toal D,lh: 1405V MD, 4a00.76'WD Wellbore: MPE-40i Design: MPU E40 wp00 REFERENCE INFORMATION WELL OETAIIb: Man: MPI] HO CooNnNe (W£i No%-: WNI Plan MPU E40, Two N" Gmmtl Lw ll'. 21.60 -500 Ve.ol(ND) Rok,om MPU E-10 Rannetl RKB®4B.tOm11 Eaalin -.Sft Ee y MPU E10 Planned RKR®48.10m11 +N46 +ELW 60l Kl9 9 lorpiMk Measuretl DeOW Relsuim: O.CO 0.0 fi01E010.]I 56932223 70"3T 14.]19N tI9.3e]SBOW GIruUOon M. Mm- C..." D � BVFVEY PROOMY CASINO DETAILS Stan nN 3-1109: 280MD, 260'NG u. A1e1619Tm1pm N4Jab1: Ye¢ NrsM. T- NI155 MO Blao Nema 7323 GSS.13 662800 8518 959'x12114' Sten GilellOO': IWMG..S]'ND 0.Pm R� wypry NaM NauyI+IMP_a Taol +1fP3Ib�bp .]fi 4352.65 IdO50.o0 8516 fi516'x81(1' 500 500 WIY.O] 14050.0 NRI Heg911MPE4ti1 LeMV'IFPNA6�Sa Hamm auxa, uc FORMATION TCY DETal6 rE. n MCN W'. Minim A CuvaWreEmom 1000 1000 lbblmadan dPs bewibEM nl NM: ]Dot.,Po N3D SoNce: Pedal C., MetlicA, Enm Rollo 160 M EDo : 1571.12' MD, 1528D9'TVD 1500 - " 40 4.rMOV 395934' MG. 3027,21T,C Al FO Mo m Syya$. a^' O OJ Oa 4� 9518' x 12114 MPE4 v,a ar NB Haat 500 1000 1500 2000 000 3500 4000 4500 5000 Vertical Section at 37.29° (1000 usfUin) MMES( moecPt AWE-Kaymr NS Toe 7500 8000 I- Mi 6 S9'x 811 REFERENCE INFORMATION Coartlinate (WE) Referenm: Well Plan: MPU E-00, 'me North Vemml (TVD) Reference: MPU E40 Planned RKB 048.10uaR Measured Depth Refemnm: MPU Edo Planned RKB ® 48. W us0 Gkulalioa Method: Minna, Cumalme WELL DL'T : Plan: MPU E-00 Ground i<vel: 21.60 +N/ -S =V -W N.nh Fasting Imitmde longitude 0.00 0.00 6016010.71 569322.23 70' 2114t749 N 141 z6' 3.530 W 5333 Project: CASING DETAILS Site: TVD TVDSS MD Size Name 4373.23 4325.13 6626.00 9-5/8 9 5/B' x 12 1/4" 4400.76 4352.66 14050.00 6-5/8 6 SM' x 812° REFERENCE INFORMATION Coartlinate (WE) Referenm: Well Plan: MPU E-00, 'me North Vemml (TVD) Reference: MPU E40 Planned RKB 048.10uaR Measured Depth Refemnm: MPU Edo Planned RKB ® 48. W us0 Gkulalioa Method: Minna, Cumalme WELL DL'T : Plan: MPU E-00 Ground i<vel: 21.60 +N/ -S =V -W N.nh Fasting Imitmde longitude 0.00 0.00 6016010.71 569322.23 70' 2114t749 N 141 z6' 3.530 W 5333 C HALLIBURTON - MPD E-00 wp04 6 SM' x 8 1/2" -4401 M@&Kayncr NB T Total 1k the 14050' MD, 4400.76- - - 400.]6' -- End Dir: 13050.78'M1ID,4386.81'TVD -Slav DU 3"/100: 12650 02' MD, 4383.82WD -- End Dir: 12110.58' Nm, 438335' TVD S. Dir 3°/100' : 12000.16 MD, 4383IMD 0�\ o Start Dir3"/100': 280MD, 280'TVD ,\ryyo End Dir : 6749.3TMg4378.65'3 -667 1 1 , 9 5/R" x 12 1/4" - - Start Dir 4°n00':6625.63'h0,43]l.2'IVD ry5� MP&Kaymcr ND Nce 61ar1 Dir 4°II00':4R0'MD, 4]9.631/0 yo° End Dir :6455.63' MD, 435838' TVD M1 ryrySo 4210 333 adDir:1674.12' hID, 1528.09' TVD - yH 8 J Start Dir 4Y/100': 3950.34 MD, 3027.21 -TVD o 0 667 1333 2000 2667 3333 4000 4667 5333 6000 6667 Wes -)/East(+) (1000 usft/m) Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-40 Wellbore: MPE-40i Plan: MPU E-40 Wp04 C HALLIBURTON - MPD E-00 wp04 6 SM' x 8 1/2" -4401 M@&Kayncr NB T Total 1k the 14050' MD, 4400.76- - - 400.]6' -- End Dir: 13050.78'M1ID,4386.81'TVD -Slav DU 3"/100: 12650 02' MD, 4383.82WD -- End Dir: 12110.58' Nm, 438335' TVD S. Dir 3°/100' : 12000.16 MD, 4383IMD 0�\ o Start Dir3"/100': 280MD, 280'TVD ,\ryyo End Dir : 6749.3TMg4378.65'3 -667 1 1 , 9 5/R" x 12 1/4" - - Start Dir 4°n00':6625.63'h0,43]l.2'IVD ry5� MP&Kaymcr ND Nce 61ar1 Dir 4°II00':4R0'MD, 4]9.631/0 yo° End Dir :6455.63' MD, 435838' TVD M1 ryrySo 4210 333 adDir:1674.12' hID, 1528.09' TVD - yH 8 J Start Dir 4Y/100': 3950.34 MD, 3027.21 -TVD o 0 667 1333 2000 2667 3333 4000 4667 5333 6000 6667 Wes -)/East(+) (1000 usft/m) HALLIBURTON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-40 Wellbore: MPE-40i Design: MPU E-40 wp04 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU E-40 MPU E-40 Planned RKB @ 48.10usft MPU E-40 Planned RKB @ 48.10usft True Minimum Curvature project 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 Site M Pt E Pad, TR -13-10 Site Position: From: Map Position Uncertainty: Northing: 6,013,798.68usft Latitude: Easting: 569,440.72usft Longitude: 0.00 usft Slot Radius: 0" Grid Convergence: Well Plan: MPU E-40 Model Name Sample Date Declination Dip Angle Well Position +N/ -S 0.00 usft Northing: 6,016,010.71 usft Latitude: +E/ -W 0.00 usft Easting: 569,322.23 usft Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: Wellbore MPE-40i 70.448 -149.434 0.53 0 70.454 -149.434 21.60 usft Magnetics Model Name Sample Date Declination Dip Angle Field Strength () (1) (nT) BGGM2018 4/1/2019 16.77 80.97 57,434.24620471 Design MPU E-40 wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 26.50 Vertical Section: Depth From (TVD) +NIS +El -W Direction (usft) (usft) (usft) (I 26.60 0.00 0.00 37.29 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NIS +El -W Rate Rate Rate Tool Face (usft) ("j M (usft) usft (usft) (usft) (o/100usft) (alloousft) (°It00usft) (') 26.50 0.00 0.00 26.50 -21.60 0.00 0.00 0.00 0.00 0.00 0.00 280.00 0.00 0.00 280.00 231.90 0.00 0.00 0.00 0.00 0.00 0.00 480.00 6.00 210.00 479.63 431.53 -9.06 -5.23 3.00 3.00 0.00 210.00 1,674.12 48.81 132.62 1,528.09 1.47999 -389.61 312.83 4.00 3.58 -6.48 -82.66 3,950.34 48.81 132.62 3,027.21 2,97911 -1,549.34 1,573.32 0.00 0.00 0.00 0.00 6,455.63 85.00 17.35 4,358.38 4,310.28 -761.50 3,092.05 4.20 1.44 -4.60 -110.99 6,625.63 85.00 17.35 4,373.20 4,325.10 -599.85 3,142.55 0.00 0.00 0.00 0.00 6,749.37 89.95 17.31 4,378.65 4,330.55 -481.88 3,179.37 4.00 4.00 -0.03 -0.44 11,822.34 89.95 17.31 4,383.10 4,335.00 4,361.27 4,688.99 0.00 0.00 0.00 0.00 12,000.16 89.95 17.31 4,383.26 4,335.16 4,531.03 4,741.91 0.00 0.00 0.00 0.00 12,110.58 89.95 14.00 4,383.35 4,335.25 4,637.33 4,771.70 3.00 0.00 -3.00 -90.00 12,650.02 89.95 14.00 4,383.82 4,335.72 5,160.75 4,902.20 0.00 0.00 0.00 0.00 13,050.78 89.20 2.00 4,386.81 4,338.71 5,556.88 4,957.88 3.00 -0.19 -2.99 -93.61 14,050.00 89.20 2.00 4,400.76 4,352.66 6,555.39 4,992.74 0.00 0.00 0.00 0.00 2272019 6:19:41 PM Page 2 COMPASS 5000.15 Build 91 Halliburton HALLIBURTON Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well Plan: MPU E-40 Company: Hiloorp Alaska, LLC TVD Reference: MPU E-40 Planned RKB @ 48.10usft Project: Milne Point MD Reference: MPU E-40 Planned RKB @ 48.10usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-40 Survey Calculation Method: Minimum Curvature Wellbore: MPE40i Design: MPU E-40 wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -21.60 26.50 0.00 0.00 26.50 -21.60 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 100.00 0.00 0.00 100.00 51.90 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 200.00 0.00 0.00 200.00 151.90 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 280.00 0.00 0.00 280.00 231.90 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 Start Dir 301100' : 280' MD, 280'TVD 300.00 0.60 210.00 300.00 251.90 -0.09 -0.05 6,016,010.62 569,322.18 3.00 -0.10 400.00 3.60 210.00 399.92 351.82 -3.26 -1.88 6,016,007.43 569,320.38 3.00 -3.74 480.00 6.00 210.00 479.63 431.53 -9.06 -5.23 6,016,001.60 569,317.08 3.00 -10.38 Start Dir 4-1100': 480' MD, 479.63'TVD 500.00 6.15 202.58 499.52 451.42 -10.96 -6.17 6,015,999.70 569,316.17 4.00 -12.45 600.00 8.14 174.14 598.77 550.67 -22.96 -7.50 6,015,987.69 569,314.94 4.00 -22.81 700.00 11.25 158.97 697.35 649.25 -39.12 -3.27 6,015,971.57 569,319.32 4.00 -33.10 800.00 14.79 150.63 794.77 746.67 -59.36 6.50 6,015,951.42 569,329.28 4.00 -43.29 900.00 18.52 145.51 890.56 842.46 -83.58 21.76 6,015,927.34 569,344.76 4.00 -53.31 1,000.00 22.34 142.08 984.25 936.15 -111.68 42.44 6,015,899.44 569,365.70 4.00 -63.13 1,100.00 26.21 139.61 1,075.40 1,027.30 -143.50 68.44 6,015,867.87 569,391.99 4.00 -72.69 1,200.00 30.11 137.74 1,163.55 1,115.45 -178.89 99.63 6,015,832.77 569,423.51 4.00 -81.95 1,300.00 34.03 136.26 1,248.27 1,200.17 -217.69 135.86 6,015,794.32 569,460.09 4.00 -90.86 1,400.00 37.97 135.06 1,329.16 1,281.06 -259.69 176.95 6,015,752.70 569,501.57 4.00 -99.38 1,500.00 41.92 134.05 1,405.81 1,357.71 -304.71 222.71 6,015,708.11 569,547.74 4.00 -107.47 1,600.00 45.87 133.18 1,477.86 1,429.76 -352.51 272.90 6,015,660.78 569,598.38 4.00 -115.09 1,674.12 48.81 132.62 1,528.09 1,479.99 -389.61 312.83 6,015,624.06 569,638.64 4.00 -120.40 End Dir : 1674.12' MD, 1528.09' TVD 1,700.00 48.81 132.62 1,545.13 1,497.03 -402.79 327.16 6,015,611.01 569,653.09 0.00 -122.21 1,800.00 48.81 132.62 1,610.99 1,562.89 -453.74 382.54 6,015,560.59 569,708.94 0.00 -129.19 1,900.00 48.81 132.62 1,676.85 1,628.75 -504.69 437.91 6,015,510.16 569,764.78 0.00 -136.17 2,000.00 48.81 132.62 1,742.71 1,694.61 -555.64 493.29 6,015,459.73 569,820.62 0.00 -143.15 2,100.00 48.81 132.62 1,808.57 1,760.47 -606.59 548.67 6,015,409.30 569,876.47 0.00 -150.13 2,200.00 48.81 132.62 1,874.43 1,826.33 -657.54 604.04 6,015,358.88 569,932.31 0.00 -157.11 2,300.00 48.81 132.62 1,940.29 1,892.19 -708.49 659.42 6,015,308.45 569,988.15 0.00 -164.09 2,400.00 48.81 132.62 2,006.15 1,958.05 -759.44 714.80 6,015,258.02 570,043.99 0.00 -171.07 2,500.00 48.81 132.62 2,072.01 2,023.91 -810.39 770.17 6,015,207.59 570,099.84 0.00 -178.05 2,600.00 48.81 132.62 2,137.87 2,089.77 -861.34 825.55 6,015,157.17 570,155.68 0.00 -185.03 2,700.00 48.81 132.62 2,203.73 2,155.63 -912.29 880.92 6,015,106.74 570,211.52 0.00 -192.01 2,800.00 48.81 132.62 2,269.59 2,221.49 -963.24 936.30 6,015,056.31 570,267.36 0.00 -198.99 2,900.00 48.81 132.62 2,335.45 2,287.35 -1,014.19 991.68 6,015,005.88 570,323.21 0.00 -205.97 3,000.00 48.81 132.62 2,401.31 2,353.21 -1,065.14 1,047.05 6,014,955.46 570,379.05 0.00 -212.95 3,100.00 48.81 132.62 2,467.18 2,419.08 -1,116.09 1,102.43 6,014,905.03 570,434.89 0.00 -219.93 3,200.00 48.81 132.62 2,533.04 2,484.94 -1,167.04 1,157.81 6,014,854.60 570,490.73 0.00 -226.91 3,300.00 48.81 132.62 2,598.90 2,550.80 -1,217.99 1,213.18 6,014,804.17 570,546.58 0.00 -233.89 3,400.00 48.81 132.62 2,664.76 2,616.66 -1,268.94 1,268.56 6,014,753.74 570,602.42 0.00 -240.87 3,500.00 48.81 132.62 2,730.62 2,682.52 -1,319.89 1,323.93 6,014,703.32 570,658.26 0.00 -247.85 3,600.00 48.81 132.62 2,796.48 2,748.38 -1,370.84 1,379.31 6,014,652.89 570,714.10 0.00 -254.83 3,700.00 48.81 132.62 2,862.34 2,814.24 -1,421.79 1,434.69 6,014,602.46 570,769.95 0.00 -261.81 3,800.00 48.81 132.62 2,928.20 2,880.10 -1,472.74 1,490.06 6,014,552.03 570,825.79 0.00 -268.79 2,272019 6:19:41PM Page 3 COMPASS 5000.15 Build 91 Halliburton HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU E-40 Company: Hilcom Alaska, LLC TVD Reference: MPU E-40 Planned RKB @ 48.10usft Project: Milne Point MD Reference: MPU E-40 Planned IRKS @ 48.10usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-40 Survey Calculation Method: Minimum Curvature Wellbore: MPE-40i Design: MPU E-40 wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Nl-S +El -W Northing Easting DLS Vert Section (usft) (1) (0) (usft) usft (usft) (usft) (usft) (usft) 2,945.96 3,900.00 48.81 132.62 2,994.06 2,945.96 -1,523.69 1,545.44 6,014,501.61 570,881.63 0.00 -275.77 3,950.34 48.81 132.62 3,027.21 2,979.11 -1,549.34 1,573.32 6,014,476.22 570,909.74 0.00 -279.28 Start Dir 4.201100' : 3950.34' MD, 3027.21'TVD 4,000.00 48.09 130.00 3,060.15 3,012.05 -1,573.87 1,601.22 6,014,451.95 570,937.88 4.20 -281.89 4,100.00 46.83 124.56 3,127.79 3,079.69 -1,618.49 1,659.79 6,014,407.88 570,996.85 4.20 -281.91 4,200.00 45.84 118.92 3,196.86 3,148.76 -1,656.54 1,721.24 6,014,370.41 571,058.65 4.20 -274.94 4,300.00 45.14 113.11 3,267.00 3,218.90 -1,687.81 1,785.27 6,014,339.74 571,122.95 4.20 -261.02 4,400.00 44.73 107.19 3,337.82 3,289.72 -1,712.13 1,851.51 6,014,316.04 571,189.42 4.20 -240.23 4,500.00 44.64 101.22 3,408.95 3,360.85 -1,729.37 1,919.62 6,014,299.44 571,257.68 4.20 -212.68 4,600.00 44.86 95.26 3,480.00 3,431.90 -1,739.43 1,989.23 6,014,290.02 571,327.37 4.20 -178.51 4,700.00 45.38 89.37 3,550.60 3,502.50 -1,742.28 2,059.97 6,014,287.84 571,398.12 4.20 -137.91 4,800.00 46.20 83.62 3,620.36 3,572.26 -1,737.88 2,131.45 6,014,292.90 571,469.56 4.20 -91.10 4,900.00 47.30 78.06 3,688.91 3,640.81 -1,726.26 2,203.30 6,014,305.18 571,541.28 4.20 -38.33 5,000.00 48.65 72.71 3,755.88 3,707.78 -1,707.49 2,275.12 6,014,324.62 571,612.92 4.20 20.12 5,100.00 50.25 67.59 3,820.91 3,772.81 -1,681.67 2,346.53 6,014,351.10 571,684.08 4.20 83.93 5,200.00 52.06 62.72 3,883.65 3,835.55 -1,648.93 2,417.15 6,014,384.50 571,754.38 4.20 152.77 5,300.00 54.06 58.10 3,943.77 3,895.67 -1,609.45 2,486.59 6,014,424.62 571,823.45 4.20 226.25 5,400.00 56.23 53.72 4,000.94 3,952.84 -1,563.44 2,554.49 6,014,471.25 571,890.91 4.20 303.99 5,500.00 58.54 49.55 4,054.86 4,006.76 -1,511.15 2,620.48 6,014,524.14 571,956.41 4.20 385.57 5,600.00 60.98 45.60 4,105.23 4,057.13 -1,452.87 2,684.21 6,014,583.02 572,019.58 4.20 470.55 5,700.00 63.54 41.83 4,151.78 4,103.68 -1,388.89 2,745.33 6,014,647.55 572,080.10 4.20 558.48 5,800.00 66.18 38.23 4,194.27 4,146.17 -1,319.58 2,803.51 6,014,717.40 572,137.63 4.20 648.88 5,900.00 68.91 34.77 4,232.47 4,184.37 -1,245.29 2,858.45 6,014,792.18 572,191.87 4.20 741.26 6,000.00 71.71 31.44 4,266.17 4,218.07 -1,166.43 2,909.84 6,014,871.51 572,242.52 4.20 835.14 6,100.00 74.56 28.22 4,295.19 4,247.09 -1,083.43 2,957.42 6,014,954.95 572,289.32 4.20 930.00 6,200.00 77.46 25.09 4,319.37 4,271.27 -996.72 3,000.92 6,015,042.05 572,332.01 4.20 1,025.33 6,300.00 80.39 22.02 4,338.59 4,290.49 -906.77 3,040.11 6,015,132.35 572,370.36 4.20 1,120.64 6,400.00 83.35 19.01 4,352.74 4,304.64 -814.07 3,074.79 6,015,225.35 572,404.16 4.20 1,215.39 6,455.63 85.00 17.35 4,358.38 4,310.28 -761.50 3,092.05 6,015,278.08 572,420.94 4.20 1,267.68 End Dir : 6455.63' MD, 4358.38' TVD 6,500.00 85.00 17.35 4,362.25 4,314.15 -719.31 3,105.23 6,015,320.39 572,433.72 0.00 1,309.23 6,600.00 85.00 17.35 4,370.97 4,322.87 -624.22 3,134.94 6,015,415.74 572,462.54 0.00 1,402.87 6,625.63 85.00 17.35 4,373.20 4,325.10 -599.85 3,142.55 6,015,440.18 572,469.93 0.00 1,426.87 Start Dir 401100' : 6625.63' MD, 4373.2'TVD 6,626.00 85.01 17.35 4,373.23 4,325.13 -599.50 3,142.66 6,015,440.53 572,470.04 4.05 1,427.22 9 518" x 12 114" 6,700.00 87.97 17.33 4,377.76 4,329.66 -529.00 3,164.67 6,015,511.22 572,491.39 4.00 1,496.64 6,749.37 89.95 17.31 4,378.65 4,330.55 -481.88 3,179.37 6,015,558.48 572,505.64 4.00 1,543.03 End Dir : 6749.37' MD, 4378.65' TVD 6,800.00 89.95 17.31 4,378.69 4,330.59 -433.54 3,194.43 6,015,606.95 572,520.26 0.00 1,590.61 6,900.00 89.95 17.31 4,378.78 4,330.68 -338.07 3,224.19 6,015,702.68 572,549.12 0.00 1,684.59 7,000.00 89.95 17.31 4,378.87 4,330.77 -242.60 3,253.95 6,015,798.41 572,577.99 0.00 1,778.57 7,100.00 89.95 17.31 4,378.96 4,330.86 -147.13 3,283.71 6,015,894.15 572,606.85 0.00 1,872.55 7,200.00 89.95 17.31 4,379.05 4,330.95 -51.66 3,313.46 6,015,989.88 572,635.72 0.00 1,966.53 7,300.00 89.95 17.31 4,379.13 4,331.03 43.80 3,343.22 6,016,085.61 572,664.58 0.00 2,060.51 2272019 6:19:41 PM Page 4 COMPASS 5000.15 Build 91 Halliburton HA LL I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU E-40 Company: Hilcorp Alaska, LLC TVD Reference: MPU E-40 Planned RKB @ 48.10usft Project: Milne Point MD Reference: MPU E-40 Planned RKB @ 48.10usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-40 Survey Calculation Method: Minimum Curvature Wellbore: MPE-40i Design: MPU E-40 wp04 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting OLS Vert Section (usft) (1) (1 (usft) usft (usft) (usft) (usft) (usft) 4,331.12 7,400.00 89.95 17.31 4,379.22 4,331.12 139.27 3,372.98 6,016,181.35 572,693.45 0.00 2,154.49 7,500.00 89.95 17.31 4,379.31 4,331.21 234.74 3,402.74 6,016,277.08 572,722.32 0.00 2,248.48 7,600.00 89.95 17.31 4,379.40 4,331.30 330.21 3,432.50 6,016,372.81 572,751.18 0.00 2,342.46 7,700.00 89.95 17.31 4,379.48 4,331.38 425.68 3,462.26 6,016,468.54 572,780.05 0.00 2,436.44 7,800.00 89.95 17.31 4,379.57 4,331.47 521.15 3,492.01 6,016,564.28 572,808.91 0.00 2,530.42 7,900.00 89.95 17.31 4,379.66 4,331.56 616.62 3,521.77 6,016,660.01 572,837.78 0.00 2,624.40 8,000.00 89.95 17.31 4,379.75 4,331.65 712.09 3,551.53 6,016,755.74 572,866.65 0.00 2,718.38 8,100.00 89.95 17.31 4,379.83 4,331.73 807.56 3,581.29 6,016,851.48 572,895.51 0.00 2,812.36 8,200.00 89.95 17.31 4,379.92 4,331.82 903.03 3,611.05 6,016,947.21 572,924.38 0.00 2,906.34 8,300.00 89.95 17.31 4,380.01 4,331.91 998.50 3,640.80 6,017,042.94 572,953.24 0.00 3,000.32 8,400.00 89.95 17.31 4,380.10 4,332.00 1,093.97 3,670.56 6,017,138.68 572,982.11 0.00 3,094.30 8,500.00 89.95 17.31 4,380.19 4,332.09 1,189.44 3,700.32 6,017,234.41 573,010.98 0.00 3,188.28 8,600.00 89.95 17.31 4,380.27 4,332.17 1,284.91 3,730.08 6,017,330.14 573,039.84 0.00 3,282.26 8,700.00 89.95 17.31 4,380.36 4,332.26 1,380.38 3,759.84 6,017,425.88 573,068.71 0.00 3,376.24 8,800.00 89.95 17.31 4,380.45 4,332.35 1,475.85 3,789.60 6,017,521.61 573,097.57 0.00 3,470.22 8,900.00 89.95 17.31 4,380.54 4,332.44 1,571.32 3,819.35 6,017,617.34 573,126.44 0.00 3,564.20 9,000.00 89.95 17.31 4,380.62 4,332.52 1,666.79 3,849.11 6,017,713.08 573,155.31 0.00 3,658.18 9,100.00 89.95 17.31 4,380.71 4,332.61 1,762.26 3,878.87 6,017,808.81 573,184.17 0.00 3,752.16 9,200.00 89.95 17.31 4,380.80 4,332.70 1,857.73 3,908.63 6,017,904.54 573,213.04 0.00 3,846.14 9,300.00 89.95 17.31 4,380.89 4,332.79 1,953.20 3,938.39 6,018,000.28 573,241.90 0.00 3,940.12 9,400.00 89.95 17.31 4,380.98 4,332.88 2,048.67 3,968.14 6,018,096.01 573,270.77 0.00 4,034.10 9,500.00 89.95 17.31 4,381.06 4,332.96 2,144.14 3,997.90 6,018,191.74 573,299.63 0.00 4,128.08 9,600.00 89.95 17.31 4,381.15 4,333.05 2,239.61 4,027.66 6,018,287.48 573,328.50 0.00 4,222.06 9,700.00 89.95 17.31 4,381.24 4,333.14 2,335.07 4,057.42 6,018,383.21 573,357.37 0.00 4,316.04 9,800.00 89.95 17.31 4,381.33 4,333.23 2,430.54 4,087.18 6,018,478.94 573,386.23 0.00 4,410.02 9,900.00 89.95 17.31 4,381.41 4,333.31 2,526.01 4,116.94 6,018,574.68 573,415.10 0.00 4,504.00 10,000.00 89.95 17.31 4,381.50 4,333.40 2,621.48 4,146.69 6,018,670.41 573,443.96 0.00 4,597.98 10,100.00 89.95 17.31 4,381.59 4,333.49 2,716.95 4,176.45 6,018,766.14 573,472.83 0.00 4,691.96 10,200.00 89.95 17.31 4,381.68 4,333.58 2,812.42 4,206.21 6,018,861.88 573,501.70 0.00 4,785.94 10,300.00 89.95 17.31 4,381.76 4,333.66 2,907.89 4,235.97 6,018,957.61 573,530.56 0.00 4,879.92 10,400.00 89.95 17.31 4,381.85 4,333.75 3,003.36 4,265.73 6,019,053.34 573,559.43 0.00 4,973.91 10,500.00 89.95 17.31 4,381.94 4,333.84 3,098.83 4,295.48 6,019,149.08 573,588.29 0.00 5,067.89 10,600.00 89.95 17.31 4,382.03 4,333.93 3,194.30 4,325.24 6,019,244.81 573,617.16 0.00 5,161.87 10,700.00 89.95 17.31 4,382.12 4,334.02 3,289.77 4,355.00 6,019,340.54 573,646.03 0.00 5,255.85 10,800.00 89.95 17.31 4,382.20 4,334.10 3,385.24 4,384.76 6,019,436.28 573,674.89 0.00 5,349.83 10,900.00 89.95 17.31 4,382.29 4,334.19 3,480.71 4,414.52 6,019,532.01 573,703.76 0.00 5,443.81 11,000.00 89.95 17.31 4,382.38 4,334.28 3,576.18 4,444.28 6,019,627.74 573,732.62 0.00 5,537.79 11,100.00 89.95 17.31 4,382.47 4,334.37 3,671.65 4,474.03 6,019,723.48 573,761.49 0.00 5,631.77 11,200.00 89.95 17.31 4,382.55 4,334.45 3,767.12 4,503.79 6,019,819.21 573,790.35 0.00 5,725.75 11,300.00 89.95 17.31 4,382.64 4,334.54 3,862.59 4,533.55 6,019,914.94 573,819.22 0.00 5,819.73 11,400.00 89.95 17.31 4,382.73 4,334.63 3,958.06 4,563.31 6,020,010.68 573,848.09 0.00 5,913.71 11,500.00 89.95 17.31 4,382.82 4,334.72 4,053.53 4,593.07 6,020,106.41 573,876.95 0.00 6,007.69 11,600.00 89.95 17.31 4,382.90 4,334.80 4,149.00 4,622.83 6,020,202.14 573,905.82 0.00 6,101.67 11,700.00 89.95 17.31 4,382.99 4,334.89 4,244.47 4,652.58 6,020,297.88 573,934.68 0.00 6,195.65 11,800.00 89.95 17.31 4,383.08 4,334.98 4,339.94 4,682.34 6,020,393.61 573,963.55 0.00 6,289.63 2272019 6:19:41 PM Page 5 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-40 Wellbore: MPE40i Design: MPU E-40 wp04 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (usft) (1) (') (usft) usft 11,822.34 89.95 17.31 4,383.10 4,335.00 11,900.00 89.95 17.31 4,383.17 4,335.07 12,000.16 89.95 17.31 4,383.26 4,335.16 Start Dir 30/100': 12000.16' MD, 4383.26 -TVD 12,100.00 89.95 14.32 4,383.34 4,335.24 12,110.58 89.95 14.00 4,383.35 4,335.25 End Dir : 12110.58' MD, 4383.35' TVD 12,200.00 89.95 14.00 4,383.43 4,335.33 12,300.00 89.95 14.00 4,383.52 4,335.42 12,400.00 89.95 14.00 4,383.61 4,335.51 12,500.00 89.95 14.00 4,383.69 4,335.59 12,600.00 89.95 14.00 4,383.78 4,335.68 12,650.02 89.95 14.00 4,383.82 4,335.72 Start Dir 3°1100' : 12650.02' MD, 4383.82 -TVD 12,700.00 89.86 12.50 4,383.91 4,335.81 12,800.00 89.67 9.51 4,384.32 4,336.22 12,900.00 89.48 6.52 4,385.07 4,336.97 13,000.00 89.29 3.52 4,386.14 4,338.04 13,050.78 89.20 2.00 4,386.81 4,338.71 End Dir :13050.78- MD, 4386.81' TVD 13,100.00 89.20 2.00 4,387.49 4,339.39 13,200.00 89.20 2.00 4,388.89 4,340.79 13,300.00 89.20 2.00 4,390.29 4,342.19 13,400.00 89.20 2.00 4,391.68 4,343.58 13,500.00 89.20 2.00 4,393.08 4,344.98 13,600.00 89.20 2.00 4,394.48 4,346.38 13,700.00 89.20 2.00 4,395.87 4,347.77 13,800.00 89.20 2.00 4,397.27 4,349.17 13,900.00 89.20 2.00 4,398.66 4,350.56 14,000.00 89.20 2.00 4,400.06 4.351.96 14,050.00 . 89.20 2.00 4,400.76 • 4,352.66 Total Depth: 14050' MD, 4400.76' TVD Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU E-40 TVD Reference: MPU E-40 Planned RKB @ 48.10usft MD Reference: MPU E-40 Planned RKB @ 48.10usft North Reference: True Survey Calculation Method: Minimum Curvature 2/272019 6:19:41 PM Page 6 COMPASS 5000.15 Build 91 Map Map +N/ -S +EI -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 4,335.00 4,361.27 4,688.99 6,020,415.00 573,970.00 0.00 6,310.63 4,435.41 4,712.10 6,020,489.34 573,992.42 0.00 6,383.61 4,531.03 4,741.91 6,020,585.23 574,021.33 0.00 6,477.74 4,627.08 4,769.11 6,020,681.52 574,047.64 3.00 6,570.64 4,637.34 4,771.70 6,020,691.80 574,050.13 3.00 6,580.37 4,724.10 4,793.33 6,020,778.75 574,070.95 0.00 6,662.50 4,821.13 4,817.52 6,020,875.99 574,094.24 0.00 6,754.35 4,918.16 4,841.72 6,020,973.24 574,117.52 0.00 6,846.20 5,015.19 4,865.91 6,021,070.48 574,140.81 0.00 6,938.04 5,112.22 4,890.10 6,021,167.72 574,164.10 0.00 7,029.89 5,160.75 4,902.20 6,021,216.36 574,175.74 0.00 7,075.84 5,209.40 4,913.66 6,021,265.11 574,186.75 3.00 7,121.48 5,307.55 4,932.75 6,021,363.42 574,204.92 3.00 7,211.13 5,406.56 4,946.68 6,021,462.54 574,217.93 3.00 7,298.34 5,506.16 4,955.43 6,021,562.21 574,225.75 3.00 7,382.87 5,556.87 4,957.88 6,021,612.94 574,227.72 3.00 7,424.70 5,606.06 4,959.59 6,021,662.14 574,228.98 0.00 7,464.87 5,705.99 4,963.08 6,021,762.08 574,231.54 0.00 7,546.48 5,805.92 4,966.57 6,021,862.03 574,234.10 0.00 7,628.09 5,905.85 4,970.06 6,021,961.98 574,236.66 0.00 7,709.70 6,005.78 4,973.55 6,022,061.93 574,239.22 0.00 7,791.32 6,105.71 4,977.04 6,022,161.88 574,241.78 0.00 7,872.93 6,205.63 4,980.53 6,022,261.83 574,244.34 0.00 7,954.54 6,305.56 4,984.02 6,022,361.77 574,246.90 0.00 8,036.15 6,405.49 4,987.51 6,022,461.72 574,249.46 0.00 8,117.76 6,505.42 4,991.00 6,022,561.67 574,252.02 0.00 8,199.38 6,555.39 4,992.74 6,022,611.64 574,253.30 0.00 8,240.18 2/272019 6:19:41 PM Page 6 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilwrp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-40 Wellbore: MPE-40i Design: MPU E-40 wp04 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 (1) (usft) (usft) Halliburton Standard Proposal Report Well Plan: MPU E-40 MPU E40 Planned RKB @ 48.10usft MPU E-40 Planned RKB @ 48.10usft True Minimum Curvature +E/ -W Northing Easting (usft) (usft) (usft) MPE-Kayner NB Heel 0.00 0.00 4,373.10 -749.58 3,092.22 6,015,290.00 572,421.00 - plan misses target center by 14.08usft at 6468.30usft MD (4359.49 TVD, -749.45 N, 3095.81 E) Depth Depth -Circle (radius 100.00) +El -W MPE-Kayner NB Toe 0.00 0.00 4,398.10 6,574.35 4,820.60 6,022,629.00 574,081.00 - plan misses target center by 173.21usft at 14050.00usft MD (4400.76 TVD, 6555.39 N, 4992.74 E) (usft) - Point 280.00 280.00 MPE-Kayner NB CPI 0.00 0.00 4,383.10 4,361.27 4,688.99 6,020,415.00 573,970.00 - plan hits target center 480.00 479.63 - Point _ -- Casing Points 1,674.12 1,528.09 Measured Vertical Casing Hole 312.83 Depth Depth Diameter Diameter 3,027.21 (usft) (usft) Name O ( ) 1,573.32 6,626.00 4,373.23 9 5/8" x 12 1/4" 9-5/8 12-1/4 4,358.38 14,050.00 4,400.76 6 5/8" x 8 1/2" 6-5/8 8-1/2 3,092.05 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NIS +El -W (usft) (usft) (usft) (usft) 280.00 280.00 0.00 0.00 480.00 479.63 -9.06 -5.23 1,674.12 1,528.09 -389.61 312.83 3,950.34 3,027.21 -1,549.34 1,573.32 6,455.63 4,358.38 -761.50 3,092.05 6,625.63 4,373.20 -599.85 3,142.55 6,749.37 4,378.65 -481.88 3,179.37 12,000.16 4,383.26 4,531.03 4,741.91 12,110.58 4,383.35 4,637.34 4,771.70 12,650.02 4,383.82 5,160.75 4,902.20 13,050.78 4,386.81 5,556.87 4,957.88 14.050.00 4,400.76 6,555.39 4,992.74 Comment Start Dir 30/100' : 280' MD, 280'TVD Start Dir 4°/100' : 480' MD, 479.63 -TVD End Dir : 1674.12' MD, 1528.09' TVD Start Dir 4.20/100': 3950.34' MD, 3027.2l'TVD End Dir : 6455.63' MD, 4358.38' TVD Start Dir 401100': 6625.63' MD, 4373.2TVD End Dir : 6749.37' MD, 4378.65' TVD Start Dir 301100': 12000.16' MD, 4383.26'TVD End Dir : 12110.58' MD, 4383.35' TVD Start Dir 30/100': 12650.02' MD, 4383.82 -TVD End Dir : 13050.78' MD, 4386.81' TVD Total Depth : 14050' MD, 4400.76' TVD 2/272019 6:19:41PM Page 7 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-40 MPE-40i MPU E-40 wp04 Sperry Drilling Services Clearance Summary Anticollision Report 27 February, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU E40 - MPE30i - MPU E40 wp04 Well Coordinates: 6,016,010.71 N, 569,322.23 E (70" 27' 14.75" N, 149° 26' 03.53" W( Datum Height: MPU E-40 Planned RKD @ 46.10usft Scan Range: 26.50 to 6,626.00 daft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 exit Geodetic Scale Factor Applied Version: 5000.15 Build: g1 Scan Type: Scan Type: 25.00 e HALLIBURTON Sperry Drilling Services Hilcorp Alaska, LLC Milne Point HALLIBURTON Anticollision Report for Plan: MPU E-40 - MPU E-40 wp04 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: MPt E Pad - Plan: MPU E40-MPE40i-MPU E40 wpD4 Scan Range: 26.50 to 6,626.00 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 Dosed on ration Warning Site Name Depth Distance Depth Separation Depth FactoSer Minimum P° g Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft M Pt E Pad MPE-04-MPE-04-MPE-04 MPE-04 - MPE-04 - MPE 0 MPE-05 - MPE-05 - MPE-05 MPE-05 - MPE-05 - MPE-05 MPE4l5-MPE4)5-MPE4)5 MPE-08 - MPE-08 - MPE-08 MPE-08 - MPE-08 - MPE-08 MPE-08- MPE-08 - MPE-08 MPE-09 - MPE-09 - MPE-09 MPE-09 - MPE-09 - MPE-D9 MPE-09 - MPE-09 - MPE-09 MPE-09 - MPE-09PB1 - MPE-09PB1 MPE-09 - MPE-09PB1 - MPE-D9PB1 MPE-09 - MPE-09PB1 - MPE-09PB1 MPE-10 - MPE-10 - MPE-10 MPE-10 - MPE-10 - MPE-10 MPE-10 - MPE-10 - MPE-10 MPE-11 - MPE-11 - MPE-11 MPE-11 - MPE-11 - MPE-11 MPE42-MPE-12-MPE-12 MPE-12 - MPE-12 - MPE-12 MPE-12 - MPE-12 - MPE-12 MPE-14 - MPE-14 - MPE-14 MPE-14 - MPE-14 - MPE-14 MPE-14 - MPE-14 - MPE-14 MPE-14 - MPE-14A- MPE-14A MPE-14 - MPE-14A- MPE-14A MPE-14 - MPE-14A- MPE-14A 26.50 494.50 26.50 493.58 36.13 539.770 Centre Distance Pass - 6,626.00 596.38 6,626.00 406.12 5,857.40 3.135 Clearance Factor Pass - 26.50 439.53 2650 43861 37A8 479.818 Centre Distance Pass - 301.50 440.68 301.50 437.37 313.26 133.127 Ellipse Separation Pass - 6,051.50 753.80 6,051.50 664.30 5,696.02 8.422 Cleamoce Factor Pass - 26.50 675.38 26.50 674.31 34.50 632.315 Centre Distance Pass - 301.50 676.72 301.50 673.42 309.77 205.405 Ellipse Separation Pass - 2,251.50 1,489.18 2,251.50 1,466.99 2,093.12 67.117 Clearance Factor Pass - 287.83 330.39 287.83 327.75 294.36 124.745 Centre Distance Pass - 326.50 330.52 326.50 327.61 332.97 113.400 Ellipse Separation Pass - 5,601.50 668.04 5,601.50 379.54 5,712.23 2.316 Clearance Factor Pass - 287.83 330.39 287.83 327.75 294.36 124.745 Centre Distance Pass - 326.50 330.52 326.50 327.61 332.97 113.400 Ellipse Separation Pass - 5,601.50 668.04 5,601.50 379.43 5,712.23 2.315 Clearance Factor Pass - 26.50 510.63 26.50 509.71 31.73 556.069 Centre Distance Pass - 351.50 512.54 351.50 508.80 360.26 137.038 Ellipse Separation Pass - 6,501.50 782.26 6,501.50 654.75 5.940.73 6.135 Clearance Factor Pass - 5,068.70 104.56 5,068.70 40.39 5,497.91 1,629 Centro Distance Pass - 5,126.50 113.82 5,126.50 30.51 5,535.31 1.366 Clearance Factor Pass - 2650 218.49 26.50 217.41 35.74 203.070 Centre Distance Pass - 276.50 219.08 276.50 215.34 283.37 58.507 Ellipse Separation Pass - 526.50 242.95 526.50 237.56 517.79 45.012 Clearance Factor Pass - 270.09 150.20 270.09 147.86 279.69 64.181 Centre Distance Pass - 301.50 150.26 301.50 147.70 311.03 56720 Ellipse Separation Pass - 3,376.50 1,493.71 3,37650 1,446.10 3,392.81 31.373 Clearance Factor Pass - 270.09 150.20 270.09 147.86 279.69 64.181 Centre Distance Pass - 301.50 150.26 301.50 147.70 311.03 58.720 Ellipse Separation Pass - 3,376.50 1,493.71 3,376.50 1,446.41 3,392.81 31.578 Clearance Factor Pass - 27 February, 2019 - 18:16 Page 2 of 8 COMPASS Hilcorp Alaska, LLC Milne Point HALLIBURTON Anticollision Report for Plan: MPU E-40. MPU E-40 wp04 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: MPt E Pad - Plan: MPU EdO-MPE-40i-MPU Edo wp04 Scan Range: 26.50 to 6,626.00 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 Summery Based on Separation Warning Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft MPE-14-MPE-I4APB1-MPE-I4APB1 270.09 150.20 270.09 147.86 279.69 64.181 Centre Distance Pass- MPE-14-MPE-I4APB1-MPE-I4APB1 301.50 15026 301.50 147.70 311.03 58.720 Ellipse Separation Pass - MPE-14-MPE-I4APBi-MPE-14AP81 3,376.50 1,493.71 3,376.50 1,446.40 3,392.81 31.575 Clearance Factor Pass - MPE-15-MP&15-MPE-15 307.78 119.94 307.78 115.41 314.22 26.487 Centre Distance Pass - MPE-1 5 - MPE-1 5 - MPE-1 5 376.50 120.35 376.50 114.82 382.99 21.765 Ellipse Separation Pass - MPE-1 5 - MPE-1 5 - MPE-1 5 751.50 156.00 751.50 144.92 756.67 14.083 Cleamnce Factor Pass- MPE-17-MPE-17-MPE-17 78.72 199.01 78.72 197.67 84.22 149.446 Centre Distance Pass - MPE-17-MPE-17-MPE-17 276.50 199.72 276.50 196.65 280.80 65.056 Ellipse Separation Pass - MPE-1 7 - MPE-1 7 - MPEA 7 5,501.50 1,230.85 5,501.50 1,087.22 5,112.31 8.569 Clearance Factor Pass - MPE-20 - MPE-20 - MPE-20 348.51 209.26 348.51 205.90 357.01 62.383 Centre Distance Pass- MPE-20-MPE-20-MPE-20 376.50 209.37 376.50 205.82 WAS 59.048 Ellipse Separation Pass - MPE-20 - MPE-20 - MPE-20 851.50 271.65 851.50 264.72 851.85 39.209 Clearance Factor Pass- MPE-20 - MPE-20A - MPE-20A 348.51 209.26 348.51 205.90 361.76 62.383 Centre Distance Pass - MPE-20 - MPE-20A- MPE-20A 376.50 209.37 376.50 205.82 389.24 59.048 Ellipse Separation Pass- MPE-20-MPE-20A-MPE-20A 851.50 271.65 851.50 264.72 856.60 39.209 Clearance Factor Pass - MPE-20-MPE-20AL1-MPE-20AL1 348.51 209.26 348.51 205.90 361.76 62.383 Centre Distance Pass - MPE-20-MPE-20AL1-MPE-20AL1 376.50 209.37 376.50 205.82 389.24 59.048 Ellipse Separation Pass- MPE-20-MPE-20AL1-MPE-20AL1 851.50 271.65 851.50 264.72 856.60 39.209 Clearance Factor Pass - MPE-20-MPE-20AL1 P91-MPE-20AL1 PB1 348.51 20926 348.51 205.90 361.76 62.383 Centre Distance Pass - MPE-20-MPE-20AL1PB1-MPE-20AL1PB1 376.50 209.37 376.50 20582 389.24 59.048 Ellipse Separation Pass - MPE-20-MPE-20AL1 PBI-MPE-20AL1 Pa 851.50 271.65 851.50 264.72 858.60 39.209 Clearance Factor Pass- MPE-21-MPE-21-MPE-21 279.53 339.05 279.53 336.94 288.80 161.106 Centre Distance Pass - MPE-21 - MPE-21 - MPE-21 301.50 339.11 301.50 336,89 310.80 152.718 Ellipse Separation Pass - MPE-21-MPE-21-MPE-21 6.526.50 787.33 6,526.50 657.21 5,990.00 6.051 Clearance Factor Pass- MPE-22-MPE-22-MPE-22 5,201.50 182.78 5,201.50 97.33 5,640.53 2.139 Clearance Factor Pass - MPE-22 - MPE-22 - MPE-22 5.226.50 176.04 5,226.50 95.05 5,655.43 2.174 Ellipse Separation Pass- MPE-22-MPE-22-MPE-22 5,294.40 167.72 5,294.40 102.84 5,695.22 2.585 Centre Distance Pass - MPE-23-MPE-23-MPE-23 6,551.50 131.67 6,551.50 62.15 6,178.34 1.894 Clearance Factor pass - MPE-23-MPE-23-MPE-23 6,626.00 102.41 6.626.00 51.66 6,185.69 2.018 Ellipse Separation Pass - MPE-24 - MPE-24 - MPE-24 282.61 179.61 282.61 177.16 291.79 73.306 Centre Distance Pass - 27 February, 2019 - 18:16 Page 3 of 8 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU E-40. MPU E-40 wpO4 282.61 179.61 282.61 177.27 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 76]32 Centre Distance pass - MPE-24-MPE-24ALl-MPE-24AL1 326.50 179.81 Reference Design: MPt E Pad - Plan: MPU Ed0-MPE401-MPU Edo wp04 177.17 332.00 68.047 Ellipse Separation Pass - MPE-24-MPE-24AL1-MPE-24AL1 Scan Range: 26.50 to 6,626.00 usft. Measured Depth. 1,496.78 3,251.50 1,431.38 3,057.67 22.885 Clearance Factor Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft MPE-30-MPE-30AL1-MPE-30ALl 333.93 391.20 333.93 Measured Minimum ®Measured Ellipse @Measured Clearance Summary Based on Separation Warning P 9 Site Name Depth Distance Depth Separation Depth Factor Minimum Pass- Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 550.80 1,028.33 MPE-24-MPE-24-MPE-24 326.50 179.81 326.50 177.06 335.40 65.342 Ellipse Separation Pass - MPE-24 - MPE-24 - MPE-24 3,251.50 1.496.78 3,251.50 1,431.17 3,061.07 22.811 Clearance Factor pass - MPE-24-MPE-24A-MPE-24A 282.61 179.61 282.61 177.27 288.39 76.732 Centre Distance Pass- MPE-24-MPE-24A-MPE-24A 326.50 179.81 326.50 177.17 332.00 68.047 Ellipse Separation Pass - MPE-24 - MPE-24A - MPE-24A 3,251.50 1,496.78 3,251.50 1,431.45 3,057.67 22.910 Clearance Factor Pass - MPE-24-MPE-24AL1-MPE-24AL1 282.61 179.61 282.61 177.27 288.39 76]32 Centre Distance pass - MPE-24-MPE-24ALl-MPE-24AL1 326.50 179.81 326.50 177.17 332.00 68.047 Ellipse Separation Pass - MPE-24-MPE-24AL1-MPE-24AL1 3,251.50 1,496.78 3,251.50 1,431.38 3,057.67 22.885 Clearance Factor Paw - MPE-30-MPE-30AL1-MPE-30ALl 333.93 391.20 333.93 388.69 350.77 155.827 Centre Distance Pass- MPE-30-MPE-30AL1-MPE-30ALI 351.50 391.24 351.50 388.60 369.11 148.511 Ellipse Separation Pass- MPE-30-MPE30A1-1-MPE-30AL1 1,076.50 558.31 1,076.50 550.80 1,028.33 74.293 Clearance Factor Pass - MPE-30 - MPE-30ALlPBI-MPE30AL1 Pal 333.93 391.20 333.93 388.69 350.77 155.827 Centre Distance Pass - MPE-30 - MPE-30ALl P81-MPE-3041-1 PB1 351.50 391.24 351.50 388.60 369.11 148.511 Ellipse Separation Pass - MPE-30-MPE3OALiPB1-MPE-30AL1PB1 1,076.50 558.31 1,076.50 550.80 1,028.33 74.292 Clearance Factor Pass - MPE-32 - MPE32 - MPE-32 26.50 55221 26.50 550.87 33.54 410.827 Centre Distance Pass - MPE-32 - MPE-32 - MPF -32 301.50 553.20 301.50 549.13 305.60 136.106 Ellipse Separation Pass - MPE-32 - MPE-32 - MPE-32 6,626.00 1,152.78 6,626.00 943.80 6,820.13 5.516 Clearance Factor Pass- MPE-32-MPE-32L1-MPE-321-1 26.50 552.21 26.50 550.87 33.54 410.827 Centre Distance Pass- MPE-32-MPE-32L1-MPE-321-1 301.50 553.20 301.50 549.13 305.60 136.106 Ellipse Separation Pass - MPE-32-MPE-321-1-MPE-32L1 6,62600 1,162.55 6,626.00 973.01 6,822.55 6.133 Clearance Factor Pass - MPE-32-MPE-32PB1-MPE-32PB1 26.50 552.21 26.50 550.87 3354 410.827 Centre Distance Pass- MPE-32-MPE32P01-MPE-32PBI 301.50 553.20 301.50 549.13 305.60 136.106 Ellipse Separation Pass - MPE-32-MPE-32PB1-MPE-32P01 6,626.00 1,151.93 6,626.00 930.94 6,842.76 5.213 Clearance Factor Pass- MPU E35 -MPU E -35 -MPU E-35 26.50 160.82 26.50 159.91 27.12 176.327 Centre Distance Paw - MPU E -35 -MPU E -35 -MPU E-35 276.50 161.15 276.50 158.57 276.19 62.619 Ellipse Separation Pass - MPU E35 -MPU E -35 -MPU E-35 826.50 266.95 826.50 261.12 778.52 45.819 Clearance Factor Pass - MPU E-35- MPU E-35 PBi -MPU E-35 PBi 26.50 160.82 26.50 159.91 27.12 176.327 Centre Distance Pass - MPU E35- MPU E-35 PSH -MPU E35 PBi 276.50 161.15 276.50 158.57 276.19 62.619 Ellipse Separation Pass - MPU E35 -MPU E-35 PBI - MPU E-35 PB1 826.50 266.95 826.50 261.12 P8.52 45.619 Clearance Factor Pass- MPU E36 -MPU E -36 -MPU E36 26.50 169.13 26.50 168.22 26.65 185.477 Centre Distance Pass - 27 February, 2019 - 18:16 Page 4 of 8 COMPASS Hilcorp Alaska, LLC Milne Point HALLIBURTON Anticollision Report for Plan: MPU E-40 - MPU E-40 wp04 Closest Approach 30 Proximity Scan on Current SumaI, Data (North Reference) Reference Design: MPt E Pad - Plan: MPU E40 - MPE40i - MPU E40 wp04 Scan Range: 26.50 to 6,626.00 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 Separation Warning pa Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft MPU E�6-MPU E$8 -MPU E-36 276.50 169.67 276.50 166.72 275.22 57AM Ellipse Separation Pass - MPUE-36-MPU E -36 -MPU E-36 651.50 230.21 651.50 224.11 610.60 37.784 Clearance Factor Pass - MPU E-36 - MPU E-36PB1 - MPU E -36P81 26.50 169.13 26.50 168.22 26.65 185.477 Centre Distance Pass - MPU E-36- MPU E-36PB1 - MPU E-36PB1 276.50 169.67 276.50 166.72 275.22 57.456 Ellipse Separation Pass - MPU E�6- MPU E -36P81 - MPU E-36PB1 651.50 230.21 651.50 224.11 610.60 37.784 Clearance Factor Pass - MPU E -37 -MPU E -37 -MPU E-37 26.50 182.09 26.50 181.18 26.88 199.648 Centre Distance Pass - MPU E -37 -MPU E -37 -MPU E-37 176.50 182.28 176.50 180.37 175.82 95.118 Ellipse Separation Pass - MPU E -37 -MPU E -37 -MPU E-37 701.50 266.67 701.50 261.70 652.88 53.680 Clearance Factor Pass - MPU E -37 -MPU E-37 PBI -MPU E-37 PBI 26.50 182.09 26.50 181.18 26.88 199.648 Centre Distance Pass- MPUE-37-MPU E417 PB1-MPU E-37 PB1 176.50 18228 176.50 180.37 175.82 95.118 Ellipse Separation Pass - MPU E -37 -MPU E-37 PB1-MPU E37 PS1 701.50 266.67 701.50 26130 652.88 53.680 Clearance Factor Pass- Plan: MPU E-30-MPE-38-MPE-38 WP07 276.50 90.62 276.50 86.63 276.70 22.706 Centre Distance Pass - Plan: MPU E-38 - MPE-38 - MPE-38 WP07 326.50 90.84 326.50 86.24 326.65 19.760 Ellipse Separation Pass - PIan:MPU E-38-MPE-38-MPE-38 WP07 526.50 10105 526.50 94.13 523.10 14.598 Clearance Factor Pass - Plan: MPU E41 -MPE41 - MPU E41 WP03 27650 30.34 276.50 27.63 276.60 11.219 Centre Distance Pass - Plan: MPU E41 -MPE41 -MPU E41 WP03 326.50 30.55 326.50 27.49 326.60 10.004 Ellipse Separation Pass - Plan: MPU E41-MPE4I-MPU E41 WP03 676.50 41.00 676.50 35.49 68093 7.448 Clearance Factor Pass - Prelim Duell-atPlan: MPU E -39 -MPU E -39i -MPU E,' 276.50 60.15 276.50 57.58 2]6.fi0 23.383 Centre Distance Pass - Prelim Duall-atPlan:MPU E -39 -MPU E -39i -MPU E-: 526.50 6148 526.50 57.18 530.56 14.278 Ellipse Separation Pass - Prelim Duall-atPlan: MPU EJ9- MPU Edg- MPU E-: ]]6.50 73.32 776.50 67.18 785.75 11.858 Clearance Factor Pass - Franc: MPU E -Pad Expansion Placeholder- Wellbore 641.17 25.35 641.17 20.07 67546 4.798 Centre Distance Pass - Prelim:MPUE-Pad Expansion Placeholder- Wellbore 651.50 25.38 651.50 20.03 665.65 4.738 Ellipse Separation Pass - Prelim: MPU E -Pad Expansion Placeholder- Wellbore 676.50 25.79 676.50 20.26 710.27 4.662 Clearance Factor Pass - 27 FebAcary. 2019 - 18:16 Page 5 of 8 COMPASS Project: Milne Point P£FERExLF INFORMATON l CFTn SIIu ABt'E. NM 1a21 OMaDeGN CUNUS3 .1-1 o. MAL.LIBURTON uom,..t wlEl pd <, sv,r, v,.sy Tw<xmn c'auna la�<I: sl so _ Site: M P! E Ped 'n,wllrvnlwl..o-... MPu uoPv.<.a Ime® . w+n .rv1-s .E w' wm1um Fmlm9 v91'wa w.el ePa""v ownl�e Well: Plan: MPU E-40 waw4D.pn R<brtrce: uPU F+9 rs.ma psa®4a+own m9.4m Mwne: M.v.xm ca,m„ sm ow 6916910.]15611111 ]o°xT 1+.]49N l4r uJs2gw Wellbore: MPE40i SURVEYPnGGIan NO GLOBAL FILTER: Ue1119wer definetl ulec0on6fipenn9 ullma Plan: MPU E-40 wp04. Oem: A18-1049TC9:90:C0 ValpatW: Vea Mnim: 211.50 To 1405000 �d1r,1'..I:Plots ® OepN From DepM To SumyVPlan Tool GSNG DETAILS 2850 48000 MPUE-aOv IMPE10p 2 MWD1IFRR.M5.ae9 T"oT"T" ms- Nm) n 000 1050M MPU H0 90 (MPE<00 MWDNFR .Ms.3g 663600 9-S I9 9WB 121/4" 4400.]6 4Ji166 1405000 6-59 652'x8I' 180.00. MPE-24 - MPE-22 tMU E-36 MPE-211 Py150.00 - MPE-11 o o PE -15 j � j .120.00 o v 90.00 U) MP E-39 wy01 m 60.00- 0 _ _ MPU E49 WP03 d U E PlacgMlder U M E41 W 0.00 2800 3150 3500 3850 4200 4550 4900 52W 5600 59W 6300 6650 0 350 700 1050 1400 1750 2100 2450 Measured Depth (700 usftlin) 0 i I m 3.00 LL ( I, j O � Collision Risk Procedures Req. I � v Collision Avoidance Req. 01,50 ND -Go Zone -Stop Drilling I i [NI=ERRIRS I 0.00 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 Measured Depth Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-40 MPE-40i MPU E-40 wp04 Sperry Drilling Services Clearance Summary Anticollision Report 27 February, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: MPt E Pad - Plan: MPU E40 - MPE40i - MPU E40 wp04 Well Coordinates: 6,016,010.71 N, 569,322.23 E (70° 27'14.75" N, 149° 26' 03.53" W) Datum Height: MPII E40 Planned RKB @ 48.10usft Scan Range: 6,626.00 to 14,050.00 usR. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 us" Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: Scan Type: 2500 , HALLI B U RTON Sperry Grilling Services HALLIBURTON Anticollision Report for Plan: MPU E-40 - MPU E-40 wp04 Hileorp Alaska, LLC Milne Point Closest Approach 30 Proximity Scan an Current Survey Data (North Reference) Reference Design: MPt E Pad - Plan: MPU E4D-MPE-40i-MPU E4D wp04 Scan Range: 6,626.00 to 14,050.00 us8. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,000.00 usfl Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Separation Wamin site Name Depth Distance Depth Separation Depth Factor Minimum Pa g Comparison Well Name - Wellbore Name - Design (usft) (usfl) (usfl) (usft) usft M Pt B Pad MPB-05 - MPB�05 - MPB-05 MPB-05-MPB-05A-MPB-05A MPS -13 - MPB-13 - MPB-13 MPB-13 - MPB-13 - MPB-13 MP&15 - MPB-15 - MP&15 MPB-15 - MPT -15 - MPB-15 MPB-15 - MPB-15 - MPS -15 MPB-27 - MPB-27 - MP&27 MPB-27 - MPB-27 - MPB-27 MPB-27 - MPB-27 - MPR -27 M Pt E Pad MPE-04-MPE-04-MPE-04 MPE-04 - MPE-04 - MPE-04 MPE-04 - MPE4)4 - MPE-04 MPE-05-MPE-05-MPE-05 MPE-08 - MPE-08 - MPE-08 MPE-08 - MPE-08 - MPE-08 MPE-09 - MPE49 - MPE-09 MPE-09-MPE4)9-MPE-09 MPE-09 - MPE-09PB1 - MPE-09PB1 MPE-09-MPE-09P61 -MPE-09PB1 MPE-10 - MPE-10 - MPE-10 MPE-10 - MPE-10 - MPE-10 MPE-10 - MPE-10 - MPE-10 MPE-11 - MPE-11 - MPE-11 MPE-12 - MPE-12 - MPE-12 MPE-12 - MPE-12 - MPE-12 14,050.00 583.60 14,050.00 428.43 5,207.87 3.761 Clearance Factor Pass - 14,05000 482.72 14,050.00 285.88 5,266.65 2.452 Clearance Factor Pass - 12,553.78 245.57 12,553.78 73.52 5,934.26 1.427 Centre Distance Pass - 12,701.00 271.00 12,701.00 36.92 5,845.26 1.158 Clearance Factor Pass - 11,759.12 1,364.15 11,759.12 1,151.83 5,678.61 6.425 Centre Distance Pass - 11,826.00 1,365.07 11,826.00 1,150.16 5,635.84 6.352 Ellipse Separetion Pass - 12,201.00 1,388.16 12,201.00 1,165.08 5,358.71 6.222 Clearance Factor Pass - 10,001.00 1,115.27 10,001.00 876.33 8,480.00 4.668 Clearance Factor Pass - 12,401.00 849.50 12,401.00 722.49 5,592.46 6.689 Ellipse Separation Pass - 12,589.18 833.75 12,589.18 736.53 5,496.48 8.576 Centre Distance Pass - 6,751.00 503.92 6,751.00 334.01 5,864.04 2.966 Clearance Factor Pass - 6,951.00 400.35 6,951.00 288.61 5,868.37 3.583 Ellipse Separation Pass - 7,085.26 377.18 7,085.26 300.25 5,871.31 4.903 Centre Distance Pass - 6,626.00 1,115.26 6,626.00 1,009.87 5,643.84 10.582 Clearance Factor Pass - 8,512.94 629.34 8,512.94 543.93 6,345.43 7.369 Ellipse Separation Pass - 8,601.00 634.79 8,601.00 548.52 6,374.48 7.358 Clearance Factor Pass - 6,626.00 727.38 6.626.00 511.97 5,833.98 3.377 Ellipse Separation Pass - 6,751.00 813.16 6,751.00 567.93 5,015.48 3.316 Clearance Factor Pass - 6,626.00 727.38 6,626.00 511.86 5,833.98 3.375 Ellipse Separation Pass - 6,751.00 813.16 6,751.00 567.82 5,615.48 3.314 Clearance Factor Pass - 7,055.89 570.21 7,055.89 522.18 6,002.70 11.873 Centre Distance Pass - 7,151.00 578.02 7,151.00 519.53 6,011.08 9.882 Ellipse Separation Pass - 7,576.00 770.50 7,576.00 640.41 6,045.79 5.923 Clearance Factor Pass - 6,626.00 1,478.38 6,626.00 1,379.46 5,754.56 14.946 Clearance Factor Pass - 9,102.58 _ 86.66 9,102.58 30.33 7,464.10 1.539 Centre Distance -- Pass- D February 2019 - 18:17 Page 2 of 6 COMPASS Hileorp Alaska, LLC Milne Point WALLIBURTON Anticollision Report for Plan: MPU E-40 - MPU E-40 wp04 Closest Approach 3D Proximity Scan on Current Survey Data (North Referencel Reference Design: MPt EPad - Plan: MPU E40-MPE401-MPU E40 wp04 Scan Range: 6,626.00 to 14,050.00 usft. Measured Depth. Soon Radius is Unlimited . Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is 1,000.00 usft Measured Minimum dMeasured Ellipse @Measured Clearance Summary Based on Separation Warning Site Name Depth Distance Depth Separation Depth Factor Minimum P Comparison Well Name - Wellbore Name -Design (usft) (usft) (usft) (usft) usft MPE-17-MPE-17-MPE-17 6,626.00 1,047,88 6,626.00 997.65 5,439.36 20.859 Ellipse Separation Pass - MPE-17 - MPE-17 - MPE-17 7,526.00 1,452.93 7,526.00 1,307.72 5,456.97 10.006 Clearance Factor Pass- MPE-21-MPE-21-MPE-21 6,626.00 725.32 6,626.00 607.56 5,990.00 6.159 Cleaance Factor Pass - MPE-21-MPE-21-MPE-21 6,926.00 615.37 6,926.00 547.65 5,990.00 9.087 Ellipse Separation Pass - MPE-21 - MPE-21 - MPE-21 7,014.87 608.92 7,014.87 551.90 5,990.00 10.680 Gene Distance Pass - 6,626.00 1,252.17 6,626.00 1,155.28 5,860.27 12.925 Clearance Factor Pass - MPE-22-MPE-22-MPE-22 6,634.58 102.03 6,634.58 50.26 6,186.52 1.971 Centre Distance Pass - MPE-23-MPE-23-MPE-23 6,676.00 110.56 6,676.00 43.83 6,190.25 1.657 Ellipse Separation Pass - MPE-23 - MPE-23 - MPE-23 6,701.00 122.T7 6,701.00 46.72 6,192.24 1.614 Clearance Factor Pass - MPE-23 - MPE-23 - MPE-23 12,251.00 755.34 12,251.00 510.51 9,290.00 3.085 Clearance Factor Pass- MPE-30 - MPE-30ALl - MPE-30ALl 12,326.00 746.51 12,326.00 507.04 9,290.00 3.117 Ellipse Separation Pass - MPE3U-MPE-30ALl-MPE-30AL1 744.78 12,376.86 510.05 9,290.00 3.173 Centre Distance Pass - MPE-30 - MPE-30ALl - MPE-30ALl 12,376.86 E,3 ,L MPE-30-MPE-30AL1 PBI-MPE-30ALI PBI 11,726.00 962.07 11,726.00 732.40 8,660.00 4.189 Clearance Factor Pass -D I � sAIO MPE-30 - MPE-30ALI PSI -MPE-30ALl PBI 11,826A0 954.48 11,82600 apa2 727.11 8,691.00 4.198 Ellipse Stion Pasa- `ft, lsrF' MPE-30-MPE-30AL1PB1-MPE-30AL1PB1 11,887.01 953.24 11,887.01 727.70 8,71027 4.226 Centre Distance Pass - MPE-32 - MPE-32 - MPE-32 -_ MPE-32 - MPE32 - MPE-32 - MPE-32-MPE32-MPE-32 - - - MPE-32-MPE-32L1-MPE-32L1 7,792.37 7860 7,792.37 41.85 6,953.17 2.139 Gene Distance Pass - MPE-32 - MPE-321-1 -MPE-32L1 - MPE-32-MPE-32PB1-MPE-32PB1 - - - MPE-32-MPE-32PB1-MPE-32PB1 - - - MPE-32 - MPE32PB1 - MPE-32PBI - 27February, 2019 - 18:17 Page 3 oi6 uwmra5c REFERENCE INFOflMATION LDEIARS➢I—NRU&40 xpD191'1NADCONCONIIB) Z .< HALUBURTON Project: Milne Point Site: MPI EPad xb(WE1 Ra,.,„,m.. w.0 Pu. wuEip. r::,, xann� Rac'R.—. Nry Rze® n cmow =�, xi bB ft., oNn..e Well: Plan: MPU E-40 :a,.. Mw E4o ^� °•+^^'e^',. µ m m c v Rzs®ae+a.n s +a� w„nmy Ey,m¢ ral�u.' Wellbore: MPE40i bol6Blon t6mzz.n +p•zr u'49x 149•±6'BssB' SURVEY PROGRAM NO GLOBAL FILTER: Usi Suter defircE FMedbndfil4nn9 cn1e1u Pen: MPU E40 wPO4 2fi 50 Ta 1b50.00 D.h 201B4418TW40:00 VdAEa40'.Yss Mnbn: Ladder/S.F. Plots CASING DUMB ® Deolh Fmm Depth ToSUme Wn Tool 2fi E0 480.00 MPU E40 uy04p EdOi) 2MwD`IFR+M6+se9 WD ypSS 0 3i Nm PH(2 of 2) 6440,00 0W.00 MPU E<D yW MPE Oi) ? MWOHF0. +MB+aap 43'3.23 43.IS] 66±600 9-58 9L8"x 131/G" 4400'6 gi366 405060 6-5/2 64:8"x91C" 180.00 I C 150,00 0 c�"0120.00 - --M E.12 - `e B-13 R 90.00 CO iu E-3 L1 U60.00 I I o 'c 30.00 U I O.OD 10000 11200 11600 12000 12400 12800 13200 13600 14000 1440 6000 7200 7600 8000 0400 6800 9200 8600 10000 10400 Measured Depth (800 UsftrJn) I I II I 4.00 LL I I m N 240 -- -- Collision Risk Procedures Req. _T _1-"-- - -- Collision AvojdanoeRq. 1.00 _ __________ ___ ___ it NoGo Zone -Stop Drilling I t NOERRORS 0.00. II 1000n 11200 11600 12000 12400 12000 13200 13800 14000 14400 6000 ]200 ]600 8000 8400 0000 9200 9500 100o0 10400 Measured Depth (800 usTUn) I-IALLIBURTON Anticollision Report for Plan: MPU E-40 - MPU E-40 wp04 From To surveymian (usft) (U -ft) 26.50 480.00 MPU E40 wp04 6.440.00 14.050A0 MPU E40 wp04 Ellipse error terns are correlated across survey tool llebn paints. Calculated ellipses Incorporate surface errors. Separation a the actual distance between ellipsoids. Distance Between centres is the straight line distance be sa e, wellbore centres. Clleaance Factor= Distance Between Profiles I (Distance Between Profiles- Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 2 MWD+IFR2+MS+Sag 2 MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point Z] Febrvary, 2019 - 18:17 Page 4 of 6 wmrnaa HALLIBURTON Anticollision Report for Plan: MPU E-40 - MPU E-40 wpO4 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor m C MewredDepth(150LGftfn) $ M Hilcorp Alaska, LLC Milne Point E-0B,MPEUBW E-09,MPE49\12 --09PB1,WE-09PB1V1 E-10,MPE-10V1 E-11, MPE-11 Vi E42,MPE-12V4 E-14,MPE-14\14 E-14A,MPE-14AV0 E-14APB1,MPE-14APB1 VO E-15,MPE-15V1 E-17,MPE-17V1 E-20,MPE-20V3 E-20A,MPE-20AV3 E-20AL1,WE-20ALi V3 E-20AL1 PB1,IvPE-20A 1PB1 V2 'E-21,MPE-21 Vi] 'E-22,MPE-22V1 'E-23,MPE-23\17 'E-24,MPE-24V12 'E-24A,MPE-24AV9 E-24AL1,WE-24AL1 V5 E30AL1,MPE-30AL1 V8 E30AL1 PBl,MPE30AL1PB1 V1 'E32,MPE32V7 'E3 1,APE320 VS 'E32PB1,WE-32PB1 V6 27February 2019 - 18:16 Page 8 of 6 COMPASS E-09, MF I I -09,MF 0 E40,MF E-11,MF E-02,MF 5 �:1-E-14,W E-14,MF 10 E44,MF E-15,MI ¢ E -17,M Pe E-20,MI -20,M E -20,M E-20,Nf E -21,M -E-22,MI 75 .... $K PE-23,MI PE -24,M t _ .;h PE -24,M RlskP dJurS Req. ItECdlisim -24,M cdesion Avoidance Req E-30 M 25 NOGG Zone -Stop polll E30,M E32.10 NOERR E32,M IE gar -32,M MewredDepth(150LGftfn) $ M Hilcorp Alaska, LLC Milne Point E-0B,MPEUBW E-09,MPE49\12 --09PB1,WE-09PB1V1 E-10,MPE-10V1 E-11, MPE-11 Vi E42,MPE-12V4 E-14,MPE-14\14 E-14A,MPE-14AV0 E-14APB1,MPE-14APB1 VO E-15,MPE-15V1 E-17,MPE-17V1 E-20,MPE-20V3 E-20A,MPE-20AV3 E-20AL1,WE-20ALi V3 E-20AL1 PB1,IvPE-20A 1PB1 V2 'E-21,MPE-21 Vi] 'E-22,MPE-22V1 'E-23,MPE-23\17 'E-24,MPE-24V12 'E-24A,MPE-24AV9 E-24AL1,WE-24AL1 V5 E30AL1,MPE-30AL1 V8 E30AL1 PBl,MPE30AL1PB1 V1 'E32,MPE32V7 'E3 1,APE320 VS 'E32PB1,WE-32PB1 V6 27February 2019 - 18:16 Page 8 of 6 COMPASS Schwartz Guy L (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Wednesday, April 10, 2019 8:25 AM To: Schwartz, Guy L (DOA) Subject: HAK MPU E-40 (PTD:219-044) Directional Plan Attachments: MPU E-40 wp06 - Proposal Report.pdf; MPU E-40 wp06_GlS.TXT Guy— Please see the attached updated directional plan for MPE-40. TD has been changed to be more than 1320' MD away from B -05A at the Schrader NB depth. Please let me know if you have any questions. Thank you for your time. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 Hilcorp Alaska, LLC Milne Point M Pt E Pad Rig: MPU E-40 MPU E -40i Plan: MPU E-40 wp06 Standard Proposal Report 09 April, 2019 HALLIBURTON Sperry Drilling Services F- Zm>O> N <g �bpYbbmMI�pN F p-�NO� �Ob 6im ON OR yNy onoO.. NrN�� Cc zAagrg Wto agzga� NN11�1 l9 V1N W�W�m Wf v a I U g m No v � g `Yw W w > > TigONMWmMOnNmO�M && O N M N p m Y. O. .n m O O O r n1� 0 m N � N N N > �nm Md mM .md-nm�uNi rn4i �8S8e8Sm°'8�5�8 N pad p p p Y SO S O O CJN N O S O O O pooripe cae�pa cayc^^rvc 3 O O N M r O ro T n y N NIS O y'OONYpO NO N prdmf {pm�mM�pN M NN N1+lMNPQY mpONMNre-pOnpy�p ZCOmi �IN<MYa ng 4 OIN nWM�NM{a� ppoopp 1P TT NMN F N m n N w Ol �N�yy n r 83 MM m p? O C �OOO m/OpMNNNNNmmiQ _aSS��ng$$mmmm ppd d6.;t °� xx2p w oommwm m g�p S m Om O O p Op S y m � 7 1i N aq ma N NPNOmMIN�16 $NNOON m z 0059 L2 O e o p4�gg 0009 f�fd Og OW�WW _�aaa 7 OOSL d C J Q c"' 3 c'a vo it $ ni 13 gii hi gKx2i i » E a a 6 Jill e sIN pQ U u 0 zs a � cgj01 zy@ad Eho e.w Zg� $C� U mry$? 0 w 5� Ea>a� ii mMJJ O�NNn E NInVNN `0888 �nmNM mry�e �pOOp amNB'a z � g m ffi x v C � Q d pd OOsn O 12 f oom z �f"Ec�y1 Dos u N OOOLI E fi ooso� w g 0000 R s � Doss m 0006 (ui/ysn 000 L) Lndad isoian aml 'Y n m O 0059 p(�� gl 0009 f�fd Og Q �L. iwa��. OOSL Qf, °dyb POOL (ui/ysn 000 L) Lndad isoian aml 'Y n m O 3333 CASING DETAILS TVD TVDSS MD Size Nem" 4373.35 4325.25 5835.00 9-512 5/8" x 12 IW 43 n88.10 4340.00 12941.50 4-1/2 4 412'z81/2" REFERENCE INFORMATION CooNMate OW ) Reference: WM Rig: MPU E40, Tme Nod6 Vediml (TVD) Reference: MPU E40 Planned RM 0 48.10u60 Meaaum i Depen Reference: MPU E40 Manned RKS ® 48.10usP CaKuemn McOrm Minimum Curvature WE12. DETARS: Rib: MPU E40 GromM laud: 21.60 -NAS +E' -W NoReng Swear, lanwde lonelmde 0.00 0.00 60I6010.T1 56932233 70° 27 14 7492 N 149° 26' 3.5298 W Project: Milne Point Site: M Pt E Pad Well: Rig: MPU E-40 Wellbore: MPU E -40i Plan: MPU E-40 wpOS Smrt Dir 3°/1 Otl : 28tl hen, 280'TVp Smrt Dir 40r10o': 480' M. 479.63'TVD Fad Du : 1675' MD, 1527.22' TVD S� �ry oM. �S- S� TO S� M1 ^yo ro o� S� yo 1N Set Dir 4.3°/100':3950' MD, 3016.95TVD MALLN ' SParrV OrMing 6IPU FAO "06 Toe 4Ilr x 81/2" Tocol Depth : 12W 5' MD, 4388.1' TVD 4388 -t MPU E -q0 wP06 N E40 wP06 CPI Evd1)u : 10609.22'MD, /383.99 TVD Smrt Dirr/100': 10046.33' MD, 4383.ITVD Pad Dir :6755.IT MD, 437855' TVD MPE-Kayner NB Hai_ �'- Smrt Dir 4°/1OP: 6632.15' ben, 4373.1 TVD Fad Dir : 6416.68' MD, 435432' TVD Smrt Dir 4.r/100': 5843' MD, 419914TtD Sam Dir 421 -AW: 53W W, 3919, 1 9W 2667 3333 4000 4667 5333 6000 6667 West( -)/East(+) (1000 wft/in) Database: NORTH US+CANADA Company: Hiloorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Rig: MPU E-40 Wellbore: MPU E401 Design: MPU E40 wp06 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Rig: MPU E-40 TVD Reference: MPU E40 Planned RKB @ 48.10usft MD Reference: MPU E40 Planned RKB @ 48, 10usft North Reference: True Survey Calculation Method: Minimum Curvature Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt E Pad, TRA 3.10 Rig: MPU E-40 Site Position: Northing: 6,013,798.68usft Latitude: 70° 26'52.9824 N From: Map Easting: 569,440.72 usft Longitude: 149° 26'0.6546 W Position Uncertainty: 0.00 usft Slot Radius: 01. Grid Convergence: 0.53 ° Well Rig: MPU E-40 Well Position +NIS 0.00 usft Northing: 6,016,010.71 usft Latitude: 70° 27' 14.7492 N +El -W 0.00 usft Easting: 569,322.23 usft Longitude: 149° 26'3.5298 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 21.60 usft ellbore MPU E-401 agnatics Model Name Sample Date Declination Dip Angle Field Strength (% (0) Wn BGGM2018 4/1/2019 16.77 80.97 57,434.24620471 Design MPU E40 wp06 Audit Notes: Version: Phase: PROTOTYPE Tie On Depth: 26.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 26.50 0.00 0.00 42.27 Plan Sections- Measured Vertical TVD Dogleg Build Turn Depth Inclinatio Azimut Depth System +NIS +EI -W Rate Rate Rate Tool Face lush) n h (usft) usft (usft) (usft) (°/100usft) (°1100usft (°1100usft 1% 26.50 0.00 0.00 26.50 -21.60 0.00 0.00 0.00 0.00 0.00 0.00 280.00 0.00 0.00 280.00 23190 0.00 0.00 0.00 0.00 0.00 0.00 480.00 6.00 210.00 479.63 431.53 -9.06 -5.23 3.00 3.00 0.00 210.00 1,675.00 49.10 132.60 1,527.22 1,479.12 -391.53 314.98 4.02 3.61 -6.48 -82.62 3,950.00 49.10 132.60 3,016.75 2,968.65 -1,555.46 1,580.74 0.00 0.00 0.00 0.00 5,300.00 55.54 57.35 3,919.19 3,871.09 -1,604.87 2,505.41 4.30 0.48 -5.57 -110.00 5,845.00 63.40 32.23 4,199.14 4,151.04 -1,273.11 2,828.88 4.21 1.44 4.61 -76.82 6,416.68 85.00 21.25 4,354.32 4,306.22 -784.34 3,071.96 4.20 3.78 -1.92 -27.79 6,632.15 85.00 21.25 4,373.10 4,325.00 -584.28 3,149.76 0.00 0.00 - 0.00 0.00 6,755.17 89.92 21.24 4,378.55 4,330.45 469.77 3,194.28 4.00 4.00 -0.01 -0.12 10,046.33 89.92 21.24 4,383.10 4,335.00 2,597.84 4,386.54 0.00 0.00 0.00 0.00 10,609.22 89.90 9.98 4,383.99 4,335.89 3,139.09 4,537.77 2.00 0.00 -2.00 -90.12 12,941.50 89.90 9.98 4,388.10 4,340.00 5,436.06 4,942.02 0.00 0.00 0.00 0.00 4/9l2019 7:31:19PM Pape 2 COMPASS 5000.15 Build 91 Halliburton H A L L I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Rig: MPU E40 Company: Hilcorp Alaska, LLC TVD Reference: MPU E-40 Planned RKB @ 48.10usft Project: Milne Point MD Reference: MPU E40 Planned RKB @ 48.10usft Site: M Pt E Pad North Reference: True Well: Rig: MPU E40 Survey Calculation Method: Minimum Curvature Wellbore: MPU E40i Depth Inclination Design: MPU E40 wp06 TVDss +N1S Planned Sumay Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N1S +E14N Northing Easting DLS Vert (waft) 11 CI (usft) usft (usft) (usft) (usft) (usft) -21.60 Section 26.50 0.00 0.00 26.50 -21.60 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 100.00 0.00 0.00 100.00 51.90 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 200.00 0.00 0.00 200.00 151.90 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 280.00 0.00 0.00 280.00 231.90 0.00 0.00 6,016,010.71 569,322.23 0.00 0.00 Start Dir 3°1100' : 280' MD, 28(l 300.00 0.60 210.00 300.00 251.90 -0.09 -0.05 6,016,010.62 569,322.18 3.00 -0.10 400.00 3.60 210.00 399.92 351.82 -3.26 -1.88 6,016,007.43 569,320.38 3.00 -3.68 480.00 6.00 210.00 479.63 431.53 -9.06 -5.23 6,016,001.60 569,317.08 3.00 -10.22 Start Dir 4.02 -Mi : 480' MD, 479.63"M 500.00 6.16 202.54 499.52 451.42 -10.96 -6.16 6,015,999.70 569,316.17 4.02 -12.25 600.00 8.16 174.02 598.77 550.67 -22.97 -7.48 6,015,987.67 569,314.96 4.02 -22.03 700.00 11.30 158.87 697.33 649.23 -39.18 -3.21 6,015,971.51 569,319.39 4.02 -31.15 800.00 14.86 150.55 794.73 746.63 -59.49 6.63 6,015,951.29 569,329.42 4.02 -39.56 900.00 18.61 145.45 890.49 842.39 -83.81 21.99 6,015,927.12 569,345.00 4.02 47.22 1,000.00 22.45 142.03 984.12 936.02 -112.01 42.80 6,015,899.11 569,366.06 4.02 -54.09 1,100.00 26.34 139.57 1,075.18 1,027.08 -143.97 68.94 6,015,867.41 569,392.50 4.02 -60.15 1,200.00 30.26 137.71 1,163.21 1,115.11 -179.51 100.30 6,015,832.16 569,424.18 4.02 -65.36 1,300.00 34.21 136.24 1,247.78 1,199.68 -216.47 136.71 6,015,793.54 569,460.96 4.02 -69.69 1,400.00 38.17 135.04 1,328.47 1,280.37 -260.65 178.01 6,015,751.75 569,502.64 4.02 -73.12 1,500.00 42.14 134.04 1,404.89 1,356.79 -305.85 223.97 6,015,706.98 569,549.02 4.02 -75.65 1,600.00 46.11 133.17 1,476.66 1,428.56 -353.84 274.39 6,015,659.47 569,599.88 4.02 -77.24 1,675.00 49.10 132.60 1,527.22 1,479.12 -391.53 314.98 6,015,622.16 569,640.80 4.02 -77.83 End Dir : 1675' MD, 1627.22' TVD 1,700.00 49.10 132.60 1,543.59 1,495.49 404.32 328.88 6,015,609.50 569,654.83 0.00 -77.93 1,800.00 49.10 132.60 1,609.06 1,560.96 455.48 384.52 6,015,558.87 569,710.94 0.00 -70.36 1,900.00 49.10 132.60 1,674.53 1,626.43 -506.65 440.16 6,015,508.23 569,767.04 0.00 -78.79 2,000.00 49.10 132.60 1,740.01 1,691.91 -557.81 495.80 6,015,457.59 569,823.15 0.00 -79.22 2,100.00 49.10 132.60 1,805.48 1,757.38 -608.97 551.44 6,015,406.95 569,879.26 0.00 -79.65 2,191.06 49.10 132.60 1,865.10 1,817.00 -655.56 602.10 6,015,360.85 569,930.35 0.00 -80.04 BPRF 2,200.00 49.10 132.60 1,870.96 1,822.86 -660.13 607.08 6,015,356.32 569,935.36 0.00 -80.08 2,300.00 49.10 132.60 1,936.43 1,888.33 -711.29 662.71 6,015,305.68 569,991.47 0.00 -80.51 2,400.00 49.10 132.60 2,001.90 1,953.80 -762.46 718.35 6,015,255.04 570,047.58 0.00 -80.94 2,500.00 49.10 132.60 2,067.38 2,019.28 -813.62 773.99 6,015,204.41 570,103.68 0.00 -81.37 2,600.00 49.10 132.60 2,132.85 2,084.75 -864.78 829.63 6,015,153.77 570,159.79 0.00 -81.80 2,700.00 49.10 132.60 2,198.33 2,150.23 -915.94 885.27 6,015,103.13 570,215.90 0.00 -82.23 2,751.58 49.10 132.60 2,232.10 2,184.00 -942.33 913.97 6,015,077.01 570,244.84 0.00 -82.45 SV2 2,600.00 49.10 132.60 2,263.80 2,215.70 -967.10 940.90 6,015,052.49 570,272.00 0.00 -82.66 2,900.00 49.10 132.60 2,329.27 2,281.17 -1,018.26 996.54 6,015,001.86 570,328.11 0.00 -83.09 3,000.00 49.10 132.60 2,394.75 2,346.65 -1,069.43 1,052.18 6,014,951.22 570,384.21 0.00 -83.52 3,100.00 49.10 132.60 2,460.22 2,412.12 -1,120.59 1,107.82 6,014,900.58 570,440.32 0.00 -83.95 3,200.00 49.10 132.60 2,525.70 2,477.60 -1,171.75 1,163.46 6,014,849.95 570,496.43 0.00 -84.37 3,300.00 49.10 132.60 2,591.17 2,543.07 -1,222.91 1,219.10 6,014,799.31 570,552.53 0.00 -84.80 3,400.00 49.10 132.60 2,656.64 2,608.54 -1,274.07 1,274.73 6,014,748.67 570,608.64 0.00 -85.23 492019 7:31:19PM Pace 3 COMPASS 5000.15 Build 91 Halliburton H A L L I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Rig: MPU E40 Company: Hilmrp Alaska, LLC TVD Reference: MPU E40 Planned RKB @ 48.10usft Project- Milne Point MD Reference: MPU E-40 Planned RKB @ 48.10usft Site; M Pt E Pad North Reference: True Well: Rig: MPU E40 Survey Calculation Method: Minimum Curvature Wellbore: MPU E -40i Depth Inclination Azimuth Design: MPU E-40 wp06 +N/ -S +E/ -W Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert (usft) V) (•) (usft) usft (Usft) Weft) (usft) (usft) 2,674.02 Section 3,500.00 49.10 132.60 2,722.12 2,674.02 -1,325.24 1,330.37 6,014,698.03 570,664.75 0.00 -85.66 3,600.00 49.10 132.60 2,787.59 2,739.49 -1,376.40 1,386.01 6,014,647.40 570,720.85 0.00 -86.09 3,700.00 49.10 132.60 2,853.07 2,804.97 -1,427.56 1,441.65 6,014,596.76 570,776.96 0.00 -86.52 3,800.00 49.10 132.60 2,918.54 2,870.44 -1,478.72 1,497.29 6,014,546.12 570,833.07 0.00 -86.95 3,900.00 49.10 132.60 2,984.02 2,935.92 -1,529.88 1,552.92 6,014,495.48 570,889.17 0.00 -87.38 3,950.00 49.10 132.60 3,016.75 2,968.65 -1,555.46 1,580.74 6,014,470.17 570,917.23 0.00 -87.59 Start Dir 4.3°1100' : 3960' MD, 3016.7111 4,000.00 48.40 129.90 3,049.72 3,001.62 -1,580.25 1,609.00 6,014,445.65 570,945.71 4.30 -86.93 4,100.00 47.18 124.33 3,116.94 3,068.84 -1,624.93 1,668.00 6,014,401.52 571,005.12 4.30 -80.30 4,200.00 46.25 118.56 3,185.52 3,137.42 -1,662.90 1,730.04 6,014,364.13 571,067.50 4.30 -66.66 4,300.00 45.62 112.64 3,255.10 3,207.00 -1,693.94 1,794.78 6,014,333.70 571,132.52 4.30 46.07 4,400.00 45.30 106.62 3,325.27 3,277.17 -1,717.87 1,861.85 6,014,310.40 571,199.81 4.30 -18.67 4,500.00 45.30 100.57 3,395.65 3,347.55 -1,734.56 1,930.87 6,014,294.35 571,268.97 4.30 15.41 4,600.00 45.61 94.55 3,465.83 3,417.73 -1,743.92 2,001.46 6,014,285.65 571,339.63 4.30 55.97 4,700.00 46.24 88.63 3,535.43 3,487.33 -1,745.89 2,073.21 6,014,284.35 571,411.39 4.30 102.78 4,800.00 47.16 82.86 3,604.04 3,555.94 -1,740.46 2,145.72 6,014,290.45 571,483.85 4.30 155.57 4,900.00 48.37 77.28 3,671.29 3,623.19 -1,727.67 2,218.59 6,014,303.92 571,556.58 4.30 214.05 5,000.00 49.83 71.93 3,736.79 3,688.69 -1,707.58 2,291.40 6,014,324.68 571,629.20 4.30 277.90 5,100.00 51.53 66.82 3,800.17 3,752.07 -1,680.31 2,363.74 6,014,352.62 571,701.28 4.30 346.74 5,200.00 53.44 61.97 3,861.09 3,812.99 -1,646.01 2,435.21 6,014,387.58 571,772.42 4.30 420.20 5,254.46 54.56 59.42 3,893.10 3,845.00 -1,624.44 2,473.63 6,014,409.51 571,810.63 4.30 462.00 Ugnu LA3 5,300.00 55.54 57.35 3,919.19 3,871.09 -1,604.87 2,505.41 6,014,429.37 571,842.23 4.30 497.86 Start Dir 4.21°1100' : 6300' MD, 3919.1977 5,400.00 56.80 52.44 3,975.03 3,926.93 -1,557.17 2,573.24 6,014,477.70 571,909.61 4.21 578.79 5,500.00 57.85 47.66 4,029.19 3,981.09 -1,503.18 2,637.65 8,014,532.27 571,973.50 4.21 662.05 5,600.00 59.27 43.01 4,081.37 4,033.27 -1,443.22 2,698.28 6,014,592.79 572,033.57 4.21 747.21 5,700.00 60.85 38.51 4,131.30 4,083.20 -1,377.59 2,754.81 6,014,658.94 572,089.48 4.21 833.80 5,741.09 61.54 36.70 4,151.10 4,103.00 -1,349.06 2,776.78 6,014,687.67 572,111.18 4.21 869.68 Ugnu MS 5,800.00 62.58 34.15 4,178.70 4,130.60 -1,306.66 2,806.94 6,014,730.35 572,140.94 4.21 921.35 5,845.00 63.40 32.23 4,199.14 4,151.04 -1,273.11 2,828.88 6,014,764.10 572,162.56 4.21 960.93 Start Dir 4.2-/100': 6846' MD, 4199.147VD 5,900.00 65.45 31.05 4,222.89 4,174.79 -1,230.87 2,854.90 6,014,806.57 572,188.18 4.20 1,009.69 6,000.00 69.19 28.99 4,261.44 4,213.34 -1,150.98 2,901.02 6,014,886.87 572,233.56 4.20 1,099.82 6,100.00 72.96 27.03 4,293.86 4,245.76 -1,067.48 2,945.42 6,014,970.78 572,277.17 4.20 1,191.48 6,200.00 76.75 25.15 4,319.98 4,271.88 -980.80 2,987.85 6,015,057.84 572,318.79 4.20 1,284.15 6,300.00 80.55 23.33 4,339.65 4,291.55 -891.41 3,028.08 6,015,147.59 572,358.19 4.20 1,377.36 6,400.00 84.36 21.54 4,352.77 4,304.67 -799.80 3,065.90 6,015,239.54 572,395.15 4.20 1,470.59 6,416.68 85.00 21.25 4,354.32 4,306.22 -764.34 3,071.96 6,015,255.06 572,401.06 4.20 1,486.10 End Dir : 6416.68' MD, 4364.32' TVD 6,500.00 85.00 21.25 4,361.58 4,313.48 -706.98 3,102.04 6,015,332.69 572,430.42 0.00 1,563.58 6,600.00 85.00 21.25 4,370.30 4,322.20 -614.13 3,138.15 6,015,425.86 572,465.66 0.00 1,656.57 6,632.15 85.00 21.25 4,373.10 4,325.00 -584.28 3,149.76 6,015,455.81 572,476.99 0.00 1,686.46 Start Dir 4°/100' : 6632.16' MD, 4373.11VD 4,9/2019 7:31:19PM Page 4 COMPASS 5000.15 Build 91 Planned Sumay Measured Halliburton H A L L I B U R T O N Standard Proposal Report Database: NORTH US+CANADA Local Co-ordinate Reference: Well Rig: MPU E40 Company: Hilcorp Alaska, LLC TVD Reference: MPU E40 Planned RKB @ 48.1 Dust Project: Milne Point MD Reference: MPU E-40 Planned RKB @ 48.10usft Site: M Pt E Pad North Reference: True Well: Rig: MPU E-40 Survey Calculation Method: Minimum Curvature Wellbore: MPU E40i (usft) (°) Design: MPU E-40 wp06 (usft) usft Planned Sumay Measured Vertical Map Map Depth Inclination Azimuth Depth TVDse +N/ -S +E/.W Northing Easting DLS Vert (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usR) 4„125.26 Section 6,635.00 85.11 21.25 4,373.35 4,325.25 -581.64 3,150.79 6,015,458.47 572,477.99 3.99 1,689.11 9 5/8" z 12114" 6,700.00 87.71 21.24 4,377.41 4,329.31 -521.18 3,174.29 6,015,519.14 572,500.93 4.00 1,749.66 6,755.17 89.92 21.24 4,378.55 4,330.45 469.77 3,194.28 6,015,570.72 572,520.44 4.00 1,801.14 End Dir : 8756.17' MD, 4378.66' TVD 6,800.00 89.92 21.24 4,378.61 4,330.51 427.98 3,210.52 6,015,612.65 572,536.29 0.00 1,842.98 6,900.00 89.92 21.24 4,378.75 4,330.65 -334.76 3,246.74 6,015,706.18 572,571.64 0.00 1,936.32 7,000.00 89.92 21.24 4,378.89 4,330.79 -241.57 3,282.97 6,015,799.72 572,606.99 0.00 2,029.66 7,100.00 89.92 21.24 4,379.03 4,330.93 -148.36 3,319.20 6,015,893.25 572,642.35 0.00 2,122.99 7,200.00 89.92 21.24 4,379.16 4,331.06 -55.16 3,355.42 6,015,986.78 572,677.70 0.00 2,216.33 7,300.00 89.92 21.24 4,379.30 4,331.20 38.05 3,391.65 6,016,080.31 572,713.06 0.00 2,309.66 7,400.00 89.92 21.24 4,379.44 4,331.34 131.26 3,427.87 6,016,173.84 572,748.41 0.00 2,403.00 7,500.00 89.92 21.24 4,379.58 4,331.48 224.47 3,464.10 6,016,267.37 572,783.76 0.00 2,496.33 7,600.00 89.92 21.24 4,379.72 4,331.62 317.67 3,500.33 6,016,360.91 572,819.12 0.00 2,589.67 7,700.00 89.92 21.24 4,379.86 4,331.76 410.88 3,536.55 6,016,454.44 572,854.47 0.00 2,683.01 7,800.00 89.92 21.24 4,379.99 4,331.89 504.09 3,572.78 6,016,547.97 572,889.83 0.00 2,776.34 7,900.00 89.92 21.24 4,380.13 4,332.03 597.30 3,609.01 6,016,641.50 572,925.18 0.00 2,869.68 8,000.00 89.92 21.24 4,380.27 4,332.17 690.50 3,645.23 6,016,735.03 572,960.54 0.00 2,963.01 8,100.00 89.92 21.24 4,380.41 4,332.31 783.71 3,681.46 6,016,828.56 572,995.89 0.00 3,056.35 8,200.00 89.92 21.24 4,380.55 4,332.45 876.92 3,717.68 6,016,922.10 573,031.24 0.00 3,149.69 8,300.00 89.92 21.24 4,380.69 4,332.59 970.13 3,753.91 6,017,015.63 573,068.60 0.00 3,243.02 8,400.00 89.92 21.24 4,380.82 4,332.72 1,063.33 3,790.14 6,017,109.16 573,101.95 0.00 3,336.36 8,500.00 89.92 21.24 4,380.96 4,332.86 1,156.54 3,826.36 6,017,202.69 573,137.31 0.00 3,429.69 8,600.00 89.92 21.24 4,381.10 4,333.00 1,249.75 3,862.59 6,017,296.22 573,172.66 0.00 3,523.03 8,700.00 89.92 21.24 4,381.24 4,333.14 1,342.96 3,898.82 6,017,389.75 573,208.02 0.00 3,616.37 8,800.00 89.92 21.24 4,381.38 4,333.28 1,436.16 3,935.04 6,017,483.29 573,243.37 0.00 3,709.70 8,900.00 89.92 21.24 4,381.51 4,333.41 1,529.37 3,971.27 6,017,576.82 573,278.72 0.00 3,803.04 9,000.00 89.92 21.24 4,381.65 4,333.55 1,622.58 4,007.50 6,017,670.35 573,314.08 0.00 3,896.37 9,100.00 89.92 21.24 4,381.79 4,333.69 1,715.79 4,043.72 6,017,763.88 573,349.43 0.00 3,989.71 9,200.00 89.92 21.24 4,381.93 4,333.83 1,808.99 4,079.95 6,017,857.41 573,364.79 0.00 4,083.04 9,300.00 89.92 21.24 4,382.07 4,333.97 1,902.20 4,116.17 6,017,950.94 573,420.14 0.00 4,176.38 9,400.00 89.92 .21.24 4,382.21 4,334.11 1,995.41 4,152.40 6,018,044.48 573,455.49 0.00 4,269.72 9,500.00 89.92 21.24 4,382.34 4,334.24 2,088.62 4,188.63 6,018,138.01 573,490.85 0.00 4,363.05 9,600.00 89.92 21.24 4,382.48 4,334.38' 2,181.82 4,224.85 6,018,231.54 573,526.20 0.00 4,456.39 9,700.00 89.92 21.24 4,382.62 4,334.52 2,275.03 4,261.08 6,018,325.07 573,561.56 0.00 4,549.72 9,800.00 89.92 21.24 4,382.76 4,334.66 2,368.24 4,297.31 6,018,418.60 573,596.91 0.00 4,643.06 9,900.00 89.92 21.24 4,382.90 4,334.80 2,461.45 4,333.53 6,018,512.13 573,632.27 0.00 4,736.40 10,000.00 89.92 21.24 4,383.04 4,334.94 2,554.65 4,369.76 6,018,605.67 573,667.62 0.00 4,829.73 10,046.33 89.92 21.24 4,383.10 4,335.00 2,597.84 4,386.54 6,018,649.00 573,684.00 0.00 4,872.97 Start Dir 2°/100' : 10046.33' MD, 4383.1'TVD 10,100.00 89.92 20.17 4,383.18 4,335.08 2,648.04 4,405.52 6,016,699.37 573,702.50 2.00 4,922.88 10,200.00 89.91 18.17 4,383.32 4,335.22 2,742.49 4,438.34 6,018,794.12 573,734.45 2.00 5,014.86 10,300.00 89.91 16.17 4,383.47 4,335.37 2,838.03 4,467.86 6,018,889.92 573,763.07 2.00 5,105.40 10,400.00 89.91 14.17 4,383.63 4,335.53 2,934.55 4,494.02 6,018,986.66 573,788.33 2.00 5,194.41 10,500.00 89.90 12.17 4,383.80 4,335.70 3,031.91 4,516.79 6,019,084.23 573,810.19 2.00 5,281.78 482019 7.31:19PM Pace 5 COMPASS 5000.15 Build 91 Planned Survey Measured Halliburton H A L L I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Rig: MPU E40 Company: Hilcorp Alaska, LLC TVD Reference: MPU E40 Planned RKB @ 48.10usft Project: Milne Point MD Reference: MPU E40 Planned RKB ® 48.10usft Site: M Pt E Pad North Reference: True Well: Rig: MPU E40 Survey Calculation Method: Minimum Curvature Wellbore: MPU E40i (usft) V) Design; MPU E40 wp06 (usft) usft Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss -NI-S +El -W Northing Easting DLS Vert (usft) V) V) (usft) usft (usft) (usft) (usft) (usft) 4,335.87 Section 10,600.00 89.90 10.17 4,383.97 4,335.87 3,130.01 4,536.16 6,019,182.49 573,828.64 2.00 5,367.39 10,609.22 89.90 9.98 4,383.99 4,335.89 3,139.09 4,537.77 6,019,191.59 573,830.17 2.00 5,375.19 End Dir : 10809.22' MD, 4383.99' TVD 4,386.54 6,018,649.00 573,684.00 - plan hits target center 10,700.00 89.90 9.98 4,384.15 4,336.05 3,228.50 4,553.50 6,019,281.13 573,845.07 0.00 5,451.93 10,800.00 89.90 9.98 4,384.32 4,336.22 3,326.98 4,570.84 6,019,379.76 573,861.49 0.00 5,536.46 10,900.00 89.90 9.98 4,384.50 4,336.40 3,425.47 4,588.17 6,019,478.39 573,877.90 0.00 5,621.00 11,000.00 89.90 9.98 4,384.68 4,336.58 3,523.96 4,605.50 6,019,577.03 573,894.31 0.00 5,705.53 11,100.00 89.90 9.98 4,354.85 4,336.75 3,622.44 4,622.84 6,019,675.66 573,910.73 0.00 5,790.06 11,200.00 89.90 9.98 4,385.03 4,336.93 3,720.93 4,640.17 6,019,774.29 573,927.14 0.00 5,874.59 11,300.00 89.90 9.98 4,385.21 4,337.11 3,819.42 4,657.50 6,019,872.93 573,943.56 0.00 5,959.13 11,400.00 89.90 9.98 4,385.38 4,337.28 3,917.90 4,674.84 6,019,971.56 573,959.97 0.00 6,043.66 11,500.00 89.90 9.98 4,385.56 4,337.46 4,016.39 4,692.17 6,020,070.20 573,976.39 0.00 6,128.19 11,600.00 89.90 9.98 4,385.73 4,337.63 4,114.87 4,709.50 6,020,168.83 573,992.80 0.00 6,212.72 11,700.00 89.90 9.98 4,385.91 4,337.81 4,213.36 4,726.84 6,020,267.46 574,009.22 0.00 6,297.26 11,800.00 89.90 9.98 4,386.09 4,337.99 4,311.85 4,744.17 6,020,366.10 574,025.63 0.00 6,381.79 11,900.00 89.90 9.98 4,386.26 4,338.16 4,410.33 4,761.50 6,020,464.73 574,042.04 0.00 6,466.32 12,000.00 89.90 9.98 4,386.44 4,338.34 4,508.82 4,778.83 6,020,563.37 574,058.46 0.00 6,550.86 12,100.00 89.90 9.98 4,386.62 4,338.52 4,607.30 4,796.17 6,020,662.00 574,074.87 0.00 6,635.39 12,200.00 89.90 9.98 4,386.79 4,338.69 4,705.79 4,813.50 6,020,760.63 574,091.29 0.00 6,719.92 12,300.00 89.90 9.98 4,386.97 4,338.87 4,804.28 4,830.83 6,020,859.27 574,107.70 0.00 6,804.45 12,400.00 89.90 9.98 4,387.15 4,339.05 4,902.76 4,848.17 6,020,957.90 574,124.12 0.00 6,888.99 12,500.00 89.90 9.98 4,387.32 4,339.22 5,001.25 4,865.50 6,021,056.54 574,140.53 0.00 6,973.52 12,600.00 89.90 9.98 4,387.50 4,339.40 5,099.74 4,882.83 6,021,155.17 574,156.95 0.00 7,058.05 12,700.00 89.90 9.98 4,387.67 4,339.57 5,198.22 4,900.17 6,021,253.80 574,173.36 0.00 7,142.58 12,800.00 89.90 9.98 4,387.85 4,339.75 5,296.71 4,917.50 6,021,352.44 574,189.77 0.00 7,227.12 12,900.00 89.90 9.98 4,388.03 4,339.93 5,395.19 4,934.83 6,021,451.07 574,206.19 0.00 7,311.65 12,941.50 89.90 9.98 4,388.10 4,340.00 5,436.06 4,942.02 6,021,492.00 574,213.00 0.00 7,346.73 Total Depth : 12941.5' MD, 4388.1' TVD Targets Target Name - hiVmiss target Dip Angle Dip Dir. TVD +NI -S +EAW Northing Easting -Shape (') (1) (usft) (usft) (waft) (usft) (usft) MPE-Kayner NB Heel 0.00 0.00 4,373.10 -749.58 3,092.22 6,015,290.00 572,421.00 - plan misses target center by 16.49usft at 6457.90usft MD (4357.91 TVD, -746.06 N, 3086.84 E) - Circle (radius 100.00) MPU E40 wp06 CP1 0.00 0.00 4,383.10 2,597.84 4,386.54 6,018,649.00 573,684.00 - plan hits target center - Point MPU E40 wp06 Toe 0.00 0.00 4,388.10 5,436.06 4,942.02 6,021,492.00 574,213.00 - plan hits target center - Point 4/92019 7:31:19PM Page 6 COMPASS 500015 Build 91 HALLIBURTON Database: NORTH US+CANADA Local Co-ordinate Reference: Company: Hilcorp Alaska, LLC TVD Reference: Project: Milne Point MD Reference: Site: M Pt E Pad North Reference: Well: Rig: MPU E-40 Survey Calculation Method: Wellbore: MPU E -40i SV2 Design: MPU E40 wp06 Ugnu LA3 Casing Points 4,151.10 Ugnu MB 480.00 Measured Vertical -9.06 -5.23 Depth Depth 1,675.00 1,527.22 (usft) (usft) Name End Dir : 1675' MD, 1527.22' TVD 12,941.50 4,388.10 41/2"x81/2" 3,016.75 -1,555.46 6,635.00 4,373.35 9 5/8"x 12 1/4" Start Dir 4.3°/100': 3950' MD, 3016.757VD Formations Measured Vertical Vertical Measured Depth Depth Depth SS (usft) (usft) Name 2,191.06 1,865.10 BPRF 2,751.58 2,232.10 SV2 5,254.46 3,893.10 Ugnu LA3 5,741.09 4,151.10 Ugnu MB Halliburton Standard Proposal Report Well Rig: MPU E40 MPU E40 Planned RKB @ 48.10usft MPU E40 Planned RKB @ 48.10usft True Minimum Curvature Casing Hole Diameter Diameter 4-1/2 8-1/2 9-5/8 12-1/4 Dip Dip Direction Lithology (I (I Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/4 +E/ -W (usft) (usft) (usft) (usft) Comment 280.00 280.00 0.00 0.00 Start Dir 3°/100' : 280' MD, 280'TVD 480.00 479.63 -9.06 -5.23 Start Dir 4.02°/100': 480' MD, 479.6TTVD 1,675.00 1,527.22 -391.53 314.98 End Dir : 1675' MD, 1527.22' TVD 3,950.00 3,016.75 -1,555.46 1,580.74 Start Dir 4.3°/100': 3950' MD, 3016.757VD 5,300.00 3,919.19 -1,604.87 2,505.41 Start Dir 4.21°/100': 5300' MD, 3919.19'TVD 5,845.00 4,199.14 -1,273.11 2,828.88 Start Dir 4.2°/100': 5645' MD, 4199.147VD 6,416.68 4,354.32 -784.34 3,071.96 End Dir : 6416.68' MD, 4354.32' TVD 6,632.15 4,373.10 -584.28 3,149.76 Start Dir 4°/100': 6632.15' MD, 4373,1'TVD 6,755.17 4,378.55 -469.77 3,194.28 End Dir : 6755.1T MD, 4378.55' TVD 10,046.33 4,383.10 2,597.84 4,386.54 Start Dir 2°/100' : 10046.33' MD, 4383.17VD 10,609.22 4,383.99 3,139.09 4,537.77 End Dir : 10809.22' MD, 4383.99' TVD 12,941.50 4,388.10 5,436.06 4,942.02 Total Depth: 12941.5'MD, 4388.1'TVD 4/92019 7:31:19PM Pace 7 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad Rig: MPU E-40 MPU E -40i MPU E-40 wp06 Sperry Drilling Services Clearance Summary Anticollision Report 09 April, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt E Pad - Rig: MPU E-40 - MPU E-401 - MPU E-40 wp06 Well Coordinates: 6,016,010.71 N, 569,322.23 E (70° 27' 14.75" N, 149° 26' 03.53" W) Datum Height: MPU E40 Planned RKB @ 46.10usft Scan Range: 26.50 to 6,635.00 usR. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.15 Build; 91 Scan Type: NO GLOBAL FILTER: Using user defined selection & fiftering criteria Scan Type: 25.00 HALLIBURTON Sperry Drilling Services Hilcorp Alaska, LLC HALLIBURTON . Milne Point Anticollision Report for Rig: MPU E-40 - MPU E-40 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt E Pad -Rig: MPU E-00 - MPU E40i -MPU Edo wp06 Scan Range: 26.60 to 6,635.00 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measure Minimum @Measure Ellipse @Measure Clearance Summary Based Site Name d Distance d Separation d Factor on Minimum Separation Warning Comparison Well Name - Wellbore Name - Design Depth lusftl Depth lusftl Deolh M Pt E Pad MPE-04 - MPE-04 - MPE-04 26.50 494.50 26.50 493.58 36.13 539.770 Centre Distance Pan - MPE-04-MPE-04-MPE-04 6,635.00 582.66 6,635.00 396.04 5,859.67 3.122 Clearance Factor Pass - MPE-05 - MPE-05 - MPE-05 26.50 439.53 26.50 438.61 37.08 479.818 Centre Distance Pass - MPE-05 - MPE-05 - MPE-05 301.50 440.68 301.50 437.20 313.26 126.630 Ellipse Separation Pass - MPE-05 - MPE-05 - MPE-05 6,051.50 748.85 6,051.50 659.01 5,681.94 8.335 Clearance Factor Pass - MPE-08 - MPE-08 - MPE-08 26.50 675.38 26.50 674.31 34.50 632.315 Centre Distance Pass - MPE-08 - MPE-08 - MPE-08 301.50 676.72 301.50 673.25 309.77 195.335 Ellipse Separation Pass - MPE-08 - MPE-08 - MPE-08 2,276.50 1,508.42 2,276.50 1,486.50 2,112.98 68.819 Clearance Factor Pass - MPE-09 - MPE-09 - MPE-09 287.83 330.39 287.83 327.70 294.36 122.425 Centre Distance Pass - MPE-09 - MPE-09 - MPE-09 5,601.50 641.93 5,601.50 349.62 5,709.65 2.196 Clearance Factor Pass - MPE-09 - MPE-09 - MPE-09 5,751.50 574.83 5,751.50 326.52 5,768.59 2.315 Ellipse Separation Pass - MPE-09-MPE-09PB1-MPE-09PB1 287.83 330.39 287.83 327.59 294.36 117.657 Centre Distance Pass - MPE-09 - MPE-09PBI - MPE-09PB1 5,601.50 641.93 5,601.50 349.51 5,709.65 2.195 Clearance Factor Pass - MPE-09-MPE-09PB1-MPE-09PB1 5,751.50 574.83 5,751.50 326.42 5,768.59 2.314 Ellipse Separation Pass - MPE-1 0 - MPE-1 0 - MPE-1 0 26.50 510.63 26.50 509.71 31.73 556.069 Centre Distance Pass - MPE-10 - MPE-1 0 - MPE-1 0 376.50 512.78 376.50 508.59 386.97 122.181 Ellipse Separation Pass - MPE-10 - MPE-1 0 - MPE-10 6,501.50 775.77 6,501.50 650.53 5,935.59 6.194 Clearance Factor Pass - MPE-11 - MPE-11 - MPE-11 5,068.14 130.65 5,068.14 68.08 5,500.05 2.088 Centre Distance Pass - MPE-11 - MPE-11 - MPE-11 5,126.50 138.55 5,126.50 59.31 5,537.23 1.749 Ellipse Separation Pass - MPE-11 - MPE-11 - MPE-11 5,151.50 146.53 5,151.50 61.79 5,552.52 1.729 Clearance Factor Pass - MPE-1 2 - MPE-1 2 - MPE-1 2 26.50 218.49 26.50 217.41 35.74 203.070 Centre Distance Pass - MPE-12 - MPE-1 2 - MPE-1 2 276.50 219.08 276.50 215.19 283.37 56.240 Ellipse Separation Pass - MPE-12 - MPE-1 2 - MPE-12 476.50 234.59 476.50 229.10 469.64 42.686 Clearance Factor Pass - 270.09 150.20 270.09 147.71 279.69 60.384 Centre Distance Pass - MPE-14 - MPE-14 - MPE-14 326.50 150.43 326.50 147.51 336.05 51.488 Ellipse Separation Pass - MPE-14 - MPE-14 - MPE-14 MPE-14 - MPE-14 - MPE-14 3,476.50 1,547.64 3,476.50 1,497.46 3,477.13 30.840 Clearance Factor Pass - MPE-1 4 - MPE-1 4A - MPE-1 4A 270.09 150.20 270.09 147.93 279.69 66.055 Centre Distance Pan - MPEA 4-MPE-14A-MPE-14A 326.50 150.43 326.50 147.72 336.05 55.548 Ellipse Separation Pass - 09 April, 2019 - 19:42 Page 2 of 8 COMPASS HALLIBURTON Anticollision Report for Rig: MPU E-40 - MPU E-40 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt E Pad - Rig: MPU E-40 - MPU EdOi - MPU E-40 woos Scan Range: 26.50 to 6,636.00 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Hilcorp Alaska, LLC Milne Point 09 April, 2019 . 19:42 Page 3 of 8 COMPASS Measure Minimum @Measure Ellipse @Measure Clearance Summary Based Site Name o Distance d Separation d Factor on Minimum Separation Warning Comparison Well Name -Wellbore Name -Design Deoth lusftl Death Weal Death MPE-14 - MPE-14A - MPE-14A 3,476.50 1,547.64 3,476.50 1,498.04 3,477.13 31.200 Clearance Factor Pass - MPE-14 - MPE-14APBl - MPE-14APB1 270.09 150.20 270.09 147.82 279.69 63.162 Centre Distance Pass - MPE-14-MPE-I4APBI-MPE-I4APB1 326.50 150.43 326.50 147.62 336.05 53.490 Ellipse Separation Pass - MPE-14-MPE-I4APB1-MPE-I4APB1 3,476.50 1,547.64 3,476.50 1,497.93 3,477.13 31.131 Clearance Factor Pass - MPE-1 5 - MPE-1 5 - MPE-1 5 307.78 119.94 307.78 115.24 314.22 25.500 Centre Distance Pass - MPE-15 - MPE-15 - MPE-15 401.50 120.71 401.50 114.56 407.98 19.636 Ellipse Separation Pass - MPE-1 5 - MPE-15 - MPE-15 726.50 151.16 726.50 140.76 731.94 14.545 Clearance Factor Pass - MPE-17 - MPE-17 - MPE-17 78.72 199.01 78.72 197.64 84.22 145.988 Centre Distance Pass - MPE-1 7 - MPE-1 7 - MPE-1 7 276.50 199.72 276.50 196.50 280.80 62.006 Ellipse Separation Pass - MPE-1 7 - MPE-1 7 - MPE-1 7 5,501.50 1,202.08 5,501.50 1,057.05 5,116.57 8.289 Clearance Factor Pass - MPE-20 - MPE-20 - MPE-20 348.51 209.26 348.51 205.69 357.01 58.713 Centre Distance Pass - MPE-20 - MPE-20 - MPE-20 376.50 209.37 376.50 205.59 384.49 55.403 Ellipse Separation Pass - MPE-20 - MPE-20 - MPE-20 751.50 246.71 751.50 240.85 755.66 42.089 Clearance Factor Pan - MPE-20-MPE-20A-MPE-20A 348.51 209.26 348.51 205.69 361.76 58.713 Centre Distance Pass - MPE-20 - MPE-20A - M PE -20A 376.50 209.37 376.50 205.59 389.24 55.403 Ellipse Separation Pass - MPE-20 - MPE-20A - MPE-20A 751.50 246.71 751.50 240.85 760.41 42.089 Clearance Factor Pan - MPE-20 - MPE-20AL1 - MPE-20ALl 348.51 209.26 348.51 206.06 361.76 65.509 Centre Distance Pass - MPE-20-MPE-20ALl-MPE-20AL1 376.50 209.37 376.50 205.96 389.24 61.413 Ellipse Separation Pass - MPE-20 - MPE-20ALl - MPE-20ALl 776.50 252.36 776.50 246.73 784.04 44.875 Clearance Factor Pass - MPE-20-MPE-20AL1 PBI -MPE-20ALl PBI 348.51 209.26 348.51 205.93 361.76 62.944 Centre Distance Pass - MPE-20 - MPE-20ALl PBI -MPE-20AL1 PBI 376.50 209.37 376.50 205.83 389.24 59.153 Ellipse Separation Pass - MPE-20 - MPE-20ALl Pal -MPE-20ALl PBI 776.50 252.36 776.50 246.60 784.04 43.860 Clearance Factor Pass - MPE-21 - MPE-21 - MPE-21 279.53 339.05 279.53 336.79 288.80 150.168 Centre Distance Pass - MPE-21 - MPE-21 - MPE-21 301.50 339.11 301.50 336.72 310.80 141.920 Ellipse Separation Pass - MPE-21 - MPE-21 - MPE-21 6,501.50 793.78 6,501.50 662.81 5,990.00 6.061 Clearance Factor Paw - MPE-22-MPE-22-MPE-22 5,226.50 149.08 5,226.50 64.79 5,658.99 1.769 Clearance Factor Pass - MPE-22 - MPE-22 - MPE-22 5,251.50 142.30 5,251.50 64.01 5,673.69 1.818 Ellipse Separation Pass - MPE-22 - MPE-22 - MPE-22 5,301.50 136.58 5,301.50 73.70 5,701.69 2.172 Centre Distance Pan - MPE-23-MPE-23-MPE-23 6,621.80 104.13 6,621.80 52.01 6,187.04 1.998 Centre Distance Pan - MPE-23-MPE-23-MPE-23 6,635.00 104.94 6,635.00 49.74 6,189.16 1.901 Clearance Factor Pass - 09 April, 2019 . 19:42 Page 3 of 8 COMPASS HALLIBURTON Anticollision Report for Rig: MPU E-40 - MPU E-40 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) Reference Design: M Pt E Pad - Rig: MPU E40 - MPU E401- MPU E40 wp06 Scan Range: 26.50 to 6,635.00 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Hilcorp Alaska, LLC Milne Point 09 April, 2019 . 19:42 Page 4 of 8 COMPASS Measure Minimum @Measure Ellipse @Measure Clearance Summary Basad Site Name d Distance d Separation d Factor on Minimum Separation Wanting Comparison Well Name - Wellbon±Name- Design Death fusal Death tusftl Death MPE-24 - MPE-24 - MPE-24 282.61 179.61 282.61 177.01 291.79 68.928 Centre Distance Pass - MPE-24 - MPE-24 - MPE-24 326.50 179.81 326.50 176.87 335.40 61.099 Ellipse Separation Pass - MPE-24 - MPE-24 - MPE-24 3,276.50 1,517.23 3,276.50 1,450.93 3,084.05 22.886 Clearance Factor Pass - MPE-24 - MPE-24A - MPE-24A 282.61 179.61 282.61 177.12 288.39 71.948 Centre Distance Pass - MPE-24 - MPE-24A - MPE-24A 326.50 179.81 326.50 176.98 332.00 63.457 Ellipse Separation Pass - MPE-24 - MPE-24A - MPE-24A 3,276.50 1,517.23 3,276.50 1,451.22 3,080.65 22.985 Clearance Factor Pass - MPE-24-MPE-24ALl-MPE-24AL1 282.61 179.61 282.61 177.12 288.39 71.948 Centre Distance Pass - MPE-24-MPE-24ALl-MPE-24AL1 326.50 179.81 326.50 176.98 332.00 63.457 Ellipse Separation Pass - MPE-24-MPE-24ALI-MPE-24AL1 3,276.50 1,517.23 3,276.50 1,451.15 3,080.65 22.960 Clearance Factor Pass - MPE-30- MPE-30ALl - MPE-30ALl 333.93 391.20 333.93 388.62 350.77 151.765 Centre Distance Pass - MPE-30 - MPE-30ALl - MPE-30ALl 351.50 391.24 351.50 388.52 369.11 144.020 Ellipse Separation Pass - MPE-30 - MPE-30ALl - MPE-30ALl 1,076.50 558.85 1,076.50 552.17 1,028.10 83.701 Clearance Factor Pass - MPE30-MPE-30AL1 PB1 - MPE-30ALl P81 333.93 391.20 333.93 388.49 350.77 144.467 Centre Distance Pass - MPE-30 - MPE-30ALl PB1 - MPE-30ALl P131 351.50 391.24 351.50 388.39 369.11 137.433 Ellipse Separation Pass - MPE-30-MPE-30AL1 PB1 -MPE30ALl PB1 1,076.50 556.85 1,076.50 552.04 1,028.10 82.099 Clearance Factor Pass - MPE-32 - MPE-32 - MPE-32 26.50 552.21 26.50 550.87 33.54 410.827 Centre Distance Pass - MPE-32 - MPE-32 - MPE-32 301.50 553.20 301.50 548.96 305.60 130.648 Ellipse Separation Pass - MPE-32-MPE32-MPE-32 6,635.00 1,133.72 6,635.00 925.81 6,823.98 5.453 Clearance Factor Pass - MPE-32 - MPE-321-1 - MPE-321-1 26.50 552.21 26.50 550.87 33.54 410.827 Centre Distance Pass - MPE-32 - MPE-321-1 - MPE-321-1 301.50 553.20 301.50 548.96 305.60 130.648 Ellipse Separation Pass - MPE-32 - MPE-32LI - MPE-321-1 6,635.00 1,143.51 6,635.00 954.93 6,826.72 6.064 Clearance Factor Pass - MPE-32-MPE-32PB1-MPE-32PB1 26.50 552.21 26.50 550.87 33.54 410.827 Centre Distance Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 301.50 553.20 301.50 548.96 305.60 130.648 Ellipse Separation Pass - MPE-32-MPE-32PB1-MPE-32PB1 6,635.00 1,132.78 6,635.00 912.71 6,846.83 5.147 Clearance Factor Pass - MPU E-35 - MPU E-35 - MPU E-35 26.50 160.82 26.50 159.91 27.12 176.327 Centre Distance Pass - MPU E -35 -MPU E -35 -MPU E-35 276.50 161.15 276.50 158.42 276.19 59.148 Ellipse Separation Pass - MPU E -35 -MPU E -35 -MPU E-35 501.50 186.98 501.50 182.92 479.30 46.017 Clearance Factor Pass - MPU E-35- MPU E-35 PBI - MPU E-35 PB1 26.50 160.82 26.50 159.91 27.12 176.327 Centre Distance Pass - MPU E-35 - MPU E-35 PB1 - MPU E-35 PBI 276.50 161.15 276.50 158.42 276.19 59.148 Ellipse Separation Pass - MPU E35 - MPU E-35 PB1 - MPU E-35 PBI 501.50 186.98 501.50 182.92 479.30 46.017 Clearance Factor Pass - 09 April, 2019 . 19:42 Page 4 of 8 COMPASS HALLIBURTON Anticollision Report for Rig: MPU E-40 - MPU E-40 wp06 uosest npproacn au Proximity scan on Current Survey Data (Highside Reference) Reference Design: M Pt E Pad - Rig: MPU E-40 - MPU E40i - MPU E-40 wp06 Scan Range: 26.50 to 6,636.00 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Hilcorp Alaska, LLC Milne Point 09 April, 2019 . 19:42 Page 5 of 8 COMPASS Measure Minimum @Measure Ellipse @Measure Clearance Summary Based Site Name d Distance d Separation d Factor on Minimum Separation Warning Comparison Well Name- Wellbore Name -Design Depth lusft) Depth !usft) Depth MPU E -36 -MPU E -36 -MPU E-36 26.50 169.13 26.50 168.22 26.65 185.477 Centre Distance Pass - MPU E -36 -MPU E -36 -MPU E-36 276.50 169.67 276.50 166.57 275.22 54.661 Ellipse Separation Pass - MPU E -36 -MPU E -36 -MPU E-36 501.50 193.45 501.50 188.28 482.62 37.361 Clearance Factor Pass - MPU E-36 - MPU E-36PB7 - MPU E-36PB7 26.50 169.13 26.50 168.22 26.65 185.477 Centre Distance Pass - MPU E-36 - MPU E-36PB7 - MPU E-36PB7 276.50 169.67 276.50 166.57 275.22 54.661 Ellipse Separation Pass - MPU E -36 -MPU E-36PB7-MPU E-36PB7 501.50 193.45 501.50 188.28 482.62 37.361 Clearance Factor Pass- MPU E -37 -MPU E -37 -MPU E-37 26.50 182.09 26.50 181.18 26.88 199.648 Centre Distance Pass - MPU E -37 -MPU E -37 -MPU E-37 176.50 182.28 176.50 180.28 175.82 90.825 Ellipse Separation Pass - MPU E -37 -MPU E -37 -MPU E-37 501.50 214.18 501.50 210.10 478.34 52.579 Clearance Factor Pass - MPU E-37 - MPU E-37 PBI - MPU E-37 PB7 26.50 182.09 26.50 181.18 26.88 199.648 Centre Distance Pass - MPU E-37 - MPU E-37 PB7 - MPU E-37 PSI 176.50 182.28 176.50 180.26 175.82 90.825 Ellipse Separation Pass - MPU E-37- MPU E-37 P81 - MPU E-37 FBI 501.50 214.18 501.50 210.10 478.34 52.579 Clearance Factor Pass - MPU E41 - MPU E41 - MPU E41 26.50 30.34 26.50 29.55 27.08 38.540 Centre Distance Pass - MPU E41 - MPU E41 - MPU E41 301.50 31.07 301.50 28.40 301.98 11.629 Ellipse Separation Pass - MPU E41 - MPU E41 - MPU E41 526.50 35.54 526.50 31.28 528.51 8.337 Clearance Factor Pass - MPU E41 -MPU E41 PBI -MPU E41 FBI 26.50 30.34 26.50 29.43 27.08 33.258 Centre Distance Pass - MPU E41 - MPU E41 P81 - MPU E41 PBI 301.50 31.07 301.50 28.27 301.98 11.110 Ellipse Separation Pass - MPU E41 - MPU E41 PBI - MPU E41 PB1 526.50 35.54 526.50 31.16 528.51 8.099 Clearance Factor Pass - MPU E41 - MPU E41 PB2 - MPU E41 PB2 26.50 30.34 26.50 29.43 27.08 33.258 Centre Distance Pass - MPU E41 - MPU E41 PB2 - MPU E41 PB2 301.50 31.07 301.50 28.27 301.98 11.110 Ellipse Separation Pass - MPU E41 - MPU E41 PB2- MPU E41 PB2 526.50 35.54 526.50 31.16 528.51 8.099 Clearance Factor Pass - MPUE41-MPU E41 PB3-MPU E41 PB3 26.50 30.34 26.50 29.43 27.06 33.258 Centre Distance Pass - MPU E41 -MPU E41 PB3-MPU E41 PB3 301.50 31.07 301.50 28.27 301.98 11.110 Ellipse Separation Pass - MPU E41 -MPU E41 PB3-MPU E41PB3 526.50 35.54 526.50 31.16 528.51 8.099 Clearance Factor Pass- Plan: MPU E-38 - MPE-38 - MPU E-38 wp09 276.50 90.62 276.50 87.61 276.70 30.140 Centre Distance Pass - Plan: MPU E-38 - MPE-38 - MPU E-38 wp09 326.50 90.84 326.50 87.41 326.65 26.511 Ellipse Separation Pass - Plan: MPU E-38 - MPE-38 - MPU E-38 wp09 501.50 98.26 501.50 93.40 499.00 20.245 Clearance Factor Pass - Prelim DualLatPlan: MPU E-39- MPU E -39i - MPU E-39 w 276.50 60.15 276.50 57.43 276.60 22.087 Centre Distance Pass - Prelim DualLatPlan: MPU E-39 - MPU E-391- MPU E-39 w 501.50 61.32 501.50 56.91 504.95 13.914 Ellipse Separation Pass - Prelim Duall-atPlan: MPU E-39 - MPU E -39i - MPU E-39 w 726.50 69.16 726.50 63.74 735.04 12.758 Clearance Factor Pass - 09 April, 2019 . 19:42 Page 5 of 8 COMPASS HALLIBURTON Anticollision Report for Rig: MPU E-40 - MPU E-40 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (Highside Reference) @Measure Reference Design: M Pt E Pad - Rig: MPU E-40 - MPU EdOi - MPU Edo WP06 d Scan Range: 26.50 to 6,635.00 usH. Measured Depth. Death 20.16 Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 685.65 Measure Minimum @geasure Site Name It Distance If Comparison Well Name - Wellbore Name - Design Death (usH1 Death Prelim: MPU E -Pad Expansion Placeholder- Wellbore # 641.27 25.32 641.27 Prelim: MPU E -Pad Expansion Placeholder- Wellbore # 651.50 25.36 651.50 Prelim: MPU E -Pad Expansion Placeholder- Wellbore # 676.50 25.77 676.50 Survey too/ Program From To (uatH tusftl 26.50 480.00 MPU E40 wp06 480.00 6,635.00 MPU Edo wp06 6,635.00 12,941.50 MPU Edo wp06 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. Ellipse @Measure Separation d (usNl Death 20.16 675.56 20.14 685.65 20.43 710.26 Clearance Summary Based Factor on Minimum 4.903 Centre Distance 4.862 Ellipse Separation 4.829 Clearance Factor Survey/Plan Survey Tool 2_Gyro-NS-GC Drill collar 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point Separation Warding Pass - Pass - Pass - 09 April 2019 - 19:42 Page 6 o/ 8 COMPASS REFERENCE INFORMATION WELL DEARSR& Mptr 40 NAD191](NADCONCONUS) M=6 Zone 04 HALLIBURTON Project Milne Point Co iroM(ME)Refmre : Was Rig, MW E40, Toe NMS CrtouM Level 21'60 Site: MPt EPad Wrsoj(rVD) ReNreNe: MPD Ei flared RKB®49.Ioft +N/-S +F1-W Northing Fislir�S VSde 1'°OSI Well: Rig: MPU E-40 Measures De{M Relererrca: MPU EJO Planned RKB ®4e.t0us0 000 0.00 6016010.]1 5693]2.23 ]0°2T 14]492N 149°26'3.5296' Wellbore: MPU E-40i CelwMlion Ma0o4: Mnimum cuonure Plan: MPU E-40 wp06 SURVEY PROGRAM NO GLOBAL FILTER: Using user defined selection 8 08ering criteria Date: 201&10-19T00:00:00 Validated: Yes Version: 26.50 To 7000.00 Ladder / S.F. Plots Depth From Depth To Survey/Plan Tool 2 Gyro-NS-GC Drill -lw CASING DETAILS 26.50 480.00 MPU E40 NpD6 TVD TVDSS MD Sime Nams SH(1 of 2) 480.00 6835.00 MPU E40 wpD6 2MWD+IFR2+M5+Seg 4373.35 12941.50 MPU E40 Wp06 2MWD +IFR2+MS+$ag 4325.25 6635.00 9-5/8 95/8"z 121/4" 6635.00 4388.10 4340.00 12941.50 4.1/2 41/2"x81/2" 180.00 MPE-24 CUE-36 M ,SL150.00 II4PE-15 '( O _ M E-22 - - - 51120.00 _ MP -23 roU E-38 WP 9. N 90.00 -� -- 0) _ _ MPU E-39 wp03 d _ b U60.00 -- - y N M U EA7 N 30.00~- 4) M U E Place older 0.00- 0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650 Measured Depth (700 usft/in) \\ 4.00-- .00 _LL LL C Collision Risk Procedures Req. 22.00- 2.00Collision Collision Avoidance Req. d to No-Go Zone -Stop Drilling 1.00 - NOERRORS 0.00 0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650 Measured Depth (700 usfttin) Hilcorp Alaska, LLC Milne Point M Pt E Pad Rig: MPU E-40 MPU E -40i MPU E-40 wp06 Sperry Drilling Services Clearance Summary Anticollision Report 09 April, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Rig: MPU E40 - MPU E40i - MPU E40 wp06 Well Coordinates: 6,016,010.71 N, 569,322.23 E (70° 27' 14.75" N, 149' 26'03.63" W) Datum Height: MPU E40 Planned RKB @ 48.10usft Scan Range: 6,635.00 to 12,941.50 usR. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: NO GLOBAL FILTER: Using user defined selection a filtering criteria Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Rig: MPU E-40 - MPU E-40 wp06 Closest Approach 30 Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Rig: MPU E-40 - MPU E-401 - MPU E40 wp06 Scan Range: 6,635.00 to 12,941.50 usfL Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Hileorp Alaska, LLC Milne Point Measure Minimum @Measure Ellipse @Measure Clearance Summary Based Site Name d Distance d Separation d Factor on Minimum Separation Warning Comparison Well Name - Wellbore Name - Design Death (usfn Death fusR) Deoth M Pt B Pad MPB-05 - MPB-05 - MPB-05 12,941.50 1,551.67 12,941.50 1,374.93 5,446.52 8.779 Clearance Factor Pan - MPB-05- MPB-05A- MPB-05A 12,941.50 1,333.68 12,941.50 1,068.34 5,702.54 5.026 Clearance Factor Pan - MPB-I3-MPB-I3-MPB-13 12,588.04 241.23 12,588.04 59.42 5,921.96 1.327 Centre Distance Paw - MPBA3-MPB-I3-MPB-13 12,710.00 258.42 12,710.00 26.87 5,844.44 1.116 Clearance Factor Pass - MPB-I5-MPB-l5-MPB-15 12,150.29 1,410.10 12,150.29 1,189.91 5,402.69 6.404 Centre Distance Pass - MPB-1 5 - MPBA 5 - MPB-1 5 12,210.00 1,410.79 12,210.00 1,189.42 5,365.08 6.373 Ellipse Separation Pass - MPB-I5-MPB-I5-MPB-15 12,410.00 1,422.06 12,410.00 1,197.95 5,233.42 6.345 Clearance Factor Pass - MPB-27 - MPB-27 - MPB-27 10,110.00 854.12 10,110.00 618.25 8,480.00 3.621 Clearance Factor Pass - MPB-27-MPB-27-MPB-27 10,310.00 796.42 10,310.00 588.23 8,480.00 3.825 Ellipse Separation Pass - MPB-27 - MPB-27 - MPB-27 10,397.56 790.28 10,397.56 596.29 8,480.00 4.074 Centre Distance Pass - M Pt E Pad MPE-04 - MPE-04 - MPE-04 6,735.00 512.89 6,735.00 342.78 5,870.48 3.015 Clearance Factor Pass - MPE-04-MPE-04-MPE-04 6,910.00 425.86 6,910.00 304.75 5,883.29 3.516 Ellipse Separation Pass - MPE-04 - MPE-04 - MPE-04 7,056.93 399.85 7,056.93 320.20 5,894.08 5.020 Centre Distance Pass - MPE-05 - MPE-05 - MPE-05 6,635.00 1,131.99 6,635.00 1,026.85 5,640.32 10.766 Clearance Factor Pass - MPE-08 - MPE-08 - MPE-08 8,460.00 722.25 8,460.00 635.65 6,414.37 8.340 Clearance Factor Pass - MPE-08 - MPE-08 - MPE-08 8,500.19 721.30 8,500.19 634.84 6,430.06 8.343 Ellipse Separation Pass - MPE-09 - MPE-09 - MPE-09 6,635.00 738.96 6,635.00 518.11 5,833.13 3.346 Ellipse Separation Pass - MPE-09 - MPE-09 - MPE-09 6,760.00 824.58 6,760.00 574.16 5,822.70 3.293 Clearance Factor Pass - MPE-09 - MPE-09PB1 - MPE-09PB1 6,635.00 738.96 6,635.00 518.00 5,833.13 3.344 Ellipse Separation Pass - MPE-09-MPE-09PB1-MPE-09PBl 6,760.00 824.58 6,760.00 574.06 5,822.70 3.291 Clearance Factor Pass - MPE-1 0 - MPE-10 - MPE-10 7,064.52 557.48 7,064.52 507.85 6,033.39 11.233 Centre Distance Pass - MPE-1 0 - MPE-1 0 - MPE-1 0 7,185.00 570.09 7,185.00 502.90 6,050.63 8.484 Ellipse Separation Pass - MPE-1 0 - MPE-1 0 - MPE-1 0 7,585.00 759.08 7,585.00 622.93 6,105.84 5.575 Clearance Factor Pass - MPE-11 - MPE-11 - MPE-11 6,635.00 1,497.32 6,835.00 1,399.22 5,751.00 15.263 Clearance Factor Pass - MPE-1 2 - MPE-1 2 - MPE-1 2 9,067.23 82.59 9,067.23 24.82 7,636.19 1.430 Centre Distance Pass - MPE-12 - MPE-12 - MPE-12 - = 09 April, 2019 - 19:52 Page 2 of 6 COMPASS Hileorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Rig: MPU E-40 - MPU E-40 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Rig: MPU E-40 - MPU E40i - MPU E40 wp06 Scan Range: 6,635.00 to 12,941.60 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measure Minimum @Measure Ellipse @Measure Clearance Summary Based Site Name d Distance d Separation d Factor on Minimum Separation Warning Comparison Well Name - Wellbore Name - Design Death luaftl Death lusftl Death MPE-1 2 - MPE-12 - MPE-12 — MPE-17-MPE-17-MPE-17 6,635.00 1,049.28 6,635.00 996.77 5,442.17 19.982 Ellipse Separation Pass- MPE-17 - MPE-17 - MPE-17 7,535.00 1,448.40 7,535.00 1,298.62 5,516.04 9.670 Clearance Factor Pass- MPE-21 - MPE-21 - MPE-21 6,635.00 716.60 6,635.00 602.14 5,990.00 6.261 Clearance Factor Pass- MPE-21 - MPE-21 - MPE-21 6,860.00 639.23 6,860.00 562.08 5,990.00 8.286 Ellipse Separation Pass- MPE-21 - MPE-21 - MPE-21 6,971.91 629.36 6,971.91 568.38 5,990.00 10.322 Centre Distance Pass- MPE-22 - MPE-22 - MPE-22 6,635.00 1,270.21 6,635.00 1,173.99 5,857.71 13.201 Clearance Factor Pass- MPE-23 - MPE-23 - MPE-23 6,635.00 104.94 6,635.00 49.74 6,189.16 1.901 Centre Distance Pass- MPE-23 - MPE-23 - MPE-23 6,660.00 110.98 6,660.00 46.78 6,193.08 1.729 Ellipse Separation Pass- MPE-23 - MPE-23 - MPE-23 6,685.00 122.17 6,685.00 48.64 6,196.81 1.662 Clearance Factor Pass- MPE-30-MPE-30ALl-MPE-30AL1 12,285.00 770.44 12,285.00 529.33 9,290.00 3.195 Clearance Factor Pass- MPE-30-MPE-30ALl-MPE-30AL1 12,360.00 758.84 12,360.00 523.58 9,290.00 3.226 Ellipse Separation Pass- MPE-30-MPE-30ALl-MPE30AL1 12,440.78 754.53 12,440.78 527.67 9,290.00 3.326 Centre Distance Pass- MPE-30-MPE-30ALl PB1 - MPE-30AL1PB1 11,910.00 1,005.94 11,910.00 782.04 8,720.00 4.493 Clearance Factor Pass- MPE-30- MPE30AL1PB1-MPE-30AL1PB1 12,010.00 997.67 12,010.00 777.02 8,754.00 4.522 Ellipse Separation Paw - MPE-30-MPE-30AL1 PB1-MPE-30ALl PB1 12,067.58 996.01 12,067.58 779.80 8,754.00 4.607 Centre Distance Pass- MPE-32 - MPE-32 - MPE-32 — MPE-32-MPE-32-MPE-32 — MPE-32-MPE-32-MPE32 — MPE-32 - MPE-321-1 - MPE-321.1 7,792.91 75.61 7,792.91 37.79 7,035.66 1.999 Centre Distance Pan - MPE-32-MPE-321-1-MPE-321-1 1111mr-0WX �Gf gar. MPE-32 - MPE-321-1 - MPE-321-1 IM9,748 Ellipiyafio� MPE-32-MPE-32PB1-MPE-32PB7 I— Cleared eFactor� MPE32-MPE-32PB7-MPE-32PB1 Centre Distance MPE-32 - MPE-32PB1 - MPE-32PB1 1111W3 Ellipse Separation 09 April. 2019 - 19:52 Page 3 or 6 COMPASS HALLIBURTON Anticollision Report for Rig: MPU E-40 - MPU E-40 wp06 Survey fool oroaram From lusftl 26.50 480.00 6,635.00 To lusftl 480.00 MPU E-40 wp06 6,635.00 MPU E40 wp06 12,941.50 MPU E40 wp06 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 I (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. SumsylPlan Survey Tool 2_Gyro-NS-GC_Drill collar 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point 09 April, 2019 - 19:52 Page 4 of 6 COMPASS NALLIBURTONPro )act: Milne Point REFERENCE INFORMATION WFL,DETADaska Za SRiS:MPUEI0 NAD1927(NADCONCONUS) Alne04 Site: M Pt E Pad CD9MnMq INTI R.N..: Wen R4 MPU E<o. Norio Ground level: 21.0 3pa�ry Ortill:nq Well: Rig: MPU ids Vsumd nPN1 Rehrenwe: MPU Edo Planned RKB a 48.10nfl Measure40pMRelere MPU E40 Planned RKB®48.10mfl +N/-6 +0w Emsting Vt{node 26naitude Wellbore: MPU E40i i M: LalcuMnon Memos: MlMmum Curvature 0.00 000 6016010 71 569322.23 ]0°2T 14.7492N 149°26'3.5298 0160107 PlanMPU E-40 WpO6 SURVEY PROGRAM NO GLOBAL FILTER: Using user defined selection S filtering criteria Date:201&10-18700:00:00 Validated Ves Version: 6000.00 To 12941.50 Ladder / S.F. Plots Depth From Depth To Smey/Plan Tool CASING DETAILS PH(2 2) 28,50 480.00 MPU E4 wpO6 2 GyroN6-GC Dril collar 480.00 81335.00 MPU E-40 Wp06 2_MWDNFR2+MS+Ssg TVD TVDSS MD Si. N. of 8635.00 12941.50 MPUE-40WP06 2 MWD+IFR2+MS+Sag 4373.35 4325.25 6635.00 9-5/8 95/8"x121/4" 4388.10 4340.00 12941.50 4.1/2 4 12" z B 1/2" 80.00 180.00- X750.00 :5150.00- � I � I pOp r0120.00 ...._.... _ O M E-12-13 a) 90.00 /) U I fE-3FL1 - Eli U60.0 I I -- o E-�2 d 30.00 __-- UI I 0.00 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 72800 13200 13600 14000 Measured Depth (800 usf /in) m LL c 3.00- 0 Collision Risk Procedures Req. m n A N 2.00 Collision Avoidance Re 1.00 - No -Go Zone - Stop Drillin NOERRORS 0.00- 6500 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 12800 13200 13600 14000 Measured Depth (800 usftlin) TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development Service Exploratory _ Stratigraphic Test —Non -Conventional FIELD:�� E*�� v(� ` POOL: /i (r/fit f_ C i <cT _ c �C Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- _- (If last two digits Production should continue to be reported as a function of the original fu 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. (Comnanv 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) in the attached application, the following well logs are / also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Date: Well Name: MILNE PT UNIT E-40 Program SER Well bore seg ElPTD#:2190440 Company HILCORP ALASKA LLC Inifial Class/Type SER / PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached - - - _ . NA. 2 Lease number appropriate........ - - _ - - - - - - - - - Yes - - - - - - - - - - - - 3 Unique well name and number - - - - - - - - - - . Yes 4 Well located in a -defined pool . . . . . . . . . . . . . . . . ................. Yes Milne Point Schrader Bluff Oil Pool (525140), governed by CO 477, amended by CO 477.05, ...... - - - - 5 Well located proper distance from, drilling unit -boundary ........................ Yes - - CO 477.05_ specifies:. "There are no restrictions as to well spacing except that no pay shall- . - - - - - - - - 6 .Well located proper distance from other wells- - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ - be opened in a well closer than 500 feet from the exterior boundary of the affected area." 7 Sufficient acreage available in drilling unit . . . . . . . . ..... . ............. Yes .. Well bore conforms to spacing requirements ......... - - .. - - - - - - - - - - - . _ - - - - - - - - - 8 Jf deviated, is wellbore plat included - . - Yes 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - YeS 10 Operator has appropriate_ bond in force - . . . . .. . .............. Yes - 11 Permit can be issued without conservation order- - - . - - - - - - Yes - Appr Date 12 Permit can be issued without administrativeapproval- - - - - - - - - - - - - - - - - Yes 13 Can permit be approved before 15 -day. wait.... -- Yes SFD 4/9/2019 .... ....... �---- � ---� - - - - - - - - - - - - - - - - - - - ............. _ _ _ - - - . - _ _ _ _ _ ...... -- -- - 14 .Well located within area and strata authorized byInjectionOrder # (put 10# incomments) _(For. Yes _ . - _ _ . _ A10.1013 ......... 15 All wells. within 1/4. mile areaof review identified (For service well only)- - - - - - - - - - - - - - - Yes _ _ _ _ - _ _ MPU 13-05, 8-05A, 13-13, E-04, E-05, E -06,-E-12, E- 1, E-23, Er30A, E-31, E-32- 16 Pre -produced injector; duration of pre -production less than 3 months -(For service well only) .. No- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - ------ - - - - - - - - - - - - - - - 17 Nonoonven, gas conforms to AS31.05.030Q. 1.A),Q.2.A-D) - . - - - . - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - ------ - --------- 18 Conductor stringprovided- - - - , - - - . . . . . .... . . . .. . ... . . . Yes - - ..... 20" set at 107 fl. - Engineering 19 Surface casing -protects all known USDWs . . . . . . . . . . . . . ................. NA. .... NO aquifers. Permafrost area 20 CMT. vol adequate to circulate on.conductor& surf.csg - . - - - - - - - - - - - - - Yes - - - - 9 5/8" will be fullycementedusing ES tool at 2500 ft.... 21 CMT. vol adequate to tie-in long string to surf csg- _ - _ ... - - - - - - - _ - - Yes - 22 CMT -will cover all known productive horizons - .... Yes 23 Casing designs adequate for C. T, B & permafrost- --------- - - - - - - - - - - - - - - - - - Yes - _ - _ _ _ _ BTC calc_supplied and. meet industy standards 24 Adequate tankage or reserve pit - - - - - - - _ - - - Yes _ _ - _ - - - Rig has steel pits- - - - - ------- --- - - - - - - - - - - - - - - - ----- - - - 25 1f a -re -drill, has a 10.403 for abandonment been approved - - - - - - - - - - - - - - - ------ NA........ Grassroots injector well. -Using swellpackersand JCD _ - - 26 Adequate wellbore separation proposed...... - - . . ............ . . . . Yes _ _ - - _ Close_ approaches to E-12 and Er32, N13 -sand is just above the OA sand in these -wells.. - - 27 If diverter required, does it meet regulations - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Diverter used to -drill to$asand ,BOPEthereafter for the lateral. Appr Date 28 Drilling fluid program schematic & equip list adequate- - - - - - - - - - - - - - - - - - ----- Yes ....... Max form pressure =-1924 psi 8.4 ppg EMW- Will drill with -8.9-9.4 PPG mud - - - GLS 4/5/2019 29 BO -PEs, do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ Innovation rig has 13518" BOPE5000 psi WP- - - - - - - 30 BOPE-press rating appropriate; test to.(put psig in comments)____ _ _ _ _ _ _ _ _ _ _ _ _ Yes MASP = 1487- psi _Will test BOPE to 3000 psi. (annular to Z500 psi) 31 Chokemanifoldcomplies w/API RP -53 (May 84)-- - - --- - - - - - - - - - - - - - - - Yes 32 Work will occur without operation shutdown- - - Yes ... CBL not required if cement goes as planned. . .......... . 33 Is presence of H23 gas probable ................ ---- ---No..._---------------.-... ................. ------------- 34 Mechanical -condition of wells within AOR verified (Por service well only) . . ...... . . . . . . Yes _ - - _ - _ _ 1/4 mile AOR completed. _Wells in area are have mechanical-integrityexcept B-05........ 35 Permit can be issued w/o hydrogen sulfide measures - - - - - - - - - - - - - - - - - - - - - Yes _ - - - - _ H2S not anticipated from drilling of offset wells; however, rig will have H26 sensors and alarms, Geology 36 Datapresentedon potential overpressure zones - - - - - .... Yes ... - .. - Operator's plannedmudweights appear sufficient to controtexpected formation pressures, Operator Appr Date 37 Seismic analysis of shallow gas zones ............................. . . . . NA - - - - will have onsite materials sufficient to build.aclive system to -1- ppg above highest anticipated mud . . SFD 3/28/2019 38 Seabed condition survey (if off -shore) -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - weight. Gas hydrates expected -at base permafrost;.mitigation discussed in Drilling Hazards section. - - 39 Contact name/phone for weeklyprogress reports [exploratory only]. - - - - - - - - - - - - - - - - NA - - _ measures discussed -in "Anticipated Drilling Hazards"_ section, - - - - - Geologic Date: Engineering Public Gas hydrates expected at base permafrost. Discussed in Drilling Hazards section. exists for increased pressure across faults. Date Date Commissioner: Commissioner: Commissioner Well path must stay 1/4 mile from B-05 and B -05A due to open SB and Ugnu sands (not cemented and could cross inject). GLS