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219-052
MEMORANDUM 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-38 MILNE PT UNIT E-38 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 E-38 50-029-23629-00-00 219-052-0 W SPT 4460 2190520 1500 207 211 206 211 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-38 Inspection Date: Tubing OA Packer Depth 702 1727 1664 1648IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230905124519 BBL Pumped:1.9 BBL Returned:1.7 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-38 (PTD# 2190520) Return to Injection Date:Tuesday, August 29, 2023 8:52:07 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, August 25, 2023 3:26 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-38 (PTD# 2190520) Return to Injection Mr. Wallace – PWI well MPE-38 (PTD# 2190520) 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 2:58 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-38 (PTD# 219-052) Missed AOGCC Witnessed MIT-IA Mr. Wallace – PWI well MPE-38 (PTD# 219-052) 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-38 (PTD# 219-052) Missed AOGCC Witnessed MIT-IA Date:Monday, July 3, 2023 12:20:57 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, June 29, 2023 2:58 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-38 (PTD# 219-052) Missed AOGCC Witnessed MIT-IA Mr. Wallace – PWI well MPE-38 (PTD# 219-052) 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 (Cl) Applications Well Field API PTD Top of Cement (ft.) Corrosion Inhibitor Fill Volume (gal) Final CI Top (ft.) Corrosion Inhibitor Treatment Date E-35 Milne Point 50029236150000 2181520 Surface 22.5 Top of Cond 10/24/2019 E-36 Milne Point 50029236200000 2190050 Surface 15 Top of Cond 10/24/2019 E-38 Milne Point 50029236260000 I Surface 20 Top of Cond 10/24/2019 E-39 Milne Point 50029236400000/60-00 2190960 Surface 20 Top of Cond 10/24/2019 E-40 Milne Point 50029236260000 2190440 Surface 25 Top of Cond 10/25/2019 E-41 Milne Point 50029236220000 2190310 Surface 15 Top of Cond 10/24/2019 E-42 Milne Point 50029236350000/60-00 2190820 Surface 17 Topof Cond 10/25/2019 M-18 Milne Point 50029236320000 2190700 3 50 Top of Cond 10/26/2019 M-06 Milne Point 50029236460000 2191130 3 30 Top of Cond 10/26/2019 Cement to surface means cement is up to the 4" outlets below the wellhead. From the 4" outlets up to the top of conductor was filled with Fill Coat Notes: #7 Initial top of Cement footage measurement was taken from the 4" outlet down to the TOC The 4" conductor outlets are anywhere from Ito 3' down from the top of the conductor DEC 0 6 2019 8CAA1NFD ��C r�Z919 DATA SUBMITTAL COMPLIANCE REPORT 9/5/2019 Permit to Drill 2190520 Well Name/No. MILNE PT UNIT E-38 f6 I ' Operator Hilcorp Alaska LLC API No. 50-029-23629-00-00 Pg2' MD 15570 TVD 4444 Completion Date 6/7/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes REQUIRED INFORMATION Mud Log No 1z Samples No ✓ DATA INFORMATION List of Logs Obtained: ROP, ABG, DGR, EWR, ADR 2"/5" MD, PB1, PB2... ABG, DGR, EWR, ADR 2"/5" TVD, P81, PB2 Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Directional Survey Yesd (from Master Well Data/Logs) Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 31014 Digital Data 105 M70 7/19/2019 Electronic Data Set, Filename: MPU E-38 DGR ABG EWR ADR.las ED C 31014 Digital Data 5745 15532 7/19/2019 Electronic Data Set, Filename: MPU E-38 ADR Quadrants All Curves.las ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 LWD Final MD.cgm ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 LWD Final TVD.cgm ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 Definitive Survey Report.pdf ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 Surveys.xlsx ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38_DSR.txt ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38_GIS.bd ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38_Plan.pdf ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38_VSec.pdf ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 LWD Final MD.emf ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 LWD Final TVO.emf ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 Geosteering.dlis ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 Geosteering.ver ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 LWD Final MD.pdf ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 LWD Final TVD.pdf ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 LWD Final MD.tif ED C 31014 Digital Data 7/19/2019 Electronic File: MPU E-38 LWD Final TVD.tif Log 31014 Log Header Scans 0 0 2190520 MILNE PT UNIT E-38 LOG HEADERS AOGCC Page 1 of 4 Thursday, September 5. 2019 DATA SUBMITTAL COMPLIANCE REPORT 9/5/2019 Permit to Drill 2190520 Well Name/No. MILNE PT UNIT E-38 Operator Hilcorp Alaska LLC API No. 50-029-23629-00-00 MD 15570 TVD 4444 Completion Date 6/7/2019 Completion Status 1WINJ Current Status 1WINJ UIC Yes Log 31015 Log Header Scans 0 0 2190520 MILNE PT UNIT E-38 LOG HEADERS ED C 31015 Digital Data 105 7178 7/19/2019 Electronic Data Set, Filename: MPU E-38 PSI DGR ABG EWR ADR.Ias ED C 31015 Digital Data 5745 7140 7/19/2019 Electronic Data Set, Filename: MPU E-38 PSI ADR Quadrants All Curves.las ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PBI LWD Final MD.cgm ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PSI LWD Final TVD.cgm ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38PB1 Definitive Survey ReporLpdf ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38PBI_DSR.txt ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38PB1_GIS.txt ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38PB1_Plan.pdf ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38PB1_VSec.pdf ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PBI LWD Final MD.emf ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PSI LWD Final TVD.emf ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PBI Geosteering.dlis ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PSI Geosteering.ver ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PBI LWD Final MD.pdf ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PBI LWD Final TVD.pdf ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PBI LWD Final MD.tif ED C 31015 Digital Data 7/19/2019 Electronic File: MPU E-38 PSI LWD Final TVD.tif ED C 31016 Digital Data 105 10268 7/19/2019 Electronic Data Set, Filename: MPU E-38 P82 DGR ABG EWR ADR.Ias ED C 31016 Digital Data 5745 10230 7/19/2019 Electronic Data Set, Filename: MPU E-38 PB2 ADR Quadrants All Curves.las ED C 31016 Digital Data 7/19/2019 Electronic File: MPU E-38 PB2 LWD Final MD.cgm A0G(( Page 2 of Thursday, September 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 9/5/2019 Permit to Drill 2190520 Well Name/No. MILNE PT UNIT E-38 MD 15570 TVD 4444 Completion Date 6/7/2019 ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data ED C 31016 Digital Data Log 31016 Log Header Scans Well Cores/Samples Information: Name INFORMATION RECEIVED Interval Start Stop Operator Hilcorp Alaska LLC API No. 50-029-23629-00-00 Completion Status 1WINJ Current Status 1WINJ UIC Yes 7/19/2019 Electronic File: MPU E-38 P82 LWD Final TVD.cgm 7/19/2019 Electronic File: MPU E-38PB2 Definitive Survey Report.pdf 7/19/2019 Electronic File: MPU E-38PB2 DSR.txt 7/19/2019 Electronic File: MPU E-38PB2 GIS.txt 7/19/2019 Electronic Fife: MPU E-38PB2_Plan.pdf 7/19/2019 Electronic File: MPU E-38PB2_VSec.pdf 7/19/2019 Electronic File: MPU E-38 PB2 LWD Final MD.emf 7/19/2019 Electronic File: MPU E-38 PB2 LWD Final TVD.emf 7/19/2019 Electronic File: MPU E-38 PB2 Geosteering.dlis 7/19/2019 Electronic File: MPU E-38 PB2 Geosteering.ver 7/19/2019 Electronic File: MPU E-38 PB2 LWD Final MD.pdf 7/19/2019 Electronic File: MPU E-38 PB2 LWD Final TVD.pdf 7/19/2019 Electronic File: MPU E-38 PB2 LWD Final MD.tif 7/19/2019 Electronic File: MPU E-38 PB2 LWD Final TVD.tif 0 0 2190520 MILNE PT UNIT E-38 LOG HEADERS Sample Set Sent Received Number Comments Completion Report OY Directional /Inclination Data Mud Logs, Image Files, Digital Data Y / P® Core Chips Y /FA Production Test Information Y /1® Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data FileoY Core Photographs Y /®A Geologic Markers/Tops Daily Operations Summary O Cuttings Samples YN Laboratory Analyses Y 10 AOGCC Page 3 of 4 Thursday, September 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 9/5/2019 Permit to Drill 2190520 Well Name/No. MILNE PT UNIT E-38 Operator Hilcorp Alaska LLC MD 15570 TVD 4444 Completion Date 6/7/2019 Completion Status 1WINJ Current Status 1WINJ COMPLIANCE HISTORY Completion Date: 6/7/2019 Release Date: 4/11/2019 Description Date Comments Comments: Compliance Reviewed By:�- Date: API No. 50-029-23629-00-00 UIC Yes AOGCC Page 4 of 4 Thursday, SLirtember 5, 2019 11LLC DATE 07/18/2019 21 90 52 Debra Oudean Hilcorp Alaska, LLC 3 1 0 1 4 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU E-38 7/18/201912:33 PM MPU E-38 219-052 MPU E-38 P61 7/18/201912:36 PM MPU E-38 P82 7/18/2019.12:36 PM (PTD MPU E-38 PB1 E-38 PB2 MPU CD 1: Log Viewers 7/18/201912:33 PM MPU E-38 7/18/201912:35 PM MPU E-38 P61 7/18/201912:36 PM MPU E-38 P82 7/18/2019.12:36 PM RECEIVED JUL 19 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 cis►�� WOMEN U ._ DATE 07/18/2019 219052 Debra Oudean Hilcorp Alaska, LLC 3 1 0 15 Geo -tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 F -mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU E-38 219-052 (PTD MPU E-38 PB1 MPU E-38 PB2 CD 1: Log Viewers : %11,-201912:33 PF.1 MPU E-381'_,/201912:3; PIA MPU E-38 PB1 7/18/201912:36 PM MPU E-38 PB2 7;"12"01912:3h PrA RECEIVED JUL 19 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: U - DATE 07/18/2019 219052 Debra Oudean Hilcorp Alaska, LLC 3 1 0 1 6 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU E-38 MPU E-38 219-052 MPU E-38 PB1 7/18/20191236 PM MPU E-38 PB2 7/19/2019112:36 PM (PTD MPU E-38 PB1 MPU E-38 PB2 CD 1: Log Viewers 7/18,1201912:33 PM MPU E-38 7/181201912:35 PM MPU E-38 PB1 7/18/20191236 PM MPU E-38 PB2 7/19/2019112:36 PM RECEIVED JUL 19 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 U MEMORANDUM TO: Jim Regg �` -' r P.R. Supervisor 1 FROM: Brian Bixby Petroleum Inspector Well Name MILNE PT UNIT E-38 IInsp Num: mitBDB190622131849 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 8, 2019 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC E-38 MILNE PT UNIT E-38 Sre. Inspector Reviewed By: P.I. Supry I IZ NON -CONFIDENTIAL Comm API Well Number 50-029-23629-00-00 Inspector Name: Brian Bixby Permit Number: 219-052-0 Inspection Date: 6/22/2019 ' Packer Depth ,4460 1500 Tubing. IA � Pretest Initial 15 Min 30 Min 45 Min 60 Min "135 737 - _.. _ 737 '=8 _ 400 1703 - 1636 - lol? E-38 Type Inj Well �---_ �+' TVD - PTD 2190520 !Type Test, SPT Test psi - -- - — BBL Pumped: 23 BBL Returned: z.3 -- _'IOA P Interval INITAL P/F -i Notes' There is no OA as this is a monobore completion. 0 Monday, July 8, 2019 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 20A 025.105 20a 025.110 GINJ ❑ WINJ ❑✓ WAGE) WDSPL ❑ No. of Completions: _ 1 1b. Well Class: Development ❑ Exploratory ❑ Service Q - Stratigraphic Test E] 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 6/7/2019 14. Permit to Drill Number / Sundry: 219-052 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: May 16, 2019 15. API Number: 50-029-23629-00-00 4a. Location of Well (Governmental Section): Surface: 3543' FSL, 1881' FEL, Sec 25, T13N, R1oE, UM, AK • Top of Productive Interval: 92' FNL, 2182' FWL, Sec 25, T13N, R1 OE, UM, AK Total Depth: 1451' FNL, 1332' FEL, Sec 22, TI 3N, R1 OE, UM, AK 8. Date TD Reached: May 31, 2019 ' 16. Well Name and Number: MPU E-38 9. Ref Elevations: KB: 48.2' GL: 21.8' BF: 21.8' 17. Field / Pool(s): Milne Point Field Schrader Bluff Oil Pool 10. Plug Back Depth MD/TVD: . 15,124' MD / 4,370' TVD - 18. Property Designation: . , ADL025,918: ADL047437, ADL025516 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 569265 ' y- 6016081 • Zone- 4 • TPI: x- 568033 y- 6017713 Zone- 4 Total Depth: x- 559203 y- 6021560 Zone- 4 11. Total Depth MD/TVD: • 15,570' MD / 4,444' TVD ' 19. DNR Approval Number: LONS 94-017 12. SSSV Depth MDfTVD: N/A 20. Thickness of Permafrost MD/TVD: 1,854' MD / 1,800' TVD 5. Directional or Inclination Survey: Yes (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary � ROP/ABG/DGR/EWR/ADR 2"/5" MD / PB1/ PB2 •-1 IL•'tom,. i V EEO) ABG/DGR/EWR/ADR 275" TVD / PB1/ PB2 JUN 26 2019 AOGCC 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE AMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 215# X-52 Surface 107' Surface 107' 42" ±270 ft3 9-5/8" 40# L-80 Surface 5,761' Surface 4,466' 12-1/4" Sig 1 L - 524 sx / T - 388 sx Stg 2 L - 401 sx / T - 240 sx 227 bbis 3-1/2" 9.3# L-80 Surface 5,585' Surface 4,460' Tieback Tieback Tubing 4-1/2" 13.5# L-80 5,573' 15,129' 4,459' 4,370' 8-1/2" Injection Liner w/ [CDs & Swell Packers 24. Open to production or injection? Yes ❑✓ No ❑ If Yes, list each interval open (MDfrVD of Top and Bottom; Perforation Size and Number; Date Perfd): Liner Run on 6/4/19 "'See attached schematic for ICD/Swell Packer Detail" COMPLETION T D :,F 4 : ea, V RIFIFD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3-1/2" 5,585' 5,573' MD / 4,370' TVD Liner Top Packer 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No E Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 f. Z3.i9 C�TINUED ON PAGE 2 RBDMS.IVJUN 2 7 Y019S°b]v, ORIGINAL NNAL op 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 1,854' 1,800' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval SB OA 5,943' 4,466' information, including reports, per 20 AAC 25.071. SV5 1,760' 1,708' SV1 2,550' 2,476' Ugnu LA3 3,912' 3,759' SB NA 4,740' 4,290' SB OA 5,660' 4,465' Formation at total depth: Schrader Bluff 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report, Open Hole 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: cdlfl of hilCOr .com Authorized vt'iaJt•N Contact Phone: 777-8389 Signature g Date. 2�//q INSTRUCTIONS General: Th' form and gerrequired attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item I: 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 K corn Alaska. LLC KB Elev above MSL 48.2' TO =15,570' (MD) / TD = 4,444'(TVD) PBTD =±15,124' (MD) / PBTD=4,370'(T/D) Schematic Milne Point Unit Well: MPU E-38 PTD: 219-052 API: 50-029-23629-00-00 TREE & WELLHEAD Tree 1 Cameron 3 1/8" SM w/ 3-1/8" 5M Cameron Wing Wellhead I Cameron 11" 5K sliplock bottom w/ (2) 2-1/16" 5K outs OPEN HOLE / CEMENT DETAIL 42" 1 270 ft3 12-1/4" Stgi L-524 sx/T-388 sx/Stg2 L-401 sx/T-240 sx 8-1/2" 1 Cementless Injection Liner in 8-1/2" hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 20" Conductor 215/X-52/Weld N/A Surface 107' N/A 9-5/8" Surface 40/L-80/TXP 8.75" Surface 5,761' 0.0758 4-1/2" Liner 13.5 / L-80 / Hyd 625 3.85" 5,573' 15,129' 0.0149 TUBING DETAIL 3-1/2" Tubing 9.2 / L-80 / EUE Srd 1 2.867" 1 Surf 1 5,585' 1 0.0087 WELL INCLINATION DETAIL KOP @ 290' Max Hole Angle = 95' @ 6,681' MD JEWELRY DETAIL No Top MD Item ID Upper Completion 1 2,232' X Nipple 3.813 2 4,765' SLB Gauge Mandrel 3 4,823' X Nipple profile: 3.813" 3.813 4 5,575' 8.25" No -Go Locater on Tieback Assy ([4] -1" Ported Seal Stem) 3.960 5 5,585' Tieback Shoe 6.180 Lower Completion 6 5,573' Liner Top Packer (TVD= 4,370') 7 15,093' 4-1/2" Drillable Packoff Sub 8 15,124' W IV (Ball on Seat/ Closed) PBTD See Page 2 for ICD and Swell Packer Detail GENERAL WELL INFO API#:50-029-23629-00-00 Completed by Innovation 06/07/2019 GD 06/25/2019 Depth MD Depth TVD ICD/Swell Packer Detail 5,763' 4,467' Tendeka Water Swell Packer 16 5,943' 4,466' 'Tendeka- ICD w/ 250L mesh, Sliding Sleeve 135# bxp 625 Wedge #17 6,012' 4,468' Tendeka Water Swell Packer 15 6,112' 4,470' 1cndeka- ICD w/ 250L mesh, Sliding Sleeve 13 5# bxp 625 Wedge 916 6,616' 4,458' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 915 6,724' 4,449' Tendeka Water Swell Packer 14 7,070' 4,429' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.59 bxp 625 Wedge #14 7,387' 4,421' Tcndeka Water Swell Packer 13 7,903' 4,416' 1 endeka- ICD w/ 250L mesh, Sliding Sleeve 13.54 bxp 625 Wedge #13 8,052' 4,409' Tendeka Water Swell Packer 12 8,194' 4,404' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 412 8,263' 4,402' Tendeka Water Swell Packer 11 8,408' 4,398' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.59 bxp 625 Wedge #11 8,596' 4,392' Tendeka Water Swell Packer 10 8,699' 4,390' Tendeka-ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 410 9,086' 4,391' Tendeka Water Swell Packer 9,309' 4,400' Tendeka-ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge #9 9,418' 4,405' Tendeka Water Swell Packer 8 9,646' 4,413' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 1354 bxp 625 Wedge #8 10,003' 4,412' Tendeka Water Swell Packer 7 10,271' 4,408' Tendeka-ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 97 10,587' 4,403' Tendeka Water Swell Packer 6 10,774' 4,397' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 46 11,337' 4,399' Tendeka Water Swell Packer 11,606' 4,392' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bp 625 WedE #5 11,878' 4,393' Tendeka Water Swell Packer 12,145' 4,399' Tendeka. ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge #4 12,832' 4,396' Tendeka Water Swell Packer 3 13,216' 4,387' Tendeka Water Swell Packer 2 13,439' 41380' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.59 bxp 625 Wedge #3 14,155' 4,367' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge #2 14,346' 4,371' Tendeka Water Swell Packer I 14,737' 4,374' Tendeka- ICD w/ 250L mesh, Sliding Sleeve 13.5# bxp 625 Wedge 41 n Well Name: MP E-38 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): 26.38 API 111: 50-029-23629-00-00 Spud Date: 5/16/2019 Job Name: 1813046D MPE-38 Drilling Contractor AFE #: AFE $: Hilcorp Energy Company Composite Report AcUuity ibir Ops Summary 5/13/2019 Spot pipe shed, mud mod and gen mod. Hook up interconnects. Start working on rig acceptance checklist.;Spot and rig up envirovac and break shack. Lay herculite and spot cuttings box. Scope derrick and bridle down. Swap from cold start to Gen power at 12:30.;Unpin top drive from derrick frame. Lower frame to floor to allow access for ATF welder to begin repairs to TD extend frame. SimOps: C/O jets and suction rubbers in pits as needed. Open MP #2 and inspect.; NU diverter system. Assist well head rep to engage slips and torque and test void. Cont. with MP#2 inspection, rig acceptance checklist. Continue to repair extend frame on top drive as per NOV procedure.;Continue N/U diverter line. Install 4' conductor valves and handles. SimOps: Finish installing Lad Safe in derrick. Work on EAM's for pits and pump room. Continue working on Rig acceptance checklist. 5/14/2019 PJSM Set Malts, Diverter brace and last section of Diverter line W/ Crane. SIMOPS Weld cracks on TD cradle. C/O Teflon on guide rails. Cut boards for pipe rack. Cont. work on EAMS for Pits & Pump Room. Cont. working on rig acceptance. Install new Beaver Slide strobe Iight.;PJSM Cont. welding TD cradle. SIMOPS install safety chains on risers in Pits. Repair dump valve in Pk #1. Cont. work on Pipe Rack decking. Tested Gas alarms. Cont. painting/ housekeeping around rig. Hazard hunt through out rig and address issues. Make list from the hazard hunt for the support crew.;Weld pad eye on 1502 rack in cellar. Install guard for lifting caps next to tool slide. Fab guard for tool slide overhead safety switch. Repair 1" steam line on cutting box. Install secondary restraints on light and antenna boxes around rig.;PJSM Cont. welding TD cradle. MPT weld on cradle, passed. Set cradle on stops. R/U and start C/O pin bushings. SIMOPS New crew perform hazard hunt. Housekeeping around rig. Install secondary restraints on overhead Egiup. Stock hopper house and prep pits for Spud Mud.; Hauled 0 bbis Fluid to MP G&I total = 0 bbis Hauled 650 bbis H2O from L -Pad Lake total = 650 trials Lost 0 bbls to formation Total fluid lost = 0 blas 5/15/2019 Rig accepted at 06:00. PJSM Complete C/O pin bushings. Pin cradle to Top Drive. Perform post weld inspection of Derrick. C/O wash pipe. SIMOPS Service Skate and bring 290 bbis 8.8 ppg Spud Mud into pits.;PJSM Perform post Top Drive inspection. C/O Saver Sub (TRQ 46K) and grabber dies. SIMOPS Spot cement silo's. Remove Gyro and MWD tools form Pipe Shed. Using UBHO and ELine.;PJSM Install bell nipple and riser. Press up Koomey unit, inspect lines for leaks. RIU Tongs, short mouse hole, clean and clear rig floor. Prep rig floor for P/U 5" D.P.;PJSM PIU M/U 125 stands 5" D. P. NC50 S-135 19.5# and 5" HWDP F/ Pipe Shed and rack back in Derrick. (Drift 3.125' OD).;Hauled 57 blas Fluid to MP G&I total = 57 bbls Hauled 130 bbls H2O from L -Pad Lake total = 780 bbls Lost 0 bbis to formation Total fluid lost = 0 bbls 5/16/2019 Continue to PU and stand back 5" D. P. and 17 its 5" HWDP F/ Pipe Shed and rack back in Derrick. UD Mouse hole. Clean and Clear Rig Floor. Hook Koomy lines to Knife Valve and Re- energize Koomy. PIU Surface Tongs. Stage BHA components on Rig Floor.;Service Rig, Grease Crown, Blocks, TD Spinners, Tongs, Elevators, Drawworks. Inspect Welds on Extend Frame.;Test diverter system, AOGCC right to witness waived by Jeff Jones. Install joint of 5" drill pipe. Knife valve open in 7 seconds, annular close in 10 seconds. Accumulator drawdown: starting pressure 3000 psi, final 1950 psi. 200 psi recharge in 10 seconds, full recharge 48 seconds.;6 N2 bottles with 2241 psi average. Tested Gas alarms on the previous day with no failures.; Pre Spud Meeting with all Personal. M/U 12.25" Kymera Bit, Mud Motor and X10. RI W. 5" HWDP tag at 100' MD. Fill surface Equip and hole W/ H2O. PT mud lines to 3,000 PSI, good. Observed Leak on Starter Head Seals. Call out Well Head Rep.;Well Head Rep Re -Inject Seal Packing in P Seals of Starter Head.;SPUD WELL: Drill F/ 80' to 220' MD. 430 GPM, 575 PSI, 40 RPM, TRQ ON 2.2K, TRQ OFF IK, WOB 3K.;BHA #1, 8" DM, 8" DGR, 8" EWR-P4,8" PWD, 8" HCIM, 8" TM, 8" NM UBHO, 2 ea 8" NM FC, X/O and 5" HWDP to 220' MD. Down load MWD SIMOPS R/U Gyro sheave and tools. Measure RFO = 6.69/8.13 = 296.24', orientate UBHO.;Rotate and slide 12.25" Surface F/ 220' to 463' MD ( 401' TVD) 425 GPM, 920 PSI, 40 RPM, TRQ ON 2K, TRQ OFF 820 ft/Ib, WOB 2-6K, Max Gas OU. ECD 9.5 ppg. P/U 54K, SLK 55K, ROT 53K. Start Gyro surveys and 3°/100 build at 276' MD, Cont Gyro every connection. SIMOPS load Pipe Shed W/ 9 518" Csg.;At 437' MD EWR failed and showed time out errors. Manual reset EWR and Geo Span. No Gamma and resistivity. Brought pumps up 500 GPM to send down link, EGR started responding. Cont. drilling.; Rotate and slide 12.25" Surface F/ 463' to 720' MD ( 715' TVD) 425 GPM, 1,100 PSI, 40 RPM, TRQ ON 3.2K, TRQ OFF 2K, WOB 8-10K, Max Gas OU. ECD 9.66 ppg. P/U 67K, SLK 67K, ROT 66K. Last Gyro survey taken at 522' MD. Maintain 3°/100 build.;Slide His 3.41. ROT Hrs 1.41, total 4.82 Hrs. Distance to WP#4 9.8', 2.3' Low, 9.8' Left.;Hauled 173 bbls Fluid to MP G&I total = 230 bbls Hauled 230 blas H2O from L -Pad Lake total = 1,010 bbls Lost 0 bbis to formation Total fluid lost = 0 bbis 5/17/2019 Drill 12.25" Surface F/ 720' to 1222' MD (1192' TVD) Total 502' (AROP 83.6') 520 GPM, 1,500 PSI, 60 RPM, TRQ ON 4.7K, TRQ OFF 2.5K, WOB 8K, Max Gas OU. ECD 9.66 ppg. P/U 82K, SLK 75K, ROT 78K. Last Gyro survey taken at 522' MD. Maintain 4°/100 build.;DriII 12.25" Surface F/ 1222' to 1,732' MD (1,681' TVD) Total 510' (AROP 85') 550 GPM, 1,500 PSI, 70 RPM, TRQ ON 4.5K, TRQ OFF 3.5K, WOB 8-12K, Max Gas 12U. ECD 10.1 ppg. P/U 95K, SLK 82K, ROT 87K. Maintain 4°/100 build.;Drill 12.25" Surface F/ 1,732'to 2,241' MD (2,176' TVD) Total 509' (AROP 840) 560 GPM, 1,740 PSI, 70 RPM, TRQ ON 5K, TRQ OFF 4.5K, WOB 5-8K, Max Gas 673U. ECD 9.9 ppg. P/U 109K, SLK 89K, ROT 97K. Start tangent at 1,659' MD maintain 13.6° Inc, 32.6° AzL:DrIII 12.25" Surface F/ 2,241' to 2,688' MD (2,610' TVD) Total 447' (AROP 745) 540 GPM, 1,650 PSI, 80 RPM, TRQ ON 5.5K, TRQ OFF 4.K, WOB 5- 6K, Max Gas 1,677U. ECD 9.9 ppg. P/U 121 K. SLK 95K, ROT 103K. Pump 30 bbl Hi Vis Sweep at 2,520' MD 20% increase sand/clay, early 18.6 bbl.;Base of Permafrost at 1,854' MD. Slide Hrs 3.83. ROT His 7.92, total 11.75 Hrs Distance to WP#4 0.6', OAS High, 0.41' Right.; Hauled 866 bbis Fluid to MP G&I total = 1,096 bbis Hauled 850 bbis H2O from L -Pad Lake total = 1,860 bbis Lost 0 bbls to formation Total fluid lost = 0 bbis 5/18/2019 Rotate & Slide 12.25" Surface F/ 2,688' to 3,194' MD (3,101' TVD) Total 506' (AROP 84.3') 540 GPM, 1,557 PSI, 80 RPM, TRQ ON 6K, TRQ OFF 5.8K, WOB 5-6K, Max Gas 1,7580. ECD 9.6 ppg. P/U 130K, SLK 95K, ROT 1 11 K. Pump 30 bbl Hi Vis Sweep at 2,520' MD 20% increase sand/clay, early 18.6 bbl.;Started our build and turn at 3,067' MD 4°/100.;Rotate & Slide 12.25" Surface F/ 3,194' to 3,515' MD (3,409' TVD) Total 321' (AROP 535) 540 GPM, 1,643 PSI, 60 RPM, TRQ ON 7K, TRQ OFF 6K, WOB 8K, Max Gas 464U. ECD 9.5 ppg. PIU 143K, SLK 108K, ROT 123K. At 3,515' MD pump 50 bbl 9.0 ppg, 300+ Vis Hi Vis Sweep 75% increase clay/sand,45 bbis early.;Rotate & Slide 12.25" Surface F/ 3,515' to 3,831' MD (3,691' TVD) Total 316' (AROP 52.6') 540 GPM, 1,727 PSI, 60 RPM, TRQ ON 8.5K, TRQ OFF 7.6K, WOB 8K, Max Gas 577U. ECD 9.5 ppg. P/U 146K, SLK 111K, ROT 126K. Cont. build and turn 4°1100.;Rotate & Slide 12.25" Surface F/ 3,831'to 4,160' MD (3,953' TVD) Total 329' (AROP 54.8') 540 GPM, 1,673 PSI, 70 RPM, TRQ ON 9K, TRQ OFF 10K, WOB 8K, Max Gas 3530. ECD 9.6 ppg. P/U 150K, SLK 113K, ROT 125K.;At 3,915' MD pump 50 bbl 9.0 ppg, 300+ Vis Hi Vis Sweep 50% increase clay/sand, 45 bbls early. Sweep had doubled in length may have high sided of hole due to low RPM.;Slide Hrs 7.58. ROT Hrs 4.17, total 11.75 Hrs. Distance to WP#4 8.09'. 4.3' High, 6.84' Right.;Hauled 981 bbls Fluid to MP GW total = 2,077 bbls Hauled 1,170 bbls H2O from L -Pad Lake total = 3,030 bbls Lost 0 bbls to formation Total fluid lost = 0 bbls 5/19/2019 Rotate & Slide 12.25" Surface F/ 4,160'to 4,531' MD (4,149' TVD) Total 371' (AROP 61.8') 540 GPM, 1,698 PSI, 80 RPM, TRQ ON 11.1 K, TRQ OFF 10.2K, WOB 1-5K, Max Gas 7040. ECD 9.5 ppg. P/U 159K, SLK 109K, ROT 132K. Build/ Turn 4°/100, Water 50 BPH. MW 9.0 ppg.;Rotate & Slide 12.25" Surface F/ 4,531'to 4,594' MD (4,221' TVD) Total 63' (AROP 42) 540 GPM, 1,715 PSI, 80 RPM, TRQ ON 11.1 K, TRQ OFF 10.1 K, WOB 12K, Max Gas 5U. ECD 9.5 ppg. P/U 160K, SLK 108K, ROT 132K. Build/Turn 4°/100, Water 50 BPH. MW 9.0 ppg.;At 4,594' MD Pump 48 bbl 9.0 ppg, 300+ Vis Sweep. Sweep returned 50 bbls early with 25% increase Clay/Sand. 580 GPM, 1,840 PSI, 80 RPM, 10.2K TRQ.;Rotate & Slide 12.25" Surface F/ 4,594' to 4,756' MD (4,296' TVD) Total 162' (AROP 54') 540 GPM, 1,810 PSI, 80 RPM, TRO ON 11.51K, TRQ OFF 10.41K, WOB 12K, Max Gas 7U. ECD 9.4 ppg. P/U 160K, SLK 108K, ROT 130K. Build/Turn 4'/100.;Rotate & Slide 12.25" Surface F/ 4,756 to 5,000' MD (4,378' TVD) Total 244' (AROP 40.6) 580 GPM, 2,008 PSI, 80 RPM, TRQ ON 12K, TRQ OFF 11.2K, WOB 11 K, Max Gas 394U. ECD 9.6 ppg. P/U 162K, SLK 107K, ROT 129K. Build/Turn 4'/100, Water on 50 BPH. MW 9.5.;Rotate & Slide 12.25' Surface F/ 5,000' to 5,324' MD (4,430' TVD) Total 324' (AROP 54') 580 GPM, 2,051 PSI, 80 RPM, TRQ ON 12-13K, TRQ OFF 11.7K, WOB 14K, Max Gas 589U. ECD 9.6 ppg. P/U 158K, SLK 109K, ROT 124K. Build/Turn 4°/100, Water on 50 BPH. MW 9.0.;At 5,027' MD may have crossed a 25' DTNW fault within the Schrader Bluff NE, causing a repeat of the NE. Slide Hrs 7.92. ROT Hrs 3.59, total 11.51 Hrs Distance to WP#4 5.06', 4.8' High, 1.2' Left.;Hauled 1,154 Jobs; Fluid to MP G&I total = 3,231 bbis Hauled 1,170 bbls H2O from L -Pad Lake total = 4,200 blots Lost 0 bbls to formation Total fluid lost = 0 bbis 5/20/2019 Rotate & Slide 12.25" Surface F/ 5,324' to TD 5,767' MD (4,467' TVD) Total 44T (AROP 73.8') 580 GPM, 2,201 PSI, 80 RPM, TRQ ON 12.51K, TRQ OFF 11.6K, WOB 13-15K, Max Gas 595U. ECD 10 ppg. P/U 153K, SLK 103K, ROT 122K. Build/Turn 4°/100. Increase MW F/ 9.0 ppg to 9.2 ppg Prior to TD.;Rack back 2 stands CBU ea F/ 5,767' to 5,681' MD. Rotate and reciprocate .CBU 3X F/ 5,681' to 5,617' MD 580 GPM, 1,803 PSI, 80 RPM, 10K TRQ. P/U 152K, SLK 98K, ROT 125K. Max Gas 661 U. Lower YP to 25 YP for running 9 5/8" Csg.;PJSM RIH on elevators F/ 5,617' to 5,767' MD P/U 162K, SLK 102K. Flow check well, Gas breaking out at surface with no gains. Appears to be shallow Gas hydates.;Rack back 1 stand. CBU 1 X Rotate and reciprocate F/ 5,744'to 5681' MD 580 GPM, 1,425 PSI, 60 RPM, 9-10K TRQ, Max Gas 505U. ROT 125K. Flow check well, Gas breaking out at surface with no gains. Appears to be shallow Gas hydrates.;PJSM BROOH F/ 5,744' to 5,425' MD 500 GPM, 1,500 PSI, 60 RPM, 10-11 K TRQ, Max Gas 331 U. P/U 155K, SLK 98K, ROT 125K Pull speed 20 FPM. Work through high TRQ sections as needed.;BROOH F/ 5,425' to 3,515' MD 560 GPM, 1,700 PSI, 60 RPM, 7.9K TRQ, Max Gas 315U. P/U 142K, SLK 105K, ROT 122K Pull speed 10-20 FPM. Work through high TRQ sections as needed. At 3,860' MD reduce pulling speed to 15 ft/min due to cutting increase at Shakers.;BROOH F/ 3,515' to 3,067' MD 560 GPM, 1,650 PSI, 60 RPM, 6-71K TRQ, Max Gas 253U. P/U 120K, SLK 98K, ROT 108K Pull speed 15 FPM. Work through high TRQ sections as needed.;Pump 28 bbl 9.0 300+ Hi Vis Sweep at end of tangent. Rotate and reciprocate F/ 3,067' to 3,006' MD 560 GPM, 1,550, 60 RPM, 6.1 K Max Gas 189U. P/U 120, SLK 98K, ROT 108K. Heavy increase in clay at Shakers during Circ. Sweep came back on time W/ 0% increase. MW 9.4 ppg.;BROOH F/ 3,067to 1,515' MD 560 GPM, 1,400 PSI, 60 RPM, 4.5-51K TRQ, Max Gas 353U. P/U 89K, SLK 78K, ROT 82K Pull speed 15-20 FPM. Work through high TRQ sections as needed. Hole unloading, CBU.;Slide Hrs 1.34. ROT Hrs 2.54, total 3.88 Hrs Land in zone. Distance to WP#4 18.59', 7.8' Low, 16.88' Left.;Hauled 693 bbls Fluid to MP G&I total = 3,924 bbls Hauled 1,040 bbls H2O from L -Pad Lake total = 5,240 bbls Lost 0 bbls to formation Total fluid lost = 0 bbls 5/21/2019 Continue BROOH F/ 1515'- T/ 712' MD. 560 gpm, 1400 psi, 60 rpm, 4-5k tq. Reduced rates @ 983' to 500 gpm, 30 rpm to help minimize induced hole issues thru build section in vertical part of hole. 19 bbl loss during total backream out from TD.;B/D TDS. POOH on elevators F/712' -T/90' MD. Rack back HWDP w/ jars. R/U HT rig tongs for breakout. UD XO, NM flex DC's. Download MWD. UD MWD. Flush and drain mtr (UD same). B/O and UD bit.; Finish Download MWD. UD MWD. Flush and drain mtr (UD same). B/O and UD bit. Bk grade= 1, 1, CT, A, F, I, BC, TD.;Service rig. Clean and clear rig floor. Count 9-5/8" casing in shed (150 jts). Prep floor for casing equipment. Static loss rate 2bph.;PJSM, Bring casing equipment to rig floor. Stg 66 bow spring centralizerson floor. M/U CRT 31 k tq (Volant). R/U bail extension, 150T side door 9-5/8" elevators, double stack power tongs.;Make up shoe track, Bakerl-ok (2 to pin end joint 5 (one above baffle adapter). Check floats - good. Continue to RIH with 9-5/8" 40# L-80 TXP casing to 1541', make up torque 20,9608 -lbs (Optimal), installing solid bow spring centralizers as per tally, filling e/ 5 joints. Calc Disp 17.5bbls, Act. 15.2.;While pulling slips, observed 9 button dies fell out. Retaining pins still in slips, but pushed in. Recovered 6 around rotary table. Inspect bowl. CBU staging up to 6 bpm/152 psi; no dies recovered. Slips had been previously inspected 4 joints prior to and appeared to be in good condition.;Continue to RIH with 9-5/8" 409 L-80 TXP casing from 1541' to 1973, make up torque 20,960ft-lbs (Optimal). installing solid bow spring centralizers as per tally, filling e/ 5 joints.;Circulate annular volume staging up to 8 bpm/215 psi reciprocating pipe.;Continue to RIH with 9-5/8" 40# L-80 TXP casing from 1973' to 3767', makeup torque 20,960ft-lbs (Optimal). installing solid bow spring centralizers as per tally, filling e/ 5 joints. PUW 192K, SOW 119K.;Hauled 299 bbls Fluid to MP G&I total = 4,223 bbls Hauled 390 bbls H2O from L -Pad Lake total = 5,630 bbls Lost 18 bbls to formation Total fluid lost = 18 bbls 5/22/2019 Continue run 9-5/8" TXP, L-80, 40# casing F/ 3767'- T/ 5767' MD as per detail. Tag btm on depth w/ 5k dn. 252k up, 128k dn. 69 total bow spring centralizer run, 144 total jts run. No obstructions or issues running to btm.;Circulate and reciprocate pipe conditioning mud for cmt job. Stage up to 7.5 bpm, 278 psi, 52% flow, 220k up, 122k on. R/D bail extensions and 1501 side door elevators. Prep floor and pits for cmt job. Prep pits for cmt job. Circ a total of 5.5 btms up.;Blow down top drive and cement lilne. Establish circulation and obtain parameter from 3-7 bpm. PJSM.;HAL fill lines W/ 5 bbl H2O PT 1500 PSI low, 4500 PSI stall, 4100 PSI high. HAL mix and pump 60 bbl 10.0 ppg Clean Spacer W/ Red Dye and 0.5 ppb Pol-E-Flake at 4 BPM, 330 PSI. Pump 220 bbl (524 sx) 12.0 ppq Type Illi Lead at 5 bpm 450 PSI. Pump 80 bbl (388 sx) 15.8 ppg Class G Tail at;4 BPM, 670 PSI. Shut down disengageVolan�t an rop Shut Off Plug. Engage Volant and HAL pump 20 bbl H2O 5 bpm, 350 PSI. Switch to Rig, pump 226.5 bbls 9.4 ppg Spud Mud at 7bpm 400 PSI. HAL pump 80 bbl H2O 4.5 bpm, FCP 740 PSI. Rig pumped 103.7 additional bbl 9.4 ppg Spud Mud at 5 bpm, 1015PSI.;Slow pumps to 3 bpm with 10 bbls to go FCP 890 PSI. Bump plug 3 bbls over calculated. Inc Press to 1436 PSI and hold for 5 minutes. Check Floats good, bled back 2 bbls. Reciprocated and rotated in downstroke 2 rpms/14Kft-lbs pipe until tail cement started around the corner,;CIP at 19:46. No losses during cement job.; Press up and ES Cementer shifted open at 2,800 PSI at 3 bpm. Stage pumps up to 4 bpm/1500psi, observe 60% loss rate, slow rate to 3bpm11000 psi with 50% losses. Observe coagulated mud, spacer and 25 bbls of green cement returned. Continue circulating staging up to 4.5 bpm/1800 psi with no Iosses.;Switch mud pumps to troubleshoot high pressure; 4.5 bpm/1650 psi stage pumps up to 6bpm/1900 psi as pressure slowly drops.;Prep for second stage cement job. Shutdown 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.;Continue to prep for cement job, build black water, empty pits. Continue circulating through ES cementer, staging pumps up to 6 bpm ICP 1965 FCP 1650 with no losses, stage up to 8 bpm ICP 1950 FCP 1650. Slow flow rate down to 4 bpm/620 psi, 5 bpm/900 psi.;PJSM 2nd stage cement job. HAI-fill lines W15 bbl H2O PT 1000 PSI low, 1370 PSI stall, 4000 PSI high. HAL mix and pump 55 bbl 10.0 ppg Clean Spacer W/ Red Dye and 0.5 ppb Pol-E-Flake at 3.5 BPM, 660 PSI. Pump 315 bbl (401 sx) 10.7 ppg Perm L Lead at 4.2 bpm, 1120 PSI. Observe clean spacer back;at 200 bbls pumped, observe 10.7 ppg cement back with 290 bbls pumped.;Hauled 625 bbls Fluid to MP G&I total = 4,848 bbls Hauled 545 bbls H2O from 6-Mile Lake total = 6,175 bbls Hauled 130 bbls from D-PR total = 130 bbls Lost 24 bbls to formation Total fluid lost = 42 bbls 5/23/2019 P.ISM 2nd stone romnnt ioh HAI fill lines W! 5 hbl H2O PT 1000 PSI lova. 1370 PSI stall. 4000 PSI blob. HAL mix and pump 55 bbl 10.0 ppq Clean Spacer e D e nd 0.5 6 PoI-E-Flake at 3.5 BPM 660 PSI. Pum 315 bbl 401 sx 10.7 ppri Perm L Lead at 4.2 bpm, 1120 PSI.;Obsewe clean spacer back at 200 bbls pumped, observe 10.7 ppg cement back with 290 bbls pumped. Pumped 50 bbls 15.8 ppg class G tail cement (270 sx), 1.169 yid, 3 bpm, 390psi. Shutdown and drop "ESICP" closing plug. HES disp w/20 bbls H2O, Rig displaced w/ 132.4 bbl.;9.3 ppg spud mud @4bpm, 1010psi. Reduced pump rate last 10 bbls of expected displacement to 2 bpm, 890 psi FCP. Bumped plug (132.4 act/ 131 calc) and psi up to 2400 psi. Saw good indicators of tool shifting closed. Held 5 min and bled off (1 bbl back). Tool closed.:CIP 0) 07:35 hrs. 227 bbls of 10.7 cement returned to surface. No losses observed during cement job.;R/D Volant CRT, R/U sidedoors 150T elevators. Clean and clear rig floor. BD cement Iine.;Disconnect knife valve accumulator hoses. Drain stack, flush with black water x 2; fill with black water, work annular x3. Flush flowline and surface equipment. Open ram doors to clean and inspect for slip buttons, none found. Disassemble diverter line and remove Knife Valve from'P.;Continue closing ram doors. Continue to flush surface lines. Rig up bridge crane. R/D chains on stack. Unbolt diverter'T'.;Lift stack. Install 'E' casing slips; set 100K down on slips. Rough cut casing and lay down joint (28.48'). Set stack back down. Clean flow box, pull riser.;Attempt to pull starting head, slips on diverter adapter catching. Pickup and set stack back on pedestal. Rig down diverter'T', N/D DSA. Disconnect starting head from diverter adapter and remove slips. Remove starting head and diveter adapter. SimOps: UD surface riser, master bushings.;Make final cut on 9-5/8" casing and dress off. Install T-103 adapter. Test P seals 500psi/5 min, 2500115min (80% casing burst) -good. Spot DSA and spacer spool. SimOps: Start building Bamdril-N ddling mud. Change out saver sub.;lnstall Cameron casing spool. Test same 500psi15000psi -good. Continue changing out saver sub. Install test plug, RILDS. SimOps: install 5" hydraulic elevators.; Install 13-5/8" x 11" DSA, and spacer spool. Prep BOP stack, remove chains, bell nipple and adapter. Hoist MPD RCD above stack and secure. Set BOPE stack. N/U BOPE.;Hauled 1457 bbls Fluid to MP G&I total = 6305 bbls Hauled 780 bbls H2O from 6-Mile Lake total = 6955 bbls Hauled 0 bbls from D-Pit total = 130 bbls Lost 0 bbls to formation Total fluid lost = 42 bbls 5124/2019 Set MPD head on stack. Tq flanges on MPD and Stack. 4 point stack. Install 20"06" riser. Hook up choke and kill lines. Install drip pan. Inspect Top Drive "J" box (Good - very slight residual oil film). C/O NC50 saver sub for inspection.; Finish nippling up MPD system. Flood stack and verify no leaks (good). Test gas alarms - H2S 10120 ppm, LEL 20/40%.;R/U test equipment. M/U side entry sub, TIW and dart valve to 5" test joint. Shell test 11" 5M stack w/ 5" test jt observe flange on choke manifold leaking. Tighten flange and shell test T/ 3000 psi (test good).;Test BOP's 250/3000 w/ 5 min hold on each. Witness waived s by AGOCC rep Austin McLeod. Accumulator drawdown: Initial pressure 3000 psi, final 1550 psi. 1st 200 psi recharge 24 secs, full recharge 89 seconds. 6 y N2 bottles at 2325psi average. Test pit G/L, flow paddle - good.;Rig down test joint, grease ISOP. Pull riser. Install rotating head test cap. Finish rigging up !\� 2" hardline in cellar for MPD. Flood system and PT MPD equipment 250/1500 psi -good. Pull test cap and re-install riser.;BOLDS pull test plug. Set 12" wear bushing with 10.8" OD. Obtain IRKS measurements. Install mousehole.;PJSM. M/U BHA, pickup 8-112" Smith tricone bit. M/U to 1.5 bend motor, install crows foot for gyro. RIH with 1 stand HWDP. Pump through motor 360 gpm -good. RIH with 2 stands HWDP, Jars and 11 joints HWDP to 592.8'.;Pick up drift (3.125") and single in the hole with BHA #2 drill out assembly to 1,927', breaking in 34 joints of new drill pipe- PUW 85K, SOW 67.;Establish circulate at 2 bpm/180 psi. Wash down from 1,927', tag up on cement at 1974' with 5K. Pick up and establish rotary 40 rpms/3400 ft-lbs, increase pump rate to 400 gpm/640psi. Drill cement from 1,974' with WOB 0-3K tag upon ES cementer at 1990' (on depth).;Drill plug and ES cementer from 1,990'to 1,993' with WOB 3-5K, 40 rpms/ 3.5 - 4.0 Kft-lbs, 400 gpm/750 psi (100 psi diff). Ream through x 3, shutdown pumps and rotary and go through with no issues. Continue washing and reaming down to 2,050'.;Continue to Pickup drift (3.125") and single in the hole with BHA #2 drill out assembly from 2,050' to 4341'. PUW 155K, SOW 97K.;Hauled 97 bbls Fluid to MP G&I total = 6402 bbls Hauled 470 bbls H2O from 6-Mile Lake total = 74255 bbls Hauled 0 bbls from D-Pit total = 130 bbls Lost 0 bbls to formation Total fluid lost = 42 bbls 5/25/2019 Continue to Pickup drift (3.125') and single in the hole with BHA #2 drill out assembly from 4341' to 5485'. 173k up, 85k dn. TIH out of derrick F/ 5485' - T/ 5609' washing down last stand.;Circulate 1.5x btms up @ 5609' MD while rot/recip pipe. 600 gpm, 1,600 psi, 40 rpm, 12k tq. Saw green cmt @ btms up. Psi dropped back to 890 psi after hole was clean of green cmt.;R/U and osi test 9-5/8". 40#. L-80 to 2500 osi w/ 30 min hold. Chart and record same (Test good). RID test equipment. 5 bbis pumped, 4.2 bbls bled back.;Wash down F/ 5.609'- T/ BFL @ 5,638' MD. Drill shoe track w/ BFL, FC and FS tagged on depth. 500 gpm, 815 psi, 40 rpm, 12.9k tq. Tripped thru shoe track clean without issues. Washed down and drilled 20' new formation F/ 5767' - 5787' MD.;Displace out 9.3 spud mud w/ 8.9 ppg Baradril "N". Pumped high vis spacer between spud/baradril.;Pulled into shoe @ 5761' MD. R/U test equipment. Close top rams and perform a12 pod EMW FIT test good). Pumped 2.7 bals, Bled back 1 bbl.;Drop memory Gyro and pump down at 125 gpm/230 psi increasing to 200 gpm/350 psi. Monitor hole, static. Pump dry job and blow down top drive, choke and kill Iines.;POOH with drill out BHA from 5730' to 3000', allowing Gyro enough time to collect survey's while in slips. PUW 162K, proper hole fill.;RIH from 3000' to 3514' to collect Gyro overlap surveys. SOW 100K.;Continue to / POOH with drill out BHA from 3415' to 519', allowing Gyro enough time to collect survey's while in slips (1.5 minutes). PUW 65K, proper hole fill.; UD HWDP, pull Gyro tool from top of float on motor. Rack back jar stand and 1 HWDP stand. Break bit and lay down. Bit grade 1 -2 -WT -G -1 -Cl -BHA. Clean and clear rig floor of BHA components.;PJSM Pick up RSS BHA #3, M/U NOV PDC bit to NRS, GeoPilol, MWD collars, float sub. Upload to MW D.;Cont. to WU BHA, pick up NM flex collars, float sub, (2) HWDP, Hydra Jars, 1 HWDP to 273'. Break in Geo -Pilot. Note: After processing Gyro data, inclination data below -4611' does not match Sperry inclination data, rendering that data unusable.;Continue to RIH with 6-1/2" RSS drilling assembly from 273' to 4594', drifting and picking up 90 joints of drill pipe, filling pipe every 2000'. PUW 145K, SOW115K. Shallow pulse test at 2117'.;Hauled 665 bbls Fluid to MP G&I total = 7067 bbls Hauled 410 bbls H2O from 6 -Mile Lake total = 7835 bbls Hauled 0 bbls from D -Pit total = 130 bbls Lost 0 bbls to formation Total fluid lost = 42 bats 5 /2 612 01 9 Continue trip in hole F/ 4954' - T/ 5736' MD. Proper displacement for trip. 145k up, 115k dn.;Cut and slip drilling line (100'). Calibrate blacks and floor saver.;Remove trip nipple and install RCD as per Beyond rep.;Grease crown, TDS and blocks.;Wash down F/ 5736'- T/ 578T MD. Drill 8.5" lateral F/ 5787' - T/ 5896' MD. 425 gpm, 900 psi, 40-110 rpm, 14k tq on, 12k tq off, 6k wob. Max gas 903u, 9.8 ECD's. 149k up, 80k dn, 117k rot. Drilled @ 40 rpm until MWD cleared casing.;Drill 8.5" hole F/ 5896' to 6370' MD Total 474' (AROP 79 fph) 490 gpm, 1270 psi, WOB 15K, adjust rotary from 100-140 rpms to mitigate stickslip with 10K-14Kft-lbs. Max Gas 1013U, ECD 10.0 ppg with 8.9 ppg drilling fluid. P/U 142K, S/O 80K. Backream 30' every stand.;Crossed an unexpected fault at 6262' with a 9' throw DTSE which resulted in exiting the base of the OA -3 sands.;Drill 8.5" hole F/ 6370'to 6627' MD Total 257' (AROP 43 fph) 515 gpm, 1380 psi, WOB 12-ISK, adjust rotary from 100-140 rpms to mitigate stickslip with 10K-14Kft-lbs. Max Gas 225U, ECD 10.13 ppg with 9.0 ppg drilling fluid. P/U 133K, S/O 92K, ROT 112K. Backream 30' every stand at 140 rpms.;DrHl 8.5" hole F/ 662T to 7134' MD Total 507' (AROP 85 fph) 540 gpm, 1530 psi, WOB 12K, 150 rpms/17Kft-lbs . Max Gas 835U, ECD 10.4 ppg with 9.0 ppg drilling fluid. P/U 143K, S/O 70K, ROT 113K. Backream 30' every stand.;0 PB drilled so far. 2 faults crossed at 5855', 6155'. 6 concretions drilled so far for a total footage of 28'(2.2%). 232' drilled in OA1 sands, 128' in OA2, and 120' in OA3.;Hauled 231 bbls Fluid to MP G&I total = 7298 bbls Hauled 260 bbls H2O from 6 -Mite Lake total = 8095 bbls Hauled 0 bbis from D -Pit total = 130 bbls Hauled 260 bbls from B pad Creek total = 260 bbls Lost 0 bbls to formation Total fluid lost = 42 bbls; Distance to Well Plan 09a: 3.88', 2.43' High, 3.02'Right 5/27/2019 Drill 8.5" hole F/ 7134'to 7178' MD Total 44' (AROP 88 fph) 540 gpm, 1530 psi, WOB 12K, 150 rpms/17Kft-lbs . ECD 10.4 ppg with 9.0 ppg drilling fluid. P/U 143K, SIC, 70K, ROT 113K. Backream 30' every stand.;Observed two faults crossed at 6656'(14' DTW) and 6760' (4' DTW) into the top of the OA -2, not the top of OA -3 as previously thought. Exited top of OA -1 sands at 6978'.;BROOH from 7,178' to 6,750'; 540 gpms/1436 psi. PUW 155K, SOW 78K.;Trough wellbore from 6,750' to 6,780' at 530 gpms/1360 psi, 120 rpms/15.5Kft-lbs x 3. Attempt to sidetrack from 6780' to 6783' with 100% deflection, but unable to see any separation from ABI. Wash down to 6815'. Trough wellbore from 6815' to 6840' x 3; 530 gpm/1345 psi, 120 rpms/15Kft-Ibs.;Sidetrack well bore from 6840' to 6881' with 100% deflection at 160"; 530 gpms/1345 psi, 120rpms/15Kft-lbs, 10-35 fph. Observe good separation in ABI. Ream through x3, work though without rotary x1 and without rotary pumps.; Drill 8.5" hole F/ 6881' to 7516' MD Total 635' (AROP 141 fph) 528 gpm, 1410psi, WOB 12K, 160 rpms/8.5Kft-lbs . Max Gas 870 U, ECD 10.4 ppg with 9.0 ppg drilling fluid. P/U 134K, S/O 89 K, ROT 108K. Backream every stand. Increased lube concentration at 7200' by 0.4% with NXS.;At 7133' shut in MPD choke on a connection, observed no increase in pressure. Continue drilling with open choke.;Drill 8.5" hole F/ 7516' to 8088' MD Total 572' (AROP 95 fph) 528 gpm, 1480psi, WOB 8K, 160 rpms/1 2.SKft-lbs. Max Gas 681 U, ECD 10.61 ppg with 9.0 ppg drilling fluid. PIU 138K, SIO 77 K, ROT 110K. Backream every stand.;Pumped high viscosity sweep at 7800' with 10% increase in cuttings, back on time. No decrease in ECD's.;Drill 8.5" hole F/ 8088' to 8720' MD Total 632' (AROP 105fph) 528 gpm, 1522psi, WOB 11 K, 160 rpms/19.6Kft-lbs . Max Gas 1163U, ECD 10.6 ppg EMW with 9.Oppg MW. P/U 155K, S/O 47 K, ROT 108K. Backream every stand.;1 PS drilled so far from (6840'- 7178) 6 faults crossed. 1167u max gas 9 concretions drilled so far for a total footage of 44' (1.5%). 929' drilled in OA1 sands, 801' in OA2, and 781' in OA3.;Hauled 461 blas Fluid to MP G&I total = 7759 bbls Hauled 0 bbls H2O from 6 -Mile Lake total = 8095 bbls Hauled 0 bbls from D -Pit total = 130 bbls Hauled 650 bbls from B pad Creek total = 910 bbls Lost 0 bbls to formation Total fluid lost = 42 bbls;Distance to Well Plan 09a: 31.01', 18.49' Low, 24.89'Right 5/28/2019 Drill 8.5" hole F/ 8720' to 9394' MD Total 674' (AROP 112fph) 525 gpm, 1703psi, WOB 9K, 160 rpms/17Kft-lbs . Max Gas 1163U, ECD 11.1 ppg EMW with 9.1 ppg MW. P/U 138K, S/O 79K, ROT 110K. Backream every stand.;Dritl 8.5" hole F/ 9394' to 10268' MD Total 874' (AROP 125fph) 528 gpm, 1745psi, WOB 12K, 160 rpms/18.50-lbs . Max Gas 1254U, ECD 11.1 ppg EMW with 9.1 ppg MW. PIU 142K, SIO 54K, ROT 107K. Backream every stand.;Logs show 674' drill out of zone since 8821'. Decision made to pull back and sidetrack to regain Inst pay. PJSM, Pump out of hole 1110268' V 8662'. 168 GPM. Pulled 20k over at 9750'& 9720', backream through with no issues. 40 RPM, 168 GPM.;Trough wellbore from 8670' to 8700' at 530 gpms/1570 psi, 120 rpms/141(ft-lbs x 3. 160R TF @ 100% deflection on GP. See .25° drop in ABI. Start control drill @ 107hr.;Sidetrack well from 8700' to 8727' with 100% deft at 160° R TF; 530 gpnU1570 psi, 120rpms/14.5Kft-lbs, 10 fph. ABI dropped 2' inc V 89.6° @ 8727'. Turned TF up to 80R and increase ROP to 307hr, increase further to 407hr at 8740'. Good separation based on ABI and calc azimuth turn at 8750'.;Drill 8.5" hole F/ 8750' to 9092' MD Total 341' (AROP 85fph) 540 gpm, 16000psi, WOB 9.5K, 160 rpms/17.5Kft-lbs . Max Gas 730U, ECD 10.8 ppg EMW with 9.1 ppg MW. P/U 143K, SIO 40K, ROT 110K. Backream 20' every stand stand.;Shut in MPD during connection at 8780', pressure build to 120 psi, 1 min. Bleed pressure off and shut in, pressure build to 90 psi. Continue drilling with open choke.;Hauaed 808 bbls Fluid to MP G&I total = 8567 bbls Hauled 0 bats H2O from 6 -Mile Lake total = 8095 bbis Hauled 0 bats from D -Pit total = 130 bats Hauled 910 bals from B pad Creek total = 1820 bbis Lost 0 bbls to formation Total fluid lost = 42 bbls;Distance to Well Plan 09a: 31.29', 18.68' Law, 25.10' Right 5/29/2019 Ddg 8.5" lateral as per Geo F/ 9,092'- T/ 9,870' MD. Total 778' (AROP 130 fph) 540 gpm, 1810 psi, WOB 5K, 160 rpms /21 Kft-lbs . Max Gas 1035U, ECD 10.9 ppg EMW with 9.1 ppg MW. P/U 154K, No dn, ROT 106K. Backream 20' every stand stand.;Shut in on connection 9750' MD. Psi built to 170 psi within 1 min. Bled off slowly and shut back in with psi building up to 100 psi within 1 min (breathing).;Drlg 8.5" lateral as per Geo F/ 9,870' - T/ 10,507' MD. Total 637' (AROP 106 fph) 540 gpm, 1900 psi, WOB 5-15K, 140 rpms /21 Kft-lbs . Max Gas 1022U, ECD 10.9 ppg EMW with 9.1 ppg MW. PIU 153K, No dn, ROT 106K. Backream 20' every stand.;Started holding 90 psi MPD back pressure during connections @ 9,995' MD to minimize impact of cycling on formation due to breathing. Continue drilling w/ 100% open MPD choke. 40 bbl Lube/Hi Vis sweep at 10,009. 20% increase in cuttings, on time. Tq reduction of 2.5k seen.; Drlg 8.5" lateral as per Geo F/ 10,507' - T/ 11,337' MD. Total 830' (AROP 138 fpr) 550 gpm, 1910 psi, WOB 5-15K, 140 rpms 121 Kft-lbs . Max Gas 1985U, ECD 11.08 ppg EMW with 9.15 ppg MW. P/U 168K, No dn, ROT 108K. Backream full stands.;MPD holding 200 psi during connections @ 11,000' MD . Continue drilling w/ 100% open MPD choke. Dump and dilute 10,800', 283 bbls 8.9 ppg Baradril-N w/ 4% lubes. ECD's drop f/ 11.3 ppg V 10.86 ppg. MBT's drop from 7 to 6.;Drlg 8.5" lateral as per Geo F/ 11,337' - T/12,161' MD. Total 824' (AROP 137 fph) 540 gpm, 1930 psi, WOB 5-15K, 140 rpms /19Kft- Ibs . Max Gas 1940U, ECD 11.2 ppg EMW with 8.95 ppg MW. P/U 155K, S/O 48k, ROT 106K. Backream full stands.;Continue holding 220 psi w/ MPD during connections U 12095' where trapped pressure started to drop to 150 psi during connection. Adjust holding pressure to 150 psi moving forward.;2 PB drilled so far from (6840' - 7178), (8750-10268) 8 faults crossed. 1985u max gas 27 concretions drilled so far for a total footage of 112' (1.8%). 2720' drilled in OAl sands, 1268' in OA2, and 1898' in OA3.;Distance to Well Plan 09a: 31.05', 30.98' Low, 2.1' Right.;Hauled 905 bbls Fluid to MP G&I total =9472 bbls Hauled 0 bbls H2O from 6-Mile Lake total = 8095 bbls Hauled 0 bbls from D-Pit total = 130 bbls Hauled 780 bbls from B pad Creek total = 2600 bbls Lost 0 bbls to formation Total fluid lost = 42 5/30/2019 Ddg 8.5" lateral as per Geo F/ 12,161' - T/12,925' MD. Total 764' (AROP 127 fph) 540 gpm, 2090 psi, WOB 1 OK, 140 rpms 1200-11as . Max Gas 1754u, ECD 11.5 ppg EMW with 9.1 ppg MW. PIU 164K, Lost do wt, ROT 106K. Backream full stands. Hold 150 psi MPD during connections.; Drlg 8.5" lateral as per Geo F/ 12,926- T/13,565' MD. Total 640' (AROP 107 fph) 540 gpm, 2100 psi, WOB 15K, 140 rpms /21 Kft-lbs . Max Gas 1814u, ECD 11.4 ppg EMW with 9.0 ppg MW. PIU 170K, No do wt, ROT 106K. Backream full stands. Hold 150 psi MPD during connections.;At 13,365' we let well flowback during connection then shut in at tail end of connection. Well built up to 76 psi with closed choke MPD.;Drlg 8.5" lateral as per Geo F/ 13,565'- T/14,259' MD. Total 694' (AROP 116 fph) 540 gpm, 2150 psi, WOB 15K, 140 rpms /22Kft-lbs . Max Gas 1782u, ECD 11.4 ppg EMW with 9.0 ppg MW. PIU 182K, No do wt, ROT 103K. Backream full stands. Hold 120 psi MPD during connections.; Pump 30 bbl Hi-Vis, Lube sweep at 14,010'. Back on calculated strokes with 10% increase in cuttings at shakers.;Drlg 8.5" lateral as per Geo F/14,259'- T/14,813' MD. Total 554' (AROP 92 fph) 510 gpm, 2050 psi, WOB 10K, 140 rpms /22Kft-lbs . Max Gas 1730u, ECD 11.5 ppg EMW with 9.05 ppg MW. P/U 182K, No do wt, ROT 100K. Backream full stands. Hold 120 psi MPD during connections.; Distance to Well Plan 09a: 51.21', 40.94' Low, 30.75' Right;2 PB drilled so Far from (6840' - 7178), (8750' -10268). 8 faults crossed. 1814u max gas. 48 concretions drilled so far for a total footage of 235' (2.6%). 3622' drilled in OA1 sands, 1695' in OA2, and 3246' in OA3.;Hauled 750 bbls Fluid to MP G&I total = 10222 bbls Hauled 0 bbls H2O from 6-Mile Lake total = 8095 bbls Hauled 0 bbls from D-Pit total = 130 bbls Hauled 1040 bbls from B pad Creek total = 3640 bbls Lost 0 bbis to formation Total fluid lost = 42 bbls 5/31/2019 Drlg 8.5" lateral as per Geo F/14,813'- T/15,286' MD. Total 473' (AROP 79 fph) 490 gpm, 2090 psi, WOB 14K, 140 rpms /22Kft-lbs . Max Gas 1310u, ECD 11.3 ppg EMW with 9.0 ppg MW. P/U 182K, No do wt, ROT 104K. Backream full stands. Hold 100 psi MPD during connections. Saw slight climb to 107 psi.;Crossed #9 projected fault @ 15,129 MD 14370' TVD. Point directional assy down @ 180° w/ 100% deflection dropping @ 4-6° DSL. Continue drilling down in section to log complete OA sand package as per geo. Wt up from 9 ppg MW to 9.3 ppg MW starting @ 15,300' MD.;Drlg 8.5" lateral as per Geo F/15,286 - T/15570' MD. Total 284' (AROP 57 fph) 490 gpm, 2090 psi, WOB 14K, 140 rpms /25.5Kft-lbs . Max Gas 519u, ECD 11.68 ppg EMW with 9.3 ppg MW. P/U 190K, No do wt, ROT 106K. Backream full stands.;Backream out of hole F/ 15,570'MD T/ 15,032'MD, 550 gpm, 2300 psi, 140 RPM - 18k Tq, Max Gas 545u, PU-182K.;Rot & Recip F115,032'MD T/15,095'MD while CBU .550 GPM, 2350 psi,160 rpm, 21 k Tq, Pumps down and monitor well for 5 min. Close MPD choke, pressure build U 72 psi in 5 min then drop U 60 psi. Open choke for 5 min, flow drop static. Close choke for 5 min, Peak @ 12 psi and drop U 8 psi.;Cont circulate @ 550 gpm. Pump 40 bbl tandem sweeps (low vis 1 high wt, high vis) after 1.5 BU. Sweep back at calc strokes with no increase in cuttings returns. Stop pumps and screen up shakers V 270's. Monitor MPD shut in pressure while change screens. Pressure build to 23 psi and drop U 21 psi.;Circulate @ 385 gpm - 1400 psi, 120 rpm - 20k Tq. Shakers running wet at 385 gpm. Perform PST at BU, Results: 5.72 sec, 6.81 sec, 7.84 sec. Continue circulate a full system volume over the 270 screens and perform PST. Passing Results: 6.04 sec , 6.69 sec, 6.59 sec. A total of 6x BU circulated.;Monitor well through RCD 2" bleed line into cellar -No Flow-. Rig down MPD RCD and install trip nipple. Fluid level in surface stack dropped from top of annular to bottom of annular. Establish circulation and check for Ieaks.;Dress shakers with 200's due to fluid running over at flow rates above 350 gpm. Pump a 40 bbl lube pill. (10% EZ- Glide). When pill exited the bit, commence BROOH.;BROOH f/ 15,031', V 14,267. 10-15 ft/min 450 gpm - 1610 psi, 120 rpm - 19k Tq. PIU 155k, SIO 63k, ROT 110k. ECD- 10.9 ppg, MW- 9.3 ppg.;2 PB drilled in lateral: (6840' - 7178),(8750'- 10268) 9 faufts crossed. 1310u max gas 56 concretions drilled for a total footage of 271' (2.8%). 3666' drilled in OA1 sands, 1718' in OA2, and 3720' in OA3. Distance to Well Plan 09a: 14.69', 13.64' Low, 5.43' Left.; Hauled 635 bbls Fluid to MP G&I total = 10857 bbls Hauled 0 bbls H2O from 6-Mile Lake total = 8095 bbls Hauled 0 bbls from D-Pit total = 130 bbls Hauled 1040 bbls from B pad Creek total = 4680 bbls Lost 0 bbls to formation Total fluid lost = 42 bbls;AFE change from drilling to completion at 06:00 6/2/19. Please refer to completions reports moving forward. UHilcorp Energy Company Composite Report Well Name: MP E-38 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): API#: 50-029-23629-00-00 Spud Date: 5/17/2019 Job Name: 1813046C MPE-38 Completion Contractor AFE #: AFE $: A""" . Ops Summary 6/1/2019 Continue BROOH F/ 14,267' - T/ 11,846' MD. 450-500 gpm, 1420 psi, 120 rpm, 10-15k tq. 30-50u bgg. 30-40 fpm pulling speed. Pump 40 bbis 10% lube pill @ 11,000' and 8,500' MD. 165k up, 68k dn, 110k rot.,Continue BROOH F/ 11,846' - T/ 7900' MD. 450-500 gpm, 1420 psi, 120 rpm, 10-15k tq. 30-50u bgg. 30-40 fpm pulling speed. Pump 40 bbis 10% lube pill @ 11,000' and 8,500' MD. 140k up, 95k dn, 107k rot.,Continue BROOH F/ 7.900'- T/ 6,308' MD. 450-500 gpm, 1000 psi, 120 rpm, 8.5-14k tq. 30-50u bgg. 5-40 fpm pulling speed. 136k up, 74k din, 108k rot. Packing off @ 6580' and started to push mud away. 20 bbis loss. Run stand back in hole t/ 6650' and BROOH at slower rate of 57min while assembly in clays. (6629-6250'). Max ECD: 11.4 ppg , Max Gas: 1813u with bottoms up after packoff.,Continue BROOH F/6,308'- T/ 5,736' MD. 450 gpm, 950 psi, 120 rpm- 6-8k tq. 20-30 fpm pulling speed. 136k up, 74k dn, 108k rot. BGG : 30-50u. Max Gas -192u. 3 bbUhr loss rate -Circulate 3x BU inside 9-5/8" shoe. Work string f/ 5736' t/ 5670' 530 GPM -1220 psi. 120 rpm - 6k Tel. BGG -6u Obtain two passing PST's. First BU results: 6.48 sec / 6.54 sec / 6.59 sec. Second BU results: 5.75 sec / 6.08 sec / 6.25 sec.,Monitor Well - Static - Sim -Ops: Remove MPD RCD bearing from stand in Derrick, UD bearing and rack stand back in Derrick. Install trip nipple.,Trip out of hole f/ 5736' U 5423'. Monitor well for swabbing. Pulling clean. Spot 40 bbl lube pill out bit (10% NXS lube), chase with dry job.,Hold kick while tripping drill. Install FOSV. Cut & Slip 56' of drlg line. Service Rig, Topdrive and dmwworks. Monitor well on trip tank. 2 bbUhr static loss rate.,Hauled 636 bbis Fluid to MP G&I total = 11493 bible Hauled 0 bbis H2O from 6 -Mile Lake total = 8095 bbis Hauled 0 bbis from D -Pit total = 130 bbis Hauled 910 bbis from B pad Creek total = 5590 bble Daily loss to formation = 74 bbis Total Mud lost on production = 74 bbls IT.t.1 Mud lost on Surface = 42 bbis 6/2/2019 Service rig - Grease crown, blocks, wash pipe, TDS, ISOP, Cobra heads, elevators, spinners and drawworks. Perform derrick inspection (good). Inspect welds on TDS frame (good). Static loss rate @ 2 bph.,POOH on elevators F/ 5423' MD - T/ 3481' MD laying down 5" drill pipe. 120k up, 102k dn.,Trip in hole out of derrick with excess stands of drill pipe F/ 3481'- T/ 5525' MD. Sym ops - B/D geo span and R/U new unft. Continue rigging down peripheral MPD equipment.,PJSM, R/D MPD lines and C/O companion flange on annulus. Empty shed and prep for laying down drill pipe., POOH on elevators F/ 5525' MD - T/ 273' laying down 5" drill pipe. 120k up, 102k dn., Rack stand HWDP in Derrick, Lay down Jars, Collars, Download MWD and lay down remaining Directional tools. Bit Grade: 2 -1 -CT -A -X -1 -BT -TD. See Photos and BHA Reports in the "O" Drive.,Rig up to RIH with liner. M/U triple connect to safety XO and handling sub. Pick up and rig up Weatherford power tongs and casing handling equipment. Load Pipeshed with ECD's & Swell Packers. Mobilize stop rings and centralizers to rig floor.,PJSM. Pickup float shoe, WIV, and 4-1/2" Packoff Valve. RIH with 4-1/2" 13.5# 625 Wedge L-80 liner with swell packers and ICD's as per tally to 2000'. Centralizer and stop ring on every joint. Tq 4-1/2" 625 Wedge t/ 9600 ft/lbs. Observe calculated displacement.,Continue RIH with 4-1/2" 13.5# 625 Wedge L-80 liner with swell packers and ICUs as per tally from 2000'to 7603', 93k up, 68k dn, Centralizer and stop ring on every joint. Tq 4-1/2" 625 Wedge U 9600 ft/lbs, P/U & SIO Wt recorded prior to entering open hole= 90k up & 77k dn, 2 BPH loss rate., Hauled 173 bbis Fluid to MP G&I total = 11666 bible Hauled 0 bbls H2O from 6 -Mile Lake total = 8095 bbis Hauled 0 bbis from D -Pit total = 130 bbis Hauled 260 bbis from B pad Creek total = 5820 bbis Daily loss to formation = 51 bbis Total Mud lost on production = 125 bbis IT.t.1 M,id lost on Surface = 42 bbis 613/2019 Cont. RIH W/ 4.5' 13.5# 625W L-80 F/ 7,603' to 9,529' MD as per tally. M/U TRQ 9.6K. P/U 102K, SLK 62K.,PJSM Set false table. R/D Weatherford 4.5" Liner Equip and R/U 2 3/8" running Equip.,PJSM W/ Weatherford and Baker for inner string. M/U Slick Stick W/ 5K rupture disc and X/O. RIH W/ 2 3/6'5.95# D.P. F/ Pipe Shed to 1,860' MD. (Drift 1.68" OD) TRQ first 25 Jnts HYD 503 to 1.81K, Cont. W/ PH6 TRQ to 3K. Lost 12 bbis, 2 bph.,PJSM Cont. RIH F/ Pipe Shed W/ 2 3/8" 5.95# inner string F/ 1,860' to 3,120' MD. TRQ PH6 3K. (Drift 1.68" OD) P/U 49K, SLK 49K.,PJSM M/U Triple Connect at 3,120' MD Work 4.5" and 2 3/8" string 15', break over 140K, P/U 115K, SLK 83K. UD Triple Connect.,PJSM RIH F/ Pipe Shed W/ 2 3/8" 5.95# inner string F/ 3,120' to 9,360' MD. TRQ PH6 3K. (Drift 1.68" OD) P/U 66K, SLK 44K.,PJSM M/U Triple Connect at 9,360' MD Work 4.5" and 2 3/8" string 15', break over 168K, P/U 124K, SLK 84K. UD Triple Connect.,PJSM Cont. RIH F/ 9,360' to 9,493' tag no/go W/ 4K set down 2X. UD Jnt 305. Tag length 27.86', P/U 10.18' Pup, 6.08' Pup and 5.4' swivel X/O M/U SLZXP Packer. 6.2' from no/go as per Baker and Cc Rep. Break over 160K, P/U 125K, SLK 86K.,P/U WU 1 Jnt 5 " HWDP to 9,567' MD stage pumps up to 2.3 bpm 1,250 PSI Circ. 2 3/8" inner string volume. No obstruction. Check float, good.,PJSM R/D Weatherford handling Equip. Prep for P/U 5" HWDP F/ Pipe Shed.,PJSM F/ picking up HWDP. RIH F/ Pipe Shed 5" HWDP W/ SLZXP and 4.5" Liner F/ 9,567' to 9,721' MD Obtain rotating parameters TRQ broke over 8.81K, 5 RPM 7.5K TRQ, 10 RPM 7.8K TRQ, 20 RPM 7.81K TRQ. Cont RIH F/ 9,721' to 10,184' MD P/U 145K, SLK 90K. Run speed 40 ft/min. Filling every 15 Jnts. Lost 25 bbis for tour.,PJSM F/ picking up HWDP. RIH F/ Pipe Shed on elevators 5" HWDP W/ SLZXP and 4.5" Liner F/ 10,184' to 12,809' MD P/U 195K, SLK 130K. At 11,973' MD set down 50K, worked string 2 BPM, 1,062 PSI, 5-10 RPM,TRQ set 9.8K. At 12,562' MD set down 50K, worked string W/ 40-60K down at 2 bpm 1,042 PSI to 2.5 bpm 1,350 PSI, 10-15 RPM TRQ limit set 13.5K. ROT P/U 194K, ROT SLK 114K.,Run speed 40 ft/min. Filling every 15 Jnts. Calc Disp 48..6 bbis, actual 37.4 bbls. Lost 11.2 bbls.,Hauled 0 bbis Fluid to MP G&I total = 11666 bbis Hauled 130 bbis H2O from 6 -Mile Lake total = 8095 bbis Hauled 0 bbls from D -Pit total = 130 bbis Hauled 0 bble from B pad Creek total = 5820 bbis Daily loss to formation =44 bbis Total Mud lost on production = 169 bbis Total Mud lost on Surface = 42 bbis Total fluid lost to formation: 211 bbis 6/4/2019 PJSM RIH F/ Pipe Shed on elevators 5" HWDP W/ SLZXP and 4.5" Liner F/ 12,809' to 15,129' MD P/U 257K, SLK 161K. 13.5K. Encountered tight spots at 13,815', 14,413', 14,743& 15,118' MD. Worked with 1.5-2 BPM, 1,080-1.250 PSI, 10 RPM, 8-13K TRQ, Max set down 50K. Max Gas 6000., Run speed 40- 60 ftlmin. Filling every 15 Jnts. Calc Disp 37.8 bbls, actual 28.8 bbls. Lost 9 bbls.,PJSM Pulled in tension W/ 254K on weight indicator at 15,129' MD. Start displacement W140 bbl Hi Vis spacer at 2 bpm, 1,220 PSI.,PJSM Cont. displacement chasing W/ 500 bbl 9.3 ppg NaCU 3% KCL Brine off Vac Trucks, Pump 40 bbl Sapp, 50 bbis Brine, 40 bbl Sapp, 50 bbl Brine and 40 bbis Sapp pills at 2.2 bpm, 1,500 PSI. Taking all retums to cutting box.,Cont. displacement off trucks. Took return back to pits after sweep and interface was seen at Shakers. Dumped Sapp and Brine pills until clean Brine was seen at Shakers. Took returns back to Pits at 2.6 bpm, 1,500 PSI. Observed 7 bph dynamic loss rate. Lost 48 bbis during displacement., PJSM for setting SLZXP. Drop 1.25" ball and pump down at 2 bpm, 1,490 PSI ball seated at 69 blots away. Cont. to Press. up to 2,900 PSI to set the SLZXP. Held for 10 minutes. Slack off 35K on the SLZXP to ensure the HRDE setting tool is in compression. Continue pressuring up 4,500 psi to neutralize and release running tools. Picked up string to 238K initial weight 255K indicating released. TOL at 5,573' MD.,PJSM for test annulus. R/U test Equip. Close BOP and test annulus to 1500 psi for 10 min and chart, good. Pumped 1.9 bbls, bled back 1.8 bbis. RID and blow down.,PJSM UD 10' pup and 1 Jnt 5" D.P. Displace 4.5" X 2 318" annulus 2X at 3 3 bpm, 2,750 PSI. Initial dynamic loss rate 24 bph, slowing to 14 bph. Total lost 26 bbis. Monitor welt for 10 Min, 3-4 bph static loss rate., PJSM UD ten Jnts 5" HWDP F/15,088' to 14,778' MD. W/ no swabbing. Pump Dry Job and blow down TD. Cont. UD 5" HWDP to pipe shed F/ 14,778' to 13,815' MD. PIU 233 K. Calc disp 16.2 bbis, actual 19.8 bbls. Lost 3.6 bbls.,Hauled 1,958 bbis Fluid to MP G&I total = 13,624 bible Hauled 130 bbis H2O from 6-Mile Lake total = 8,095 bible Hauled 0 bbis from D-Pit total = 130 bbis Hauled 0 bbis from B pad Creek total = 5,820 bbis Daily loss to formation =68 bbis Total Mud lost on production = 237 bbls Total Mud lost on Surface = 42 bbis Total fluid lost to formation: 211 blots 615/2019 Continue to POOH UD 5" HWDP f/ 13,974" to 9,493'. PUW 68. Lost 31 bbls to formation.,UD Liner Running Tool. Inspect same. (Good) Change out pipe handling equipment. Rig up Weatherford power tongs. Rig up safety joint.,POOH laying down 2-3/8" inner string from 9412'to 9412'. Static toss rate 5.4 bph.,Cont POOH laying down 2-3/8" inner string from 9412" to surface. Calc Disp 20 bbls, actual 60 bbis, lost 40 bbls. Rig down handling equipment, and safety joint. Monitor hole on trip tank: static loss rate 6 bph.,PJSM UD slick stick. , 2 3/8" handling Equip, Power Tongs and break off triple connect F/ TIW. Install 5" Elevators and PIU 3.5" Stinger W/ no/go.,PJSM RIH WI 3.5" Stinger on 5" 19.5# D.P. F/ Derrick to TOL at 5,573' MD. Set down 6K 2X. P/U 135K, SLK 113K. Calc Disp 47 bbls, actual 40 bbis. Lost 7 bbls.,PJSM P/U to 5,567' putting no/go 7' about liner top. Est Circ at .5 bpm washing up slowly. Rack back 1 stand 5" D.P. to 5,539' MD. CBU 1X and start displacing to clean 9.3 ppg Brine at 10 bpm, 310 PSI, 30 RPM, TRQ 5K, ROT 125K, P/U 135K, SLK 113K. Lost about 81 bbis during displacement. Dynamic loss rate 16 bph.,PJSM Cont. displacing to clean 9.3 ppg clean brine at 10 bpm, 310 PSI, 30 RPM, 5K TRQ. ROT 125K, P/U 135K, SLK 113K. Dynamic loss rate 16 BPH. Shut down monitor well 15 Min, 6 bph static loss rate.,PJSM POOH UD 5" D.P. to Pipe Shed F/ 5,539 to 1,420' MD. P/U 64K, SLK 60K. Calc Disp 36 bbls, actual 65 bbls, Lost 29 bbls.,Safety latch pin on Hydraulic Elevators broke. Service rig and skate while going to Dyon to borrow a set of manual Elevatom.,PJSM Cont POOH UD 5" D.P. to Pipe Shed F/ 1,420'to 1,022' MD. P/U 64K, SLK 60K.,Hauled 575 bbis Fluid to MP G&I total = 14,199 bbis Hauled 0 bbis H2O from 6-Mile Lake total = 8,095 bbis Hauled 0 bbis from D-Pit total = 130 bbls Hauled 0 bbis from B pad Creek total = 5,820 bbis Daily loss to formation =160 bbis Total Mud lost on production = 397 bbis Total Mud lost on Surface = 42 bbis Total fluid lost to formation: 439 bbis 6/6/2019 Cont. POOH UD 5" D.P. to Pipe Shed F/ 1,022' to 300' MD. P/U 48K, SLK 46K., PJSM RIH 5" D.P. F/ Derrick FI 300' to 3,350' MD. Calc Disp 25 bbls, actual 13.5. Lost 11.5 bbis-POOH UD 5" D.P. to Pipe Shed F/ 3,350' to 785' MD. P/U 55K, SLK 54K. Cato Disp 24.5 bbls, actual 44 bbls. Lost 19.5 bbls., PJSM Breaking ice off Derrick. Monitor hole on trip tank, 7 bph static loss.,PJSM Cut 69' and slip 11 wraps of drilling line. 146' left on drilling spool. Check brake pads. Monitor hole on trip tank 7 bph static loss.,PJSM POOH UD 5" D.P. to Pipe Shed F/ 785' to surface. UD 3.5" stinger W/ no/go. Calc Disp 12 bbis, actual 6 bbis. Lost 7 bbls.,PJSM ROLDS and remove Wear Ring.,PJSM Clean and clear rig floor of 5" handling Equip. R/U 3.5" elevators. Bring 100 cannon clamps, SLB Equip, gauge line spool, hang sheave, load jewelry in pipe shed abd R/U Weatherford Power Tongs.,PJSM for running 3.5" Tubing. P/U MIU * ' Baker 7 3/8" Tie Back Bullet Seal Assy to 3.5" 9.3# L-80 EUE to 819' MD. M/U SLB Gauge Mandrel line and test to 5,000 PSI F/ 5 Min., Cont. RIH 3.5" Tubing 1Ooy and control line setting Cannon Clamps as per tally F/ 819'to 2,819' MD. Check conductivity every 500'. P/U 57K, SLK 55K. Calc Disp 8 bbis, actual -20 bbis, Lost 28 bbls. TRQ EUE 8 rd to 3.2K.,PJSM for running 3.5" Tubing. PIU M/U Baker 7 318" Tie Back Bullet Seal Assy to 3.6'9.39 L-80 EUE F/ 2,819' to TOL at 5,573' MD. Tag TOL 2X 5K. Calc Disp 8 bbls, actual -16.5 bbls, Lost 24.5 bbis. Check conductivity every 500'. TRQ EUE 8 rd to 3.2K.,PJSM Perform space out 17.5', UD 2 Jnts 3.5" Tubing. P/U 1 ea 2.09', 3.12'& 10.08' Pups setting no/go 1.98' off TOL. P/U MU Hanger and 3.5" landing joint. Terminate SLB gauge line as per SLB and NOS Rep onsite.,Hauled 396 bbis Fluid to MP G&I total = 14,595 bbis Hauled 0 bbis H2O from 6-Mile Lake total = 8,095 bbis Hauled 0 bbis from D-Pit total = 130 bbis Hauled 0 bbis from B pad Creek total = 5,820 bbis Daily loss to formation =167 bbis Total Mud lost on production = 564 bbls Total Mud lost on Surface = 42 bbis Total fluid lost to formation: 439 bbis 6/7/2019 Continue to Terminate SLB Gauge Control line., RIH 2' from landing out. Close annular, PT IA 500 psi to ensure seal engagement. Strip up see pressure drop / locating ports to A. Line up establish reverse circulation at 4.5 bpm/450 FCP Reverse in 175 bbis of corrosion inhibited brine and 200 bbis diesel down back side, chase lines with 10 bbis brine. FCP @ 500 psi @ 2 bpm.,Strip in hole until seals are engaged. Bleed off pressure and open annular. Drain Stack and Land hanger. RI LDS. PUW 74K, SOW 64K. Loss Rate @ 13 bph. RIU and PT 9-5/&'x 3.5" annulus to 2000 Psi for 30 minutes - good test. Rig down test equipment. Witness Waived By Matt Hererra., Pull landing joint. Break out X/O's and UD. Clean and clear rig floor while monitoring well, well taking fluid. Set BPV. RIU and flush surface equipment with fresh water. Start loading DP in Pipe Shed.,PJSM Drain BOPE. NOS set BPV. Flush Top Drive and all surface lines with H2O. RID ROPE. SIMOPS Clean pits and process 5" D.P. in Pipe Shed. Set Herculite and mats on E-42., PJSM SLB and NOS rep terminate and test gauge line. N/U Tree and test void and seals 500 PSI low and 5,000 PSI high. RIU test Equip for testing Tree. SIMOPS Clean Pits. Start inspection on MP #1.,PJSM R/U test Equip. Test Tree 500 PSI low and 5,000 PSI high 5 Min/ 15 Min. NOS install BPV. RID test Equip.,Remove companion flange F/ annulus. Clean and clear rig floor. Clean and prep for cellar for move. SIMOPS Disconnect inner connects. Cont. processing 5" D.P. in Pipe Shed. C/O valves and seats on MP 01. Install Tee on E-42.,PJSM RID rig tongs and Bridal up. Scope down Derrick. SIMOPS Clear Equip around rig. Secure Pipe Shed. Stage Well Head & Tree behind E-42. Start Prep rooftops and stairs around rig.R/U LRS, PT lines to 2,500 PSI, Freeze Protect well WI 25 bible Diesel down 3.5" Tubing.,Hauled 535 bbis Fluid to MP G&I total = 15,130 bbis Hauled 0 bbis H2O from 6-Mile Lake total = 8,095 blots Hauled 0 bbis from D-Pit total = 130 bbls Hauled 0 bbis from B pad Creek total = 5,820 bbls Daily loss to formation =60 bbis Total Mud lost on production = 624 bbis Total Mud lost on Surface = 42 bbis Total fluid lost to formation: 439 bbis Hilcorp Alaska, LLC Milne Point MPtEPad MPU E-38 Sperry Drilling Definitive Survey Report 04 June, 2019 HALLIBURTON Sperry Drilling Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-38 Wellbore: MPU E-38 Design: MPU E-38 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-38 MPU E-38 Actual RKB @ 48.18usft MPU E-38 Actual RKB @ 48.18usft 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 Paint Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU E-38 Well Position +N/S +E/ -W Position Uncertainty Wellbore MPU E-38 Magnetics Model Name 0.00 usft Northing: 6,016,081.06 usfl 0.00 usft Easting: 569,265.12 usfl 0.00 usft Wellhead Elevation: 0.00 usfl Sample Date Declination (I BGGM2018 5/29/2019 16.69 Design MPU E-38 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +NIS (usft) (usft) 26.38 0.00 Latitude: 70° 27'15.4464 N Longitude: 149° 26'5.1882 W Ground Level: 21.80 usft Dip Angle Field Strength C) (nT) 80.96 57,428.23056825 Tie On Depth: 8,653.62 +EI -W Direction (usft) (') 0.00 295.00 Survey Program Date 6/412019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 415.00 MPU E-38PB1 SDI Gyro (MPU E-38PB1 2_Gyro-NS-GC_Drill toll: H029Ga: North seeking single shot in drill colla 05/08/2019 484.73 5,728.83 MPU E-38PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/17/2019 5,791.41 6,809.02 MPU E-38PB1 MWD+IFR2+MS+Sag (2) 2MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/26/2019 6,840.00 8,653.62 MPU E-38PB2 MWD+IFR2+MS+Sag (3) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/28/2019 8,700.00 13,940.68 MPU E-38 MWD+IFR2+MS+Sag (4) (MF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis+ sa 05/29/2019 13,940.68 14,004.28 MPU E-38 MWD Interp Azi+Sag (MPU E 2_MWD _Interp Azi+Sag H003Mb: Interpolated azimuth + sag correctior 05/29/2019 14,068.50 15,501.20 MPU E-38 MWD+IFR2+MS+Sag(5) IMF 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/29/2019 Survey 66412019 6+02:59PM Page 2 COMPASS 5000.15 Build 91 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 26.38 0.00 0.00 26.38 -21.80 0.00 0.00 6,016,081.06 569,265.12 0.00 0.00 UNDEFINED 100.00 0.40 265.25 100.00 51.82 -0.02 -0.26 6,016,081.04 569,264.86 0.54 0.22 2_Gyro-NS-GC_Drill collar (1 166.00 0.48 274.71 166.00 117.82 -0.02 -0.76 6,016,081.04 569,264.36 0.16 0.68 2_Gyro-NS-GC_Dril collar (1 228.00 0.52 282.53 228.00 179.82 0.06 -1.29 6,016,081.11 569,263.82 0.13 1.20 2_Gyro-NS.GC_DnIJ collar (1 290.00 0.83 346.13 289.99 241.81 0.56 -1.68 6,016,081.61 569,263.44 1.22 1.76 2_Gyro-NS-GC_Drill collar (1 352.00 2.70 13.26 351.96 303.78 2.42 -1.45 6,016,083.47 569,263.65 3.22 2.34 2_Gyro-NS-GC Dnll collar (1 415.00 4.31 19.46 414.84 366.66 6.10 -0.32 6,016,087.15 569,264.74 2.62 2.87 2_Gyro-NS-GC_Drill collar (1 484.73 7.41 33.76 484.20 436.02 12.31 3.05 6,016,093.39 569,268.06 4.88 2.43 2_MWD+IFR2+MS+Sag (2) 546.64 9.25 41.00 545.46 497.28 19.38 8.54 6,016,100.52 569,273.47 3.42 0.46 2_MWD+IFR2+MS+Sag(2) 66412019 6+02:59PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-38 Wellbore: MPU E-38 Design: MPU E-38 Survey MD Inc Azi TVD TVDSS +NIS (usft) (°) (1) (usft) (usft) (usft) 609.18 11.00 51.54 607.03 558.85 26.89 671.65 12.92 55.89 668.14 619.96 34.51 736.05 13.98 54.86 730.77 682.59 43.03 799.21 16.76 55.19 791.67 743.49 52.62 863.21 20.15 55.13 852.37 804.19 64.19 899.52 20.42 53.97 886.42 838.24 71.49 926.70 19.68 53.76 911.96 863.78 76.99 990.18 17.77 53.81 972A7 923.89 89.03 1,053.16 17.81 54.52 1,032.04 983.86 100.29 1,117.77 17.54 54.62 1,093.60 1,045.42 111.66 1,180.55 18.59 50.91 1,153.29 1,105.11 123.45 1,245.59 18.94 50.29 1,214.87 1,166.69 136.73 1,307.78 17.70 51.13 1,273.91 1,225.73 149.11 1,372.53 17.88 47.93 1,335.56 1,287.38 161.95 1,436.75 17.66 46.76 1,396.72 1,348.54 175.23 1,498.90 17.76 46.38 1,455.92 1,407.74 188.23 1,563.71 16.50 42.63 1,517.86 1,469.68 201.82 1,625.75 14.33 36.92 1,577.67 1,529.49 214.44 1,689.74 13.22 34.70 1,639.82 1,591.64 226.79 1,753.71 13.17 33.23 1,702.10 1,653.92 238.90 1,817.71 12.57 32.69 1,764.49 1,716.31 250.86 1,881.46 12.84 32.77 1,826.68 1,778.50 262.65 1,945.97 13.20 33.05 1,889.53 1,841.35 274.85 2,008.81 13.13 33.34 1,950.72 1,902.54 286.83 2,073.58 13.20 34.75 2,013.79 1,965.61 299.05 2,136.37 13.69 32.90 2,074.86 2,026.68 311.18 2,201.32 13.89 33.46 2,137.93 2,089.75 324.14 2,264.17 13.49 30.83 2,199.00 2,150.82 336.73 2,327.69 13.44 30.86 2,260.77 2,212.59 349.43 2,392.22 13.87 30.54 2,323.48 2,275.30 362.53 2,456.05 14.35 30.62 2,385.38 2,337.20 375.92 2,519.70 14.64 33.88 2,447.01 2,398.83 389.39 2,583.46 14.39 32.30 2,508.73 2,460.55 402.77 2,647.49 14.17 32.84 2,570.79 2,522.61 416.08 2,710.38 14.15 33.67 2,631.76 2,583.58 428.95 2,774.32 13.50 31.31 2,693.85 2,645.67 441.83 2,837.62 13.44 32.08 2,755.41 2,707.23 454.38 2,901.77 13.08 32.68 2,817.85 2,769.67 466.80 2,965.54 13.56 33.24 2,879.90 2,831.72 479.13 3,028.74 13.95 33.59 2,941.29 2,893.11 491.67 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-38 MPU E-38 Actual RKB @ 48.18usft MPU E-38 Actual RKB @ 48.18usft True Minimum Curvature NORTH US + CANADA 6/4/2019 6:02:59PM Page 3 COMPASS 5000.15 Build 91 Map Map Vertical +El -W Northing Easting DLS Section (usft) (ft) (ft) (°1700') (ft) Survey Tool Name 16.51 6,016,108.10 569,281.37 4.06 -3.60 2_MWD+IFR2+MS+Sag (2) 26.96 6,016,115.82 569,291.75 3.39 -9.85 2_MWD+IFR2+MS+Sag (2) 39.28 6,016,124.45 569,303.99 1.69 -17.42 2_MWD+IFR2+MS+Sag (2) 53.00 6,016,134.16 569,317.62 4.40 -25.80 2_MWD+IFR2+MS+Sag (2) 69.62 6,016,145.89 569,334.14 5.30 -35.97 2_MWD+IFR2+MS+Sag (2) 79.88 6,016,153.29 569,344.32 1.33 42.18 2_MWD+IFR2+MS+Sag (2) 87.40 6,016,158.85 569,351.80 2.74 -46.68 2 MWD+IFR2+MS+Sag(2) 103.84 6,016,171.04 569,368.12 3.01 -56.49 2_MWD+IFR2+MS+Sag(2) 119.44 6,016,182.45 569,383.61 0.35 -65.87 2_MWD+IFR2+MS+Sag (2) 135.43 6,016193.97 569,399.49 0.42 -75.55 2_MWD+IFR2+MS+Sag(2) 150.91 6,016,205.90 569,414.86 2.48 -84.60 2_MWD+IFR2+MS+Sag(2) 167.08 6016,219.33 569,430.90 0.62 -93.64 2_MWD+IFR2+MS+Sag(2) 182.20 6,016,231.85 569,445.91 2.04 -102.11 2_MWD+IFR2+MS+Sag(2) 197.24 6,016,244.82 569,460.83 1.54 -110.32 2_MWD+IFR2+MS+Sag (2) 211.66 6,016,258.23 569,475.12 0.65 -117.77 2_MWD+IFR2+MS+Sag(2) 225.39 6016,271.36 569,488.73 0.25 -124.72 2_MWD+IFR2+MS+Sag (2) 238.78 6,016,285.07 569,501.99 2.58 -131.11 2_MWD+IFR2+MS+Sag(2) 249.36 6,016,297.79 569,512.45 4.26 -135.37 2_MWD+IFR2+MS+Sag (2) 258.28 6,016,310.22 569,521.26 1.92 -138.24 2_MWD+IFR2+MS+Sag (2) 266.44 6016,322.40 569,529.30 0.53 -140.51 2_MWD+IFR2+MS+Sag (2) 274.19 6,016,334.43 569,536.95 0.96 -142.49 2_MWD+IFR2+MS+Sag (2) 281.78 6,016,346.30 569,544.42 0.42 -144.37 2_MWD+IFR2+MS+Sag (2) 289.67 6016358.57 569,552.20 0.57 -146.37 2_MWD+IFR2+MS+Sag(2) 297.51 6016,370.62 569,559.92 0.15 -148.41 2_MWD+IFR2+MS+Sag(2) 305.77 6,016,382.91 569,568.06 0.51 -150.73 2_MWD+IFR2+MS+Sag (2) 313.89 6,016,395.12 569,576.07 1.04 -152.97 2_MWD+IFR2+MS+Sag (2) 322.36 6,016,408.15 569,584.42 0.37 -155.17 2_MWD+IFR2+MS+Sag (2) 330.28 6,016,420.81 569,592.22 1.18 -157.03 2_MWD+IFR2+MS+Sag(2) 337.86 6,016,433.58 569,599.69 0.08 -158.53 2_MWD+IFR2+MS+Sag(2) 345.64 6,016,446.75 569,607.34 0.68 -160.05 2_MWD+IFR2+MS+Sag(2) 353.56 6,016,460.22 569,615.13 0.75 -161.56 2_MWD+IFR2+MS+Sag (2) 362.06 6,016,473.76 569,623.51 1.36 -163.57 2_MWD+IFR2+MS+Sag (2) 370.78 6016,487.23 569,632.11 0.73 -165.82 2_MWD+IFR2+MS+Sag (2) 379.28 6,016,500.61 569,640.48 0.40 -167.90 2 MWD+IFR2+MS+Sag(2)M 387.72 6,016,513.55 569,648.80 0.32 -170.11 2_WD+IFR2+MS+Sag(2) 395.93 6,016,526.51 569,656.89 1.35 -172.11 2_MWD+IFR2+MS+Sag (2) 403.68 6,016539.13 569,664.52 0.30 -173.83 2_MWD+IFR2+MS+Sag (2) 411.56 6,016,551.62 569,672.28 0.60 -175.72 2_MWD+IFR2+MS+Sag (2) 419.55 6,016,564.02 569,680.16 0.78 -177.75 2_MWD+IFR2+MS+Sag (2) 427.83 6,016,576.64 569,688.32 0.63 -179.95 2_MWD+IFR2+MS+Sag(2) 6/4/2019 6:02:59PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-38 Project: Milne Point ND Reference: MPU E-38 Actual RKB @ 48.18usft Site: M Pt E Pad MD Reference: MPU E-38 Actual RKB @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38 Survey Calculation Method: Minimum Curvature Design: MPU E-38 Database: NORTH US+CANADA Survey Map Map MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS (usft) (°) (1) (usft) (usft) (use) (use) (ft) (ft) (°1100') 3,092.66 14.01 26.44 3,003.32 2,955.14 505.02 435.54 6,016,590.06 569,695.90 2.70 3,156.19 14.38 17.14 3,064.92 3,016.74 519.45 441.29 6,016,604.54 569,701.52 3.63 3,220.01 14.01 14.17 3,126.79 3,078.61 534.51 445.51 6,016,619.64 569,705.60 1.28 3,281.95 14.96 5.41 3,186.77 3,138.59 549.74 448.10 6,016,634.89 569,708.05 3.85 3,345.46 16.64 356.45 3,247.89 3,199.71 566.98 448.31 6,016,652.13 569,708.10 4.66 3,410.77 17.70 349.57 3,310.29 3,262.11 586.08 445.93 6,016,671.20 569,705.55 3.51 3,473.62 19.27 339.13 3,369.92 3,321.74 605.17 440.51 6,016,690.24 569,699.94 5.82 3,537.85 21.90 332.89 3,430.05 3,381.87 625.74 431.27 6,016,710.73 569,690.52 5.33 3,601.53 24.21 329.22 3,488.64 3,440.46 647.54 419.18 6,016,732.41 569,678.22 4.27 3,663.52 25.99 326.10 3,544.78 3,496.60 669.73 405.09 6,016,754.47 569,663.93 3.58 3,728.88 28.09 319.52 3,603.00 3,554.82 693.33 387.11 6,016,777.90 569,645.73 5.59 3,792.93 30.22 315.02 3,658.94 3,610.76 716.21 365.92 6,016,800.57 569,624.33 4.77 3,856.04 32.54 313.84 3,712.82 3,664.64 739.20 342.45 6,016,823.35 569,600.65 3.80 3,920.42 35.41 313.48 3,766.20 3,718.02 764.04 316.42 6,016,847.93 569,574.40 4.47 3,983.50 37.12 312.67 3,817.06 3,768.88 789.51 289.16 6,016,873.15 569,546.91 2.82 4,047.56 38.22 312.03 3,867.77 3,819.59 815.88 260.23 6,016,899.25 569,517.73 1.82 4,110.98 41.04 311.37 3,916.61 3,868.43 842.78 230.03 6,016,925.87 569,487.28 4.50 4,174.76 44.70 309.11 3,963.34 3,915.16 870.78 196.90 6,016,953.55 569,453.89 6.22 4,238.00 47.02 307.33 4,007.38 3,959.20 898.85 161.24 6,016,981.28 569,417.98 4.19 4,301.74 47.74 305.94 4,050.55 4,002.37 926.83 123.60 6,017,008.91 569,380.09 1.96 4,365.61 51.17 303.88 4,092.06 4,043.88 954.58 83.80 6,017,036.29 569,340.03 5.90 4,429.48 53.36 303.73 4,131.15 4,082.97 982.68 41.83 6,017,064.00 569,297.81 3.43 4,492.95 55.58 303.34 4,168.03 4,119.85 1,011.21 -1.23 6,017,092.12 569,254.49 3.53 4,555.71 58.71 302.30 4,202.07 4,153.89 1,039.78 -45.53 6,017,120.27 569,209.93 5.18 4,620.54 61.21 302.15 4,234.53 4,186.35 1,069.70 -93.00 6,017,149.75 569,162.18 3.86 4,683.68 62.46 301.93 4,264.33 4,216.15 1,099.23 -140.19 6,017,178.84 569,114.73 2.00 4,747.33 6441 299.54 4,292.79 4,244.61 1,128.31 -189.12 6,017,207.46 569,065.54 4.55 4,811.01 66.78 297.90 4,319.11 4,270.93 1,156.17 -239.97 6,017,234.94 569,014.43 4.40 4,874.91 70.42 297.05 4,342.42 4,294.24 1,183.61 -292.75 6,017,261.78 568,961.41 5.83 4,938.84 73.83 295.31 4,362.04 4,313.86 1,210.44 -347.35 6,017,288.10 568,906.57 5.93 5,002.62 76.39 294.97 4,378.43 4,330.25 1,236.62 -403.14 6,017,313.76 568,850.54 4.05 5,066.15 78.55 295.05 4,392.21 4,344.03 1,262.84 -459.34 6,017,339.45 568,794.10 3.40 5,130.30 79.89 295.86 4,404.21 4,356.03 1,289.92 -516.24 6,017,366ol 568,736.96 2.43 5,193.79 83.41 295.44 4,413.43 4,365.25 1,317.11 -572.86 6,017,392.66 568,680.10 5.58 5,257.32 83.55 297.00 4,420.64 4,372.46 1,345.00 -629.48 6,017,420.02 568,623.22 2.45 5,321.04 81.48 298.27 4,428.94 4,380.76 1,374.30 -685.45 6,017,448.80 568,566.99 3.80 5,384.66 80.82 298.10 4,438.73 4,390.55 1,403.99 -740.85 6,017,477.97 568,511.32 1.07 5,448.81 82.63 297.36 4,447.96 4,399.78 1,433.52 -797.04 6,017,506.98 568,454.86 3.04 5,512.37 84.81 296.61 4,454.91 4,406.73 1,462.19 -853.34 6,017,535.12 568,398.31 3.62 5,575.69 86.39 295.90 4,459.77 4,411.59 1,490.12 -909.96 6,017,562.51 568,341.44 2.73 Vertical Section (ft) Survey Tool Name -181.30 2_MWD+IFR2+MS+Sag(2) -180.41 2_MWD+IFR2+MS+Sag (2) -177.88 2_MWD+IFR2+MS+Sag (2) -173.79 2_MWD+IFR2+MS+Sag (2) -166.69 2_MWD+IFR2+MS+Sag (2) -156.47 2_MWD+IFR2+MS+Sag(2) -143.48 2_MWD+IFR2+MS+Sag (2) -126.41 2_MWD+IFR2+MS+Sag (2) -106.24 2_MWD+IFR2+MS+Sag (2) -84.10 2_MWD+IFR2+MS+Sag (2) 57.83 2_MWD+IFR2+MS+Sag(2) -28.96 2_MWD+IFR2+MS+Sag(2) 2.04 2_MWD+IFR2+MS+Sag (2) 36.12 2_MWD+IFR2+MS+Sag (2) 71.59 2_MWD+IFR2+MS+Sag(2) 108.96 2_MWD+IFR2+MS+Sag(2) 147.70 2_MWD+IFR2+MS+Sag (2) 189.56 2_MWD+IFR2+MS+Sag'(2) 233.74 2_MWD+IFR2+MS+Sag (2) 279.68 2_MWD+IFR2+MS+Sag(2) 327.48 2_MWD+IFR2+MS+Sag (2) 377.39 2_MWD+IFR2+MS+Sag (2) 428.47 2_MWD+IFR2+MS+Sag (2) 480.69 2_MWD+IFR2+MS+Sag(2) 536.37 2_MWD+IFR2+MS+Sag (2) 591.61 2_MWD+IFR2+MS+Sag (2) 648.25 2_MWD+IFR2+MS+Sag(2) 706.11 2_MWD+IFR2+MS+Sag (2) 765.54 2_MWD+IFR2+MS+Sag(2) 826.36 2_MWD+IFR2+MS+Sag (2) 887.99 2 MWD+IFR2+MS+Sag (2) 950.00 2_MWD+IFR2+MS+Sag(2) 1,013.02 2_MWD+IFR2+MS+Sag (2) 1,075.82 2 MWD+IFR2+MS+Sag(2) 1,138.92 2_MWD+IFR2+MS+Sag(2) 1,202.03 2_MWD+IFR2+MS+Sag(2) 1,264.79 2_MWD+IFR2+MS+Sag (2) 1,328.20 2_MWD+IFR2+MS+Sag (2) 1,391.34 2_MWD+IFR2+MS+Sag(2) 1,454.45 2_MWD+IFR2+MS+Sag (2) 6142019 6:02:59PM Page 4 COMPASS 5000.15 Build 91 Survey Halliburton Definitive Survey Report Map Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-38 Project: Milne Point ND Reference: MPU E-38 Actual RKB @ 48.18usft Site: M Pt E Pad MD Reference: MPU E-38 Actual RKB @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38 Survey Calculation Method: Minimum Curvature Design: MPU E-38 Database: NORTH US+CANADA Survey 6142019 6 02:59PM Page 5 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) (°/too.) (ft) Survey Tool Name 5,639.99 85.90 296.04 4,464.09 4,415.91 1,518.21 -967.63 6,017,590.07 568,283.51 0.79 1,518.60 2_MWD+IFR2+MS+Sag(2) 5,728.83 89.94 294.55 4,467.32 4,419.14 1,556.13 -1,047.89 6,017,627.24 568,202.91 4.85 1,607.36 2_MWD+IFR2+MS+Sag(2) 5,791.41 91.00 296.59 4,466.81 4,418.63 1,583.14 -1,104.33 6,017,653.72 568,146.23 3.67 1,669.93 2_MWD+IFR2+MS+Sag (3) 5,856.13 90.38 299.15 4,466.03 4,417.85 1,613.39 -1,161.53 6,017,683.43 568,088.75 4.07 1,734.56 2_MWD+IFR2+MS+Sag(3) 5,919.12 89.08 299.14 4,466.32 4,418.14 1,644.07 -1,216.55 6,017,713.59 568,033.46 2.06 1,797.38 2_MWD+IFR2+MS+Sag (3) 5,982.72 88.90 297.70 4,467.44 4,419.26 1,674.33 -1,272.47 6,017,743.33 567,977.26 2.28 1,860.85 2_MWD+IFR2+MS+Sag(3) 6,045.81 88.52 295.45 4,468.86 4,420.68 1,702.55 -1,328.88 6,017,771.02 567,920.60 3.62 1,923.90 2_MWD+IFR2+MS+Sag(3) 6,109.41 88.46 293.53 4,470.54 4,422.36 1,728.90 -1,386.73 6,017,796.83 567,862.51 3.02 1,987.47 2_MWD+IFR2+MS+Sag(3) 6,173.04 88.28 292.77 4,472.35 4,424.17 1,753.91 -1,445.22 6,017,821.29 567,803.80 1.23 2,051.04 2 MWD+IFR2+MS+Sag(3) 6,236.57 87.78 292.13 4,474.53 4,426.35 1,778.15 -1,503.90 6,017,844.99 567,744.90 1.28 2,114.47 2_MWD+IFR2+MS+Sag (3) 6,299.94 88.84 292.08 4,476.40 4,428.22 1,801.99 -1,562.58 6,017,868.27 567,686.00 1.67 2,177.73 2_MWD+IFR2+MS+Sag (3) 6,363.67 91.25 291.80 4,476.35 4,428.17 1,825.80 -1,621.69 6,017,891.53 567,626.68 3.81 2,241.37 2_MWD+IFR2+MS+Sag (3) 6,427.42 93.54 291.53 4,473.69 4,425.51 1,849.31 -1,680.88 6,017,914.49 567,567.28 3.62 2,304.95 2_MWD+IFR2+MS+Sag(3) 6,491.22 94.90 290.96 4,468.99 4,420.81 1,872.37 -1,740.18 6,017,936.99 567,507.77 2.31 2,368.44 2_MWD+IFR2+MS+Sag(3) 6,554.84 94.76 290.22 4,463.64 4,415.46 1,894.66 -1,799.53 6,017,958.73 567,448.23 1.18 2,431.64 2_MWD+IFR2+MS+Sag (3) 6,618.08 94.58 290.37 4,458.49 4,410.31 1,916.52 -1,858.65 6,017,980.04 567,388.92 0.37 2,494.46 2_MWD+IFR2+MS+Sag(3) 6,681.14 94.95 290.62 4,453.25 4,405.07 1,938.52 -1,917.51 6,018,001.49 567,329.85 0.71 2,557.11 2_MWD+IFR2+MS+Sag(3) 6,745.14 94.95 290.52 4,447.73 4,399.55 1,960.93 -1,977.21 6,018,023.34 567,269.96 0.16 2,620.68 2_MWD+IFR2+MS+Sag(3) 6,809.02 94.71 290.50 4,442.35 4,394.17 1,983.23 -2,036.82 6,018,045.08 567,210.14 0.38 2,684.14 2_MWD+IFR2+MS+Sag(3) 6,840.00 94.62 290.45 4,439.83 4,391.65 1,994.03 -2,065.75 6,018,055.61 567,181.12 0.33 2,714.92 2_MWD+IFR2+MS+Sag (4) 6,873.13 92.53 291.78 4,437.76 4,389.58 2,005.94 -2,096.59 6,018,067.24 567,150.17 7.47 2,747.91 2_MWD+IFR2+MS+Sag(4) 6,936.01 92.41 291.93 4,435.05 4,386.87 2,029.33 -2,154.90 6,018,090.08 567,091.65 0.31 2,810.63 2_MWD+IFR2+MS+Sag (4) 7,000.21 92.04 293.20 4,432.56 4,384.38 2,053.94 -2,214.14 6,018,114.14 567,032.19 2.06 2,874.73 2_MWD+IFR2+MS+Sag (4) 7,064.55 92.60 293.51 4,429.96 4,381.78 2,079.43 -2,273.16 6,018,139.07 566,972.94 0.99 2,938.99 2_MWD+IFR2+MS+Sag (4) 7,127.27 92.42 293.13 4,427.21 4,379.03 2,104.23 -2,330.70 6,018,163.34 566,915.18 0.67 3,001.62 2_MWD+IFR2+MS+Sag(4) 7,190.39 91.61 291.85 4,424.99 4,376.81 2,128.36 -2,388.98 6,018,186.92 566,856.68 2.40 3,064.64 2_MWD+IFR2+MS+Sag(4) 7,253.82 91.12 292.19 4,423.48 4,375.30 2,152.14 -2,447.77 6,018,210.15 566,797.68 0.94 3,127.96 2_MWD+IFR2+MS+Sag (4) 7,317.39 90.93 292.82 4,422.34 4,374.16 2,176.47 -2,506.49 6,018,233.93 566,738.75 1.03 3,191.46 2 MWD+IFR2+MS+Sag(4) 7,380.84 91.24 294.31 4,421.14 4,372.96 2,201.83 -2,564.63 6,018,258.74 566,680.37 2.40 3,254.88 2_MWD+IFR2+MS+Sag(4) 7,443.56 92.05 295.98 4,419.34 4,371.16 2,228.47 -2,621.38 6,018,284.85 566,623.38 2.96 3,317.57 2_MWD+IFR2+MS+Sag(4) 7,507.52 92.29 296.67 4,416.92 4,368.74 2,256.81 -2,678.67 6,018,312.66 566,565.84 1.14 3,381.47 2_MWD+IFR2+MS+Sag (4) 7,571.46 91.67 296.71 4,414.71 4,366.53 2,285.51 -2,735.76 6,018,340.83 566,508.49 0.97 3,445.34 2_MWD+IFR2+MS+Sag (4) 7,635.24 90.25 296.33 4,413.64 4,365.46 2,313.98 -2,792.82 6,018,368.76 566,451.17 2.30 3,509.09 2_MWD+IFR2+MS+Sag (4) 7,699.16 89.20 296.22 4,413.95 4,365.77 2,342.28 -2,850.14 6,018,396.52 566,393.60 1.65 3,572.99 2_MWD+IFR2+MS+Sag (4) 7,762.36 89.20 295.95 4,414.83 4,366.65 2,370.07 -2,906.89 6,018,423.78 566,336.60 0.43 3,636.17 2_MWD+IFR2+MS+Sag(4) 7,826.09 89.14 297.24 4,415.75 4,367.57 2,398.59 -2,963.87 6,018,451.77 566,279.36 2.03 3,699.87 2_MWD+IFR2+MS+Sag(4) 7,889.69 90.32 297.50 4,416.05 4,367.87 2,427.83 -3,020.35 6,018,480.48 566,222.62 1.90 3,763.41 2_MWD+IFR2+MS+Sag (4) 7,952.42 92.24 297.54 4,414.65 4,366.47 2,456.81 -3,075.97 6,018,508.94 566,166.74 3.06 3,826.06 2 MWD+IFR2+MS+Sag (4) 8,016.50 93.60 297.32 4,411.39 4,363.21 2,486.29 -3,132.77 6,018,537.88 566,109.67 2.15 3,890.00 2_MWD+IFR2+MS+Sag(4) 8,080.73 93.03 296.34 4,407.67 4,359.49 2,515.23 -3,189.99 6,018,566.29 566,052.19 1.76 3,954.09 2_MWD+IFR2+MS+Sag(4) 6142019 6 02:59PM Page 5 COMPASS 5000.15 Build 91 Company: Hiloorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-38 Wellbore: MPU E-38 Design: MPU E-38 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-38 MPU E-38 Actual RKB @ 48.18usft MPU E-38 Actual RKB @ 48.18usft True Minimum Curvature NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +EI -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,144.27 91.48 295.80 4,405.17 4,356.99 2,543.13 -3,247.02 6,018,593.66 565,994.91 2.58 4,017.57 2_MWD+IFR2+MS+Sag (4) 8,207.59 91.18 295.15 4,403.70 4,355.52 2,570.36 -3,304.16 6,018,620.35 565,937.52 1.13 4,080.87 2_MWD+IFR2+MS+Sag (4) 8,271.77 91.24 294.65 4,402.35 4,354.17 2,597.37 -3,362.36 6,018,646.82 565,879.07 0.78 4,145.03 2_MWD+IFR2+MS+Sag(4) 8,335.30 91.74 294.21 4,400.70 4,352.52 2,623.64 -3,420.19 6,018,672.55 565,821.02 1.05 4,208.54 2_MWD+IFR2+MS+Sag (4) 8,398.80 92.54 292.69 4,398.32 4,350.14 2,648.89 -3,478.40 6,018,697.25 565,762.58 2.70 4,271.97 2_MWD+IFR2+MS+Sag (4) 8,462.83 92.04 292.61 4,395.77 4,347.59 2,673.53 -3,537.44 6,018,721.34 565,703.31 0.79 4,335.89 2_MWD+IFR2+MS+Sag (4) 8,525.37 90.99 292.85 4,394.11 4,345.93 2,697.69 -3,595.10 6,018,744.95 565,645.43 1.72 4,398.36 2_MWD+IFR2+MS+Sag (4) 8,589.48 91.43 293.30 4,392.76 4,344.58 2,722.81 -3,654.07 6,018,769.52 565,586.24 0.98 4,462.42 2_MWD+IFR2+MS+Sag(4) 8,653.62 91.61 293.00 4,391.06 4,342.88 2,748.01 -3,713.03 6,018,794.18 565,527.06 0.55 4,526.51 2_MWD+IFR2+MS+Sag(4) 8,700.00 90.36 293.90 4,390.26 4,342.08 2,766.47 -3,755.57 6,018,812.24 565,484.35 3.32 4,572.86 2_MWD+IFR2+MS+Sag(5) 8,717.62 89.88 294.24 4,390.22 4,342.04 2,773.65 -3,771.66 6,018,819.27 565,468.20 3.34 4,590.48 2_MWD+IFR2+MS+Sag(5) 8,781.52 89.57 295.20 4,390.53 4,342.35 2,800.37 -3,829.70 6,018,845.45 565,409.92 1.58 4,654.38 2_MWD+IFR2+MS+Sag (5) 8,845.50 89.70 295.67 4,390.94 4,342.76 2,827.85 -3,887.48 6,018,872.39 565,351.89 0.76 4,718.35 2_MWD+IFR2+MS+Sag (5) 8,908.34 89.70 295.66 4,391.27 4,343.09 2,855.07 -3,944.12 6,018,899.07 565,295.01 0.02 4,781.19 2_MWD+IFR2+MS+Sag (5) 8,972.27 89.76 294.33 4,391.57 4,343.39 2,882.08 -4,002.06 6,018,925.54 565,236.82 2.08 4,845.11 2_MWD+IFR2+MS+Sag (5) 9,033.16 90.32 294.41 4,391.53 4,343.35 2,907.21 -4,057.52 6,018,950.15 565,181.13 0.93 4,906.00 2 MWD+IFR2+MS+Sag (5) 9,101.91 89.76 294.23 4,391.48 4,343.30 2,935.52 -4,120.17 6,018,977.87 565,118.23 0.86 4,974.75 2_MWD+IFR2+MS+Sag(5) 9,163.41 88.03 293.71 4,392.66 4,344.48 2,960.50 -4,176.35 6,019,002.33 565,061.82 2.94 5,036.22 2_MWD+IFR2+MS+Sag (5) 9,226.47 86.98 292.56 4,395.41 4,347.23 2,985.25 -4,234.28 6,019,026.54 565,003.67 2.47 5,099.19 2_MWD+IFR2+MS+Sag (5) 9,290.77 86.98 291.59 4,398.80 4,350.62 3,009.38 4,293.79 6,019,050.11 564,943.95 1.51 5,163.31 2_MWD+IFR2+MS+Sag (5) 9,354.47 86.79 291.55 4,402.26 4,354.08 3,032.77 4,352.94 6,019,072.94 564,884.59 0.30 5,226.81 2_MWD+IFR2+MS+Sag(5) 9,417.66 87.35 292.84 4,405.49 4,357.31 3,056.60 4,411.37 6,019,096.24 564,825.95 2.22 5,289.84 2_MWD+IFR2+MS+Sag(5) 9,481.40 87.66 293.18 4,408.26 4,360.08 3,081.50 4,469.98 6,019,120.58 564,767.11 0.72 5,353.48 2_MWD+IFR2+MS+Sag(5) 9,545.43 88.16 293.14 4,410.60 4,362.42 3,106.66 4,528.81 6,019,145.20 564,708.05 0.78 5,417.43 2_MWD+IFR2+MS+Sag(5) 9,608.94 88.40 293.25 4,412.50 4,364.32 3,131.67 -4,587.16 6,019,169.65 564,649.48 0.42 5,480.88 2_MWD+IFR2+MS+Sag(5) 9,672.26 88.52 292.75 4,414.21 4,366.03 3,156.40 4,645.43 6,019,193.84 564,590.99 0.81 5,544.14 2_MWD+IFR2+MS+Sag(5) 9,735.93 89.45 293.07 4,415.33 4,367.15 3,181.18 3,704.07 6,019,218.07 564,532.13 1.54 5,607.76 2_MWD+IFR2+MS+Sag(5) 9,801.04 90.01 292.98 4,415.64 4,367.46 3,206.65 -4,763.99 6,019,242.98 564,471.98 0.87 5,672.83 2_MWD+IFR2+MS+Sag (5) 9,664.39 91.06 293.22 4,415.05 4,366.87 3,231.50 3,822.25 6,019,267.29 564,413.49 1.70 5,736.14 2_MWD+IFR2+MS+Sag(5) 9,928.42 91.06 293.22 4,413.86 4,365.68 3,256.74 3,881.09 6,019,291.98 564,354.43 0.00 5,800.13 2_MWD+IFR2+MS+Sag (5) 9,991.90 92.05 293.92 4,412.14 4,363.96 3,282.11 3,939.25 6,019,316.81 564,296.04 1.91 5,863.56 2 MWD+IFR2+MS+Sag(5) 10,055.56 92.04 294.30 4,409.87 4,361.69 3,308.10 -4,997.32 6,019,342.25 564,237.74 0.60 5,927.17 2_MWD+IFR2+MS+Sag(5) 10,119.65 90.62 294.49 4,408.38 4,360.20 3,334.56 -5,055.67 6,019,368.17 564,179.15 2.24 5,991.24 2 MWD+IFR2+MS+Sag(5) 10,183.28 89.94 293.96 4,408.07 4,359.89 3,360.67 -5,113.70 6,019,393.73 564,120.89 1.35 6,054.86 2_MWD+IFR2+MS+Sag(5) 10,247.22 90.19 293.58 4,408.00 4,359.82 3,386.44 -5,172.21 6,019,418.96 564,062.14 0.71 6,118.79 2_MWD+IFR2+MS+Sag (5) 10,309.72 90.25 293.15 4,407.76 4,359.58 3,411.23 -5,229.59 6,019,443.21 564,004.55 0.69 6,181.26 2_MWD+IFR2+MS+Sag(5) 10,373.68 90.25 292.69 4,407.48 4,359.30 3,436.14 -5,288.49 6,019,467.56 563,945.41 0.72 6,245.18 2 MWD+IFR2+MS+Sag (5) 10,436.86 90.07 292.31 4,407.30 4,359.12 3,460.32 -5,346.87 6,019,491.20 563,886.83 0.67 6,308.30 2_MWD+IFR2+MS+Sag (5) 10,501.16 91.55 292.52 4,406.39 4,358.21 3,484.83 -5,406.30 6,019,515.16 563,827.17 2.32 6,372.52 2_MWD+IFR2+MS+Sag (5) 10,564.95 92.79 293.81 4,403.98 4,355.80 3,509.91 5,464.90 6,019,539.68 563,768.34 2.80 6,436.23 2_MWD+IFR2+MS+Sag(5) 6742019 6: 02: 59PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-38 Project: Milne Point TVD Reference: MPU E-38 Actual IRKS @ 48.1 Busft Site: M Pt E Pad MD Reference: MPU E-38 Actual RKB @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38 Survey Calculation Method: Minimum Curvature Design: MPU E-38 Database: NORTH US+CANADA Survey Map Map MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') 10,628.51 93.03 294.13 4,400.75 4,352.57 3,535.69 -5,522.91 6,019,564.93 563,710.11 0.63 10,692.31 91.11 294.44 4,398.45 4,350.27 3,561.92 -5,581.02 6,019,590.61 563,651.76 3.05 10,755.61 90.68 294.11 4,397.46 4,349.28 3,587.94 -5,638.72 6,019,616.09 563,593.83 0.86 10,819.17 90.62 294.28 4,396.74 4,348.56 3,613.98 -5,696.69 6,019,641.59 563,535.62 0.28 10,882.90 90.44 294.04 4,396.15 4,347.97 3,640.07 -5,754.83 6,019,667.13 563,477.24 0.47 10,946.42 90.38 293.31 4,395.69 4,347.51 3,665.57 -5,813.01 6,019,692.09 563,418.84 1.15 11,010.37 89.82 292.34 4,395.58 4,347.40 3,690.38 -5,871.95 6,019,716.35 563,359.68 1.75 11,074.26 90.01 292.16 4,395.68 4,347.50 3,714.57 -5,931.08 6,019,739.99 563,300.33 0.41 11,137.59 88.83 291.27 4,396.32 4,348.14 3,738.00 5,989.91 6,019,762.87 563,241.29 2.33 11,201.26 89.14 291.48 4,397.45 4,349.27 3,761.20 -6,049.19 6,019,785.51 563,181.80 0.59 11,264.86 89.64 292.76 4,398.12 4,349.94 3,785.15 -6,108.11 6,019,808.91 563,122.67 2.16 11,326.06 89.64 293.08 4,398.51 4,350.33 3,808.98 -6,164.47 6,019,832.21 563,066.09 0.52 11,389.61 91.00 295.37 4,398.15 4,349.97 3,835.06 -6,222.42 6,019,857.75 563,007.91 4.19 11,455.15 91.99 296.14 4,396.44 4,348.26 3,863.52 -6,281.43 6,019,885.66 562,948.64 1.91 11,518.91 91.86 294.86 4,394.30 4,346.12 3,890.96 -6,338.94 6,019,912.56 562,890.88 2.02 11,582.88 91.80 295.20 4,392.26 4,344.08 3,918.01 -6,396.88 6,019,939.07 562,832.70 0.54 11,646.68 91.05 294.22 4,390.67 4,342.49 3,944.67 -6,454.82 6,019,965.18 562,774.53 1.93 11,709.99 90.31 293.27 4,389.92 4,341.74 3,970.16 -6,512.76 6,019,990.13 562,716.35 1.90 11,774.19 89.20 293.35 4,390.20 4,342.02 3,995.56 -6,571.72 6,020,014.98 562,657.16 1.73 11,837.69 88.15 293.93 4,391.66 4,343.48 4,021.02 -6,629.87 6,020,039.90 562,598.78 1.89 11,900.74 87.97 294.21 4,393.60 4,345.62 4,046.72 -6,687.41 6,020,065.06 562,541.02 0.53 11,964.93 88.28 294.33 4,395.90 4,347.72 4,073.09 -6,745.89 6,020,090.88 562,482.29 0.52 12,028.91 88.77 294.26 4,397.55 4,349.37 4,099.41 -6,804.19 6,020,116.65 562,423.76 0.77 12,092.21 89.39 294.99 4,398.56 4,350.38 4,125.78 -6,861.72 6,020,142.48 562,365.99 1.51 12,154.64 88.96 295.18 4,399.46 4,351.28 4,152.24 -6,918.26 6,020,168.42 562,309.22 0.75 12,219.76 90.69 295.54 4,399.66 4,351.48 4,180.13 -6,977.10 6,020,195.76 562,250.12 2.71 12,283.58 91.86 297.27 4,398.24 4,350.06 4,208.51 -7,034.25 6,020,223.60 562,192.72 3.27 12,347.37 90.56 296.73 4,396.89 4,348.71 4,237.46 -7,091.07 6,020,252.02 562,135.64 2.21 12,411.27 90.44 296.66 4,396.33 4,348.15 4,266.16 -7,148.16 6,020,280.19 562,078.29 0.22 12,475.08 90.31 296.46 4,395.92 4,347.74 4,294.69 -7,205.23 6,020,308.18 562,020.96 0.37 12,538.20 90.63 296.23 4,395.40 4,347.22 4,322.70 -7,261.79 6,020,335.67 561,964.15 0.62 12,601.46 89.76 296.41 4,395.18 4,347.00 4,350.75 -7,318.49 6,020,363.18 561,907.19 1.40 12,666.33 90.44 297.19 4,395.07 4,346.89 4,380.00 -7,376.39 6,020,391.89 561,849.03 1.60 12,730.41 89.51 298.30 4,395.10 4,346.92 4,409.83 -7,433.11 6,020,421.19 561,792.05 2.26 12,793.35 89.39 297.75 4,395.70 4,347.52 4,439.40 -7,488.66 6,020,450.24 561,736.22 0.89 12,856.93 89.64 296.75 4,396.24 4,348.06 4,468.51 -7,545.18 6,020,478.82 561,679.44 1.62 12,921.30 89.20 294.62 4,396.89 4,348.71 4,496.41 -7,603.19 6,020,506.17 561,621.18 3.38 12,984.99 91.06 293.93 4,396.75 4,348.57 4,522.59 -7,661.24 6,020,531.81 561,562.89 3.11 13,048.75 92.67 293.68 4,394.67 4,346.49 4,548.31 -7,719.55 6,020,556.99 561,504.36 2.56 13,112.10 92.79 293.64 4,391.66 4,343.48 4,573.71 -7,777.50 6,020,581.84 561,446.17 0.20 Vertical Section (ft) Survey Tool Name 6,499.70 2_MWD+IFR2+MS+Sag(5) 6,563.45 2_MWD+IFR2+MS+Sag (5) 6,626.74 2_MWD+IFR2+MS+Sag (5) 6,69029 2_MWD+IFR2+MS+Sag (5) 6,754.01 2 MWD+IFR2+MS+Sag (5) 6,817.51 2_MWD+IFR2+MS+Sag (5) 6,881.41 2_MWD+IFR2+MS+Sag (5) 6,945.23 2_MWD+IFR2+MS+Sag(5) 7,008.45 2_MWD+IFR2+MS+Sag (5) 7,071.98 2_MWD+IFR2+MS+Sag (5) 7,135.50 2_MWD+IFR2+MS+Sag(5) 7,196.66 2_MWD+IFR2+MS+Sag(5) 7,260.19 2_MWD+IFR2+MS+Sag (5) 7,325.70 2_MWD+IFR2+MS+Sag (5) 7,389.42 2_MWD+IFR2+MS+Sag(5) 7,453.36 2_MWD+IFR2+MS+Sag (5) 7,517.14 2_MWD+IFR2+MS+Sag (5) 7,580.43 2_MWD+IFR2+MS+Sag (5) 7,644.60 2_MWD+IFR2+MS+Sag(5) 7,708.06 2_MWD+IFR2+MS+Sag(5) 7,771.07 2_MWD+IFR2+MS+Sag(5) 7,835.22 2_MWD+IFR2+MS+Sag(5) 7,899.17 2_MWD+IFR2+MS+Sag (5) 7,962.46 2_MWD+IFR2+MS+Sag (5) 8,024.89 2_MWD+IFR2+MS+Sag(5) 8,090.00 2_MWD+IFR2+MS+Sag(5) 8,153.78 2_MWD+IFR2+MS+Sag(5) 8,217.52 2_MWD+IFR2+MS+Sag(5) 8,281.39 2_MWD+IFR2+MS+Sag(5) 8,345.17 2_MWD+IFR2+MS+Sag(5) 8,408.27 2_MWD+IFR2+MS+Sag(5) 8,471.52 2_MWD+IFR2+MS+Sag(5) 8,536.35 2 MWD+IFR2+MS+Sag (5) 8,600.36 2_MWD+IFR2+MS+Sag (5) 8,663.21 2_MWD+IFR2+MS+Sag (5) 8,726.73 2_MWD+IFR2+MS+Sag (5) 8,791.09 2_MWD+IFR2+MS+Sag(5) 8,854.77 2_MWD+IFR2+MS+Sag(5) 8,918.48 2_MWD+IFR2+MS+Sag(5) 8,981.74 2_MWD+IFR2+MS+Sag(5) 61142019 6:02:59PM Page 7 COMPASS 5000.15 Build 91 Survey Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) 13,176.25 92.85 293.06 4,388.50 4,340.32 4,599.10 -7,836.33 6,020,606.68 13,239.96 92.29 293.40 4,385.64 4,337.46 4,624.20 -7,894.81 6,020,631.24 13,303.47 91.05 292.49 4,383.79 4,335.61 4,648.95 -7,953.27 6,020,655.44 13,367.04 91.80 292.32 4,382.21 4,334.03 4,673.17 -8,012.03 6,020,679.11 13,430.90 92.23 292.43 4,379.97 4,331.79 4,697.47 -8,071.04 6,020,702.86 13,494.37 92.29 293.38 4,377.46 4,329.28 4,722.15 -8,129.46 6,020,726.99 13,558.23 91.98 293.84 4,375.08 4,326.90 4,747.71 -8,187.93 6,020,752.00 13,622.12 91.73 293.32 4,373.02 4,324.84 4,773.26 -8,246.46 6,020,777.00 13,685.78 90.62 294.30 4,371.71 4,323.53 4,798.95 -8,304.69 6,020,802.15 13,749.88 90.69 294.96 4,370.98 4,322.80 4,825.66 -8,362.95 6,020,828.32 13,813.68 90.07 295.58 4,370.55 4,322.37 4,852.90 -8,420.64 6,020,855.01 13,877.30 90.38 296.27 4,370.30 4,322.12 4,880.71 -8,477.86 6,020,882.29 13,940.68 90.62 295.68 4,369.75 4,321.57 4,908.47 -8,534.84 6,020,909.51 14,004.28 90.75 297.09 4,368.99 4,320.81 4,936.73 -8,591.80 6,020,937.24 14,068.50 90.69 296.22 4,368.18 4,320.00 4,965.54 -8,649.19 6,020,965.51 14,132.11 90.69 296.07 4,367.42 4,319.24 4,993.56 -8,706.29 6,020,993.00 14,195.63 89.32 295.88 4,367.41 4,319.23 5,021.38 -8,763.39 6,021,020.29 14,258.87 88.52 296.08 4.368.60 4,320.42 5,049.08 -8,820.23 6,021,047.45 14,321.87 88.71 296.66 4,370.13 4,321.95 5,077.06 -8,876.66 6,021,074.90 14,385.20 88.65 296.66 4,371.59 4,323.41 5,105.46 -8,933.24 6,021,102.78 14.450.36 88.71 297.20 4,373.09 4,324.91 5,134.97 -8,991.32 6,021,131.74 14,513.72 88.52 296.87 4,374.62 4,326.44 5,163.76 -9,047.74 6,021,160.00 14,577.80 89.51 296.40 4,375.72 4,327.54 5,192.48 -9,105.01 6,021,188.19 14,641.60 90.38 295.16 4,375.78 4,327.60 5,220.23 -9,162.46 6,021,215.40 14,704.80 91.31 295.05 4,374.85 4,326.67 5,247.04 -9,219.68 6,021,241.67 14,768.46 90.99 294.90 4,373.57 4,325.39 5,273.91 -9,277.38 6,021,268.00 14,832.28 91.05 294.75 4,372.44 4,324.26 5,300.70 -9,335.29 6,021,294.25 14,895.35 90.81 294.39 4,371.41 4,323.23 5,326.92 -9,392.64 6,021,319.94 14,958.95 89.63 291.24 4,371.17 4,322.99 5,351.58 -9,451.26 6,021,344.05 15,023.28 90.13 290.62 4,371.30 4,323.12 5,374.56 -9,511.34 6,021,366.47 15,086.55 90.44 291.48 4,370.99 4,322.81 5,397.29 -9,570.39 6,021,388.64 15,150.31 90.26 292.32 4,370.60 4,322.42 5,421.07 -9,629.55 6,021,411.87 15,214.28 87.16 292.42 4,372.04 4,323.86 5,445.40 -9,688.68 6,021,435.65 15,278.31 83.50 291.71 4,377.25 4,329.07 5,469.37 -9,747.81 6,021.459.07 15,341.49 80.39 291.14 4,386.10 4,337.92 5,492.22 -9,806.04 6,021,481.37 15,404.78 77.49 291.45 4,398.24 4,350.06 5,514.78 -9,863.91 6,021,503.39 15,469.26 74.10 291.58 4,414.06 4,365.88 5,537.70 -9,922.05 6,021,525.76 15,501.20 72.55 291.34 4,423.23 4,375.05 5,548.89 -9,950.53 6,021,536.69 15,570.00 72.55 291.34 4,443.86 4,395.68 5,572.78 -10,011.66 6,021,560.00 Map Vertical Easting DLS Section (ft) (°1100') (ft) Survey Tool Name 561,387.12 0.91 9,045.79 2_MWD+IFR2+MS+Sag(5) 561,328.41 1.03 9,109.41 2_MWD+IFR2+MS+Sag (5) 561,269.73 2.42 9,172.85 2_MWD+IFR2+MS+Sag (5) 561,210.76 1.21 9,236.33 2 MWD+IFR2+MS+Sag (5) 561,151.52 0.70 9,300.08 2_MWD+IFR2+MS+Sag(5) 561,092.88 1.50 9,363.46 2_MWD+IFR2+MS+Sag(5) 561,034.18 0.87 9,427.26 2_MWD+IFR2+MS+Sag(5) 560,975.43 0.90 9,491.09 2_MWD+IFR2+MS+Sag(5) 560,916.97 2.33 9,554.73 2 MWD+IFR2+MS+Sag (5) 560,858.46 1.04 9,618.82 2_MWD+IFR2+MS+Sag(5) 560,800.53 1.37 9,682.62 2_MWD+IFR2+MS+Sag(5) 560,743.06 1.19 9,746.23 2_MWD+IFR2+MS+Sag (5) 560,685.83 1.00 9,809.60 2_MWD+IFR2+MS+Sag(5) 560,628.61 2.23 9,873.17 2_MWD _lnterp Azi+Sag(6) 560,570.96 1.36 9,937.36 2_MWD+IFR2+MS+Sag (7) 560,513.61 0.24 10,000.95 2_MWD+IFR2+MS+Sag (7) 560,456.26 2.18 10,064.46 2_MWD+IFR2+MS+Sag(7) 560,399.17 1.30 10,127.68 2_MWD+IFR2+MS+Sag(7) 560,342.49 0.97 10,190.64 2_MWD+IFR2+MS+Sag (7) 560,285.65 0.09 10,253.93 2_MWD+IFR2+MS+Sag (7) 560,227.30 0.83 10,319.04 2_MWD+IFR2+MS+Sag (7) 560,170.62 0.60 10,382.34 2_MWD+IFR2+MS+Sag (7) 560,113.09 1.71 10,446.38 2_MWD+IFR2+MS+Sag (7) 560,055.40 2.37 10,510.17 2_MWD+IFR2+MS+Sag (7) 559,997.93 1.48 10,573.36 2_MWD+IFR2+MS+Sag (7) 559,939.99 0.56 10,637.01 2_MWD+IFR2+MS+Sag (7) 559,881.84 0.25 10,700.82 2_MWD+IFR2+MS+Sag (7) 559,824.25 0.69 10,763.88 2 MWD+IFR2+MS+Sag(7) 559,765.42 5.29 10,827.43 2_MWD+IFR2+MS+Sag(7) 559,705.13 1.24 10,891.59 2_MWD+IFR2+MS+Sag(7) 559,645.88 1.44 10,954.71 2_MWD+IFR2+MS+Sag (7) 559,586.51 1.35 11,018.38 2_MWD+IFR2+MS+Sag (7) 559,527.15 4.85 11,082.25 2_MWD+IFR2+MS+Sag (7) 559,467.81 5.82 11,145.98 2_MWD+IFR2+MS+Sag (7) 559,409.38 5.00 11,208.40 2_MWD+IFR2+MS+Sag (7) 559,351.31 4.61 11,270.38 2_MWD+IFR2+MS+Sag (7) 559,292.96 5.26 11,332.77 2_MWD+IFR2+MS+Sag(7) 559,264.38 4.91 11,363.30 2_MWD+IFR2+MS+Sag(7) 559,203.04 0.00 11,428.80 PROJECTED to To 6/4/2019 6:02:59PM Page 8 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-38 Project: Milne Point TVD Reference: MPU E-38 Actual RKB @ 48.18usft Site: M Pt E Pad MD Reference: MPU E-38 Actual RKB @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38 Survey Calculation Method: Minimum Curvature Design: MPU E-38 Database: NORTH US+CANADA Survey Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) 13,176.25 92.85 293.06 4,388.50 4,340.32 4,599.10 -7,836.33 6,020,606.68 13,239.96 92.29 293.40 4,385.64 4,337.46 4,624.20 -7,894.81 6,020,631.24 13,303.47 91.05 292.49 4,383.79 4,335.61 4,648.95 -7,953.27 6,020,655.44 13,367.04 91.80 292.32 4,382.21 4,334.03 4,673.17 -8,012.03 6,020,679.11 13,430.90 92.23 292.43 4,379.97 4,331.79 4,697.47 -8,071.04 6,020,702.86 13,494.37 92.29 293.38 4,377.46 4,329.28 4,722.15 -8,129.46 6,020,726.99 13,558.23 91.98 293.84 4,375.08 4,326.90 4,747.71 -8,187.93 6,020,752.00 13,622.12 91.73 293.32 4,373.02 4,324.84 4,773.26 -8,246.46 6,020,777.00 13,685.78 90.62 294.30 4,371.71 4,323.53 4,798.95 -8,304.69 6,020,802.15 13,749.88 90.69 294.96 4,370.98 4,322.80 4,825.66 -8,362.95 6,020,828.32 13,813.68 90.07 295.58 4,370.55 4,322.37 4,852.90 -8,420.64 6,020,855.01 13,877.30 90.38 296.27 4,370.30 4,322.12 4,880.71 -8,477.86 6,020,882.29 13,940.68 90.62 295.68 4,369.75 4,321.57 4,908.47 -8,534.84 6,020,909.51 14,004.28 90.75 297.09 4,368.99 4,320.81 4,936.73 -8,591.80 6,020,937.24 14,068.50 90.69 296.22 4,368.18 4,320.00 4,965.54 -8,649.19 6,020,965.51 14,132.11 90.69 296.07 4,367.42 4,319.24 4,993.56 -8,706.29 6,020,993.00 14,195.63 89.32 295.88 4,367.41 4,319.23 5,021.38 -8,763.39 6,021,020.29 14,258.87 88.52 296.08 4.368.60 4,320.42 5,049.08 -8,820.23 6,021,047.45 14,321.87 88.71 296.66 4,370.13 4,321.95 5,077.06 -8,876.66 6,021,074.90 14,385.20 88.65 296.66 4,371.59 4,323.41 5,105.46 -8,933.24 6,021,102.78 14.450.36 88.71 297.20 4,373.09 4,324.91 5,134.97 -8,991.32 6,021,131.74 14,513.72 88.52 296.87 4,374.62 4,326.44 5,163.76 -9,047.74 6,021,160.00 14,577.80 89.51 296.40 4,375.72 4,327.54 5,192.48 -9,105.01 6,021,188.19 14,641.60 90.38 295.16 4,375.78 4,327.60 5,220.23 -9,162.46 6,021,215.40 14,704.80 91.31 295.05 4,374.85 4,326.67 5,247.04 -9,219.68 6,021,241.67 14,768.46 90.99 294.90 4,373.57 4,325.39 5,273.91 -9,277.38 6,021,268.00 14,832.28 91.05 294.75 4,372.44 4,324.26 5,300.70 -9,335.29 6,021,294.25 14,895.35 90.81 294.39 4,371.41 4,323.23 5,326.92 -9,392.64 6,021,319.94 14,958.95 89.63 291.24 4,371.17 4,322.99 5,351.58 -9,451.26 6,021,344.05 15,023.28 90.13 290.62 4,371.30 4,323.12 5,374.56 -9,511.34 6,021,366.47 15,086.55 90.44 291.48 4,370.99 4,322.81 5,397.29 -9,570.39 6,021,388.64 15,150.31 90.26 292.32 4,370.60 4,322.42 5,421.07 -9,629.55 6,021,411.87 15,214.28 87.16 292.42 4,372.04 4,323.86 5,445.40 -9,688.68 6,021,435.65 15,278.31 83.50 291.71 4,377.25 4,329.07 5,469.37 -9,747.81 6,021.459.07 15,341.49 80.39 291.14 4,386.10 4,337.92 5,492.22 -9,806.04 6,021,481.37 15,404.78 77.49 291.45 4,398.24 4,350.06 5,514.78 -9,863.91 6,021,503.39 15,469.26 74.10 291.58 4,414.06 4,365.88 5,537.70 -9,922.05 6,021,525.76 15,501.20 72.55 291.34 4,423.23 4,375.05 5,548.89 -9,950.53 6,021,536.69 15,570.00 72.55 291.34 4,443.86 4,395.68 5,572.78 -10,011.66 6,021,560.00 Map Vertical Easting DLS Section (ft) (°1100') (ft) Survey Tool Name 561,387.12 0.91 9,045.79 2_MWD+IFR2+MS+Sag(5) 561,328.41 1.03 9,109.41 2_MWD+IFR2+MS+Sag (5) 561,269.73 2.42 9,172.85 2_MWD+IFR2+MS+Sag (5) 561,210.76 1.21 9,236.33 2 MWD+IFR2+MS+Sag (5) 561,151.52 0.70 9,300.08 2_MWD+IFR2+MS+Sag(5) 561,092.88 1.50 9,363.46 2_MWD+IFR2+MS+Sag(5) 561,034.18 0.87 9,427.26 2_MWD+IFR2+MS+Sag(5) 560,975.43 0.90 9,491.09 2_MWD+IFR2+MS+Sag(5) 560,916.97 2.33 9,554.73 2 MWD+IFR2+MS+Sag (5) 560,858.46 1.04 9,618.82 2_MWD+IFR2+MS+Sag(5) 560,800.53 1.37 9,682.62 2_MWD+IFR2+MS+Sag(5) 560,743.06 1.19 9,746.23 2_MWD+IFR2+MS+Sag (5) 560,685.83 1.00 9,809.60 2_MWD+IFR2+MS+Sag(5) 560,628.61 2.23 9,873.17 2_MWD _lnterp Azi+Sag(6) 560,570.96 1.36 9,937.36 2_MWD+IFR2+MS+Sag (7) 560,513.61 0.24 10,000.95 2_MWD+IFR2+MS+Sag (7) 560,456.26 2.18 10,064.46 2_MWD+IFR2+MS+Sag(7) 560,399.17 1.30 10,127.68 2_MWD+IFR2+MS+Sag(7) 560,342.49 0.97 10,190.64 2_MWD+IFR2+MS+Sag (7) 560,285.65 0.09 10,253.93 2_MWD+IFR2+MS+Sag (7) 560,227.30 0.83 10,319.04 2_MWD+IFR2+MS+Sag (7) 560,170.62 0.60 10,382.34 2_MWD+IFR2+MS+Sag (7) 560,113.09 1.71 10,446.38 2_MWD+IFR2+MS+Sag (7) 560,055.40 2.37 10,510.17 2_MWD+IFR2+MS+Sag (7) 559,997.93 1.48 10,573.36 2_MWD+IFR2+MS+Sag (7) 559,939.99 0.56 10,637.01 2_MWD+IFR2+MS+Sag (7) 559,881.84 0.25 10,700.82 2_MWD+IFR2+MS+Sag (7) 559,824.25 0.69 10,763.88 2 MWD+IFR2+MS+Sag(7) 559,765.42 5.29 10,827.43 2_MWD+IFR2+MS+Sag(7) 559,705.13 1.24 10,891.59 2_MWD+IFR2+MS+Sag(7) 559,645.88 1.44 10,954.71 2_MWD+IFR2+MS+Sag (7) 559,586.51 1.35 11,018.38 2_MWD+IFR2+MS+Sag (7) 559,527.15 4.85 11,082.25 2_MWD+IFR2+MS+Sag (7) 559,467.81 5.82 11,145.98 2_MWD+IFR2+MS+Sag (7) 559,409.38 5.00 11,208.40 2_MWD+IFR2+MS+Sag (7) 559,351.31 4.61 11,270.38 2_MWD+IFR2+MS+Sag (7) 559,292.96 5.26 11,332.77 2_MWD+IFR2+MS+Sag(7) 559,264.38 4.91 11,363.30 2_MWD+IFR2+MS+Sag(7) 559,203.04 0.00 11,428.80 PROJECTED to To 6/4/2019 6:02:59PM Page 8 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-38 Wellbore: MPU E-38 Design: MPU E-38 Halliburton Definitive Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-38 MPU E-38 Actual RKB @ 48.18usft MPU E-38 Actual RKB @ 48.18usft True Minimum Curvature NORTH US + CANADA Checked By: Chelsea Wright „ate ._ Approved By: Mitch Laird - Date: 06-04-2019 6/4/2019 6:0259PM Page 9 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-38PB1 500292362970 Sperry Drilling Definitive Survey Report 04 June, 2019 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-38 Project: Milne Point TVD Reference: MPU E-38 Actual RKB @ 48.18usft Site: M Pt E Pad MD Reference: MPU E-38 Actual IRKS @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-38PB7 Database: NORTH US+CANADA Iroject Milne Point, ACT, MILNE POINT dap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point dap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU E-38 Well Position +N/ -S +E/ -W Position Uncertainty 0.00 usft Northing: 0.00 usft Easting: 0.00 usft Wellhead Elevation: 6,016,081.06 usfl 569,265.12 usfl 0.00 usfl Latitude: Longitude: Ground Level: 70° 27' 15.4464 N 149° 26'5.1882 W 21.80 usft Wellbore MPU E-38PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2018 9/17/2018 17.06 80.98 57,454.56347142 Design MPU E-38PB1 Vertical MD Inc Azi TVD Audit Notes: +N/S +E/ -W Northing Easting DLS Section Version: 1.0 Phase: ACTUAL Tie On Depth: 26.38 (usfl) Vertical Section: (ft) Depth From (TVD) +N/ -S +E/ -W Direction 0.00 0.00 26.38 (usfl) (usft) (usfl) V) 569,265.12 0.00 0.00 UNDEFINED 26.38 0.00 0.00 295.00 51.82 Survey Program Date 6/4/2019 From To (usfl) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 415.00 MPU E-38PB1 SDI Gyro (MPU E-38PB1 2_Gyro-NS-GC_Drill cull: H029Ga: North seeking single shot in drill colla 05/08/2019 484.73 5,728.83 MPU E-38PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/17/2019 5,791.41 7,063.99 MPU E-38PB7 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/26/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usfl) (1 0 (usfl) (usft) (usfl) (usfl) (ft) (ft) (1/100') (ft) Survey Tool Name 26.38 0.00 0.00 26.38 -21.80 0.00 0.00 6,016,081.06 569,265.12 0.00 0.00 UNDEFINED 100.00 0.40 265.25 100.00 51.82 -0.02 -0.26 6,016,081.04 569,264.86 0.54 0.22 2_Gyro-NS-GC_Drill collar (1 166.00 0.48 274.71 166.00 117.82 -0.02 -0.76 6,016,081.04 569,264.36 0.16 0.68 2_Gyro-NS-GC_Drill collar (1 228.00 0.52 282.53 228.00 179.82 0.06 -1.29 6,016,081.11 569,263.82 0.13 1.20 2_Gyro-NS-GC_Drill collar (1 290.00 0.83 346.13 289.99 241.81 0.56 -1.68 6,016,081.61 569,263.44 1.22 1.76 2_Gyro-NS-GC_Drill collar (11 352.00 2.70 13.26 351.96 303.78 2.42 -1.45 6,016,083.47 569,263.65 3.22 2.34 2_Gyro-NS-GC_Drill collar (1 415.00 4.31 19.46 414.84 366.66 6.10 -0.32 6,016,087.15 569,264.74 2.62 2.87 2_Gyr0-NS-GC_Dnll collar (1 484.73 7.41 33.76 484.20 436.02 12.31 3.05 6,016,093.39 569,268.06 4.88 2.43 2_MWD+IFR2+MS+Sag(2) 546.64 9.25 41.00 545.46 497.28 19.38 8.54 6,016,100.52 569,273.47 3.42 0.46 2_MWD+IFR2+MS+Sag(2) 609.18 11.00 51.54 607.03 558.85 26.89 16.51 6,016,108.10 569,281.37 4.06 -3.60 2_MWD+IFR2+MS+Sag 12) 671.65 12.92 55.89 668.14 619.96 34.51 26.96 6,016,115.82 569,291.75 3.39 -9.85 2_MWD+IFR2+MS+Sag(2) 736.05 13.98 54.86 730.77 682.59 43.03 39.28 6,016,124.45 569,303.99 1.69 -17.42 2_MWD+IFR2+MS+Sag (2) 6142019 6:00:31PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-38 Wellbore: MPU E-38PB1 Design: MPU E-38PB1 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) 0 (1 (usft) (usft) (usft) 799.21 16.76 55.19 791.67 743.49 52.62 863.21 20.15 55.13 852.37 804.19 64.19 899.52 20.42 53.97 886.42 838.24 71.49 926.70 19.68 53.76 990.18 17.77 53.81 1,053.16 17.81 54.52 1,117.77 17.54 54.62 1,180.55 18.59 50.91 1,245.59 18.94 50.29 1,307.78 17.70 51.13 1,372.53 17.88 47.93 1,436.75 17.66 46.76 1,498.90 17.76 46.38 1,563.71 16.50 42.63 1,625.75 14.33 36.92 1,689.74 13.22 34.70 1,753.71 13.17 33.23 1,817.71 12.57 32.69 1,881.46 12.84 1,945.97 13.20 2,008.81 13.13 2,073.58 13.20 2,136.37 13.69 2,201.32 13.89 2,264.17 13.49 2,327.69 13.44 2,392.22 13.87 2,456.05 14.35 2,519.70 14.64 2,583.46 14.39 2,647.49 14.17 2,710.38 14.15 2,774.32 13.50 2,837.62 13.44 2,901.77 13.08 2,965.54 13.56 3,028.74 13.95 3,092.66 14.01 3,156.19 14.38 3,220.01 14.01 32.77 33.05 33.34 34.75 32.90 911.96 972.07 1,032.04 1,093.60 1,153.29 1,214.87 1,273.91 1,335.56 1,396.72 1,455.92 1,517.86 1,577.67 1,639.82 1,702.10 1,764.49 1,826.68 1,889.53 1,950.72 2,013.79 2,074.86 863.78 923.89 983.86 1,045.42 1,105.11 1,166.69 1,225.73 1,287.38 1,348.54 1,407.74 1,469.68 1,529.49 1,591.64 1,653.92 1,716.31 1,778.50 1,841.35 1,902.54 1,965.61 2,026.68 76.99 89.03 100.29 111.66 123.45 136.73 149.11 161.95 175.23 188.23 201.82 214.44 226.79 238.90 250.86 262.65 274.85 286.83 299.05 311.18 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +E/ -W Northing (usft) (ft) 53.00 6,016,134.16 69.62 6,016,145.89 79.88 6,016,153.29 87.40 6,016,158.85 103.84 6,016,171.04 119.44 6,016,182.45 135.43 6,016,193.97 150.91 6,016,205.90 167.08 6,016,219.33 182.20 6,016,231.85 197.24 6,016,244.82 211.66 6,016,258.23 225.39 6,016,271.36 238.78 6,016,285.07 249.36 6,016,297.79 258.28 6,016,310.22 266.44 6,016,322.40 274.19 6,016,334.43 281.78 6,016,346.30 289.67 6,016,358.57 297.51 6,016,370.62 305.77 6,016,382.91 313.89 6,016,395.12 33.46 2,137.93 2,089.75 324.14 322.36 6,016,408.15 30.83 2,199.00 2,150.82 336.73 330.28 6,016,420.81 30.86 2,260.77 2,212.59 349.43 337.86 6,016,433.58 30.54 2,323.48 2,275.30 362.53 345.64 6,016,446.75 30.62 2,385.38 2,337.20 375.92 353.56 6,016,460.22 33.88 2,447.01 2,398.83 389.39 362.06 6,016,473.76 32.30 2,508.73 2,460.55 402.77 370.78 6,016,487.23 32.84 2,570.79 2,522.61 416.08 379.28 6,016,500.61 33.67 2,631.76 2,583.58 428.95 387.72 6,016,513.55 31.31 2,693.85 2,645.67 441.83 395.93 6,016,526.51 32.08 2,755.41 2,707.23 454.38 403.68 6,016,539.13 32.68 2,817.85. 2,769.67 466.80 411.56 6,016,551.62 33.24 2,879.90 2,831.72 479.13 419.55 6,016,564.02 33.59 2,941.29 2,893.11 491.67 427.83 6,016,576.64 26.44 3,003.32 2,955.14 505.02 435.54 6,016,590.06 17.14 3,064.92 3,016.74 519.45 441.29 6,016,604.54 14.17 3,126.79 3,078.61 534.51 445.51 6,016,619.64 Well MPU E-38 MPU E-38 Actual RKB @ 48.18usft MPU E-38 Actual RKB @ 48.18usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (o/too-) (ft) Survey Tool Name 569,317.62 4.40 -25.80 2_MWD+IFR2+MS+Sag (2) 569,334.14 5.30 -35.97 2_MWD+IFR2+MS+Sag (2) 569,344.32 1.33 -42.18 2_MWD+IFR2+MS+Sag(2) 569,351.80 2.74 -46.68 2_MWD+IFR2+MS+Sag(2) 569,368.12 3.01 -56.49 2_MWD+IFR2+MS+Sag(2) 569,383.61 0.35 -65.87 2_MWD+IFR2+MS+Sag(2) 569,399.49 0.42 -75.55 2_MWD+IFR2+MS+Sag (2) 569,414.86 2.48 -84.60 2_MWD+IFR2+MS+Sag (2) 569,430.90 0.62 -93.64 2_MWD+IFR2+MS+Sag (2) 569,445.91 2.04 -102.11 2_MWD+IFR2+MS+Sag(2) 569,460.83 1.54 -110.32 2_MWD+IFR2+MS+Sag(2) 569,475.12 0.65 -117.77 2_MWD+IFR2+MS+Sag(2) 569,488.73 0.25 -124.72 2_MWD+IFR2+MS+Sag (2) 569,501.99 2.58 -131.11 2_MWD+IFR2+MS+Sag (2) 569,512.45 4.26 -135.37 2_MWD+IFR2+MS+Sag (2) 569,521.26 1.92 -138.24 2_MWD+IFR2+MS+Sag (2) 569,529.30 0.53 -140.51 2_MWD+IFR2+MS+Sag(2) 569,536.95 0.96 -142.49 2_MWD+IFR2+MS+Sag(2) 569,544.42 0.42 -144.37 2_MWD+IFR2+MS+Sag (2) 569,552.20 0.57 -146.37 2_MWD+IFR2+MS+Sag (2) 569,559.92 0.15 -148.41 2_MWD+IFR2+MS+Sag (2) 569,568.06 0.51 -150.73 2_MWD+IFR2+MS+Sag(2) 569,576.07 1.04 -152.97 2_MWD+IFR2+MS+Sag(2) 569,584.42 0.37 -155.17 2_MWD+IFR2+MS+Sag(2) 569,592.22 1.18 -157.03 2_MWD+IFR2+MS+Sag(2) 569,599.69 0.08 -158.53 2_MWD+IFR2+MS+Sag(2) 569,607.34 0.68 -160.05 2_MWD+IFR2+MS+Sag (2) 569,615.13 0.75 -161.56 2_MWD+IFR2+MS+Sag (2) 569,623.51 1.36 -163.57 2_MWD+IFR2+MS+Sag (2) 569,632.11 0.73 -165.82 2_MWD+IFR2+MS+Sag (2) 569,640.48 0.40 -167.90 2_MWD+IFR2+MS+Sag(2)M 569,648.80 0.32 -170.11 2_WD+IFR2+MS+Sag(2) 569,656.89 1.35 -172.11 2_MWD+IFR2+MS+Sag(2) 569,664.52 0.30 -173.83 2_MWD+IFR2+MS+Sag (2) 569,672.28 0.60 -175.72 2_MWD+IFR2+MS+Sag (2) 569,680.16 0.78 -177.75 2_MWD+IFR2+MS+Sag (2) 569,688.32 0.63 -179.95 2_MWD+IFR2+MS+Sag(2) 569,695.90 2.70 -181.30 2_MWD+IFR2+MS+Sag (2) 569,701.52 3.63 -180.41 2_MWD+IFR2+MS+Sag (2) 569,705.60 1.28 -177.88 2_MWD+IFR2+MS+Sag(2) 6/42019 6.00.31 PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU E-38 Project: Milne Point TVD Reference: MPU E-38 Actual RKB @ 48.18usft Site: M Pt E Pad MD Reference: MPU E-38 Actual RKB @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-38PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +FJ-W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,281.95 14.96 5.41 3,186.77 3,138.59 549.74 448.10 6,016,634.89 569,708.05 3.85 -173.79 2_MWD+IFR2+MS+Sag(2) 3,345.46 16.64 356.45 3,247.89 3,199.71 566.98 448.31 6,016,652.13 569,708.10 4.66 -166.69 2_MWD+IFR2+MS+Sag (2) 3,410.77 17.70 349.57 3,310.29 3,262.11 586.08 445.93 6,016,671.20 569,705.55 3.51 -156.47 2_MWD+IFR2+MS+Sag (2) 3,473.62 19.27 339.13 3,369.92 3,321.74 605.17 440.51 6,016,690.24 569,699.94 5.82 -143.48 2_MWD+IFR2+MS+Sag (2) 3,537.85 21.90 332.89 3,430.05 3,381.87 625.74 431.27 6,016,710.73 569,690.52 5.33 -126.41 2_MWD+IFR2+MS+Sag (2) 3,601.53 24.21 329.22 3,488.64 3,440.46 647.54 419.18 6,016,732.41 569,678.22 4.27 -106.24 2_MWD+IFR2+MS+Sag (2) 3,663.52 25.99 326.10 3,544.78 3,496.60 669.73 405.09 6,016,754.47 569,663.93 3.58 -84.10 2_MWD+IFR2+MS+Sag (2) 3,728.88 28.09 319.52 3,603.00 3,554.82 693.33 387.11 6,016,777.90 569,645.73 5.59 -57.83 2_MWD+IFR2+MS+Sag(2) 3,792.93 30.22 315.02 3,658.94 3,610.76 716.21 365.92 6,016,800.57 569,624.33 4.77 -28.96 2_MWD+IFR2+MS+Sag(2) 3,856.04 32.54 313.84 3,712.82 3,664.64 739.20 342.45 6,016,823.35 569,600.65 3.80 2.04 2_MWD+IFR2+MS+Sag (2) 3,920.42 35.41 313.48 3,766.20 3,718.02 764.04 316.42 6,016,847.93 569,574.40 4.47 36.12 2_MWD+IFR2+MS+Sag(2) 3,983.50 37.12 312.67 3,817.06 3,768.88 789.51 289.16 6,016,873.15 569,546.91 2.82 71.59 2_MWD+IFR2+MS+Sag(2) 4,047.56 38.22 312.03 3,867.77 3,819.59 815.88 260.23 6,016,899.25 569,517.73 1.82 108.96 2_MWD+IFR2+MS+Sag(2) 4,110.98 41.04 311.37 3,916.61 3,868.43 842.78 230.03 6,016,925.87 569,487.28 4.50 147.70 2 MWD+IFR2+MS+Sag(2) 4,174.76 44.70 309.11 3,963.34 3,915.16 870.78 196.90 6,016,953.55 569,453.89 6.22 189.56 2_MWD+IFR2+MS+Sag(2) 4,238.00 47.02 307.33 4,007.38 3,959.20 898.85 161.24 6,016,981.28 569,417.98 4.19 233.74 2_MWD+IFR2+MS+Sag(2) 4,301.74 47.74 305.94 4,050.55 4,002.37 926.83 123.60 6,017,008.91 569,380.09 1.96 279.68 2_MWD+IFR2+MS+Sag(2) 4,365.61 51.17 303.88 4,092.06 4,043.88 954.58 83.80 6,017,036.29 569,340.03 5.90 327.48 2_MWD+IFR2+MS+Sag(2) 4,429.48 53.36 303.73 4,131.15 4,082.97 982.68 41.83 6,017,064.00 569,297.81 3.43 377.39 2_MWD+IFR2+MS+Sag (2) 4,492.95 55.58 303.34 4,168.03 4,119.85 1,011.21 -1.23 6,017,092.12 569,254.49 3.53 428.47 2_MWD+IFR2+MS+Sag (2) 4,555.71 58.71 302.30 4,202.07 4,153.89 1,039.78 -45.53 6,017,120.27 569,209.93 5.18 480.69 2_MWD+IFR2+MS+Sag(2) 4,620.54 61.21 302.15 4,234.53 4,186.35 1,069.70 -93.00 6,017,149.75 569,162.18 3.86 536.37 2_MWD+IFR2+MS+Sag(2) 4,683.68 62.46 301.93 4,264.33 4,216.15 1,099.23 -140.19 6,017,178.84 569,114.73 2.00 591.61 2_MWD+IFR2+MS+Sag(2) 4,747.33 64.41 299.54 4,292.79 4,244.61 1,128.31 -189.12 6,017,207.46 569,065.54 4.55 648.25 2_MWD+IFR2+MS+Sag(2) 4,811.01 66.78 297.90 4,319.11 4,270.93 1,156.17 -239.97 6,017,234.84 569,014.43 4.40 706.11 2_MWD+IFR2+MS+Sag(2) 4,874.91 70.42 297.05 4,342.42 4,294.24 1,183.61 -292.75 6,017,261.78 568,961.41 5.83 765.54 2 MWD+IFR2+MS+Sag (2) 4,938.94 73.83 295.31 4,362.04 4,313.86 1,210.44 -347.35 6,017,288.10 568,906.57 5.93 826.36 2_MWD+IFR2+MS+Sag (2) 5,002.62 76.39 294.97 4,378.43 4,330.25 1,236.62 403.14 6,017,313.76 568,850.54 4.05 887.99 2_MWD+IFR2+MS+Sag (2) 5,066.15 78.55 295.05 4,392.21 4,344.03 1,262.84 -459.34 6,017,339.45 568,794.10 3.40 950.00 2_MWD+IFR2+MS+Sag (2) 5,130.30 79.89 295.86 4,404.21 4,356.03 1,289.92 -516.24 6,017,366.01 568,736.96 2.43 1,013.02 2_MWD+IFR2+MS+Sag (2) 5,193.79 83.41 295.44 4,413.43 4,365.25 1,317.11 -572.86 6,017,392.66 568,680.10 5.58 1,075.82 2_MWD+IFR2+MS+Sag (2) 5,257.32 83.55 297.00 4,420.64 4,372.46 1,345.00 -629.48 6,017,420.02 568,623.22 2.45 1,138.92 2_MWD+IFR2+MS+Sag(2) 5,321.04 81.48 298.27 4,428.94 4,380.76 1,374.30 -685.45 6,017,448.80 568,566.99 3.80 1,202.03 2_MWD+IFR2+MS+Sag(2) 5,384.66 80.82 298.10 4,438.73 4,390.55 1,403.99 -740.85 6,017,477.97 568,511.32 1.07 1,264.79 2_MWD+IFR2+MS+Sag (2) 5,448.81 82.63 297.36 4,447.96 4,399.78 1,433.52 -797.04 6,017,506.98 568,454.86 3.04 1,328.20 2_MWD+IFR2+MS+Sag (2) 5,512.37 84.81 296.61 4,454.91 4,406.73 1,462.19 -853.34 6,017,535.12 568,398.31 3.62 1,391.34 2_MWD+IFR2+MS+Sag(2) 5,575.69 86.39 295.90 4,459.77 4,411.59 1,490.12 -909.96 6,017,562.51 568,341.44 2.73 1,454.45 2_MWD+IFR2+MS+Sag(2) 5,639.99 85.90 296.04 4,464.09 4,415.91 1,518.21 -967.63 6,017,590.07 568,283.51 0.79 1,518.60 2_MWD+IFR2+MS+Sag (2) 5,728.83 89.94 294.55 4,467.32 4,419.14 1,556.13 -1,047.89 6,017,627.24 568,202.91 4.85 1,607.36 2_MWD+IFR2+MS+Sag(2) 5,791.41 91.00 296.59 4,466.81 4,418.63 1,583.14 -1,104.33 6,017,653.72 568,146.23 3.67 1,669.93 2_MWD+IFR2+MS+Sag(3) 6/42019 6:00:31PM Page 4 COMPASS 5000.15 Build 91 Survey Halliburton Definitive Survey Report Map Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E,38 Project: Milne Point TVD Reference: MPU E-38 Actual IRKS @ 48.18usft Site: M Pt E Pad MD Reference: MPU E-38 Actual RKB @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38PB1 Survey Calculation Method: Minimum Curvature Design: MPU E-38PB1 Database: NORTH US+CANADA Survey 6/42019 6:00: 31PM Page 5 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 5,856.13 90.38 299.15 4,466.03 4,417.85 1,613.39 -1,161.53 6,017,683.43 568,088.75 4.07 1,734.56 2_MWD+IFR2+MS+Sag (3) 5,919.12 89.08 299.14 4,466.32 4,418.14 1,644.07 -1,216.55 6,017,713.59 568,033.46 2.06 1,797.38 2_MWD+IFR2+MS+Sag(3) 5,982.72 88.90 297.70 4,467.44 4,419.26 1,674.33 -1,272.47 6,017,743.33 567,977.26 2.28 1,860.85 2_MWD+IFR2+MS+Sag(3) 6,045.81 88.52 295.45 4,468.86 4,420.68 1,702.55 -1,328.88 6,017,771.02 567,920.60 3.62 1,923.90 2_MWD+IFR2+MS+Sag (3) 6,109.41 88.46 293.53 4,470.54 4,422.36 1,728.90 -1,386.73 6,017,796.83 567,862.51 3.02 1,987.47 2_MWD+IFR2+MS+Sag (3) 6,173.04 88.28 292.77 4,472.35 4,424.17 1,753.91 -1,445.22 6,017,821.29 567,803.80 1.23 2,051.04 2_MWD+IFR2+MS+Sag (3) 6,236.57 87.78 292.13 4,474.53 4,426.35 1,778.15 -1,503.90 6,017,844.99 567,744.90 1.28 2,114.47 2_MWD+IFR2+MS+Sag (3) 6,299.94 88.84 292.08 4,476.40 4,428.22 1,801.99 -1,562.58 6,017,868.27 567,686.00 1.67 2,177.73 2_MWD+IFR2+MS+Sag(3) 6,363.67 91.25 291.80 4,476.35 4,428.17 1,825.80 -1,621.69 6,017,891.53 567,626.68 3.81 2,241.37 2_MWD+IFR2+MS+Sag (3) 6,427.42 93.54 291.53 4,473.69 4,425.51 1,849.31 -1,680.88 6,017,914.49 567,567.28 3.62 2,304.95 2_MWD+IFR2+MS+Sag (3) 6,491.22 94.90 290.96 4,468.99 4,420.81 1,872.37 -1,740.18 6,017,936.99 567,507.77 2.31 2,368.44 2_MWD+IFR2+MS+Sag (3) 6,554.84 94.76 290.22 4,463.64 4,415.46 1,894.66 -1,799.53 6,017,958.73 567,448.23 1.18 2,431.64 2 MWD+IFR2+MS+Sag(3) 6,618.08 94.58 290.37 4,458.49 4,410.31 1,916.52 -1,858.65 6,017,980.04 567,388.92 0.37 2,494.46 2_MWD+IFR2+MS+Sag (3) 6,681.14 94.95 290.62 4,453.25 4,405.07 1,938.52 -1,917.51 6,018,001.49 567,329.85 0.71 2,557.11 2_MWD+IFR2+MS+Sag (3) 6,745.14 94.95 290.52 4,447.73 4,399.55 1,960.93 -1,977.21 6,018,023.34 567,269.96 0.16 2,620.68 2_MWD+IFR2+MS+Sag (3) 6,809.02 94.71 290.50 4,442.35 4,394.17 1,983.23 -2,036.82 6,018,045.08 567,210.14 0.38 2,684.14 2_MWD+IFR2+MS+Sag (3) 6,872.14 94.52 290.39 4,437.27 4,389.09 2,005.21 -2,095.78 6,018,066.51 567,150.99 0.35 2,746.85 2_MWD+IFR2+MS+Sag (3) 6,935.95 94.14 290.76 4,432.45 4,384.27 2,027.57 -2,155.34 6,018,088.31 567,091.22 0.83 2,810.29 2_MWD+IFR2+MS+Sag (3) 6,999.86 95.09 292.87 4,427.31 4,379.13 2,051.24 -2,214.48 6,018,111.43 567,031.88 3.61 2,873.89 2_MWD+IFR2+MS+Sag(3) 7,063.99 94.82 294.89 4,421.77 4,373.59 2,077.10 -2,272.90 6,018,136.75 566,973.23 3.17 2,937.77 2_MWD+IFR2+MS+Sag(3) 7,178.00 94.82 294.89 4,412.19 4,364.01 2,124.92 -2,375.95 6,018,183.60 566,869.74 0.00 3,051.37 PROJECTED to TD Checked By: Chelsea Wright n�'�: `, s Approved By: Mitch Laird -M Date: 06-04-2019 6/42019 6:00: 31PM Page 5 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad MPU E-38PB2 500292362971 Sperry Drilling Definitive Survey Report 04 June, 2019 HALLIBURTON 5porry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-38 Project: Milne Point TVD Reference: MPU E-38 Actual RKB @ 48.18usft Site: M Pt E Pad MD Reference: MPU E-38 Actual RKB @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38PB2 Survey Calculation Method: Minimum Curvature Design: MPU E-38PB2 Database: NORTH US+CANADA 'reject Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU E-38 MPU E-38PB2 Well Position +NIS 0.00 usft Northing: 6,016,081.06 usfl Latitude: 70° 27' 15.4464 N +E/ -W 0.00 usft Easting: 569,265.12 usfl Longitude: 149` 26'5.1882 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: 21.80 usft Wellbore MPU E-38PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength Vertical MD M (`) (nT) TVDSS BGGM2018 5/28/2019 16.69 Northing 80.96 57,428.33438250 Design MPU E-38PB2 (usft) (I M Audit Notes: (usft) (usft) (usft) (ft) Version: 1.0 Phase: ACTUAL Tie On Depth: 6,809.02 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 6,016,081.06 (usft) (usft) (usft) M 0.40 26.38 0.00 0.00 295.00 Survey Program Date 6/4/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 415.00 MPU E-38PB1 SDI Gyro (MPU E-38PB1 2_Gyro-NS-GC_Drill Coll; H029Ga: North seeking single shot in drill colla 05/08/2019 484.73 5,728.83 MPU E-38PB1 MWD+IFR2+MS+Sag (1) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 05/17/2019 5,791.41 6,809.02 MPU E-38PB1 MWD+IFR2+MS+Sag (2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/26/2019 6,840.00 10,183.03 MPU E-38PB2 MWD+IFR2+MS+Sag (3) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 05/28/2019 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W Northing Easting DLS Section (usft) (I M (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 26.38 0.00 0.00 26.38 -21.80 0.00 0.00 6,016,081.06 569,265.12 0.00 0.00 UNDEFINED 100.00 0.40 265.25 100.00 51.82 -0.02 -0.26 6,016,081.04 569,264.86 0.54 0.22 2_Gymo-NS-GC_Drill collar It 166.00 0.48 274.71 166.00 117.82 -0.02 -0.76 6,016,081.04 569,264.36 0.16 0.68 2_Gyro-NS-GC_Drill collar (I 228.00 0.52 282.53 228.00 179.82 0.06 -1.29 6,016,081.11 569,263.82 0.13 1.20 2_Gym-NS-GC_Drill collar (I 290.00 0.83 346.13 289.99 241.81 0.56 -1.68 6,016,081.61 569,263.44 1.22 1.76 2_Gyro-NS-GC_Drill collar (I 352.00 2.70 13.26 351.96 303.78 2.42 -1.45 6,016,083.47 569,263.65 3.22 2.34 2_Gyro-NS-GC_Drill cellar (1 415.00 4.31 19.46 414.84 366.66 6.10 -0.32 6,016,087.15 569,264.74 2.62 2.87 2_Gyro-NS-GC_Drill collar (1 484.73 7.41 33.76 484.20 436.02 12.31 3.05 6,016,093.39 569,268.06 4.88 2.43 2_MWD+IFR2+MS+Sag (2) 546.64 9.25 41.00 545.46 497.28 19.38 8.54 6,016,100.52 569,273.47 3.42 0.46 2_MWD+IFR2+MS+Sag (2) 609.18 11.00 51.54 607.03 558.85 26.89 16.51 6,016,108.10 569,281.37 4.06 -3.60 2_MWD+IFR2+MS+Sag(2) 671.65 12.92 55.89 666.14 619.96 34.51 26.96 6,016,115.82 569,291.75 3.39 -9.85 2_MWD+IFR2+MS+Sag (2) 6/4,2019 6:01:49PM Page 2 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-38 Wellbore: MPU E-38PB2 Design: MPU E-38PB2 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU E-38 MPU E-38 Actual RKB @ 48.18usft MPU E-38 Actual RKB @ 48.18usft True Minimum Curvature NORTH US + CANADA Map Map MD Inc Azi TVD TVOSS +Nl-S +E/ -W Northing Easting DLS (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') 736.05 13.98 54.86 730.77 682.59 43.03 39.28 6,016,124.45 569,303.99 1.69 799.21 16.76 55.19 791.67 743.49 52.62 53.00 6,016,134.16 569,317.62 4.40 863.21 20.15 55.13 852.37 804.19 64.19 69.62 6,016,145.89 569,334.14 5.30 899.52 20.42 53.97 886.42 838.24 71.49 79.88 6,016,153.29 569,344.32 1.33 926.70 19.68 53.76 911.96 863.78 76.99 87.40 6,016,158.85 569,351.80 2.74 990.18 17.77 53.81 972.07 923.89 8903 103.84 6,016,171.04 569,368.12 3.01 1,053.16 17.81 54.52 1,032.04 983.86 100.29 119.44 6,016,182.45 569,383.61 0.35 1,117.77 17.54 54.62 1,093.60 1,045.42 111.66 135.43 6,016,193.97 569,399.49 0.42 1,180.55 18.59 50.91 1,153.29 1,105.11 123.45 150.91 6,016,205.90 569,414.86 2.48 1,245.59 18.94 50.29 1,214.87 1,166.69 136.73 167.08 6,016,219.33 569,430.90 0.62 1,307.78 17.70 51.13 1,273.91 1,225.73 149.11 182.20 6,016,231.85 569,445.91 2.04 1,372.53 17.88 47.93 1,335.56 1,287.38 161.95 197.24 6,016,244.82 569,460.83 1.54 1,436.75 17.66 46.76 1,396.72 1,348.54 175.23 211.66 6,016,258.23 569,475.12 0.65 1,498.90 17.76 46.38 1,455.92 1,407.74 188.23 225.39 6,016,271.36 569,488.73 0.25 1,563.71 16.50 42.63 1,517.86 1,469.68 201.82 238.78 6,016,285.07 569,501.99 2.58 1,625.75 14.33 36.92 1,577.67 1,529.49 214.44 249.36 6,016,297.79 569,512.45 4.26 1,689.74 13.22 34.70 1,639.82 1,591.64 226.79 258.28 6,016,310.22 569,521.26 1.92 1,753.71 13.17 33.23 1,702.10 1,653.92 238.90 266.44 6,016,322.40 569,529.30 0.53 1,817.71 12.57 32.69 1,764.49 1,716.31 250.86 274.19 6,016,334.43 569,536.95 0.96 1,881.46 12.84 32.77 1,826.68 1,778.50 262.65 281.78 6,016,346.30 569,544.42 0.42 1,945.97 13.20 33.05 1,889.53 1,841.35 274.85 289.67 6,016,358.57 569,552.20 0.57 2,008.81 13.13 33.34 1,950.72 1,902.54 286.83 297.51 6,016,370.62 569,559.92 0.15 2,073.58 13.20 34.75 2,013.79 1,965.61 299.05 305.77 6,016,382.91 569,568.06 0.51 2,136.37 13.69 32.90 2,074.86 2,026.68 311.18 313.89 6,016,395.12 569,576.07 1.04 2,201.32 13.89 33.46 2,137.93 2,089.75 324.14 322.36 6,016,408.15 569,584.42 0.37 2,264.17 13.49 30.83 2,199.00 2,150.82 336.73 330.28 6,016,420.81 569,592.22 1.18 2,327.69 13.44 30.86 2,260.77 2,212.59 349.43 337.86 6,016,433.58 569,599.69 0.08 2,392.22 13.87 30.54 2,323.48 2,275.30 362.53 345.64 6,016,446.75 569,607.34 0.68 2,456.05 14.35 30.62 2,385.38 2,337.20 375.92 353.56 6,016,460.22 569,615.13 0.75 2,519.70 14.64 33.88 2,447.01 2,398.83 389.39 362.06 6,016,473.76 569,623.51 1.36 2,583.46 14.39 32.30 2,508.73 2,460.55 402.77 370.78 6,016,487.23 569,632.11 0.73 2,647.49 14.17 32.84 2,570.79 2,522.61 416.08 379.28 6,016,500.61 569,640.48 0.40 2,710.38 14.15 33.67 2,631.76 2,583.58 428.95 387.72 6,016,513.55 569,648.80 0.32 2,774.32 13.50 31.31 2,693.85 2,645.67 441.83 395.93 6,016,526.51 569,656.89 1.35 2,837.62 13.44 32.08 2,755.41 2,707.23 454.38 403.68 6,016,539.13 569,664.52 0.30 2,901.77 13.08 32.68 2,817.85 2,769.67 466.80 411.56 6,016,551.62 569,672.28 0.60 2,965.54 13.56 33.24 2,879.90 2,831.72 479.13 419.55 6,016,564.02 569,680.16 0.78 3,028.74 13.95 33.59 2,941.29 2,893.11 491.67 427.83 6,016,576.64 569,688.32 0.63 3,092.66 14.01 26.44 3,003.32 2,955.14 505.02 435.54 6,016,590.06 569,695.90 2.70 3,156.19 14.38 17.14 3,064.92 3,016.74 519.45 441.29 6,016,604.54 569,701.52 3.63 Vertical Section (ft) Survey Tool Name -17.42 2_MWD+IFR2+MS+Sag(2) -25.80 2_MWD+IFR2+MS+Sag(2) -35.97 2_MWD+IFR2+MS+Sag 12) -42.18 2_MWD+IFR2+MS+Sag (2) 46.68 2_MWD+IFR2+MS+Sag (2) -56.49 2_MWD+IFR2+MS+Sag(2) -65.87 2_MWD+IFR2+MS+Sag (2) -75.55 2_MWD+IFR2+MS+Sag (2) -84.60 2_MWD+IFR2+MS+Sag(2) -93.64 2_MWD+IFR2+MS+Sag (2) -102.11 2_MWD+IFR2+MS+Sag (2) -110.32 2_MWD+IFR2+MS+Sag (2) -117.77 2_MWD+IFR2+MS+Sag (2) .124.72 2_MWD+IFR2+MS+Sag (2) -131.11 2_MWD+IFR2+MS+Sag (2) -135.37 2_MWD+IFR2+MS+Sag(2) -138.24 2_MWD+IFR2+MS+Sag(2) -140.51 2 MWD+IFR2+MS+Sag (2) -142.49 2_MWD+IFR2+MS+Sag (2) .144.37 2_MWD+IFR2+MS+Sag (2) A46.37 2_MWD+IFR2+MS+Sag(2) -148.41 2_MWD+IFR2+MS+Sag (2) -150.73 2_MWD+IFR2+MS+Sag(2) -152.97 2_MWD+IFR2+MS+Sag (2) -155.17 2_MWD+IFR2+MS+Sag (2) -157.03 2_MWD+IFR2+MS+Sag(2) -158.53 2_MWD+IFR2+MS+Sag (2) -160.05 2_MWD+IFR2+MS+Sag (2) .161.56 2_MWD+IFR2+MS+Sag (2) -163.57 2_MWD+IFR2+MS+Sag (2) -165.82 2_MWD+IFR2+MS+Sag(2) -167.90 2_MWD+IFR2+MS+Sag(2) -170.11 2_MWD+IFR2+MS+Sag (2) -172.11 2_MWD+IFR2+MS+Sag (2) -173.83 2_MWD+IFR2+MS+Sag(2) -175.72 2_MWD+IFR2+MS+Sag(2) -177.75 2_MWD+IFR2+MS+Sag(2) -179.95 2_MWD+IFR2+MS+Sag (2) -181.30 2_MWD+IFR2+MS+Sag (2) -180.41 2_MWD+IFR2+MS+Sag (2) 6742019 6:01:49PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: MPU E-38 Wellbore: MPU E-38PB2 Design: MPU E-38PB2 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (°) (°) (usft) (usft) (usft) 3,220.01 14.01 14.17 3,126.79 3,078.61 534.51 3,281.95 14.96 5.41 3,186.77 3,138.59 549.74 3,345.46 16.64 356.45 3,247.89 3,199.71 566.98 3,410.77 17.70 349.57 .3,310.29 3,262.11 586.08 3,473.62 19.27 339.13 3,369.92 3,321.74 605.17 3,537.85 21.90 332.89 3,4M05 3,381.87 625.74 3,601.53 24.21 329.22 3,488.64 3,440.46 647.54 3,663.52 25.99 326.10 3,544.78 3,496.60 669.73 3,728.88 28.09 319.52 3,603.00 3,554.82 693.33 3,792.93 30.22 315.02 3,658.94 3,610.76 716.21 3,856.04 32.54 313.84 3,712.82 3,664.64 739.20 3,920.42 35.41 313.48 3,766.20 3,718.02 764.04 3,983.50 37.12 312.67 3,817.06 3,768.88 789.51 4,047.56 38.22 312.03 3,867.77 3,819.59 815.88 4,110.98 41.04 311.37 3,916.61 3,868.43 842.78 4,174.76 44.70 309.11 3,963.34 3,915.16 870.76 4,238.00 47.02 307.33 4,007.38 3,959.20 898.85 4,301.74 47.74 305.94 4,050.55 4,002.37 926.83 4,365.61 51.17 303.68 092.06 4,043.88 954.58 4,429.48 53.36 4,492.95 55.58 4,555.71 58.71 4,620.54 61.21 4,683.68 62.46 4,747.33 64.41 4,811.01 66.78 4,874.91 70.42 4,938.84 73.83 5,002.62 76.39 5,066.15 78.55 5,130.30 79.89 5,193.79 83.41 5,257.32 83.55 5,321.04 81.48 5,384.66 80.82 5,448.81 82.63 5512.37 84.81 5,57569 86.39 5,639,99 85.90 5,728.83 89.94 303.73 303.34 302.30 302.15 301.93 299.54 297.90 297.05 295.31 294.97 295.05 295.86 295.44 297.00 298.27 298.10 297.36 296.61 295.90 296.04 294.55 4,131.15 4,168.03 4,202.07 4,234.53 4,264.33 4,292.79 4,319.11 4,342.42 4,362.04 4,378.43 4,392.21 4,404.21 4,413.43 4,420.64 4,428.94 4,438.73 4,447.96 4,454.91 4,459.77 4,464.09 4,467.32 4,082.97 4,119.85 4,153.89 4,186.35 4,216.15 4,244.61 4,270.93 4,294.24 4,313.86 4,330.25 4,344.03 4,356.03 4,365.25 4,372.46 4,380.76 4,390.55 4,399.78 4,406.73 4,411.59 4,415.91 4,419.14 982.68 1,011.21 1,039.78 1,069.70 1,099.23 1,128.31 1,156.17 1,183.61 1,210.44 1,236.62 1,262.84 1,289.92 1,317.11 1,345.00 1,374.30 1,403.99 1,433.52 1,462.19 1,490.12 1,518.21 1,556.13 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +E/ -W Northing (usft) (ft) 445.51 6,016,619.64 448.10 6,016,634.89 448.31 6,016,652.13 445.93 6,016,671.20 440.51 6,016,690.24 431.27 6,016,710.73 419.18 6,016,732.41 405.09 6,016,754.47 387.11 6,016,777.90 365.92 6,016,800.57 342.45 6,016,823.35 316.42 6,016,847.93 289.16 6,016,873.15 260.23 6,016,899.25 230.03 6,016,925.87 196.90 6,016,953.55 161.24 6,016,981.28 123.60 6,017,008.91 83.80 6,017,036.29 41.83 6,017,064.00 -1.23 6,017,092.12 -45.53 6,017,120.27 -93.00 6,017,149.75 -140.19 6,017,178.84 -189.12 6,017,207.46 -239.97 6,017,234.84 -292.75 6,017,261.78 -347.35 6,017,288.10 -403.14 6,017,313.76 -459.34 6,017,339.45 -516.24 6,017,366.01 -572.86 6,017,392.66 -629.48 6,017,420.02 -685.45 6,017,448.80 -740.85 6,017,477.97 -797.04 6,017,506.98 -853.34 6,017,535.12 -909.96 6,017,562.51 -967.63 6,017,590.07 -1,047.89 6,017,627.24 Well MPU E-38 MPU E-38 Actual RKB @ 48.18usft MPU E-38 Actual RKB @ 48.18usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (°1100') (ft) Survey Tool Name 569,705.60 1.28 -177.88 2_MWD+IFR2+MS+Sag (2) 569,708.05 3.85 -173.79 2_MWD+IFR2+MS+Sag (2) 569,708.10 4.66 -166.69 2_MWD+IFR2+MS+Sag(2) 569,705.55 3.51 -156.47 2_MWD+IFR2+MS+Sag (2) 569,699.94 5.82 -143.48 2_MWD+IFR2+MS+Sag(2) 569,690.52 5.33 -126.41 2_MWD+IFR2+MS+Sag(2) 569,678.22 4.27 -106.24 2_MWD+IFR2+MS+Sag (2) 569,663.93 3.58 -84.10 2_MWD+IFR2+MS+Sag(2) 569,645.73 5.59 -57.83 2_MWD+IFR2+MS+Sag (2) 569,624.33 4.77 -28.96 2_MWD+IFR2+MS+Sag (2) 569,600.65 3.80 2.04 2_MWD+IFR2+MS+Sag(2) 569,574.40 4.47 36.12 2_MWD+IFR2+MS+Sag(2) 569,546.91 2.82 71.59 2_MWD+IFR2+MS+Sag(2) 569,517.73 1.82 108.96 2_MWD+IFR2+MS+Sag(2) 569,487.28 4.50 147.70 2_MWD+IFR2+MS+Sag (2) 569,453.89 6.22 189.56 2_MWD+IFR2+MS+Sag(2) 569,417.98 4.19 233.74 2_MWD+IFR2+MS+Sag(2) 569,380.09 1.96 279.68 2_MWD+IFR2+MS+Sag(2) 569,340.03 5.90 327.48 2_MWD+IFR2+MS+Sag(2) 569,297.81 3.43 377.39 2_MWD+IFR2+MS+Sag (2) 569,254.49 3.53 428.47 2_MWD+IFR2+MS+Sag (2) 569,209.93 5.18 480.69 2_MWD+IFR2+MS+Sag(2) 569,162.18 3.86 536.37 2_MWD+IFR2+MS+Sag (2) 569,114.73 2.00 591.61 2_MWD+IFR2+MS+Sag (2) 569,065.54 4.55 648.25 2_MWD+IFR2+MS+Sag(2) 569,014.43 4.40 706.11 2_MWD+IFR2+MS+Sag (2) 568,961.41 5.83 765.54 2_MWD+IFR2+MS+Sag (2) 568,906.57 5.93 826.36 2_MWD+IFR2+MS+Sag (2) 568,850.54 4.05 887.99 2_MWD+IFR2+MS+Sag (2) 568,794.10 3.40 950.00 2_MWD+IFR2+MS+Sag(2) 568,736.96 2.43 1,013.02 2_MWD+IFR2+MS+Sag (2) 568,680.10 5.58 1,075.82 2_MWD+IFR2+MS+Sag(2) 568,623.22 2.45 1,138.92 2_MWD+IFR2+MS+Sag(2) 568,566.99 3.80 1,202.03 2_MWD+IFR2+MS+Sag(2) 568,511.32 1.07 1,264.79 2 MWD+IFR2+MS+Sag (2) 568,454.86 3.04 1,328.20 2_MWD+IFR2+MS+Sa9(2) 568,398.31 3.62 1,391.34 2_MWD+IFR2+MS+Sag (2) 568,341.44 2.73 1,454.45 2_MWD+IFR2+MS+Sag(2) 568,283.51 0.79 1,518.60 2_MWD+IFR2+MS+Sag (2) 568,202.91 4.85 1,607.36 2_MWD+IFR2+MS+Sag(2) 61412019 6:01:49PM Page 4 COMPASS 5000.15 Build 91 Company: Project: Site: Well: Wellbore: Design: Survey Hiloorp Alaska, LLC Milne Point M Pt E Pad MPU E-38 MPU E-38PB2 MPU E-38PB2 MD Inc (usft) (1) 5,791.41 91.00 5,856.13 90.38 5,919.12 89.08 5,982.72 88.90 6,045.81 88.52 6,109.41 88.46 6,173.04 88.28 6,236.57 87.78 6,299.94 88.84 6,363.67 91.25 6,427.42 93.54 6,491.22 94.90 6,554.84 94.76 6,618.08 94.58 6,681.14 94.95 6,745.14 94.95 6,809.02 94.71 6,840.00 94.62 6,873.13 92.53 6,936.01 92.41 7,000.21 92.04 7,064.55 92.60 7,127.27 92.42 7,190.39 91.61 Azi 296.59 299.15 299.14 297.70 295.45 293.53 292.77 292.13 292.08 291.80 291.53 290.96 290.22 290.37 290.62 290.52 290.50 290.45 291.78 291.93 293.20 293.51 293.13 291.85 TVD (usft) 4,466.81 4,466.03 4,466.32 4,467.44 4,468.86 4,470.54 4,472.35 4,474.53 4,476.40 4,476.35 4,473.69 4,468.99 4,463.64 4,458.49 4,453.25 4,447.73 4,442.35 4,439.83 4,437.76 4,435.05 4,432.56 4,429.96 4,427.21 4,424.99 7,253.82 91.12 292.19 4,423.48 7,317.39 90.93 292.82 4,422.34 7,380.84 91.24 294.31 4,421.14 7,443.56 92.05 295.98 4,419.34 7,507.52 92.29 296.67 4,416.92 7,571.46 91.67 296.71 4,414.71 7,635.24 90.25 296.33 4,413.64 7,699.16 89.20 296.22 4,413.95 7,762.36 89.20 295.95 4,414.83 7,826.09 89.14 297.24 4,415.75 7,889.69 90.32 297.50 4,416.05 7,952.42 92.24 297.54 4,414.65 8,016.50 93.60 297.32 4,411.39 8,080.73 93.03 296.34 4,407.67 8,144.27 91.48 295.80 4,405.17 8,207.59 91.18 295.15 4,403.70 TVDSS (usft) 4,418.63 4,417.85 4,418.14 4,419.26 4,420.68 4,422.36 4,424.17 4,426.35 4,428.22 4,428.17 4,425.51 4,420.81 4,415.46 4,410.31 4,405.07 4,399.55 4,394.17 4,391.65 4,389.58 4,386.87 4,384.38 4,381.78 4,379.03 4,376.81 4,375.30 4,374.16 4,372.96 4,371.16 4,368.74 4,366.53 4,365.46 4,365.77 4,366.65 4,367.57 Halliburton Definitive Survey Report +N/ -S (usft) 1,583.14 1,613.39 1,644.07 1,674.33 1,702.55 1,728.90 1,753.91 1,778.15 1,801.99 1,825.80 1,849.31 1,872.37 1,894.66 1,916.52 1,938.52 1,960.93 1,983.23 1,994.03 2,005.94 2,029.33 2,053.94 2,079.43 2,104.23 2,128.36 2,152.14 2,176.47 2,201.83 2,228.47 2,256.81 2,285.51 2,313.98 2,342.28 2,370.07 2,398.59 4,367.87 2,427.83 4,366.47 2,456.81 4,363.21 2,486.29 4,359.49 2,515.23 4,356.99 2,543.13 4,355.52 2,570.36 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +EI -W Northing (usft) (ft) -1,104.33 6,017,653.72 -1,161.53 6,017,683.43 -1,216.55 6,017,713.59 -1,272.47 6,017,743.33 -1,328.88 6,017,771.02 -1,386.73 6,017,796.83 -1,445.22 6,017,821.29 -1,503.90 6,017,844.99 -1,562.58 6,017,868.27 -1,621.69 6,017,891.53 -1,680.88 6,017,914.49 -1,740.18 6,017,936.99 -1,799.53 6,017,958.73 -1,858.65 6,017,980.04 -1,917.51 6,018,001.49 -1,977.21 6,018,023.34 -2,036.82 6,018,045.08 -2,065.75 6,018,055.61 -2,096.59 6,018,067.24 -2,154.90 6,018,090.08 -2,214.14 6,018,114.14 -2,273.16 6,018,139.07 -2,330.70 6,018,163.34 -2,388.98 6,018,186.92 -2,447.77 6,018,210.15 -2,506.49 6,018,233.93 -2,564.63 6,018,258.74 -2,621.38 6,018,284.85 -2,678.67 6,018,312.66 -2,735.76 6,018,340.83 -2,792.82 6,018,368.76 -2,850.14 6,018,396.52 -2,906.89 6,018,423.78 -2,963.87 6,018,451.77 -3,020.35 6,018,480.48 -3,075.97 6,018,508.94 -3,132.77 6,018,537.88 -3,189.99 6,018,566.29 -3,247.02 6,018,593.66 -3,304.16 6,018,620.35 Well MPU E-38 MPU E-38 Actual RKB @ 48.18usft MPU E-38 Actual RKB @ 48.1 Busft True Minimum Curvature NORTH US + CANADA Map Easting DLS (ft) (°/100') 568,146.23 3.67 568,088.75 4.07 568,033.46 2.06 567,977.26 2.28 567,920.60 3.62 567,862.51 3.02 567,803.80 1.23 567,744.90 1.28 567,686.00 1.67 567,626.68 3.81 567,567.28 3.62 567,507.77 2.31 567,448.23 1.18 567,388.92 0.37 567,329.85 0.71 567,269.96 0.16 567,210.14 0.38 567,181.12 0.33 567,150.17 7.47 567,091.65 0.31 567,032.19 2.06 566,972.94 0.99 566,915.18 0.67 566,856.68 2.40 566,797.68 0.94 566,738.75 1.03 566,680.37 2.40 566,623.38 2.96 566,565.84 1.14 566,508.49 0.97 566,451.17 2.30 566,393.60 1.65 566,336.60 0.43 566,279.36 2.03 566,222.62 1.90 566,166.74 3.06 566,109.67 2.15 566,052.19 1.76 565,994.91 2.58 Vertical Section (ft) Survey Tool Name 1,669.93 2_MWD+IFR2+MS+Sag(3) 1,734.56 2_MWD+IFR2+MS+Sag (3) 1,797.38 2_MWD+IFR2+MS+Sag (3) 1,860.85 2_MWD+IFR2+MS+Sag (3) 1,923.90 2_MWD+IFR2+MS+Sag (3) 1,987.47 2_MWD+IFR2+MS+Sag(3) 2,051.04 2_MWD+IFR2+MS+Sag(3) 2,114.47 2_MWD+IFR2+MS+Sag(3) 2,177.73 2_MWD+IFR2+MS+Sag(3) 2,241.37 2_MWD+IFR2+MS+Sag(3) 2,304.95 2_MWD+IFR2+MS+Sag (3) 2,368.44 2_MWD+IFR2+MS+Sag(3) 2,431.64 2_MWD+IFR2+MS+Sag(3) 2,494.46 2_MWD+IFR2+MS+Sag(3) 2,557.11 2_MWD+IFR2+MS+Sag (3) 2,620.68 2_MWD+IFR2+MS+Sag (3) 2,684.14 2_MWD+IFR2+MS+Sag (3) 2,714.92 2_MWD+IFR2+MS+Sag (4) 2,747.91 2_MWD+IFR2+MS+Sag (4) 2,810.63 2_MWD+IFR2+MS+Sag(4) 2,874.73 2_MWD+IFR2+MS+Sag (4) 2,938.99 2_MWD+IFR2+MS+Sag(4) 3,001.62 2_MWD+IFR2+MS+Sag (4) 3,064.64 2_MWD+IFR2+MS+Sag (4) 3,127.96 2_MWD+IFR2+MS+Sag(4) 3,191.46 2_MWD+IFR2+MS+Sag(4) 3,254.88 2_MWD+IFR2+MS+Sag(4) 3,317.57 2_MWD+IFR2+MS+Sag (4) 3,381.47 2_MWD+IFR2+MS+Sag (4) 3,445.34 2_MWD+IFR2+MS+Sag(4) 3,509.09 2_MWD+IFR2+MS+Sag(4) 3,572.99 2_MWD+IFR2+MS+Sag (4) 3,636.17 2_MWD+IFR2+MS+Sag(4) 3,699.87 2_MWD+IFR2+MS+Sag(4) 3,763.41 2_MWD+IFR2+MS+Sag (4) 3,826.06 2_MWD+IFR2+MS+Sag(4) 3,890.00 2_MWD+IFR2+MS+Sag (4) 3,954.09 2_MWD+IFR2+MS+Sag (4) 4,017.57 2 MWD+IFR2+MS+Sag (4) 565,937.52 1.13 4,080.87 2_MWD+IFR2+MS+Sag (4) 6742019 6:01:49PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU E-38 Project: Milne Point TVD Reference: MPU E-38 Actual RKB @ 48.18usft Site: M Pt E Pad MD Reference: MPU E-38 Actual RKB @ 48.18usft Well: MPU E-38 North Reference: True Wellbore: MPU E-38PB2 Survey Calculation Method: Minimum Curvature Design: MPU E-38PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,271.77 91.24 294.65 4,402.35 4,354.17 2,597.37 -3,362.36 6,018,646.82 565,879.07 0.78 4,145.03 2_MWD+IFR2+MS+Sag (4) 8,335.30 91.74 294.21 4,400.70 4,352.52 2,623.64 -3,420.19 6,018,672.55 565,821.02 1.05 4,208.54 2_MWD+IFR2+MS+Sag (4) 8,398.80 92.54 292.69 4,398.32 4,350.14 2,648.89 -3,478.40 6,018,697.25 565,762.58 2.70 4,271.97 2_MWD+IFR2+MS+Sag (4) 8,462.83 92.04 292.61 4,395.77 4,347.59 2,673.53 -3,537.44 6,018,721.34 565,703.31 0.79 4,335.89 2_MWD+IFR2+MS+Sag (4) 8,525.37 90.99 292.85 4,394.11 4,345.93 2,697.69 -3,595.10 6,018,744.95 565,645.43 1.72 4,398.36 2_MWD+IFR2+MS+Sag(4) 8,589.48 91.43 293.30 4,392.76 4,344.58 2,722.81 -3,654.07 6,018,769.52 565,586.24 0.98 4,462.42 2_MWD+IFR2+MS+Sag(4) 8,653.62 91.61 293.00 4,391.06 4,342.88 2,748.01 -3,713.03 6,018,794.18 565,527.06 0.55 4,526.51 2_MWD+IFR2+MS+Sag(4) 8,717.65 91.43 292.80 4,389.36 4,341.18 2,772.92 -3,771.99 6,018,818.53 565,467.87 0.42 4,590.47 2_MWD+IFR2+MS+Sag (4) 8,781.09 92.73 292.25 4,387.06 4,338.88 2,797.21 -3,830.55 6,018,842.27 565,409.10 2.22 4,653.81 2_MWD+IFR2+MS+Sag (4) 8,845.13 92.54 292.23 4,384.11 4,335.93 2,821.42 -3,889.76 6,018,865.93 565,349.67 0.30 4,717.71 2_MWD+IFR2+MS+Sag(4) 8,908.68 91.11 292.28 4,382.09 4,333.91 2,845.48 -3,948.55 6,018,889.44 565,290.67 2.25 4,781.15 2_MWD+IFR2+MS+Sag(4) 8,972.02 89.38 292.22 4,381.82 4,333.64 2,869.46 4,007.17 6,018,912.87 565,231.83 2.73 4,844.41 2 MWD+IFR2+MS+Sag (4) 9,035.48 87.59 293.02 4,383.50 4,335.32 2,893.86 4,065.72 6,018,936.72 565,173.06 3.09 4,907.79 2_MWD+IFR2+MS+Sag(4) 9,099.49 87.54 292.59 4,386.22 4,338.04 2,918.64 4,124.68 6,018,960.96 565,113.88 0.68 4,971.70 2_MWD+IFR2+MS+Sag (4) 9,163.24 88.03 292.69 4,388.68 4,340.50 2,943.16 3,183.47 6,018,984.93 565,054.87 0.78 5,035.35 2_MWD+IFR2+MS+Sag(4) 9,226.67 86.97 293.08 4,391.45 4,343.27 2,967.81 3,241.85 6,019,009.03 564,996.27 1.78 5,098.67 2_MWD+IFR2+MS+Sag(4) 9,290.34 86.98 294.07 4,394.81 4,346.63 2,993.24 3,300.12 6,019,033.91 564,937.76 1.55 5,162.23 2_MWD+IFR2+MS+Sag (4) 9,354.41 86.05 293.93 4,398.70 4,350.52 3,019.25 3,358.55 6,019,059.38 564,879.11 1.47 5,226.17 2_MWD+IFR2+MS+Sag (4) 9,418.47 85.12 294.59 4,403.63 4,355.45 3,045.49 3,416.77 6,019,085.07 564,820.64 1.78 5,290.04 2_MWD+IFR2+MS+Sag(4) 9,481.87 86.18 294.85 4,408.44 4,360.26 3,071.93 3,474.20 6,019,110.97 564,762.98 1.72 5,353.25 2_MWD+IFR2+MS+Sag(4) 9,545.31 87.04 294.15 4,412.19 4,364.01 3,098.19 3,531.82 6,019,136.69 564,705.12 1.75 5,416.58 2_MWD+IFR2+MS+Sag(4) 9,608.85 86.61 292.32 4,415.71 4,367.53 3,123.21 3,590.12 6,019,161.18 564,646.60 2.95 5,479.99 2_MWD+IFR2+MS+Sag(4) 9,673.23 87.29 291.93 4,419.14 4,370.96 3,147.43 3,649.67 6,019,184.83 564,586.83 1.22 5,544.19 2_MWD+IFR2+MS+Sag (4) 9,735.53 87.41 293.10 4,422.02 4,373.84 3,171.26 3,707.16 6,019,208.12 564,529.13 1.89 5,606.37 2_MWD+IFR2+MS+Sag(4) 9,799.62 87.66 294.29 4,424.77 4,376.59 3,196.99 3,765.79 6,019,233.31 564,470.26 1.90 5,670.38 2_MWD+IFR2+MS+Sag(4) 9,864.66 89.89 294.94 4,426.16 4,377.98 3,224.07 3,824.91 6,019,259.84 564,410.91 3.57 5,735.40 2_MWD+IFR2+MS+Sag(4) 9,928.20 92.11 294.93 4,425.06 4,376.88 3,250.85 3,882.51 6,019,286.08 564,353.06 3.49 5,798.93 2_MWD+IFR2+MS+Sag (4) 9,991.84 92.98 294.16 4,422.23 4,374.05 3,277.26 4,940.34 6,019,311.95 564,294.99 1.82 5,862.50 2_MWD+IFR2+MS+Sag (4) 10,055.78 91.17 293.43 4,419.91 4,371.73 3,303.04 3,998.80 6,019,337.18 564,236.30 3.05 5,926.38 2_MWD+IFR2+MS+Sag(4) 10,114.07 91.37 292.99 4,418.62 4,370.44 3,326.01 -5,052.36 6,019,359.65 564,182.53 0.83 5,984.63 2_MWD+IFR2+MS+Sag (4) 10,183.03 91.74 292.78 4,416.75 4,368.57 3,352.82 5,115.87 6,019,385.86 564,118.79 0.62 6,053.52 2_MWD+IFR2+MS+Sag (4) 10,26800 91.74 292.78 4,414.17 4,365.99 3,385.70 -5,194.18 6,019,418.01 564,040.18 0.00 6,138.38 PROJECTEDto TD Checked By: Chelsea WrightApproved By: Mitch Laird - - • Date: 06-04-2019 674/2019 6:01:49PM Page 6 COMPASS 5000.15 Build 91 MilcorP Energy Company CASING & CEMENTING REPORT Lease S Well No. MP E-38 Date Run 22 -May -19 County Stale Alaska Sup, S Barber l C Montague CASING RECORD can:a To 5.787.00 Shoe Dubb 5.780.00 PBTD: Cag Wt On Hook: 252 Type Float Collar Conventional No. Him to Run: Casing (Or Liner) Detail Dag W9, On Slips: 100 Type of Shoe: BWlman Setting Depths ins. Component Size WI. Grade THD Make Length Bottom Top _Yes No Shoe 103/4 40.0 L-80 BTC yjayinholeSolutic 1.58 5,761.13 5,759.55 2 Casln 95/8 40.0 L-80 TXP BTC ]9.0] 5,759.55 5,680.48 Float Collar 103/4 BTC wnhole Solutic 1.29 5,680.48 5,618.06 1 Casing 95/8 40.0 L-80 UP BTC 39.95 5,679.19 5,639.24 Baffle Ada ter 103/4 L-80 UP BTC Halliburton 1.47 5,639.24 5,63].77 92 Casing 95/8 40.0 L-80 Up BTC 3,621.84 5,637.77 2,015.93 Pup Joint 95/8 40.0 L-80 UP BTC 13.99 2,015.93 2,001.94 ESICP 30 UP BTC Halliburton 11.89 2,001.94 1,990.05 Pup Joint 95/8 40.0 L-80 UP BTC 12.85 1,990.05 1,9]].20 48 Casio 95/8 40.0 L-80 UP BTC1,939.31 1,9]].20 37.89 CutJoint 95/8 40.0 L-80 UP BTC 12.50 3].89 25.39 Cag Wt On Hook: 252 Type Float Collar Conventional No. Him to Run: 17.5 Dag W9, On Slips: 100 Type of Shoe: BWlman Casing Crew WwNerfoN Rotate Csg X Yes No Reap Csg X Yes No 50 Ft. Min. 9.3 PPG Fluid Description: Said Mud Sacks: $24 yield _ siy, foot) 12 Liner hanger Info(MakelMode0: Liner top PackeR: _Yes No Liner hanger teal pressure: A Used To Determine TOC: Realms Ross, Held X Yes No Centralizer Placement 2 on joint 1 Volume pumped(BBLs) 80 Mixing l Pumping Rate (bpm): Flusb(Spacer) 1 every joint to 47W c Whler Density (ppg) 1 every other joint to 374T 1 every joint 5 joints, and 2 pup joints before and after stage calar(2211'-181 Of 1 every one, joint hem ISIT to 2" CEMENTING REPORT Shoe@ 5760 FC@ 5,678.06 Top of Liner III lush (Spacer) dei): 899 Pump used for lisp. Rig .. Clean Spacer Density(on) to Volume pumped(BBLa) I Slurry Yes No % Returns during jab 11 Type 1111 Spacerretwil? Sacks: $24 yield _ siy, foot) 12 Volume pumped(BBts) 220 Mixing/ Pumping Rate(bpm): Sorry, 1,900 A Used To Determine TOC: Realms i. Glass G Sacks: 388 Yield: sity(ppg) 15.8 Volume pumped(BBLs) 80 Mixing l Pumping Rate (bpm): Flusb(Spacer) c Whler Density (ppg) B4 Rate (bpm): 5 Volume: Spud Mud Density(ppg) 9.3 Rate (bpm): 3 Volume (actual I calculated): 41E dei): 899 Pump used for lisp. Rig Bump Plug? X Yes No Bump press ig Rotated? X Yes No Reciprocated? X Yes No % Returns during jab 11 ant returns to surface? X as _No Spacerretwil? X Yes No Vol to Surf, 25 mt In Piece At 19:48 Date: 51222019 Estimatetl TOC: 1,900 A Used To Determine TOC: Realms Stage Collar® 1908.92 Type ESICP Closure OK Y reflush(Spacer) ype: Clean Spacer Density (ppg) 10 Volume pumped (BBLs) L Sacks: 401 Yield'. 10.7 Volume pumped(BBLs) 315 Mixing l Pumping Rate (bpm) Class G Sacks: 240 Yield ity(ppg) 15.8 Volume pump.d(BBLs) 50 Midng l Pumping Rate(bpm): Flush (Spacer) Water Densiy(ppg) 8A Rate(bpm): 20 Volume: Spud Mud Oensity(ppg) 9.4 Rate(bpm): 3 Volume (actual /calculated): 13: ;psi)'. 890 Pump used far dap Rig Bump Plug? X Yes No Burry press ig Rotated? _Yes X No Recipmeatetl? _Yea X No % Returns during job 1 :nt returns to surface] X Yes _No Spacer returns? X Yes _No Vol WSurf 22] :ntln Place At 7:35 Date: 5QM019 Es9mated TOC: 4 ttl Us" To Determine TOC: Retums Calculated Cmt Vol a 0% excess: WAS Total Volume cm Pumped: WS Cort returned w surface: 252 Calculated cement left in wellbore: 413 OH volume Calculated. 340.1 OH volume actual: 403.65 Actual%Washout 101 WELLHEAD Make Cameron Type SSH Serial No. Size 11 W.P. 5000 Test head to 5000 P51G 35 MIN Yes OF Remarks: LLC MPU E-38 OH Sidetrack Summary PBI PB2 TD 7,178' MD / 4,411' TVD 10,268' MD / 4,414' TVD KOP 6,840' MD 8,700' MD Date 5/27/2019 5/28/2019 PTD: 219-052 / API: 50-029-23629-00-00 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU E-38 Hilcorp Alaska, LLC Permit to Drill Number: 219-052 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w -aogcc.alaska.gov Surface Location: 3543' FSL, 1881' FEL, SEC. 25, TUN, R10E, UM, AK Bottomhole Location: 1351' FNL, 1533' FEL, SEC. 22, RIOE, 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, J sie�elowski Commissioner DATED this I I day of April, 2019. 4 STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMMI ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED APR 0 3 2019 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas Service - WAG ❑ Service - Disp ❑ 1 c. Speci e o dor: Drill ❑� Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj ❑� Single Zone ❑� Coalbed as as ydrates ❑ 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-38 3. Address: 6. Proposed Depth: - 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 MD: 15,789' TVD: 4,470' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3543' FSL, 1881' FEL, Sec 25, T13N, R10E, UM, AK ADL025518, ADL047437, ADL025516• 04 5A )JD Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 269' FNL, 2507' FWL, Sec 25, T13N, R10E, UM, AK LONS 94-017 5/5/2019 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1351' FNL, 1533' FEL, Sec 22, T13N, R10E, UM, AK 6400 9724' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 48.3' 15. Distance to Nearest Well Open Surface: x-569265 y- 6016081 1 Zone -4 GL / BF Elevation above MSL (ft): 21.8' to Same Pool: 120' to MPE-13B 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94.4 degrees Downhole: 1959 1 Surface: 1513 r 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 42" 20" 215# X-42 Weld 107' Surface Surface 107' 107' ±270 0 Sig 1 L - 834 ft3 / T- 458 ft3 12-1/4" 9-5/8" 40# L-80 TXP 5,548' Surface Surface 5,548' 4,450' Stg 2 L - 1937 ft3 / T - 314 43 ieback 3-1/2" 9.3# L-80 EUE 5,400' Surface Surface 5,400' 4,437' Tieback Assy. 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 10,389' 5,400' 4,437' 15,789' 4,470' Cementless Injection Liner w/ ICDs 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑� 20. Attachments: Property Plat a BOP Sketch Drilling Program Time v. Depth Plot v Shallow Hazard Analysis Diverter Sketch e Seabed Report e Drilling Fluid Program e 20 AAC 25.050 requirements e 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: 'eft el hIICOf .COfD Authorized Title: Drilling Manager - Contact Phone: 777-8395 Authorized Signatu — Date: F- –5. Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number:9. + 0 O 50- 02 —,),3 �a a l—OO•'O� Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: 300,E O S - 6L f' Samples req'd: Yes ❑ No [� Mud log req'd: Yes ❑ No [� /+ HzS measures: Yes ❑ No Directional svy req'd: Yes []� No,❑,/ WeJ( -to /+e_ �V/�/y-e Spacing r[V]y� exception req'd: Yes Ll No [2' Inclination -only svy req'd: Yes E] NoE 'j �"�,� /•��"(j� aC C a VwAAtZ:. U, h 7"n 1V Post initial injection MIT req'd: Yes No❑ ""t APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: p � etft • v p (g) SutinSB Fo Land Form 10-4 1 Revised 5/2017 This permit is valid for 24 t ff oval per 20 AAC 25.005 Attachments in Duplicate a (� • � • fA • o a o v o 0 ry 3a ry c p xOF 3� v vii 3a c A c v Y'a E c E p ri d a v c a w m< a< v y v m u`t u't p p w °- O1 v nc M 3 v- `m n m c m c u m 2 D - u n a<\ >= E c np!+ « v m v- v '° o c v v o N - a N m _ a N n < z a w> a N w- > z z '� v b �d Y o E `v v m ry o py o py of do r M ad ¢or v v I E c� oin 1O °ip .any � as E v v v w o E Y Eo �^ c o �nvu� a b 'C ca `� v`t c 0 Np 0 O a of p N m 'twn 'tmna.'no N v v v nE v : u mn y v v dE c E m o'in m m @J vi� vi wI `� E n u �'t nia u u ww c a0 N na - a0 < i�nr m c Q a .v.O 6 vi` r u N "oi r c p a a c a a c c o a a a a a a y v v v v v v v. v v v v v v 'o 0 0 n o o n n = o o O o 0 0 t u� U U V U U 00 U U U U U U N 6 0 a d o a m a :• N < < o u io m in in E z z N N V' fA N N M V V m V b N V O N v N WS N m < u1 N << O O V Ol ilf vl H E t `t Z m o z z I fG V V1 17 M M V1 V N N V 01 OI V j sf N N fV VI M UI I� b b M zo N n CM d' VI V W It M 10 M N O b l0 O] CO N N o< O v 6 a' s r •m^ p 0a w V v W( in a ti n m n w n io m io O io b ry o v `n o Ln n io Lq m o in .y m a b b b p O v o ad vi a vi vi 6 vi v o 0 H h 3 a m a o a o >> ti 3 a a a ;o a a O a n m o m O n Y � N 6 > Y 6 > Y ✓1 ✓1 y N ti m ti M <J O M T O O O O •"� J ti J d LL d Lb d dLL LL d w d d < 1 d U U 0 0 0 0 0 d0d o 0 g q $ o q 0 0 6? T 0o 0 0 0 4 4 4 4 4 0 6 O+ V1 V1 n n V1 b M b M W O'J w 0 O O 0 a N N N N N N N N N N N N M N N N fl N O N O N O N M N T N 01 OI Of OI Ol 01 01 Ol N 01 01 O1 01 Ol R N O N O N O N O N O N O N O N O N O N O N O N O N O o d d d d cc d d d d d d d vl N V1 VI Vf vl Vf vl ul In ul 1n V1 vl tD b V N n < N O] n O N O1 N O N b V O V O M O Vf O Vf N •-I O a O O N 0 O O n Q N N O 4 4 N 1� n V M O] N M O N m O N 01 Ot e4 O N N N Ol rl W w .Y n N fi � W N O 0 N O o N Hilcorp Alaska, LLC Milne Point Unit (MPU) E-38 Drilling Program Version 1 4/2/2019 Table of Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic..........................................................................................................6 7.0 Drilling / Completion Summary.....................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 R/U and Preparatory Work..........................................................................................................10 10.0 NIU 13-5/8" 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 N/U and Test.........................................................................................................................26 15.0 Drill 8-1/2" Hole Section...............................................................................................................27 16.0 Run 4-1/2" Injection Liner (Lower Completion)........................................................................32 17.0 Run 3-1/2" Tubing (Upper Completion).....................................................................................37 18.0 RDMO............................................................................................................................................39 19.0 Innovation Rig Diverter Schematic.............................................................................................40 20.0 Innovation Rig BOP Schematic....................................................................................................41 21.0 Wellhead Schematic......................................................................................................................42 22.0 Days Vs Depth................................................................................................................................43 23.0 Formation Tops & Information...................................................................................................44 24.0 Anticipated Drilling Hazards.......................................................................................................45 25.0 Innovation Rig Layout..................................................................................................................48 26.0 FIT Procedure................................................................................................................................49 27.0 Innovation Rig Choke Manifold Schematic................................................................................50 28.0 Casing Design.................................................................................................................................51 29.0 8-1/2" Hole Section MASP............................................................................................................52 30.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................53 31.0 Surface Plat (As Built) (NAD 27).................................................................................................54 32.0 Schrader Bluff OA Sand Offset MW vs TVD Chart..................................................................55 33.0 Drill Pipe Information 5" 19.5# 5-135 DS -50 & NC50...............................................................56 H Hilcrp �� X22 1.0 Well Summary Milne Point Unit E-38 SB Injector Drilling Procedure Well MPU E-38 Pad Milne Point "E" Pad Planned Completion Type 3-1/2" Injection Tubing Target Reservoir(s) Schrader Bluff OA Sand Directional Plan WP09 Planned Well TD, MD / TVD 15,789' MD / 4,470' TVD PBTD, MD / TVD 15,784' MD / 4,470' TVD Surface Location (Governmental) 3543' FSL, 1881' FEL, Sec 25, T13N, R10E, UM, AK Surface Location AD 27 X= 569,265. 1, Y= 6,016,081.0 Top of Productive Horizon (Governmental) 269' FNL, 2507' FWL, Sec 25, T13N, R10E, UM, AK TPH Location INAD 27) X= 568,359.9 Y= 6,017,540.0 BHL (Governmental) 1351' FNL, 1533' FEL, Sec 22, T13N, R1 OE, UM, AK BHL AD 27 X= 559,000.6 Y=6,021,657.6 AFE Number 1813046 AFE Drilling Das 20 days AFE Completion Das 4 days AFE Drilling Amount $4,333,732 AFE Completion Amount $1,455,427 AFE Facility Amount $591,000 Maximum Anticipated Pressure (Surface) 1513 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1959 psig Work String 5" 19.5# 5-135 DS -50 & NC 50 KB Elevation above MSL: 26.5 ft + 21.8 ft = 48.3 ft GL Elevation above MSL: 21.8 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure 2.0 Management of Change Information Hilcorp Alaska, LLC xilcotp Changes to Approved Permit to Drill Date: 412/2019 1 Subject: Changes to Approved Permit to Drill for MPU E-38 File #: MPU E-38 Drilling and Completion Program Any modifications to MPU E-38 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the AOGCC. Approval Drilling Manager Prepared: Drilling Engineer Page 3 Date Date By H xilcorp [Dopy co�v+�r 3.0 Tubular Program: Milne Point Unit E-38 SB Injector Drilling Procedure 4.0 Drill Pipe Information: AMe `( (in) TJ ID TJ OD Wt m a conn MAJ M/U Tension Section . in in .- #/ft Min Max (k -lbs) Surface& 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560klb Production 5" 4.276" 3.25" 6.625" 19.5 S-135 NC50 31,032 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 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, mmyersghilcorp, ieneel@hilcorp.com and cdingerr@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 mm, ers a hilcoM,com ieneel@hilcorpcom and cdingerna hilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hilcoEp.com iengeighilcorp.com and cdinger@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Milne Point Unit Work Phone Cell Phone E-38 SB Injector Drilling Manager Hilcorp Evmgy Compuy Drilling Procedure 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, mmyersghilcorp, ieneel@hilcorp.com and cdingerr@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 mm, ers a hilcoM,com ieneel@hilcorpcom and cdingerna hilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hilcoEp.com iengeighilcorp.com and cdinger@hilcorp.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 mmVers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 leneel@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 kflemine@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 caiones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdineer hilcorp.com Page 5 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure o=w , 6.0 Planned Wellbore Schematic 1 MT KB FSVabv MS- 9' Milne Point Unit Well: MPU E-38 Proposed Schematic PTD: TSD API: TBD TREE ✓§ WELLHEAD Tree I Cameron 3IA6' SLI / 3-1116' SM C.I. Win Wellhead Camemn 117SKx bevw..1121 2-L3O.5X cues OPEN HOLE/ CEMENT DETAIL 42" 1 -2M h3 >2-114" 1 ft3 Tall Top I Stgg2 1- 937 fUl ad/316 h3Td SPF •9n eeeon Liner m a-IfT We CASING DETAIL SIE, Type I WW Qrade/CO DrdilD Top I SM SPF 20' C rxlc N/A/X-52/Weld I IVA saA 107• NIA 9-5/9• 5 rfaee I W/L-80/TXP 1 8.75' 1Surtam sw 00758 8-11Y I Liner I13.51190 /UPA625I 3215" I SSAW 15,777 0.0149 TUBING DETAIL 3-112' 1 7.F..m 1 9.2 1 490 I NC 1 2.99Y 1 Surf I 15,400 Q0152 WELL INCLINATION DETAIL GENERAL WELL INFO 2W APICTB0 —1 1de n8le=90.0 ACo leted b, Inn wl. Future JEWELRY DETAIL N0 Top MO Nem ID upper comp a ,on 1 12.SOP x Nook 2.813 2 IS= XNNi a Mfik:1725"Now12EI3Paakm Bare 2]25 3 1 15,395' I8.25'No Ga bmteran Te:back 4 -1"Parted 5.19lem1 1992 d 1 150.00 I Tiebak Sloe 6.1Bd Laver wr4mian 8 s5,40O Nner Tm Packer FVD=6ASa - S 15774' Y BaC an Closed PBr0 - OWN 0.1m Np/ypn ft'.. Pmo MP U rnn TD=157&P"N/TD=4,40. VVDJ PaM=15,7W (No /PBTD=4,4O. 'rM1] Page 6 � gwx P«k� L,✓ IC D 00 4,u/las H Hilcorp 7.0 Drilling / Completion Summary MPU E-38 is a Grassroots iniector planned to be drilled program targeting the on Milne Point Unit E-38 SB Injector Drilling Procedure E-38 is part of an The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. An 8.5" lateral section will then be drilled. A 4-1/2" ICD iniection 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 May 5th, 2019, pending rig schedule. Surface casing will be run to 5,548' MD / 4,450 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 3-1/2" 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 H Hilcorp E� 2,T Milne Point Unit E-38 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-38. 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,/low 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" p r 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 U Hilcrp �� X22_ Summary of BOP Equipment and Test Requirements Milne Point Unit E-38 SB Injector Drilling Procedure 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 him cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" 13-5/8" x 51M 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, 3,000 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.reag@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: gu.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(2alaska.gov Primary Contact for Opportunity to witness: AOGCC.Insl2ectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/o%zc/forms/TestWit!2essNotif.html Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure Earp Camgoy 9.0 R/U and Preparatory Work 9.1 E-38 will utilize a newly set 20" conductor on E Pad Expansion. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4" nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Innovation Rig. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<800F). 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Ensure 5" liners in mud pumps. • White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 381 gpm @ 140 spm @ 96.5% volumetric efficiency. Page 10 H Hilcorp M �= 10.0 N/U 13-5/8" 5M Diverter Configuration Milne Point Unit E-38 SB Injector Drilling Procedure 10.1 N/U 13-5/8" CTI BOP stack in diverter configuration (Diverter Schematic attached to program). • N/U 20" x 13-5/8" DSA • N/U 13 5/8", 5M diverter "T". • NU Knife gate & 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). • Diverter line must be 75 ft from nearest ignition source • Place drip berm at the end of diverter line. • Utilized extensions if needed. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the 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 11 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure � Eo—r 10.5 Rig & Diverter Orientation: *Orientation may differ on location 75' Radius Clear of litnItion Sources Diverter Line MPU E Pad Expansion * Drawing Not To Scale Diverter Line May Be Oriented Different On Location Page 12 25 ■ ■ 21 11 ■ ■ 7 18 ■ ■ 16 20 ■ ■ 23 24 ■ ■ 19 14 ■ ' 12 3 15 ■ 17 E-38 15 E-38 E-37 — E-36 E-41 E-35 75' Radius Clear of litnItion Sources Diverter Line MPU E Pad Expansion * Drawing Not To Scale Diverter Line May Be Oriented Different On Location Page 12 Milne Point Unit E-38 SB Injector HilMT�y Drilling Procedure E -W Comryey 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub for wireline gyro • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135. • Run a solid float in the surface hole section. 11.2 5" Drill string, HWDP, and Jars will come from Weatherford. 11.3 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 11.4 Drill 12-1/4" hole section to section TD, in the Schrader OA sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. • Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. J• Gas hydrates have been encountered on E -Pad, typically around 2100-2400' TVD (fust 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 UC21T 11.5 Milne Point Unit E-38 SB 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. 12-1/4" hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ Depth Interval MW g) 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 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). Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure Gey Ca T System Type: 8.8 — 9.8 ppg Pre -Hydrated Aquagel/freshwater spud mud PYff Y1PYtIPG' ^`� Section ZrDensity Concentration viscoslt7y Plastic Viscosit Yield Point API FL PH Tem Surface 8.8 - 9.8 11 75-175 1 20-40 25-45 <10 1 8.5 - 9.0 1 <_ 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 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. 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 Milne Point Unit — 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 E-38 SB Injector Float Collar w/ Stage Cementer Bypass Baffle 'Top Hat' Hilcorp � �21T Drilling Procedure 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120' shoe track assembly consisting of: 9-5/8" Float Shoe 1 joint — 9-5/8" DWC, 2 Centralizers 10' from each end w/ stop rings 1 joint — 9-5/8" DWC, 1 Centralizer mid joint w/ stop ring 9-5/8" Float Collar w/ Stage Cementer Bypass Baffle 'Top Hat' 1 joint — 9-5/8" DWC, 1 Centralizer mid joint with stop ring 9-5/8" HES Baffle Adaptor • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 16 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure SRV Cmr 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part 50 No. Closing Sleeve No. Shear Pins Doming Sleeve Vo. Shear Pins ES Cementer Depth Baffle Adapter (ff used) WT ID Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole TD "Reference Casing Sales Manual sec 5 Page 17 »A Racpp FS -R Rumim nraer Part No. Omall Length B She oft plug Mo, ID Ager Dritlom C OD Max. Twl OD D OD LL Openig Seat ID E Shut-off Plug Closing Seat ID Plug Set Racpp FS -R Rumim nraer Part No. ES -11 Cementer SO No. She oft plug Closing Plug OD Opening Plug OD LL OD Shut-off Plug OD Bypass Plug lit used) OD l Racpp FS -R Rumim nraer ES -11 Cementer She oft plug Baffle Adapter By -Pass Piu, LL Br Pas: R.M. Float Collar, Float Shoe l Milne Point Unit E-38 SB Injector Hilco Drilling Procedure X22 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 Ugnu water sand for isolation with Geologist • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES -II Stage tool so that it is positioned at least 100' TVD below the permafrost (— 2,500' MD). (Halliburton ESIPC with packer element may be used). • Install centralizers over couplings on 5 joints below and 10 joints above stage tool. ��J _ iy • 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. �/��n • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to yy open at — 3000 psi. Reference ESIPC Procedure. 9-5/81140# L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Depth Interval Centralization Shoe— 1000' Above Shoe 1/jt 1000' above Shoe — 2000' above Shoe k2k (Top of Ugnu) Page 18 H Hilcotp �Z= TXP ,BTC outside Diameter 96251n. Wall Thickness 0.395 in. Grade LBOTypet- R&h. Wall 97.5% Thickness Connection 00 Option REGULAR Connection OD REGULAR Option 19 Band: Red Drift API Star lard Type Casing Milne Point Unit E-38 SB Injector Drilling Procedure -- 111082018 I -) Grade LBO ow Type 1 Connection 00 Option REGULAR COUPLING PNEeODY 2ody: Red 19 Band: Red 1st Bard: crown 21,d Band: 2nd Bard: - an. ani band: - 3ni Sand: - Ibs 41h Sand - GEOMETRY Thhe . per m 5 Connection 00 Option REGULAR PERFORMANCE Nominal 00 Nominal ID 9.625 in. 8.835 in NominW Might Wal Thickness 40 93t9 0395. Ods Faln End Might 167S.. 38.9710.'9 00 Ta6ance API PERFORMANCE Body Yed Stwrth 916.1000¢. 1rremal Yx 5750 psi SPAYS 80000 psi cow.. 3090 W GEOMETRY Cot,,, h" OD 10.625 in. Coupling Length 10.825 n. Coonec5on ID BAA to hake -up Lias 41.891 in. Thhe . per m 5 Connection 00 Option REGULAR PERFORMANCE Tension SlFaenry 100.0% Jmnl Ys Sl qth 916000x1000 Intro Fre mCapuyol 5750.000 psi Ibs Compmssion=_ffciency 100-A Compression Strenglh 916.000.1000 fits.. A8owable Bending 33 Acaft Ibs Emtnal P.. Capacity 3090.000 psi MAKE-UP TORQUES —71 Minimum 18860 ft -±t., Opunum 20959E -Ica 23OSO hJbs OPERATION LIMB TORQUES Opmmg Tm" 35600 ft -k, Yield Torque A341N h-Ibs Notes This connection is fully interchangeable with: TXPS BTC - 9.625 in - 36143.5147 / 53.5 / 58.4 lbslfl [t] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5031 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 Tenaris technical sales representative. Page 19 Milne Point Unit E-38 SB Injector Drilling Procedure 12.8 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10' from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 20 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 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 1St stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 11' Stage Total Cement Volume: `1 Section Milne Point Unit Vol (bbl) Vol (ft3) E-38 SB Injector Hilcorp Ems C mOmY Drilling Procedure 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 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 1St stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail, TOC brought to stage tool. Estimated 11' Stage Total Cement Volume: `1 Page 21 Iq3 31"^ Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" a (4,548'- 2500') x .0558 bpf x 1.3 = 148.6 834 j Casing Total Lead 148.6 834 12-1/4" OH x 9-5/8" (5,548'- 4,548') x.0558 bpf x 1.3 = 72.5 407 Casing ~ 9-5/8" Shoe Track 120'x .0758 bpf = 9.1 51.09 Total Tail 81.6 458 Page 21 Iq3 31"^ n Hil UM Milne Point Unit E-38 SB Injector Drilling Procedure Cement Slurry Design (11' 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: 5,428' x.0758 bpf = 411.4 bbls Voles 40 bbls of weighted spacer or water to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 Lead Slurry Tail Slurry System ExtendaCEM TM 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: 5,428' x.0758 bpf = 411.4 bbls Voles 40 bbls of weighted spacer or water to be left behind stage tool, confirm fluid is compatible with cement behind stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. Page 22 Milne Point Unit E-38 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 Second Stage Surface Cement Job: Milne Point Unit E-38 SB Injector Drilling Procedure 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. (If ESIPC is used and packer element inflated, CBU x minimum before pumping second stage). Hold pre job safety meeting. 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump curt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2n1 Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) SwiftCEM'm System (Hal Cem) 20" Conductor 9-5/8" Casing (110') x.26 bpf x 1= 28.6 161 v v 12-1/4" OH x 9-5/8" Casing (2000'- 110') x.0558 bpf x 3 = 316.4 1776.3 J Total Lead 345 1937 12-1/4" OH x 9-5/8" Casing (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'm 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 Envy Comp.oy Milne Point Unit E-38 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 retums 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 duringjob, if intermittent note timing during pumping ofjob. 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" casingtally & casing and cement report to iengd@hilcorp.com and cdinzer@hilcorp com This will be included with the EOW documentation that goes to the AOGCC. Page 25 H Hilcorp 14.0 BOP N/U and Test Milne Point Unit E-38 SB Injector Drilling Procedure 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 f 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. l/ Page 26 H Hilcorp E=W Campu�Y 15.0 Drill 8-1/2" Hole Section 15.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.220 PDM) Milne Point Unit E-38 SB Injector Drilling Procedure 15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool or ESIPC. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 R/U and test casing to 2500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC reg is 50% of burst = 6870 / 2 = —3500 psi, but max test pressure on the well is �4 i� 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and V �qvt volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20' of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume retumed. 15.8 POOH & LD Cleanout BHA 15.9 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# 5-135 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 Milne Point Unit E-38 SB Injector Drilling Procedure • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter sufficient hole 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 De Isity Yield Point Total Solids MBT HPHT Production 1 8.9-9.5 J 1 15-25 20-25 <10% <7 <11.0 System Formu-r 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 n Hilc Eorp W C!a Milne Point Unit E-38 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 OA Concretions: 5-10% of lateral • Abnormal Pressure may be seen on E-38 as we drill the lateral. Monitor pressure on connections with MPD if necessary • A/C: • C-41 is a close approach at 13,100 — 14,150. C-41 lateral is abandoned and fully cemented. • E -13B is a close approach at 10,523 — 10,618. E -13B is a long term S/I SB vertical Injector. 8.4 ppg EMW from BHSP 2/20/2018. Monitor MWD surveys for magnetic interference. 15.15 Reference: Open hole sidetracking practice: • If a known fault is coming up, put a slight "kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the onenhole sidetrack is achieved. Page 29 Milne Point Unit E-38 SB Injector Drilling Procedure 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 (x3 350ml samples passing through the screen in the same amount of time which will indicate no plugging of the screen). Reference PST Test Procedure • Injection Control Devices (ICDs) are wire wrapped, and require passing PST with 250µ Coupons • Circulate and condition mud as much as needed to pass the production screen test • If not passing after first test, call Completion Engineer 15.18 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (385 gpm max). • Rotate at maximum rpm that can be sustained. • Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). • If backreaming operations are commenced, continue backreaming to the shoe • 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 (x3 350ml samples passing through the screen in the same amount of time which will indicate no plugging of the screen). Reference PST Test Procedure • 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 • If MPD has been used to offset pressure on BROOH, spot KWF in the surface casing 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-38 SB Injector Hilcorp Drilling Procedure E. ��> Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted Page 31 H Hilcorp U� 16.0 Run 4-1/2" Injection Liner (Lower Completion) Milne Point Unit E-38 SB Injector Drilling Procedure 16.1. Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2" liner with ICD and swell packers, the following well control response procedure will be followed: • With ICD across the BOP: P/U & M/U the 5" safety joint (with 4-1/2" crossover installed on bottom, TIW valve in open position on top, 4-1/2" handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 4-1/2" liner. • With 4-1/2" solid joint across BOP: Slack off and position the 4-1/2" solid joint to MU the TIW valve. Shut in ram or annular on 4-1/2" solid joint. Close TIW valve. 16.2. Confirm VBR have been tested on 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" han mg bove 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 M/U to FOSV. • Ensure the liner has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 16.5. Run 4-1/2" injection liner. • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. Thread compound can plug the ICDs. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Use lift nubbins and stabbing guides for the liner run. • Fill 4-'/2" 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 ±40' • 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. Page 32 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure • 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 Maximum=Yieldorque Operating Tor ue 4.5" 8,000 ft -lbs 9,600 ft -lbs 12,800 ft -lbs 15,000 ft -lbs Page 33 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure tKao��, For the latest performance data. always visit our website: www.tenaris.com Wedge 625© ..,....1uo4non Oobide Diameter 1500 n. Min. Wall 97.5% sMYS BOOM psi tallaFde 8510 psi Thickness (i) Grade L00 CONNECTION DATA Type 1 Wall Tli&...s 0290 r.. Conmohon OD REGULAR COUPLING OPEBODY Connecdon OD 4.714 in. Oplidn 3.00h Makeup Loan 1.830 n. Threademin 3.59 cavi. OD 09. REGULAR Body Red ist Band: Red Grade LBO Type 1- Drift API Standard let Band: Grown 2nd Band: I 91.0 n Jam VUM sannipt 279370. t DDD 2nd Barb-- Brorn T'. casing 3N Band: - 3N Band. - CPrrprteslon Efteni BIDS % Congression sorpN 290.115AIDDo Max adirnable Rending 4n Band. - PIPE BODY DATA GEOMETRY NPminal OD 4300 h Nom+na Wnyo 1350 Ill Drill 3795 in Nominal ID 3820 n. lNaOThniness 0290 n. Ran End Weilbt 13.054tsYt W TmEeare API PERFORMANCE Body Yesa sereno 307.1000 Ws Inlema Yield 9020 psi sMYS BOOM psi tallaFde 8510 psi CONNECTION DATA GEOMETRY Connecdon OD 4.714 in. CannecCm lD 3.00h Makeup Loan 1.830 n. Threademin 3.59 cavi. OD 09. REGULAR PERFORMANCE Tenrim Efo 91.0 n Jam VUM sannipt 279370. t DDD Irama Fnni.re Capao!y 9020 COD psi lbs CPrrprteslon Efteni BIDS % Congression sorpN 290.115AIDDo Max adirnable Rending 73.7'11 D5 Ib5 Edenal Pressure capadty asm.wDgu MAKE-UP TORQUES Minimum 0010khs G}.e. 9100Nbe M.. 12M Nbe OPERATION LIMIT TORQUES eperavq Tu . ima Nbs Yie1LTagae 15010 k4bs Notes For further information on concepts indicated in this datasheet download the Datasheet Manual from www to lans.001711 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" 4.7 4/ft inner string. Page 34 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure o E -217 16.8. Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.9. M/U Baker SLZXP liner top packer to inner string and 4-1/2" liner. Fill liner tieback sleeve with "Pal mix", ensure mixture is thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 16.10. Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.11. RIH w/ liner on DP no faster than 30 ft/min — this is to prevent buckling the liner and drill string. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. 16.12. The liner and inner string will prevent the DP from auto filling. Fill DP every 5 stands, more frequently if SOW trend indicates. 16.13. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 16.14. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.15. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.16. Rig up to pump down the work string with the rig pumps. 16.17. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 16.18. Rig up to pump down the work string with the rig pumps. 16.19. Break circulation and begin displacing wellbore to —9.2 ppg KCl/NaCl (adjust brine weight if needed). Note the large OD on the ICDs. Begin circulating at —1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. 16.20. Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the ICDs. Note all losses. Catch mud for future use if feasible. 16.21. Monitor the returned fluids carefully and when no more filter cake appears at the shaker begin pumping SAPP pill. 16.22. Mix and pump 3 tandem 40 bbl 10 ppb SAPP pills (120 bbl total SAPP pill) with 100 bbl in between. Keep circulation rate low to keep from packing off around the ICDs. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Page 35 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure ear comp.or 16.23. Repeat pumping SAPP pills as needed until the wellbore is clean. 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 36 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure Ercrp Compeoy 17.0 Run 3-1/2" Tubing (Upper Completion) 17.1 NqI& 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 tc wrivard@hileorp.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-'/2" EUE 8RND x NC -50 crossover is on rig floor and M/TJ 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-%" 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-'/z" 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-'/2" 9.3# EUE 8RND space out pups • 1 joint 3-%" 9.3# EUE 8RND tubing • Tubing hanger with 3-1/2" EUE 8RND pin down Page 37 Milne Point Unit E-38 SB Injector Drilling Procedure 0I llw. V_ 45n2 Tubing Specification Sheet 3-112, 9.30#, L80, EUE 8RD, R2 GD, 3.500 in Connection: 3-112" EDE 8RD ID. 2.992 In - Coupling OD: 4.500 In Wolght: 9.30 1bs/R Tod Joint ID: 2.992 in Grade: L80 Drift: 2.897 in Tube Wall: 0.254 in Connection I Tool Joint Performance Tubing Length, R2 Thread Compound Friction Factor. 110 Inspection Class: Maximum MUT: „._..�- 4.000 R -lbs....._--- - RISM 0.203 in Opdmal MUT: 3,200 ft -lbs —. - -- -- Tube Tensile: 163,178 tbs Minimum MUT: 2,400 ft -lbs Tube Collapse: 7,399 psi Tube Internal Burst9,289 psi Tubing Assembly Displacement Estimate: 0.00339 bbis/fl Capacity Estimate: 0.00870 bblslft (Ineludps Tool Joints) 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 1% corrosion inhibitor. 17.8 Freeze protect the tubing and IA to 3000' MD 17.9 Land hanger. RILDs and test hanger. Page 38 H Hilcorp Milne Point Unit E-38 SB Injector Drilling Procedure 17.10 Continue pressurizing the annulus to 2,000 psi and test for 30 charted minutes. / kt lam— C� i. Note this test must be witnessed by the AOGCC representative. 17.11 Set BPV, ensure new body seals are installed each time. ND BOPE and NU adapter flange and tree. 17.12 Pull BPV. Set TWC. Test tree to 5000 psi. 17.13 Pull TWC. Set BPV. Bullhead tubing freeze protect. 17.14 Secure the tree and cellar. 18.0 RDMO 18.1 RDMO Innovation Rig Page 39 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure Em 4-7 19.0 Innovation Rig Diverter Schematic 3.18' KDI *518 Technology Page 40 ontroi Tedmology 3.58' SM Control et m*U Doube Ram -18' Choke Line X16' D venter Line Milne Point r E-38 SB Injector Hilcorp Drilling Procedure � �O. 20.0 Innovation Rig BOP Schematic —`�13-518" 5M Control Technology Annular BOP FINEYE Technology Double Ram 3-118" Kill Line3-118" Choke Line c o ----X13.5/8" 5M Control ® _ Technology Single Ram 13-5/8"x 5M 11"x5M 9-518" DBL D Seal 2-1/16" x SM Casing Hanger13-5/8" x 5M S-22 13-518" NOM 9-518" BTC Btm x 2-1116" x 5M 10.5" -4 SA Pin Top W/ Primary Seal 20" Casing 9-518" Casing Page 41 21.0 Wellhead Schematic Milne Point Unit E-38 S8 Injector Drilling Procedure Page 42 H Hilcorp UMT 22.0 Days Vs Depth 0 2000 4000 mm L 8000 n v a v 3 10000 v OE Page 43 64819111 14000 16000 18000 -2 Milne Point Unit E-38 SB Injector Drilling Procedure MPU E-38 SB OA Injector Days vs Depth 3 8 13 18 23 Days 28 H Hilcorp lwco�2 23.0 Formation Tops & Information Milne Point Unit E-38 SB Injector Drilling Procedure MPU E-38 Formations (Wp09) MD (ft) TVDss (ft) TVD (ft) (psi) Formation Pressurt8.46 Base Permafrost 1934 -1830 1878 826.32 LA3 3968 -3760 3808 1675.52Schrader medium sand and small gravel even Unconsolidated coarse to mem Bluff NA 4769 -4258 4306 1894.64Schrader Bluff OA 5595 -4406 4454 1959.76 a GENERALIZED GEOLOGICAL FORECAST SS GEOLOGICAL TVD FM LITH DESCRIPTION "Gaol. • p'Pa' TaL,.n Gub medium sand and small gravel even Unconsolidated coarse to mem ntoo.. 600 'minor cllffitone. gravel conglomerate to 1400'. wood fragments, 1,000'Heavy C _c Nroughoul permafrost zone- Abundant pyrite at 1500 n. a -41111 RUNNING GRAVELS 17W Basepertnahosl 2,000' Be prepared for HYDRATE gas cut HYDRATESB C Ed 2000 to 2500'ss(E4end E-8) nlrktok Lia a°22a-231,.,E-"-.,Saga '4110 HYDRATES! GAS CUT MUD r,Ea� A predominantly clay to N- 3000' wltn Imerheds of sand, clays Add alllslones even Occasional shows of coal. v r 3,000 Illlrj Continued lnterxds of sand, ctaya and autstOnes win Occasional shows of coal. Clay, sunshine and sand Inierbeds hetween 3000 and 6000-. Lignite3400.350011. SVirsevzIsmcrerany("muddier")than none In the Produce Bay area. 2500 UG4'K1SA SWABBINGISTICKY L IN Ugnu: TfilGhpackage-200IelDOnlnsameareas,.nwsslywa[n-f1gMMEped.eldrough g e name:ones are lined wren hydrocarhon. The Ugnu rection interbedded fluvial sadatone A F and stilet represents Me in" progradation of the Ugnu defuse system over the underlying CLAYfGUMBO' E -20a. -28. - C i shallow manna Schrader Blue seceon. Fluvial nacre can make H adlelcun to datennine tap ee Uglu ckeIs picked -32 8 -12. Individual aceem bounding surface of themr D Y v and base of units. pege D v A at the regional unconlamUry WOS Aft me M -sands Lplow). GAS CUT MUO E-24 AT 3DS6 `p M -Sands: Fimial, deltaic cawruml sandstones ecei aded over Me underlying SMIgne TVD; E -13B p 3618 tvd. 4,0009 J marine sandstones of der, Schrader Bluff. The M -Sands are subdrrded Into neat TIGHrfPACKiNG OFF, E -25A-, alhounsegrapike units Isla, MD- Mc Iran lap to bbdaml mat can tre dencuK td covetata due a is A IO Mine Dwlar4e11aC nature. TM MTOS inertia this laxer hwel boundary. M -rend Internet Sudace cuing ext. a I ate typically coargening upward packages d vsrylr�g NicMesses, rang rlg from'id.80'tH<k. for Schrader Blurt C Cana. At zones are highly unconsodiWied sandstones wick pormloes range kf the 30JeM. and canplellon. 2 pe meaMMies, reacting unewds of 200050001M Each M .lid interval acts as a L,,,a hydraubcally sepaate reservoir eased on current understanding. TIGHTILEDGES(COAL) As N -Sands: men-svdsala Gampauw astacaed. marina snorHmessndarones rNet RUNNING SURFACE AC O coarsen upwards iron, thln. slily mudsiOAes IMO thin, law he'Ll"s very fine to nwburm CASING. E-2/. -]] 8 -25. ' :3grained santlslonas. The Na, KC 8 NDeends are M , best quakty reservoir rock of tlen, 0 Ya h gh neLgosa fine to metllum grelnetl sanMta . Nsantl pori ny ra u3 from 12-39 a d m perie eababes range Dom 100.3000 rad. The NC 6 NDaads ere the Immary targe, with 3 j Z E secondary targets in 0w NB- ns The more unwnsolseated ends Itypical%1M NB. NC 8 J m NO) tend to washout, and the finer graved slay mudstones can cause slow ROP. Each N-eand acts as a hydrauflcalry Isolated Separate reservoir. ,r zsss O.62nds: Thevii Oswads of tow) the, clean rad, very At ening s. nes(IConsist fine (Intervening aisles) W thin bedded, very nlw m fine primar to thi lied upwards Dom very mudand These Oe and O stores are 25-30'etick. DA -sand is primary sanet o A to is. Mare 11 rn ftes wallaa Eyed. portsluesrangefrom. target EBpao. only Ny 6 reach only the Oand drawn ream upwards Of SW Md, whereas pernaeamines m the In the OBhondde,, karrad, ds "on d, There 0s, sands than canelae Over the "on- 350 red There are O b y nodulesandgenses t caused aynodules an ( Mayconal) islateallywhen nIX12011Id1) 8nd YOrr ROP. Each G -9811d MCN88GI5 8s, 8 hjV]ranlrCddy isolated IeSefYOlr, and h&SatdInturse acts As a rdetlecg II The sub -se gree, 5J0 n faults and the latera discontinuity of the Ngi811dmake ake et D durderolla essential for clear pick Wedhilcation dawn Brough the Uglu and N -sands. es well as careful t8gd' AS 11113' Geoateenng In honeontal wens. Page 44 5 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure Emgy Comymny 24.0 Anticipated Drilling Hazards 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 may be 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 45 Milne Point Unit E-38 SB Injector Drilling Procedure 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. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 46 n Hilcorp E., c2N Milne Point Unit E-38 SB Injector 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 on drill wells on this pad. 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 1-12S 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. �l 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 47 H Hilcorp Uro 17 25.0 Innovation Rig Layout Milne Point Unit E-38 SB Injector Drilling Procedure Page 48 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit E-38 5B 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. PX 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 49 0 Milne Point Unit E-38 SB Injector Hilcorp Drilling Procedure � 4T, 27.0 Innovation Rig Choke Manifold Schematic Page 50 Milne Point Unit E-38 SB Injector Hilco Drilling Procedure � �, T 28.0 Casing Design Design Criteria: Hole Size 12-1/4" Mud Density: 9.2 ppg Hole Size 8-1/2" Mud Density: 9.2 ppg Hole Size Mud Density: Drilling Mode MASP: 1513 psi (see attached MASP determination & MASP: Production Mode MASP: 1513 nsi (see attached MASP determination & Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Calculation & Casing Design Factors Hilcorp DATE: 41212019 1 WELL: MPU E-38 Casing OD DESIGN BY: Joe Engel Design Criteria: Hole Size 12-1/4" Mud Density: 9.2 ppg Hole Size 8-1/2" Mud Density: 9.2 ppg Hole Size Mud Density: Drilling Mode MASP: 1513 psi (see attached MASP determination & MASP: Production Mode MASP: 1513 nsi (see attached MASP determination & Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 51 Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 4-1/2" Top (MD) 0 5,398 Top (TVD) 0 4,315 Bottom (MD) 5,548 15,788 Bottom (TVD) 4,450 4,470 Length 5,548 10,390 Weight (ppf) 40 13.5 Grade L-80 L-80 Connection T)p H625 Weight w/o Bouyancy Factor (lbs) 221,920 140,265 Tension at Top of Section (lbs) 221,920 140,265 Min strength Tension (1000 lbs) 916 279 Worst Case Safety Factor (Tension) 4.13 1.99 Collapse Pressure at bottom (Psi) 2,198 2,208 Collapse Resistance w/o tension (Psi) 3,090 8,540 Worst Case Safety Factor (Collapse) 1 1.41 3.87 MASP (psi) 1,513 1,513 Minimum Yield (psi) 5,750 9,020 Worst case safety factor (Burst) 3.80 5.96 Page 51 H Hilcorp UMC, Milne Point Unit E-38 SB Injector Drilling Procedure 29.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 14 Hilcorp 8-1/2" Hole Section MPU E-38 Milne Point Unit MD TVD Planned Top: 5548 4450 Planned TD: 15788 4470 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OA Sandi 4,450 1 1959 1 Oil 1 8.47 1 0.440 Offset Well Mud Densities Well MW ranee Too (TVD) Bottom (TVD) Date MPU E-35 9.0-10.3 Surface 4423 2018 MPU E-37 9.3-9.7 Surface 4375 2018 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore togas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 4,450 (ft) x 0.78(psi/ft)= 3471 3471(psi) - [0.1(psi/ft)*4450(ft)]= 3026 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 4450 (ft) x 0.44(psi/ft)= 1958 psi 1958(psi)-0.1(psi/ft)*4450(ft) 1513 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 52 30.0 Spider Plot (NAD 27) (Governmental Sections) Milne Point Unit E-38 SB Injector Drilling Procedure Milne Point Unit MPE-38 Well 0 1.200 2.400 awe: �s WP09 Feet Page 53 H HilcoTp M T - 31.0 Surface Plat (As Built) (NAD 27) NOTES, 1, ALASKA VAX PLM4'. 0001IDRAMS APE ZOFE 1. NQ27, 2. BASS M LOCADRi R M0MJMENT3 f -3 AND E-1. } BASS M EIEYATM NAME PONT DATUM MA, 1 UOOETO "TONS APE NA027. ! PAID MEAN SCALE FACTOR Ifi D99990FA 6. SURVEY DAM MAY 31, 2046 A JAY 1, 2018 . 7. AEIEPE6C6 FIELD BOOK N0d-02 PGS 14-29 HDJII 2 PCS 69-73 Milne Point Unit E-38 SB Injector Drilling Procedure VICINITY MAP N.T.S. 1 crsun As LT CCMCOCXIR SURVEYOR'S CERTIFICATE 3■ ■e L PROPERLY REOSTEMID MIO UCCINSED SECTION ■ 33 COORDINATES THE STATE OF A A AND /MAT GRAPHIC SCALE ■ 2 BO% I zT ■ ■ 32 N®1,829.99'15.945" AV AAE D ■ ■ 31 t IAM " 200 fl. E-35 ■ ■ 4 149.4334550' 1720' FEL E i 29'■ 70.4544939' 21.7•3.817 13 ■ 1115 %= 569 407.52' E- 1 450.03''00.964" 25 ■ ■ 30 1,738' FEL 9 ■ ■ 6 -N- 23■ E 2 E-37 U ■ ■ 7 749.433767 T IL ■ ■16 MRI E -PAD 2D ■ ■ z3 70.4542906' I 24 ■ 11119 %= 569 265.12' E=1 291.58''05.189" ■ 12 1,801' FEL ! ■ ?) N.1,859.75''15.210" E-38 21.7' 3,519' FSL " E-39 E-39 $E-37 E-38 149'26'04.836' 749.4346211' E-41 E-35 NOTES, 1, ALASKA VAX PLM4'. 0001IDRAMS APE ZOFE 1. NQ27, 2. BASS M LOCADRi R M0MJMENT3 f -3 AND E-1. } BASS M EIEYATM NAME PONT DATUM MA, 1 UOOETO "TONS APE NA027. ! PAID MEAN SCALE FACTOR Ifi D99990FA 6. SURVEY DAM MAY 31, 2046 A JAY 1, 2018 . 7. AEIEPE6C6 FIELD BOOK N0d-02 PGS 14-29 HDJII 2 PCS 69-73 Milne Point Unit E-38 SB Injector Drilling Procedure VICINITY MAP N.T.S. 1 crsun As LT CCMCOCXIR SURVEYOR'S CERTIFICATE PLANT 1 l4AEBY GERTFY THAT 1 AM ■ DOVNG CONOOCT' PROPERLY REOSTEMID MIO UCCINSED SECTION TO PRACTCE LAND SURVENNO IN COORDINATES THE STATE OF A A AND /MAT GRAPHIC SCALE 1M4 AS-8VU RE EUNX A wRVcY BO% 40c MADE eY ME OR VNOER MY ERECT 0 ,00 200 9UPEIIN510N ANO NAT ML N®1,829.99'15.945" AV AAE N FEET) OOlROOAAS M1. 201&5 S OF t IAM " 200 fl. E-35 1S s O 111 C INII BT bWAIMIAN. JMAi A WELL A.S.P. PLANT GEODETIC GEODE11C LAR LELEV. SECTION O. COORDINATES COORDINATESP701'2715.945, ON(DMS) POST ON D DD) BO% OFFSETS Y=6 016,133.24' N®1,829.99'15.945" 70.4544292' 21"7 3.594' FSL E-35 %: 569.426.37' E= 1,450.02''00.438" 149.4334550' 1720' FEL N=1,860.12'16.176" 70.4544939' 21.7•3.817 FSL E-�Y=8,016.156.74' %= 569 407.52' E- 1 450.03''00.964" 149.4336067' 1,738' FEL Y=6,016180.37 N=1.890.58''16.412" 70.4545589' 21 T3,641'FSL E-37 X- 569 386.31' E- 1 44984''07.542" 749.433767 T 1 757' FEL N=1,890.22'7'15.416" 70.4542906' 21.8' 3,543'FSL E_�Y-6016,081.06' %= 569 265.12' E=1 291.58''05.189" 149.4347747' 1,801' FEL Y016.05725' N.1,859.75''15.210" 70.4542250' 21.7' 3,519' FSL " E-39 X69 284.13' E=1,241.52' 149'26'04.836' 749.4346211' 1.863 FEL 76034.09'N=1,829.93' �YXRSSI 218 3,496'FSL E_47 302.90' E- 1,291-66' 149'26'04.091 149.4344897 1,844' FEL 4w. 1AGQ! r-7 il DUPM rrilcorp Alaska Ulu SMAII MILNE POINT, ALASKA .EcC ILP E -PAD, WELLS 33. 36. 37, 36. % & 41 ®m m,' " aDe CONDUCTOR AS -BUILT .1 9•x Page 54 H Me= UC mvgvy Milne Point Unit E-38 SB Injector Drilling Procedure 32.0 Schrader Bluff OA Sand Offset MW vs TVD Chart 500 1000 2000 d 2500 m 3500 m 4500 Page 55 Schrader Bluff OA Sand Offset MW vs TVD MW. PPg 8.5 8.7 8.9 9.1 9.3 9.5 9.7 9.9 10.1 10.3 10.5 —MPU L-46 (2015) —MPU L-47 (2015) —MPU L-48 (2015) —MPU L-49 (2015) —MPU L-50 (2015) —MPU F-106 (2017) —MPU F-107 (2017) —MPU F-108 (2017) —MPU F-109 (2017) —MPU F-110 (2017) 33.0 Drill Pipe Information 5" 19.5# S-135 DS -50 & NC50 Drill Pipe Configuration Pipe Body OD m: 5.000 Milne Point Unit m 0.362 Pipe Body Grade S-135 E-38 SB Injector Tool Joint SMYS Hilo GPOS50 Drilling Drilling Procedure 6.625 Ent C21T m: 3250 33.0 Drill Pipe Information 5" 19.5# S-135 DS -50 & NC50 Drill Pipe Configuration Pipe Body OD m: 5.000 Pipe Body Wall Ttsdmess m 0.362 Pipe Body Grade S-135 Dull Pipe Length Tool Joint SMYS Connection GPOS50 Tod Joint OD 6.625 Tool Joint ID m: 3250 Pin Torg 9 Box Torg In: 12 Drill Pipe Performance Te lwl 80 % Inspection Class Tod JohaTorsiarltu Stren0lh Tad JaidTanae Straglh Nominal Weight Designation 19.50 Drill Pipe Approximate Length wn 37.5 SmocthEtge Height w1302 RatsEE Tool Joint SMYS 120 OOD Upset Type IEl1 Max Upset OD (DTE) Iml 5.125 Friction Factor 11.0 124 NGe: TO�9 aN:e may IntlWe nY91i[N9 Drill -Pipe Length Range2 Nominal Seen anuvmn 29 036 0.0065 0.72 0.0172 36,100 Tension 0.1y 0560600 Drih Size y +I^� 3.125 ennrnun rlvr -�32.100 1467,400 NNe: OIITeleCT21 D.Tvls Gi IJ59NIfM. Y b: O91 ppe a:SeTdY va Wes a2 ne3 eYmRs ane miY �eYeW-' lu GC[ D�0' �nll Ntnrtx, IMemnl p1aYe W 11Np env vlM1ee IxtYf. Connection Performance GPDS50 ( 6.625 Um) OD X 3.250 cw ID ) 120,000 1%n nar Trvmnlmne cvnnecl.riaveraonal lenne.auvf Ral•rr.xoSe.ronmoum ne aanm Tod JohaTorsiarltu Stren0lh Tad JaidTanae Straglh rna.n M41250.000 71,800 Elevator Shoulder Information SmoothEtlge Heiphl 3+32 Raised 560800 560800 Box OD slm 6.812 58.100 58.100 Elevator Capacity it n41,658,0010 124 Assumed Elevator Bore Diameter Im 5219 Pipe Body Slip Crushing Capacity Tool Joint Dimensions aelv,ced 00 ria 6.435 I.Lamsn� Jo19�b Wlpn 5.930 urnon Tbal lase ww 5.93 LalelmSan In Elevator OD 3132 Raised 6.812 ml bol Joint I Wom to Bevel wood to Min TJ ODfa D Diameter AS Pro man Class NMn EkvaY, u�anb nmeeM SNurtnn £'seal[, 9vrt`. na'.<a11aYv, antl cMlS1 se wmr.wnaee9 eevem, oo moo.:oekmru�a xr vUNm arteonp nnAa.iy nlvva. Pipe Body configured9n ( 5 1n1 OD 0.362 oe Wall S-135) Pipe Bodv Performance Page 56 Pipe Body Confgunroon ( 5 ml OD 0.362(-) Wall S-135) Nem: 4m mi aunt b. a1 T.p%R&W MMI. Nominal 80 % Inspection Class API Premnim Ctass Pipe Tensile Strength lea 71 100 560800 560800 Pipe Torsional Strength I^ -X174.100 58.100 58.100 T14hpeBody Torsional Ratio 0.97 124 124 80% Pipe Torsional Strength <Iun159300 46.500 46.500 Burst s 17,105 15,638 15638 Cdlapse IOa'1 1502 10.029 10.029 Pipe OD cn 5900 4.855 4.855 Wall Thickness rml 0.362 0290 0290 Nominal Pipe ID an 4276 14276 4276 Cross Sectional Area of Pipe Body 4m -3i 5275 4.154 4.154 Cross Sectoral Area of 00 ar 19.635 18.514 18.514 Gross Sectional Area of ID Im•:1 14.360 14360 14360 Section Moduhs (-j 5.708 4-476 4.476 Polar SecBao Modulus m^ren 11.415 la.953 1&953 Nem: 4m mi aunt b. a1 T.p%R&W MMI. H Hilcotp Milne Point Unit E-38 SB Injector Drilling Procedure 500204050016200 1W Weatherford 5" 19.50 Ib/ft S-135 w/ NC 50 6-518" OD x 3-1/4" 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 19.50 Itis Adjusted Weight With Tool Joint per Foot 23.08 lbs TOOL JOINT DATA Outside Diameter 6-518' Inside Diameter 3-1/4' API Drift 3-118' Rabbit OD, Suggested 3-1116" Minimum Make-up Torque 25.900 ft -lbs Maximum Recommend Make-up Torque 26,800 ft -lbs Torsional Yield Strength 51,700 ft -lbs Tensile Strength 1,269.000 Itis TUBE DATA New Premium Outside Diameter 5.000" 4.855' Inside Diameter 4.276" 4.276' Wall Thickness 0.362" 0.290' Cross Sectional Area 5.275 sq in 4.154 sq in Maximum Hook Loadlrensile Strength 712.000 lbs 560,800 lbs, Slip Crushing i Slip Type (SDXL) 572.100 lbs 453,500 lbs Burst Pressure 17,100 psi 16.100 psi Collapse Pressure 15,700 psi 10.000 psi Torsional Yield Strength 74.100 ft-Ibs 58.100 ft-lbs— -lbsCa aci W) Tool Joint Capacity 0.726 US gavft 0.726 US galtft Dis lacement W! Tool Joint 0.353 US oallft 0.322 US al/ft Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss. damage or injury resulting from the use of the information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. Page 57 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-38 M P E-38 Plan: MPU E-38 wp09 Standard Proposal Report 19 March, 2019 HALLIBURTON Sperry Drilling Services REFERENCE INFORMATION CU ixb (NIE) Rehre.: WaA Plen: MPU E38, Thee WnS Meluul (NU) Retie- MKE uy02 KBE Q d0]0aM1 Meuured De Refemm: MPE48 uy02 KBE a 40.Musfl Caltulelon 6MVad: MMhnum C1 m CASING OEFAILs ND NDSS MO Size Name 40.5p.W M02005548.50 9518 95W x121.' 0)0.00 4421.)0 15)8091 X59 859'x81.' Sbd Dir3°/100': MV AN.30PND: M' RTTE SM Sed 064°/100':5WMD, N929TVD EN Olr : W75MD. 944X1' NO SW Dir d°/t OP:1 WP MD, 1457,05']0 Project: Milne Point Site: MPtEPad Well: Plan: MPU E38 HALLISURTON Wellbore: MPE-38 ND Design: MPU E-38 wp09 Sperry 0,11N., V Hd Tar9e1 HI TAlazka, LLC 1 28.50 090 Cale,Reh n Wl1 Mlnurvun Curvadve E1v "" 15CW8q 5""'T MA. 000 O.M 51'an C'maslA rA 3D pYaa 000 sv.. Petlal Cu- O, 300.00 0.0o Oo0 MelhW: Warwn Me111M: Envr Rale e 0.00 aW FRWRAl2 Wb:.1BM1-5-1 IW..m VJi1eW: Tu Vaalm'. - Fmm 0.PA it 9umy , 3 .SO 50.0 YPUEd0 apN 1MPEM S�OymNS(BC_OM mils 5010 3190 Y91 E�l0 viW R.IPEY) yMNpIFl92�Ms�5q 65ett� 15MB.Po BW Ede PE.N 2 MNpIFR2�M9� REFERENCE INFORMATION CU ixb (NIE) Rehre.: WaA Plen: MPU E38, Thee WnS Meluul (NU) Retie- MKE uy02 KBE Q d0]0aM1 Meuured De Refemm: MPE48 uy02 KBE a 40.Musfl Caltulelon 6MVad: MMhnum C1 m CASING OEFAILs ND NDSS MO Size Name 40.5p.W M02005548.50 9518 95W x121.' 0)0.00 4421.)0 15)8091 X59 859'x81.' Sbd Dir3°/100': MV AN.30PND: M' RTTE SM Sed 064°/100':5WMD, N929TVD EN Olr : W75MD. 944X1' NO SW Dir d°/t OP:1 WP MD, 1457,05']0 WELL OETRILS: -1, MPU -1 GmuM Level: 21.00 aN/4 1E/ -W No Nm9 ..MNp LaMwde L ".ft .00 0.0 60160910fi 09.5.12 12r IS, .4N 14V M 6.1 IN End Dir : 1BM03MD.1510&l ep p P 20. Y r p ,p p (l y S Fp qq F K AQ �p''�p ,C'° j '�,C ^' p MID 66d�^11 +S 4Q a���. �(+�p'�y S"i Sp <jO�'" �g �'£,p�z° �pa`'?",cZ A` Fapa �°a°s5 o ' p�q^�°gP O^�F°e SA ?9,9 dqp ,gip, yso d ` $ 4 4p0`2'Or°.pyo 3544 Regd 3& ,R RB,�a g;s �a.e�$�3 R8a 88€'ry� �A 4 a $: e d' eFgyad' S`3o3'ga\�ap8dQ yb cS �,' ya W ag g�°C'1 e$e�$ a a z J �. m MPU E-38 uyJ9 -6Sm. 8IW W knnetm daMomailaBb 9sxxlz lu• � � o n MPU E,3810 CPI n MPU E -M upV CPJ MPU Ede x008 CP5 MPU E-30 uyM C% � $ 6VE40 vg0]Neel MPU E38yM CP2 MPU E -M 008 CW MPU E-91uy38 CM 6144E 3B v.D08 LPBs 750 1500 22W 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 Verd.1 Section at 295.00° (1500 UsNin) SEC))- R LS Sec MD Inc A9 ND .Nl-6 sEl-W Dleg V Hd Tar9e1 Annoution 1 28.50 090 000 MA. 000 O.M 000 000 2 300.00 0.0o Oo0 300.00 0.00 aW 0.E0 0.00 00o Slml Dir 3•n DY: 30PMD,300' 1):SPPTTP 3 5w Z50 5000 54919 10.50 1252 3DO .00 -6.91 SWOir 41 W: 550' MD, 549nN 4900.110 2150 50,W M],30 6669 A48 4.00 000 4395 5 98]50 18.00 50.00 96964 85.69 102.13 4.00 18000 56.34 End Dir : BB].5' MD. 96964' ND 6 1500.00 1800 5000 145]05 18]49 Y3,45 000 0.00 -1232] Sd11D04°/100': 150VMD,1457MS 7 165983 1363 3285 161080 21926 25258 400 -140.07 -13823 End 00:(44983'440, 1fi10 BB'NO e 30]309 13 fi3 326s 20862] saD 01 oz s0 000 0.00 -1 M.ed MadD' 4°n00 3ms03' MD.2M6.2TND 9 524850 0500 29500 442415 134113 520.)4 400 -90.61 1128.3) SM D :53105 MD M24,15- WD 10 5548.50 8500 29500 4450M 146743 09160000 0.00 142823 MPEJB u)dl]N I 3 DY4°N00. SM83MD,445 3WD 11 MM B4 4433 2840] 445532 150322 9]001 400 45.62151441 EMDlr: NHAMMOM55,VT 12 SB45N 4433 8407 446140 5092. (16362 DW 0001]25.34 Sbd Dl4'MW . 51MSWMD,d48140'Nl3 13 5925 2] 9150 N398 4481,60 162156 -1235.12 IW -1W 1804)6 ENO 59z52TMOM814ND 14 4400.2) 8150 ID3.BB 446M 201]3] -2125W 000 00 2]]921 MPU E -M x908 LPI 8 013-fIW fi9p 27- W. N360B'ND 15 en" 969118 293.% 4431.63 2053 74 -220]fi5 300 -0W M68.]5 EM Dk : 644996 MD t"GTN➢ 16 ]1]610 MA9 29395 Mf]O6 2130.06 -33]940 0.00 000 30566] Sed Dir3°/iW.]178,1.,441].16I f] ]301A2 9950 A3.% 441631 213939 -240038 3.00 1]89030]90 End DIr :].142' M0,441..V' f0 ]501 A2 "350 283Po 4]980 226089 28)4.02 0.00 00093]902 MPU E38 wTUB LP2 SbdDir 3°/10':)50142' MD. 4390'NO 19 ]54244 9226 293,% 439591 22)]83 -2711.91 300 -1]9.00 342040 End Dir :]51291 MD, 439591' NO 20 ]9d8A3 9328 29396 438394 240.9] 299905 000 0.00 3]2J.68 lel DIr Pmoo:]046d3' MD, 43M WWO 21 ]801 0. 50 60 2MAM 4303 5] 423 236 40943 300 1]9.913]]681 End Dir :701.50' MD, 430257 ND 22 9101.58 %.60 28396 43]000 281065 4135,N 0.0 0.00 4970.55 MPU E40 x900 CP3 Sed Oh rPOW: 910150' MD. 437MD 23 9236]D 8655 29398 43]336 296549 425997 3W -1]9055113.5] End Dir : 9236]' MD. 437336' NO 24 9401.]8 8655 H396 438331 303239 440996 OW 0W 52 ]632 504D03-flOV'. 94D1.)B'MD,4NMAIND 25 95010 89.55 SMAS 4386)2 3073.M _eSHW 30 0.0] 53]835 End Dir 9501.8' MD, 438672' ND 26 10301.90 8955 29396 4393.00 339289 423242 0W OW 617620 MPU E36w CP4 Sen If 3,WIW: 10X1.9 IA, 4393' 27 U62.85 94.43 29395 4387A2 34631043]938 303 -006030.96 EM Dir : 1 HID W MD, 4M]A2' ND RB 104)813 :4 43 283.% 43M.16 3469.1 -539421 0.00 000 6355.20 Start Dir J.O°/1W 101 ]9.1 J'MD. 4344187/0 29 10602.12 90.]0 29396 43 ,M 351966 SY5.48 3.03 1)8.92 (4)804 EM DIr: t%02.12'MO. 43M98' NO 30 11802.12 90,0 2930 436800 404494 EM2.99 0.00 000]6]2)5 MPU E40w 8CP5 sled Du3.0°/1W : 11002.12' M04J66ND 31 1106198 BB.91 2942fi 1366. 4031.14 655].0] 344 1]0.53 ]]38.99 End Dir:11061]8'M0,43fifi2'ND 32 (100.04 BB.91 284.26 436353 4081.45 I76a.70 0.00 0.00 )85942 Sbd Dir 3WMW': 1199.8, Mp, 436B.MTYD 33 12052.10 91.00 29412 438658 410.47 4.D. 306 -105 ]92]6] End Dir: 1.52.1' MD. 4.e58'N11 Jd 13002.10 9100 394.22 4352.0 44M.14-]fi9]f9 0.0 000 M]]A4 MPU E-Mw08 CK Sbd Dir 3°H00': 1.0.1' MD. 4=WD 35 131W.16 93.78 285.20 434 92 4540.44 -7861" 3.W 19.37...4. End Dir : l31WIVMD,4U7.9Y1D 36 13192.96 93]8 .520 134131 457951 486997 OM OW 440.00 Bed OM 3 hllll':13192.%MID, A l81'IVD 37 1.0123 9050 ESW 433].]3 4625-0] -]9869) 300 -1]6.55 91]].20 EndDer : 13302.33'MD,43V.)3TW 38 143023 8030 .5 .0 492".00 SOdO.O A0]520 000 O.W 101]].44 MN EUS uyY CP] SMd Dir PtlM':1d302.3]'MD. 4J29TD 39 14302./2 88.10 .5W 43..98 4402.31 490]0 900 -1]0981025].32 End Dir: 14302.41 MO.4329.44' WD 40 1494324 89.10 NS4W 434800 5319.19 4455,]0 0.00 0.001017.03 5164 D13°/10': 140321 MD, ."WND 41 150000 0980 205. 434804 5343.1] -9.7.21 300 0021M74.M Shed DY SHW':15WP MD, 4349 U4 42 1519800 0000 D5W 4367N Sd255] 40393 5.00 180001106956 EN DY: 15IN MD, 4MTWN 43 15)88 BO 0000 3950 44)11.0 5872.34-1013.11 000 0.001165346 Thiel Depth: 19448' MD "M ND WELL OETRILS: -1, MPU -1 GmuM Level: 21.00 aN/4 1E/ -W No Nm9 ..MNp LaMwde L ".ft .00 0.0 60160910fi 09.5.12 12r IS, .4N 14V M 6.1 IN End Dir : 1BM03MD.1510&l ep p P 20. Y r p ,p p (l y S Fp qq F K AQ �p''�p ,C'° j '�,C ^' p MID 66d�^11 +S 4Q a���. �(+�p'�y S"i Sp <jO�'" �g �'£,p�z° �pa`'?",cZ A` Fapa �°a°s5 o ' p�q^�°gP O^�F°e SA ?9,9 dqp ,gip, yso d ` $ 4 4p0`2'Or°.pyo 3544 Regd 3& ,R RB,�a g;s �a.e�$�3 R8a 88€'ry� �A 4 a $: e d' eFgyad' S`3o3'ga\�ap8dQ yb cS �,' ya W ag g�°C'1 e$e�$ a a z J �. m MPU E-38 uyJ9 -6Sm. 8IW W knnetm daMomailaBb 9sxxlz lu• � � o n MPU E,3810 CPI n MPU E -M upV CPJ MPU Ede x008 CP5 MPU E-30 uyM C% � $ 6VE40 vg0]Neel MPU E38yM CP2 MPU E -M 008 CW MPU E-91uy38 CM 6144E 3B v.D08 LPBs 750 1500 22W 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250 Verd.1 Section at 295.00° (1500 UsNin) REFEPENCE INFORMATION HALLIBYRT4AJ wnNm:un 11 Rnercn=ew PNi�Pa.- xPU ex Tr8W Fea��ry Mol ndaKa: MWKaE�<wu:n CepN Pe2rtn�e: MPE ryAZKBE®aO.Yrvsn Bparry Orilling 4' IaMun e4N'. MiNmum Cuvarw }uW RPrE:15 W S/IIA:ISLm AO UF.NTW MPV &]H aylp •Y I�lPla'Mu!]39.VR)lN a. a.)V'rgY b 5.9'iH l/1' WWSu(d P/I Wz)'I�lla�%AO. U+I.AITT Etl O6: IaIN,/O1.N. U419P T'O DW E�)e VP09 Sy�w]"/Iw:rMpl l'Mq Uzmn 'mob Dy,Imsx.re+nw5el'rvo Ae•I!e-]e.yaecr 'swop Jm��nAm llw)a+Im.wesJ'nn EPVf le up%C r .4onYa)).delm:lw Im.alSrtlnrvn Pmro:a .nevxrvo wu Eae woe a �lo+m,.�edn rvo 9wYrrm MJrro le"evo agild rol'S9'I.d.4)gryp MPI: F-Je xT'AIHCP 4dD^roPl%ISYMV.AIpSPMI Sw WTrta':16W AW.H'ND �J Vv l N'l0,UV5V1'NII RIPLr E�]H vyYCP Swt4 i/IW:xS Y%'/Vo +YMO.u16S 1'MI xmfi :ro59 WVL)ecNBCP __ ze^tiu]'nlW �mdii MQ.TizNi"mrM) Fe50n:5V'S]i Ib'M1 MPV E -]H x90E [P 9WV.frIW:3N5At'..41 111 "" Srv-r/L6Yl/OY'SY w5W'IVD .WE-)Hy90]N[ _ _EM0.e 5w.a xm.uzV.ls rvo a Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-38 Wellbore: MPE-38 Plan: MPU E-38 wp09 -11000 p- snow s.mr Mu.zwP.z+mm IA'�PNw:I vlw lalaeo-nv HZ_8_ mMn. �aurrvu� rwol�a/Im:sSo zw w) r Im. )m.d. )mrvo. m sT ry -0000 -6LWtl -A]Oo JWo -3M -xWo -LM 0 1000 Wulf-)/Eat(+1(1500 MfUin) CASING DE�LS -11000 p- snow s.mr Mu.zwP.z+mm IA'�PNw:I vlw lalaeo-nv HZ_8_ mMn. �aurrvu� rwol�a/Im:sSo zw w) r Im. )m.d. )mrvo. m sT ry -0000 -6LWtl -A]Oo JWo -3M -xWo -LM 0 1000 Wulf-)/Eat(+1(1500 MfUin) HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-38 Wellbore: MPE-38 Design: MPU E-38 wp09 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU E-38 TVD Reference: MPE-38 wp02 KBE @ 48.30usft MD Reference: MPE-38 wp02 KBE @ 48.30usft 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, TR -13-10 MPE-38 Magnetics Model Name Sample Date Site Position: Northing: 6,013,798.68usft Latitude: 70° 26'52.9824 N From: Map Easting: 569,440.72usft Longitude: 149° 26'0.6546 W Position Uncertainty: 0.00 usft Slot Radius: 0.. Grid Convergence: 0.53 ° Well Plan: MPU E-38 26.50 Well Position +N/ -S 0.00 usft Northing: 6,016,081.06 usft Latitude: 70° 27' 15.4464 N +El -W 0.00 usft Easting: 569,265.12 usft Longitude: 149° 26'5.1882 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 21.80 usft Wellbore MPE-38 Magnetics Model Name Sample Date BGGM2018 9/17/2018 Design MPU E-38 wp09 Audit Notes: Version: Phase: Vertical Section: Depth From (TVD) (usft) 26.50 Declination Dip Angle (1) (°) 17.06 80.98 Field Strength (nT) 57,454.56347142 PLAN Tie On Depth: 26.50 +NIS +EI -W Direction (usft) (usft) (I 0.00 0.00 295.00 3/192019 12:56:59PM Page 2 COMPASS 5000.15 Build 91 Halliburton H A LL I B U R TO N Standard Proposal Report Database: NORTH US+ CANADA Local Co-ordinate Reference: Well Plan: MPU E-38 Company: Hilcorp Alaska, LLC TVD Reference: MPE-38 wp02 KBE @ 48.30usft Project: Milne Point MD Reference: MPE-38 wp02 KBE @ 48.30usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-38 Survey Calculation Method: Minimum Curvature Wellbore: MPE-38 Design: MPU E-38 wp09 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (1/100usft) (°1100usft) (11100usft) (°) 26.50 0.00 0.00 26.50 -21.80 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 251.70 0.00 0.00 0.00 0.00 0.00 0.00 550.00 7.50 50.00 549.29 500.99 10.50 12.52 3.00 3.00 0.00 50.00 900.00 21.50 50.00 887.30 839.00 66.69 79.48 4.00 4.00 0.00 0.00 987.50 18.00 50.00 969.64 921.34 85.69 102.13 4.00 -4.00 0.00 180.00 1,500.00 18.00 50.00 1,457.05 1,408.75 187.49 223.45 0.00 0.00 0.00 0.00 1,659.83 13.63 32.65 1,610.88 1,562.58 219.26 252.56 4.00 -2.73 -10.85 -140.87 3,075.08 13.63 32.65 2,986.27 2.93797 500.07 432.50 0.00 0.00 0.00 0.00 5,248.50 85.00 295.00 4,424.15 4,375.85 1,341.13 -620.74 4.00 3.28 -4.49 -98.61 5,548.50 85.00 295.00 4,450.30 4,402.00 1,467.43 -891.60 0.00 0.00 0.00 0.00 5,634.84 88.33 294.07 4,455.32 4,407.02 1,503.22 -970.01 4.00 3.85 -1.08 -15.62 5,845.89 88.33 294.07 4,461.48 4,413.18 1,589.26 -1,162.62 0.00 0.00 0.00 0.00 5,925.27 91.50 293.96 4,461.60 4,413.30 1,621.56 -1,235.12 4.00 4.00 -0.14 -1.98 6,900.27 91.50 293.96 4,436.08 4,387.78 2,017.37 -2,125.80 0.00 0.00 0.00 0.00 6,989.96 94.19 293.96 4,431.63 4,383.33 2,053.74 -2,207.65 3.00 3.00 0.00 -0.03 7,178.40 94.19 293.96 4,417.86 4,369.56 2,130.06 -2,379.40 0.00 0.00 0.00 0.00 7,201.42 93.50 293.96 4,416.31 4,368.01 2,139.39 -2,400.38 3.00 -3.00 0.01 179.90 7,501.42 93.50 293.96 4,398.00 4,349.70 2,260.99 -2,674.02 0.00 0.00 0.00 0.00 7,542.94 92.26 293.96 4,395.91 4,347.61 2,277.83 -2,711.91 3.00 -2.99 -0.01 -179.88 7,846.43 92.26 293.96 4,383.94 4,335.64 2,400.97 -2,989.05 0.00 0.00 0.00 0.00 7,901.58 90.60 293.96 4,382.57 4,334.27 2,423.36 -3,039.43 3.00 -3.01 0.00 179.91 9,101.58 90.60 293.96 4,370.00 4,321.70 2,910.65 -4,135.96 0.00 0.00 0.00 0.00 9,236.70 86.55 293.96 4,373.36 4,325.06 2,965.49 -4,259.37 3.00 -3.00 0.00 -179.95 9,401.78 86.55 293.96 4,383.31 4,335.01 3,032.39 -4,409.96 0.00 0.00 0.00 0.00 9,501.90 89.55 293.96 4,386.72 4,338,42 3,073.02 -4,501.38 3.00 3.00 0.00 0.07 10,301.90 89.55 293.96 4,393.00 4,344.70 3,397.89 -5,232.42 0.00 0.00 0.00 0.00 10,462.85 94.43 293.95 4,387.42 4,339.12 3,463.18 -5,379.38 3.03 3.03 0.00 -0.06 10,479.13 94.43 293.95 4,386.16 4,337.86 3,469.77 -5,394.21 0.00 0.00 0.00 0.00 10,602.12 90.70 293.96 4,380.66 4,332.36 3,519.66 -5,506.48 3.03 -3.03 0.00 179.92 11,802.12 90.70 293.96 4,366.00 4,317.70 4,006.94 -6,602.99 0.00 0.00 0.00 0.00 11,861.38 88.91 294.26 4,366.20 4,31790 4,031.14 -6,657.07 3.06 -3.02 0.50 170.53 11,983.84 88.91 294.26 4,368.53 4,320.23 4,081.45 -6,768.70 0.00 0.00 0.00 0.00 12,052.10 91.00 294.22 4,368.58 4,320.28 4,109.47 -6,830.94 3.06 3.06 -0.06 -1.05 13,002.10 91.00 294.22 4,352.00 4,303.70 4,499.14 -7,697.19 0.00 0.00 0.00 0.00 13,100.16 93.78 295.20 4,347.92 4,299.62 4,540.09 -7,786.18 3.00 2.83 1.00 19.37 13,192.96 93.78 295.20 4,341.81 4,293.51 4,579.51 -7,869.97 0.00 0.00 0.00 0.00 13,302.33 90.50 295.00 4,337.73 4,289.43 4,625.87 -7,968.93 3.00 -2.99 -0.18 -176.55 14,302.33 90.50 295.00 4,329.00 4,280.70 5,048.47 -8,875.20 0.00 0.00 0.00 0.00 14,382.42 88.10 295.00 4,329.98 4,281.68 5,082.31 -8,947.78 3.00 -3.00 0.00 -179.98 14,943.24 88.10 295.00 4,348.60 4,300.30 5,319.19 -9,455.78 0.00 0.00 0.00 0.00 15,000.00 89.80 295.00 4,349.64 4,301.34 5,343.17 -9,507.21 3.00 3.00 0.00 0.02 15,196.00 80.00 295.00 4,367.04 4,318.74 5,425.57 -9,683.93 5.00 -5.00 0.00 180.00 15,788.90 80.00 295.00 4,470.00 4,421.70 5,672.34 -10,213.11 0.00 0.00 0.00 0.00 31192019 12.56:59PM Page 3 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-38 Wellbore: MPE-38 Design: MPU E-38 wp09 Planned Survey Measured Map Map Vertical +N/ -S +EI -W Depth Inclination Azimuth Depth TVDss (usft) (usft) (°) (usft) (1) (usft) usft 6,016,081.06 26.50 0.00 0.00 0.00 0.00 6,016,061.06 26.50 -21.80 0.00 100.00 0.00 0.00 569,265.12 0.00 0.00 100.00 51.70 6,016,081.06 200.00 0.00 0.00 1.68 0.00 6,016,082.76 200.00 151.70 -1.11 300.00 8.01 0.00 569,273.07 0.00 -4.42 300.00 251.70 6,016,091.68 Start Dir 3°1100' 3.00 : 300' MD, 300'TVD : 50' RT TF 6,016,096.48 400.00 4.00 3.00 28.07 50.00 6,016,109.43 399.95 351.65 -18.45 500.00 53.91 6.00 569,318.61 50.00 -29.74 499.63 451.33 6,016,148.48 550.00 4.00 7.50 85.69 50.00 6,016,167.69 549.29 500.99 -56.34 Start Dir 4°/100' 105.09 : 550' MD, 549.29'TVD 0.00 -57.97 108.04 600.00 6,016,190.28 9.50 0.00 50.00 127.90 598.73 550.43 569,416.34 700.00 -84.09 13.50 176.10 50.00 569,439.82 696.71 648.41 167.63 800.00 6,016,250.52 17.50 0.00 50.00 187.49 793.05 744.75 569,486.79 900.00 -123.27 21.50 243.71 50.00 569,506.87 887.30 839.00 219.26 987.50 6,016,302.63 18.00 4.00 50.00 227.23 969.64 921.34 569,520.64 End Dir : 987.5' MD, 969.64' TVD 6,016,330.61 569,533.16 1,000.00 -140.63 18.00 283.09 50.00 569,545.69 981.52 933.22 286.75 1,100.00 6,016,370.52 18.00 0.00 50.00 306.60 1,076.63 1,028.33 569,570.75 1,200.00 -150.04 18.00 321.24 50.00 569,583.28 1,171.74 1,123.44 346.28 1,300.00 6,016,430.40 18.00 0.00 50.00 366.12 1,266.84 1,218.54 569,608.34 1,400.00 -159.46 18.00 359.38 50.00 569,620.87 1,361.95 1,313.65 405.81 1,500.00 6,016,490.27 18.00 0.00 50.00 425.65 1,457.05 1,408.75 569,645.92 Start Dir4°/100': 1500' MD, 1457.05'TVD 397.53 6,016,530.18 1,600.00 0.00 15.10 465.33 40.27 6,016,550.14 1,552.92 1,504.62 -175.15 1,659.83 422.96 13.63 569,683.51 32.65 -178.29 1,610.88 1,562.58 6,016,585.08 End Dir : 1659.83' MD, 1610.88' ND 6,016,590.14 569,695.84 1,700.00 -181.21 13.63 443.41 32.65 569,703.57 1,649.92 1,601.62 551.76 1,800.00 6,016,636.88 13.63 4.00 32.65 579.07 1,747.10 1,698.80 569,699.71 1,900.00 -154.08 13.63 32.65 1,844.29 1,795.99 2,000.00 13.63 32.65 1,941.47 1,893.17 2,100.00 13.63 32.65 2,038.65 1,990.35 2,200.00 13.63 32.65 2,135.84 2,087.54 2,300.00 13.63 32.65 2,233.02 2,184.72 2,400.00 13.63 32.65 2,330.20 2,281.90 2,500.00 13.63 32.65 2,427.39 2,379.09 2,600.00 13.63 32.65 2,524.57 2,476.27 2,700.00 13.63 32.65 2,621.75 2,573.45 2,800.00 13.63 32.65 2,718.94 2,670.64 2,900.00 13.63 32.65 2,816.12 2,767.82 3,000.00 13.63 32.65 2,913.30 2,865.00 3,075.08 13.63 32.65 2,986.27 2,937.97 Start Dir 401100' : 3075.08' MD, 2986.27TVD 3,100.00 13.52 28.43 3,010.49 2,962.19 3,200.00 13.78 11.46 3,107.71 3,059.41 3,300.00 15.12 356.29 3,204.58 3,156.28 3,400.00 17.28 344.18 3,300.63 3,252.33 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU E-38 MPE-38 wp02 KBE @ 48.30usft MPE-38 wp02 KBE @ 48.30usft True Minimum Curvature 3/19/2019 12:56:59PM Page 4 COMPASS 5000.15 Build 91 Map Map +N/ -S +EI -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) -21.80 0.00 0.00 6,016,081.06 569,265.12 0.00 0.00 0.00 0.00 6,016,061.06 569,265.12 0.00 0.00 0.00 0.00 6,016,081.06 569,265.12 0.00 0.00 0.00 0.00 6,016,081.06 569,265.12 0.00 0.00 1.68 2.01 6,016,082.76 569,267.11 3.00 -1.11 6.73 8.01 6,016,087.86 569,273.07 3.00 -4.42 10.50 12.52 6,016,091.68 569,277.54 3.00 -6.91 15.25 18.18 6,016,096.48 569,283.15 4.00 -10.03 28.07 33.45 6,016,109.43 569,298.30 4.00 -18.45 45.24 53.91 6,016,126.79 569,318.61 4.00 -29.74 66.69 79.48 6,016,148.48 569,343.97 4.00 -43.85 85.69 102.13 6,016,167.69 569,366.44 4.00 -56.34 88.18 105.09 6,016,170.20 569,369.37 0.00 -57.97 108.04 128.76 6,016,190.28 569,392.86 0.00 -71.03 127.90 152.43 6,016,210.36 569,416.34 0.00 -84.09 147.77 176.10 6,016,230.44 569,439.82 0.00 -97.15 167.63 199.77 6,016,250.52 569,463.31 0.00 -110.21 187.49 223.45 6,016,270.61 569,486.79 0.00 -123.27 207.37 243.71 6,016,290.67 569,506.87 4.00 -133.24 219.26 252.56 6,016,302.63 569,515.60 4.00 -136.23 227.23 257.66 6,016,310.65 569,520.64 0.00 -137.49 247.07 270.38 6,016,330.61 569,533.16 0.00 -140.63 266.91 283.09 6,016,350.57 569,545.69 0.00 -143.77 286.75 295.81 6,016,370.52 569,558.22 0.00 -146.91 306.60 308.52 6,016,390.48 569,570.75 0.00 -150.04 326.44 321.24 6,016,410.44 569,583.28 0.00 -153.18 346.28 333.95 6,016,430.40 569,595.81 0.00 -156.32 366.12 346.67 6,016,450.35 569,608.34 0.00 -159.46 385.96 359.38 6,016,470.31 569,620.87 0.00 -162.60 405.81 372.10 6,016,490.27 569,633.39 0.00 -165.73 425.65 384.81 6,016,510.23 569,645.92 0.00 -168.87 445.49 397.53 6,016,530.18 569,658.45 0.00 -172.01 465.33 410.24 6,016,550.14 569,670.98 0.00 -175.15 485.17 422.96 6,016,570.10 569,683.51 0.00 -178.29 500.07 432.50 6,016,585.08 569,692.92 0.00 -180.64 505.11 435.48 6,016,590.14 569,695.84 4.00 -181.21 527.06 443.41 6,016,612.17 569,703.57 4.00 -179.12 551.76 444.93 6,016,636.88 569,704.86 4.00 -170.06 579.07 440.04 6,016,664.14 569,699.71 4.00 -154.08 3/19/2019 12:56:59PM Page 4 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-38 Wellbore: MPE-38 Design: MPU E-38 wp09 Planned Survey Halliburton Standard Proposal Report Local Coordinate Reference: Well Plan: MPU E-38 TVD Reference: MPE-38 wp02 KBE @ 48.30usft MD Reference: MPE-38 wp02 KBE @ 48.30usft North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S (usft) (') (") (usft) usft (usft) 3,500.00 20.00 334.97 3,395.40 3,347.10 608.87 3,600.00 23.08 328.01 3,488.42 3,440.12 641.00 3,700.00 26.40 322.66 3,579.24 3,530.94 675.32 3,800.00 29.88 318.45 3,667.41 3,619.11 711.64 3,900.00 33.46 315.06 3,752.52 3,704.22 749.81 4,000.00 37.12 312.26 3,834.14 3,785.84 789.63 4,100.00 40.83 309.90 3,911.87 3,863.57 830.90 4,200.00 44.59 307.87 3,985.34 3,937.04 873.44 4,300.00 48.38 306.09 4,054.19 4,005.89 917.02 4,400.00 52.19 304.51 4,118.08 4,069.78 961.43 4,500.00 56.02 303.09 4,176.70 4,128.40 1,006.47 4,600.00 59.86 301.79 4,229.77 4,181.47 1,051.91 4,700.00 63.72 300.59 4,277.03 4,228.73 1,097.53 4,800.00 67.59 299.47 4,318.25 4,269.95 1,143.11 4,900.00 71.46 298.41 4,353.22 4,304.92 1,188.42 5,000.00 75.34 297.39 4,381.78 4,333.48 1,233.24 5,100.00 79.23 296.41 4,403.79 4,355.49 1,277.37 5,200.00 83.11 295.46 4,419.13 4,370.83 1,320.57 5,248.50 85.00 295.00 4,424.15 4,375.85 1,341.13 End Dir : 5248.5' MD, 4424.15' TVD 5,300.00 85.00 295.00 4,428.64 4,380.34 1,362.81 5,400.00 85.00 295.00 4,437.36 4,389.06 1,404.91 5,500.00 85.00 295.00 4,446.07 4,397.77 1,447.01 5,548.50 85.00 295.00 4,450.30 4,402.00 1,467.43 Start Dir 4°1100' : 5548.5' MD, 4450.3TVD - 9 518" x 12 1/4" 5,600.00 86.98 294.44 4,453.90 4,405.60 1,488.92 5,634.84 88.33 294.07 4,455.32 4,407.02 1,503.22 End Dir : 5634.84' MD, 4455.32' TVD 5,700.00 88.33 294.07 4,457.23 4,408.93 1,529.78 5,800.00 88.33 294.07 4,460.14 4,411.84 1,570.55 5,845.89 88.33 294.07 4,461.48 4,413.18 1,589.26 Start Dir 4°/100' : 5845.89' MD, 4461.487VD 5,900.00 90.49 293.99 4,462.04 4,413.74 1,611.29 5,925.27 91.50 293.96 4,461.60 4,413.30 1,621.56 End Dir : 5925.27' MD, 4461.6' TVD 6,000.00 91.50 293.96 4,459.65 4,411.35 1,651.90 6,100.00 91.50 293.96 4,457.03 4,408.73 1,692.49 6,200.00 91.50 293.96 4,454.41 4,406.11 1,733.09 6,300.00 91.50 293.96 4,451.79 4,403.49 1,773.68 6,400.00 91.50 293.96 4,449.18 4,400.88 1,814.28 6,500.00 91.50 293.96 4,446.56 4,398.26 1,854.87 6,600.00 91.50 293.96 4,443.94 4,395.64 1,895.47 6,700.00 91.50 293.96 4,441.32 4,393.02 1,936.07 6,800.00 91.50 293.96 4,438.70 4,390.40 1,976.66 3/192019 12:56:59PM Page 5 COMPASS 5000.15 Build 91 Map Map +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) 3,347.10 428.75 6,016,693.83 569,688.15 4.00 -131.26 411.12 6,016,725.79 569,670.23 4.00 -101.71 387.24 6,016,759.88 569,646.03 4.00 -65.56 357.23 6,016,795.93 569,615.68 4.00 -23.00 321.22 6,016,833.75 569,579.33 4.00 25.76 279.40 6,016,873.18 569,537.14 4.00 80.49 231.97 6,016,914.01 569,489.33 4.00 140.92 179.15 6,016,956.04 569,436.13 4.00 206.76 121.22 6,016,999.08 569,377.80 4.00 277.69 58.44 6,017,042.91 569,314.61 4.00 353.36 -8.87 6,017,087.31 569,246.89 4.00 433.39 -80.39 6,017,132.08 569,174.96 4.00 517.41 -155.76 6,017,176.99 569,099.17 4.00 605.01 -234.63 6,017,221.83 569,019.89 4.00 695.75 -316.61 6,017,266.37 568,937.51 4.00 789.19 -401.29 6,017,310.40 568,852.42 4.00 884.88 488.26 6,017,353.71 568,765.05 4.00 982.35 -577.11 6,017,396.08 568,675.81 4.00 1,081.14 -620.75 6,017,416.23 568,631.99 4.00 1,129.37 -667.24 6,017,437.48 568,585.30 0.00 1,180.68 -757.53 6,017,478.74 568,494.63 0.00 1,280.30 -847.82 6,017,519.99 568,403.97 0.00 1,379.92 -891.60 6,017,540.00 568,360.00 0.00 1,428.23 -938.27 6,017,561.05 568,313.14 4.00 1,479.60 -970.00 6,017,575.05 568,281.28 4.00 1,514.41 -1,029.47 6,017,601.06 568,221.57 0.00 1,579.53 -1,120.74 6,017,640.97 568,129.94 0.00 1,679.48 -1,162.62 6,017,659.29 568,087.89 0.00 1,725.34 -1,212.04 6,017,680.86 568,038.27 4.00 1,779.44 -1,235.12 6,017,690.91 568,015.10 4.00 1,804.70 -1,303.39 6,017,720.61 567,946.56 0.00 1,879.39 -1,394.74 6,017,760.35 567,854.84 0.00 1,979.34 -1,486.09 6,017,800.09 567,763.12 0.00 2,079.29 -1,577.44 6,017,839.84 567,671.41 0.00 2,179.24 -1,668.79 6,017,879.58 567,579.69 0.00 2,279.19 -1,760.15 6,017,919.32 567,487.97 0.00 2,379.14 -1,851.50 6,017,959.06 567,396.26 0.00 2,479.09 -1,942.85 6,017,998.80 567,304.54 0.00 2,579.04 -2,034.20 6,018,038.54 567,212.82 0.00 2,678.99 3/192019 12:56:59PM 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-38 Wellbore: MPE-38 Design: MPU E-38 wp09 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (usft) (0) (0) (usft) usft 6,900.27 91.50 293.96 4,436.08 4,387.78 Start Dir 3-1100': 6900.27' MD, 4436.08TVD 6,989.96 94.19 293.96 4,431.63 4,383.33 End Dir : 6989.96' MD, 4431.63' TVD 7,000.00 94.19 293.96 4,430.89 4,382.59 7,100.00 94.19 293.96 4,423.59 4,375.29 7,178.40 94.19 293.96 4,417.86 4,369.56 Start Dir 3°/100' : 7178.4' MD, 4417.86'TVD 7,201.42 93.50 293.96 4,416.31 4,368.01 End Dir : 7201.42' MD, 4416.31' TVD 7,300.00 93.50 293.96 4,410.30 4,362.00 7,400.00 93.50 293.96 4,404.19 4,355.89 7,501.42 93.50 293.96 4,398.00 4,349.70 Start Dir 301100' : 7501.42' MD, 4398'TVD 7,542.94 92.26 293.96 4,395.91 4,347.61 End Dir : 7542.94' MD, 4395.91' TVD 7,600.00 92.26 293.96 4,393.66 4,345.36 7,700.00 92.26 293.96 4,389.72 4,341.42 7,800.00 92.26 293.96 4,385.77 4,337.47 7,846.43 92.26 293.96 4,383.94 4,335.64 Start Dir 3-1100': 7846.43' MD, 4383.94'TVD 7,901.58 90.60 293.96 4,382.57 4,334.27 End Dir : 7901.58' MD, 4382.57' TVD 8,000.00 90.60 293.96 4,381.54 4,333.24 8,100.00 90.60 293.96 4,380.49 4,332.19 8,200.00 90.60 293.96 4,379.44 4,331.14 8,300.00 90.60 293.96 4,378.39 4,330.09 8,400.00 90.60 293.96 4,377.35 4,329.05 8,500.00 90.60 293.96 4,376.30 4,328.00 8,600.00 90.60 293.96 4,375.25 4,326.95 8,700.00 90.60 293.96 4,374.21 4,325.91 8,800.00 90.60 293.96 4,373.16 4,324.86 81900.00 90.60 293.96 4,372.11 4,323.81 9,000.00 90.60 293.96 4,371.06 4,322.76 9,101.58 90.60 293.96 4,370.00 4,321.70 Start Dir 30/100' : 9101.58' MD, 4370'TVD 9,200.00 87.65 293.96 4,371.50 4,323.20 9,236.70 86.55 293.96 4,373.36 4,325.06 End Dir : 9236.7' MD, 4373.36' TVD 9,300.00 86.55 293.96 4,377.18 4,328.88 9,401.78 86.55 293.96 4,383.31 4,335.01 Start Dir 3-1100': 9401.78' MD, 4383.311 VD 9,501.90 89.55 293.96 4,386.72 4,338.42 End Dir : 9501.9' MD, 4386.72' TVD 9,600.00 89.55 293.96 4,387.49 4,339.19 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU E-38 MPE-38 wp02 KBE @ 48.30usft MPE-38 wp02 KBE @ 48.30usft True Minimum Curvature 3/1912019 12:56:59PM Page 6 COMPASS 5000.15 Build 91 Map Map +Nl-S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 4,387.78 2,017.37 -2,125.80 6,018,078.39 567,120.86 0.00 2,779.20 2,053.74 -2,207.65 6,018,114.00 567,038.68 3.00 2,868.76 2,057.81 -2,216.80 6,018,117.98 567,029.49 0.00 2,878.77 2,098.31 -2,307.94 6,018,157.62 566,937.99 0.00 2,978.49 2,130.06 -2,379.40 6,018,188.71 566,866.25 0.00 3,056.67 2,139.39 -2,400.38 6,018,197.84 566,845.18 3.00 3,079.63 2,179.35 -2,490.30 6,018,236.96 566,754.90 0.00 3,178.01 2,219.88 -2,581.51 6,018,276.64 566,663.33 0.00 3,277.81 2,260.99 -2,674.02 6,018,316.88 566,570.45 0.00 3,379.02 2,277.83 -2,711.92 6,018,333.36 566,532.40 2.99 3,420.48 2,300.98 -2,764.02 6,018,356.03 566,480.09 0.00 3,477.49 2,341.55 -2,855.33 6,018,395.75 566,388.41 0.00 3,577.39 2,382.13 -2,946.65 6,018,435.47 566,296.74 0.00 3,677.30 2,400.97 -2,989.04 6,018,453.91 566,254.17 0.00 3,723.69 2,423.35 -3,039.42 6,018,475.83 566,203.59 3.01 3,778.81 2,463.32 -3,129.36 6,018,514.95 566,113.29 0.00 3,877.21 2,503.93 -3,220.74 6,018,554.70 566,021.55 0.00 3,977.18 2,544.54 -3,312.11 6,018,594.46 565,929.81 0.00 4,077.16 2,585.14 -3,403.49 6,018,634.21 565,838.07 0.00 4,177.14 2,625.75 -3,494.87 6,018,673.96 565,746.32 0.00 4,277.12 2,666,36 -3,586.25 6,018,713.71 565,654.58 0.00 4,377.10 2,706.97 -3,677.63 6,018,753.47 565,562.84 0.00 4,477.07 2,747.57 -3,769.00 6,018,793.22 565,471.10 0.00 4,577.05 2,788.18 -3,860.38 6,018,832.97 565,379.35 0.00 4,677.03 2,828.79 -3,951.76 6,018,872.72 565,287.61 0.00 4,777.01 2,869.40 -4,043.14 6,018,912.48 565,195.87 0.00 4,876.99 2,910.65 -4,135.96 6,018,952.86 565,102.67 0.00 4,978.54 2,950.60 -4,225.88 6,018,991.97 565,012.40 3.00 5,076.93 2,965.49 4,259.37 6,019,006.54 564,978.77 3.00 5,113.57 2,991.14 -4,317.11 6,019,031.66 564,920.79 0.00 5,176.75 3,032.39 4,409.96 6,019,072.04 564,827.58 0.00 5,278.32 3,073.02 -4,501.39 6,019,111.81 564,735.79 3.00 5,378.36 3,112.86 4,591.03 6,019,150.81 564,645.78 0.00 5,476.44 3/1912019 12:56:59PM Page 6 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt E Pad Well: Plan: MPU E-38 Wellbore: MPE-38 Design: MPU E-38 wp09 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss (usft) (0) (_) (usft) usft 9,700.00 89.55 293.96 4,388.27 4,339.97 9,800.00 89.55 293.96 4,389.06 4,340.76 9,900.00 89.55 293.96 4,389.84 4,341.54 10,000.00 89.55 293.96 4,390.63 4,342.33 10,100.00 89.55 293.96 4,391.41 4,343.11 10,200.00 89.55 293.96 4,392.20 4,343.90 10,301.90 89.55 293.96 4,393.00 4,344.70 Start Dir 3.03-/100': 10301.9' MD, 4393'TVD 10,400.00 92.52 293.96 4,391.23 4,342.93 10,462.85 94.43 293.95 4,387.42 4,339.12 End Dir : 10462.85' MD, 4387.42' TVD 10,479.13 94.43 293.95 4,386.16 4,337.86 Start Dir 3.03-1100': 10479.13' MD, 4386.16'TVD 10,500.00 93.79 293.96 4,384.66 4,336.36 10,602.12 90.70 293.96 4,380.66 4,332.36 End Dir : 10602.12' MD, 4380.66' TVD 10,700.00 90.70 293.96 4,379.46 4,331.16 10,800.00 90.70 293.96 4,378.24 4,329.94 10,900.00 90.70 293.96 4,377.02 4,328.72 11,000.00 90.70 293.96 4,375.80 4,327.50 11,100.00 90.70 293.96 4,374.58 4,326.28 11,200.00 90.70 293.96 4,373.36 4,325.06 11,300.00 90.70 293.96 4,372.13 4,323.83 11,400.00 90.70 293.96 4,370.91 4,322.61 11,500.00 90.70 293.96 4,369.69 4,321.39 11,600.00 90.70 293.96 4,368.47 4,320.17 11,700.00 90.70 293.96 4,367.25 4,318.95 11,802.12 90.70 293.96 4,366.00 4,317.70 Start Dir 3.0611100': 11802.12' MD, 4366'TVD 11,861.38 88.91 294.26 4,366.20 4,317.90 End Dir : 11861.38' MD, 4366.2' TVD 11,900.00 88.91 294.26 4,366.93 4,318.63 11,983.84 88.91 294.26 4,368.53 4,320.23 Start Dir 3.06°/100' : 11983.84' MD, 4368.53'TVD 12,000.00 89.41 294.25 4,368.76 4,320.46 12,052.10 91.00 294.22 4,368.58 4,320.28 End Dir : 12052.1' MD, 4368.58' TVD 12,100.00 91.00 294.22 4,367.74 4,319.44 12,200.00 91.00 294.22 4,366.00 4,317.70 12,300.00 91.00 294.22 4,364.25 4,315.95 12,400.00 91.00 294.22 4,362.51 4,314.21 12,500.00 91.00 294.22 4,360.76 4,312.46 12,600.00 91.00 294.22 4,359.02 4,310.72 12,700.00 91.00 294.22 4,357.27 4,308.97 12,800.00 91.00 294.22 4,355.53 4,307.23 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU E-38 MPE-38 wp02 KBE @ 48.30usft MPE-38 wp02 KBE @ 48.30usft True Minimum Curvature 3/192019 12:56:59PM Page 7 COMPASS 5000.15 Build 91 Map Map +N/ -S +EI -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 4,339.97 3,153.47 -4,682.41 6,019,190.57 564,554.04 0.00 5,576.42 3,194.07 -4,773.79 6,019,230.32 564,462.29 0.00 5,676.40 3,234.68 -4,865.17 6,019,270.07 564,370.55 0.00 5,776.38 3,275.29 -4,956.55 6,019,309.83 564,278.80 0.00 5,876.36 3,315.90 -5,047.93 6,019,349.58 564,187.06 0.00 5,976.34 3,356.51 -5,139.31 6,019,389.33 564,095.31 0.00 6,076.32 3,397.89 -5,232.43 6,019,429.84 564,001.83 0.00 6,178.20 3,437.71 -5,322.05 6,019,468.83 563,911.84 3.03 6,276.26 3,463.19 -5,379.38 6,019,493.76 563,854.29 3.03 6,338.98 3,469.78 -5,394.21 6,019,500.21 563,839.40 0.00 6,355.21 3,478.23 -5,413.24 6,019,508.49 563,820.30 3.03 6,376.02 3,519.66 -5,506.48 6,019,549.05 563,726.69 3.03 6,478.03 3,559.40 -5,595.91 6,019,587.96 563,636.89 0.00 6,575.89 3,600.01 -5,687.29 6,019,627.71 563,545.15 0.00 6,675.87 3,640.62 -5,778.67 6,019,667.46 563,453.41 0.00 6,775.84 3,681.22 -5,870.04 6,019,707.21 563,361.67 0.00 6,875.82 3,721.83 -5,961.42 6,019,746.96 563,269.93 0.00 6,975.79 3,762.44 -6,052.79 6,019,786.71 563,178.18 0.00 7,075.77 3,803.05 -6,144.17 6,019,826.47 563,086.44 0.00 7,175.75 3,843.65 -6,235.55 6,019,866.22 562,994.70 0.00 7,275.72 3,884.26 -6,326.92 6,019,905.97 562,902.96 0.00 7,375.70 3,924.87 -6,418.30 6,019,945.72 562,811.22 0.00 7,475.67 3,965.47 -6,509.68 6,019,985.47 562,719.48 0.00 7,575.65 4,006.94 -6,602.99 6,020,026.07 562,625.79 0.00 7,677.75 4,031.15 -6,657.08 6,020,049.77 562,571.49 3.06 7,737.00 4,047.01 -6,692.28 6,020,065.30 562,536.14 0.00 7,775.61 4,081.45 -6,768.70 6,020,099.03 562,459.41 0.00 7,859.42 4,088.09 -6,783.44 6,020,105.53 562,444.62 3.06 7,875.58 4,109.47 -6,830.94 6,020,126.47 562,396.92 3.06 7,927.67 4,129.12 -6,874.62 6,020,145.71 562,353.06 0.00 7,975.56 4,170.14 -6,965.80 6,020,185.87 562,261.51 0.00 8,075.54 4,211.15 -7,056.99 6,020,226.03 562,169.96 0.00 8,175.51 4,252.17 -7,148.17 6,020,266.20 562,078.41 0.00 8,275.49 4,293.19 -7,239.35 6,020,306.36 561,986.85 0.00 8,375.46 4,334.21 -7,330.54 6,020,346.53 561,895.30 0.00 8,475.44 4,375.23 -7,421.72 6,020,386.69 561,803.75 0.00 8,575.41 4,416.24 -7,512.91 6,020,426.86 561,712.20 0.00 8,675.39 3/192019 12:56:59PM Page 7 COMPASS 5000.15 Build 91 Halliburton H A L L I B U R TO N Standard Proposal Report Database: NORTH US + CANADA Local Coordinate Reference: Well Plan: MPU E-38 Company: Hilcorp Alaska, LLC TVD Reference: MPE-38 wp02 KBE @ 48.30usft Project: Milne Point MD Reference: MPE-38 wp02 KBE @ 48.30usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-38 Survey Calculation Method: Minimum Curvature Wellbore: MPE-38 Design: MPU E-38 wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E1 -W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 4,305.48 12,900.00 91.00 294.22 4,353.78 4,305.48 4,457.26 -7,604.09 6,020,467.02 561,620.64 0.00 8,775.37 13,002.10 91.00 294.22 4,352.00 4,303.70 4,499.14 -7,697.19 6,020,508.03 561,527.17 0.00 8,877.44 Start Dir 301100' : 13002.1' MD, 4352'TVD 13,100.16 93.78 295.20 4,347.92 4,299.62 4,540.09 -7,786.18 6,020,548.15 561,437.81 3.00 8,975.40 End Dir : 13100.16' MD, 4347.92' TVD 13,192.96 93.78 295.20 4,341.81 4,293.51 4,579.51 -7,869.97 6,020,586.78 561,353.66 0.00 9,068.00 Start Dir 301100' : 13192.96' MD, 4341.81'TVD 13,200.00 93.56 295.18 4,341.35 4,293.05 4,582.50 -7,876.33 6,020,589.72 561,347.28 3.00 9,075.03 13,302.33 90.50 295.00 4,337.73 4,289.43 4,625.87 -7,968.93 6,020,632.21 561,254.28 3.00 9,177.28 End Dir : 13302.33' MD, 4337.73' TVD 13,400.00 90.50 295.00 4,336.87 4,288.57 4,667.14 -8,057.45 6,020,672.66 561,165.40 0.00 9,274.95 13,500.00 90.50 295.00 4,336.00 4,287.70 4,709.40 -8,148.08 6,020,714.07 561,074.39 0.00 9,374.94 13,600.00 90.50 295.00 4,335.13 4,286.83 4,751.66 -8,238.70 6,020,755.48 560,983.38 0.00 9,474.94 13,700.00 90.50 295.00 4,334.26 4,285.96 4,793.92 -8,329.33 6,020,796.89 560,892.37 0.00 9,574.94 13,800.00 90.50 295.00 4,333.38 4,285.08 4,836.18 -8,419.96 6,020,838.31 560,801.37 0.00 9,674.93 13,900.00 90.50 295.00 4,332.51 4,284.21 4,878.44 -8,510.58 6,020,879.72 560,710.36 0.00 9,774.93 14,000.00 90.50 295.00 4,331.64 4,283.34 4,920.70 -8,601.21 6,020,921.13 560,619.35 0.00 9,874.92 14,100.00 90.50 295.00 4,330.77 4,282.47 4,962.96 -8,691.84 6,020,962.54 560,528.34 0.00 9,974.92 14,200.00 90.50 295.00 4,329.89 4,281.59 5,005.22 -8,782.47 6,021,003.95 560,437.34 0.00 10,074.92 14,302.33 90.50 295.00 4,329.00 4,280.70 5,048.47 -8,875.21 6,021,046.33 560,344.21 0.00 10,177.24 Start Dir 301100' : 14302.33' MD, 4329'TVD 14,382.42 88.10 295.00 4,329.98 4,281.68 5,082.31 -8,947.78 6,021,079.49 560,271.33 3.00 10,257.32 End Dir : 14382.42' MD, 4329.98' TVD 14,400.00 88.10 295.00 4,330.56 4,282.26 5,089.74 -8,963.71 6,021,086.77 560,255.34 0.00 10,274.89 14,500.00 88.10 295.00 4,333.88 4,285.58 5,131.97 -9,054.29 6,021,128.16 560,164.38 0.00 10,374.84 14,600.00 88.10 295.00 4,337.20 4,288.90 5,174.21 -9,144.87 6,021,169.55 560,073.41 0.00 10,474.78 14,700.00 88.10 295.00 4,340.52 4,292.22 5,216.45 -9,235.45 6,021,210.94 559,982.45 0.00 10,574.73 14,800.00 88.10 295.00 4,343.84 4,295.54 5,258.69 -9,326.03 6,021,252.33 559,891.49 0.00 10,674.67 14,900.00 88.10 295.00 4,347.17 4,298.87 5,300.92 -9,416.61 6,021,293.72 559,800.53 0.00 10,774.62 14,943.24 88.10 295.00 4,348.60 4,300.30 5,319.19 -9,455.78 6,021,311.61 559,761.20 0.00 10,817.83 Start Dir 301100' : 14943.24' MD, 4348.6TVD 15,000.00 89.80 295.00 4,349.64 4,301.34 5,343.17 -9,507.21 6,021,335.12 559,709.55 3.00 10,874.58 Start Dir 501100' : 15000' MD, 4349.647VD 15,100.00 84.80 295.00 4,354.35 4,306.05 5,385.37 -9,597.71 6,021,376.47 559,618.67 5.00 10,974.44 15,196.00 80.00 295.00 4,367.04 4,318.74 5,425.57 -9,683.93 6,021,415.87 559,532.09 5.00 11,069.57 End Dir : 15196' MD, 4367.04' TVD 15,200.00 80.00 295.00 4,367.74 4,319.44 5,427.24 -9,687.50 6,021,417.50 559,528.51 0.00 11,073.51 15,300.00 80.00 295.00 4,385.10 4,336.80 5,468.86 -9,776.75 6,021,458.28 559,438.88 0.00 11,171.99 15,400.00 80.00 295.00 4,402.47 4,354.17 5,510.48 -9,866.01 6,021,499.07 559,349.25 0.00 11,270.47 15,500.00 80.00 295.00 4,419.83 4,371.53 5,552.10 -9,955.26 6,021,539.85 559,259.62 0.00 11,368.95 15,600.00 80.00 295.00 4,437.20 4,388.90 5,593.72 -10,044.51 6,021,580.64 559,169.99 0.00 11,467.43 15,700.00 80.00 295.00 4,454.56 4,406.26 5,635.34 -10,133.77 6,021,621.42 559,080.36 0.00 11,565.91 15,788.90 80.00 295.00 4,470.00 4,421.70 5,672.34 -10,213.11 6,021,657.68 559,000.69 0.00 11,653.46 Total Depth : 15788.9' MD, 4470' TVD 3/192019 12:56:59PM Page 8 COMPASS 5000.15 Build 91 311912019 12:56:59PM Page 9 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 Plan: MPU E-38 Company: Hilcorp Alaska, LLC TVD Reference: MPE-38 wp02 KBE @ 48.30usft Project: Milne Point MD Reference: MPE-38 wp02 KBE @ 48.30usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-38 Survey Calculation Method: Minimum Curvature Wellbore: MPE-38 Design: MPU E-38 wp09 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/ -S +EI -W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) MPU E-38 wp08 CP7 0.00 0.00 4,329.00 5,048.47 -8,875.20 6,021,046.33 560,344.21 - plan hits target center -Circle (radius 50.00) MPU E-38 wp08 CP5 0.00 0.00 4,366.00 4,006.94 -6,602.99 6,020,026.07 562,625.79 - plan hits target center - Circle (radius 50.00) MPU E-38 wp08 CP6 0.00 0.00 4,352.00 4,499.14 -7,697.19 6,020,508.03 561,527.17 - plan hits target center - Circle (radius 50.00) MPU E-38 wp08 CP2 0.00 0.00 4,398.00 2,260.99 -2,674.02 6,018,316.88 566,570.45 - plan hits target center - Circle (radius 50.001 MPU E-38 wp08 CP3 0.00 0.00 4,370.00 2,910.65 -4,135.96 6,018,952.86 565,102.67 - plan hits target center - Circle (radius 50.00) MPU E-38 wp08 CP8 0.00 0.00 4,350.00 5,386.50 -9,600.14 6,021,377.58 559,616.23 - plan misses target center by 4.58usft at 15102.08usft MD (4354.54 TVD, 5386.25 IN, -9599.59 E) - Circle (radius 50.00) MPU E-38 wp08 CP4 0.00 0.00 4,393.00 3,397.89 -5,232.42 6,019,429.84 564,001.83 - plan hits target center -Circle (radius 50.00) MPU E-38 wp08 CPI 0.00 0.00 4,436.08 2,017.37 -2,125.80 6,018,078.39 567,120.86 - plan hits target center - Circle (radius 50.00) MPE-38 wp07 Heel 0.00 0.00 4,450.30 1,467.43 -891.60 6,017,540.00 568,360.00 - plan hits target center - Circle (radius 50.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name () (11) 15,788.90 4,470.00 65/8"x81/2" 6-5/8 8-1/2 5,548.50 4,450.30 9 5/8" x 12 1/4" 9-5/8 12-114 311912019 12:56:59PM Page 9 COMPASS 5000.15 Build 91 Plan Annotations Measured Vertical Halliburton H AL L I B O R TO N Depth Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU E-38 Company: Hilcorp Alaska, LLC TVD Reference: MPE-38 wp02 KBE @ 48.30usft Project: Milne Point MD Reference: MPE-38 wp02 KBE @ 48.30usft Site: M Pt E Pad North Reference: True Well: Plan: MPU E-38 Survey Calculation Method: Minimum Curvature Wellbore: MPE-38 12.52 Start Dir 40/100' : 550' MD, 549.29'TVD Design: MPU E-38 wp09 969.64 85.69 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 300.00 300.00 0.00 0.00 Start Dir 3°/100' : 300' MD, 300'TVD : 50` RT TF 550.00 549.29 10.50 12.52 Start Dir 40/100' : 550' MD, 549.29'TVD 987.50 969.64 85.69 102.13 End Dir : 987.5' MD, 969.64' TVD 1,500.00 1,457.05 187.49 223.45 Start Dir 40/100' : 1500' MD, 1457.05'TVD 1,659.83 1,610.88 219.26 252.56 End Dir : 1659.83' MD, 1610.88' TVD 3,075.08 2,986.27 500.07 432.50 Start Dir 4°/100' : 3075.08' MD, 2986.27'TVD 5,248.50 4,424.15 1,341.13 -620.75 End Dir : 5248.5' MD, 4424.15' TVD 5,548.50 4,450.30 1,467.43 -891.60 Start Dir 4-/100': 5548.5' MD, 4450.3'TVD 5,634.84 4,455.32 1,503.22 -970.00 End Dir : 5634.84' MD, 4455.32' TVD 5,845.89 4,461.48 1,589.26 -1,162.62 Start Dir40/100': 5845.89'MD, 4461.48'TVD 5,925.27 4,461.60 1,621.56 -1,235.12 End Dir : 5925.27' MD, 4461.6' TVD 6,900.27 4,436.08 2,017.37 -2,125.80 Start Dir 3-/100': 6900.27' MD, 4436.087VD 6,989.96 4,431.63 2,053.74 -2,207.65 End Dir : 6989.96' MD, 4431.63' TVD 7,178.40 4,417.86 2,130.06 -2,379.40 Start Dir 3°/100' : 7178.4' MD, 4417.86'TVD 7,201.42 4,416.31 2,139.39 -2,400.38 End Dir : 7201.42' MD, 4416.31' TVD 7,501.42 4,398.00 2,260.99 -2,674.02 Start Dir 3-1100': 7501.42' MD, 43987VD 7,542.94 4,395.91 2,277.83 -2,711.92 End Dir : 7542.94' MD, 4395.91' TVD 7,846.43 4,383.94 2,400.97 -2,989.04 Start Dir 3-1100': 7846.43' MD, 4383.94'TVD 7,901.58 4,382.57 2,423.35 -3,039.42 End Dir : 7901.58' MD, 4382.57' TVD 9,101.58 4,370.00 2,910.65 -4,135.96 Start Dir 3°/100' : 9101.58' MD, 4370'TVD 9,236.70 4,373.36 2,965.49 4,259.37 End Dir : 9236.7' MD, 4373.36' TVD 9,401.78 4,383.31 3,032.39 -4,409.96 Start Dir 3°/100' : 9401.78' MD, 4383.31 -TVD 9,501.90 4,386.72 3,073.02 -4,501.39 End Dir : 9501.9' MD, 4386.72' TVD 10,301.90 4,393.00 3,397.89 -5,232.43 Start Dir 3.030/100': 10301.9' MD, 4393'TVD 10,462.85 4,387.42 3,463.19 -5,379.38 End Dir : 10462.85' MD, 4387.42' TVD 10,479.13 4,386.16 3,469.78 -5,394.21 Start Dir 3.03°/100' : 10479.13' MD, 4386.16'TVD 10,602.12 4,380.66 3,519.66 -5,506.48 End Dir : 10602.12' MD, 4380.66' TVD 11,802.12 4,366.00 4,006.94 -6,602.99 Start Dir 3.06-1100': 11802.12' MD, 4366'TVD 11,861.38 4,366.20 4,031.15 -6,657.08 End Dir : 11861.38' MD, 4366.2' TVD 11,983.84 4,368.53 4,081.45 -6,768.70 Start Dir 3.06-1100': 11983.84' MD, 4368.53'TVD 12,052.10 4,368.58 4,109.47 -6,830.94 End Dir : 12052.1' MD, 4368.58' TVD 13,002.10 4,352.00 4,499.14 -7,697.19 Start Dir 3-1100': 13002.1' MD, 4352 -TVD 13,100.16 4,347.92 4,540.09 -7,786.18 End Dir : 13100.16' MD, 4347.92' TVD 13,192.96 4,341.81 4,579.51 -7,869.97 Start Dir 3-1100'; 13192.96' MD, 4341.81'TVD 13,302.33 4,337.73 4,625.87 -7,968.93 End Dir : 13302.33' MD, 4337.73' TVD 14,302.33 4,329.00 5,048.47 -8,875.21 Start Dir 3°/100' : 14302.33' MD, 4329 -TVD 14,382.42 4,329.98 5,082.31 -8,947.78 End Dir : 14382.42' MD, 4329.98' TVD 14,943.24 4,348.60 5,319.19 -9,455.78 Start Dir 3-/100': 14943.24' MD, 4348.6'TVD 15,000.00 4,349.64 5,343.17 -9,507.21 Start Dir 51/100' : 15000' MD, 4349.64'TVD 15,196.00 4,367.04 5,425.57 -9,683.93 End Dir : 15196' MD, 4367.04' TVD 15,788.90 4,470.00 5,672.34 -10,213.11 Total Depth: 15788.9' MD, 4470' TVD 3/192019 12.56:59PM Page 10 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-38 MPE-38 MPU E-38 wp09 Sperry Drilling Services Clearance Summary Anticollision Report 19 March, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad -Plan: MPU E-38 - MPE-38 - MPU E-38 wp09 Well Coordinates: 6,016,081.06 IN, 569,265.12 E (70° 27' 15.45" N, 149. 26' 05.19" W) Datum Height: MPE-38 wp02 KBE @ 48.3nusft Scan Range: 26.50 to 5,548.50 Usft. Measured Depth, Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 2,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: _131M. m_.rM?1Mrr.M Scan Type: 2500 HALLIBURTON Sperry Orilling Services HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU E-38 - MPU E-38 wp09 Closest Approach 3D Proximity Soon on Current Survey Data (North Reference) MPE-03-MPE-03-MPE-03 Reference Design: MPt E Pad - Plan: MPU EJB-MPE438-MPU E-38 wpOg 564.24 760.63 Scan Range: 26.50 to 5,548.50 usft. Measured Depth. 751.07 81.110 Centre Distance Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 2,500.00 usft MPE-03-MPE-03-MPE-03 801.50 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 1,365.12 M Pt A Pad 1,331.38 4,125.00 M Pt C Pad Pass - MPE-04-MPE-04-MPE-04 M Pt E Pad MPE-03-MPE-03-MPE-03 760.63 564.24 760.63 557.28 751.07 81.110 Centre Distance Pass- MPE-03-MPE-03-MPE-03 801.50 564.34 801.50 557.10 789.44 77.993 Ellipse Separation Pass - MPE-03 - MPE,03 - MPE-03 5,548.50 1,365.12 5,548.50 1,331.38 4,125.00 40.467 Clearance Factor Pass - MPE-04-MPE-04-MPE-04 1,734.45 151.98 1,734.45 136.68 1,758.05 9.933 Ellipse Separation Pass - MPE-04-MPE-0 -MPE-04 1,751.50 15228 1,751.50 136.94 1,772.01 9.927 Clearance Factor Pass- MPE-0S-MPE-05-MPE-05 1,705.21 5748 1,705.21 42.87 1,729.39 3.936 Clearance Factor Pass- MPE-06-MPE06-MPE-06 1,859.82 82.63 1,859.82 60.67 1,854.90 3.762 Ellipse Separation Pass - MPE-06-MPE-06-MPE-06 1,876.50 82.88 1,876.50 60.85 1,870.48 3.762 Clearer. Fac[l, Pass - MPE-07-MPE-07-MPE-07 1,087.09 172.93 1,087.09 159.85 1,074.80 13.221 Centre Distance Pass - MPE-07-MPE-07-MPE-07 1,101.50 172.98 1,101.50 159.73 1,088.50 13.052 Ellipse Separation Pass - MPE-07 - MPE-07 - MPE-07 1,326.50 188.87 1,326.50 172.96 1,301.06 11.869 Clearance Factor Pass- MPE-08-MPE-0B-MPE-0B 2,218.10 361.72 2,218.10 341.69 2,224.02 18.059 Centre Distance Pass - MPE-06-MPE-0B-MPE-0B 2,226.50 361.75 2,226.50 341.67 2,230.87 18.019 Ellipse Separation Pass - MPE-08 - MPE-08 - MPE48 2,326.50 366.64 2,326.50 346.06 2,313.93 17.815 Clearance Factor Pass - MPE-09-MPE-09-MPE-09 1,816.82 180.21 1,816.82 145.91 1,866.86 5.254 Centre Distance Pass - MPE-09-MPE-09-MPE-09 1876.50 182.10 1,87650 143.22 1,921.04 4.683 Ellipse Separation Pass - MPE-09-MPE-09-MPE-09 2,001.50 199.40 2,001.50 152.31 2,030.58 4.234 Clearance Factor Pass- MPE4)9-MPE-09PB1-MPE-09PS1 1,816.82 180.21 1,816.82 145.91 1,866.86 5.254 Centre Distance Pass - MPE-09-MPE-09PB1-MPE-09PBi 1,876.50 182.10 1,876.50 143.22 1,921.04 4.683 Ellipse Separation Pass- MPE-09-MPE-09PB1-MPE-09PBi 2,001.50 199.40 2,001.50 152.31 2,030.58 4.234 Clearance Factor Pass - MPE-10-MPE-10-MPE-10 2,121.62 71.96 2,121.62 53.05 2,207.40 3.806 Centre Distance Pass - MPE-10 - MPE-10 - MPE-10 2,126.50 72.02 2,126.60 53.00 2,211.33 3.788 Clearance Factor Pass - MPE-11-MPE-11-MPE-11 387.87 178.89 387.87 174.61 393.35 41.827 Centre Distance Pass - 19 Mann, 2019 - 12:58 Page 2 of 10 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU E-38 - MPU E-38 wp09 Closest Approach 3D Prolrimity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad - Plan: MPU Ed8 - MPE-38 - MPU E38 wp09 Scan Range: 26.50 to 5,548.50 can. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 2,500.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usftl (usft) (usft) usft MPE-11-MPE-11-MPE-11 551.50 179.30 551.50 173.59 556.82 31.402 Ellipse Separation Pass - MPE-11 - MPE-11 - MPE-11 1,901.50 337.95 1,901.50 321.91 1,898.24 21.064 Clearance Factor Pass - MPE-12 - MPE-12 - MPE-12 1,130.64 134.88 1,13064 126.65 1,096.19 16.384 Centre Distance Pass- MPE-12-MPE-12-MPE-12 1,151.50 134.93 1,151.50 126.53 1,116.42 16.064 Ellipse Separation Pass - MPE-1 2 - MPE-1 2 - MPE-1 2 1,351.50 147.37 1,351.50 137.27 1,299.04 14.586 Clearance Factor Pass - MPE-13 - MPE-13B - MPE-13B 26.50 300.01 26.50 299.09 37.11 326.653 Centre Distance Pass - MPE-1 3 - MPE-1 38 - MPE-1 3B 226.50 301.37 226.50 298.76 234.48 115.409 Ellipse Separation Pass - MPE-1 3 - MPE-1 3B - MPE-1 3B 1,376.50 405.53 1,376.50 393.83 1,320.16 34.652 Clearance Factor Pass - MPE-14 - MPE-14 - MPE-1 4 383.01 59.58 383.01 56.22 392.37 17.754 Centre Distance Paw - MPE-44-MPE-14-MPE-14 451.50 59.73 451.50 55.84 460.74 15.366 Ellipse Separation Pass - MPE-14 - MPE-14 - MPE-14 601.50 63.73 601.50 58.98 609.62 13.401 Clearance Factor Pass - MPE-14 - MPE-1 4A - MPE-1 4A 383.01 59.58 383.01 56.22 392.37 17.755 Centre Distance paw - MPE-14-MPE-14A-MPE-14A 451.50 59.73 451.50 5564 460.74 15.366 Ellipse Separation Pass- MPE-14-MPE-14A-MPE-14A 601.50 63.73 601.50 58.98 609.62 13.401 Clearance Factor pass - MPEA4-MPE-I4APB1-MPE-I4APB1 383.01 59.58 383.01 5622 392:37 17.755 Centre Distance Pass - MPE-14-MPE-I4APB1-MPE-I4APB1 451.50 59.73 451.50 55.84 460.74 15.366 Ellipse Separation Pass - MPE-14-MPE-I4APB1-MPE-I4APB1 601.50 63.73 601.50 58.98 609.62 13.401 Clearance Factor Pass - MPE-1 5 - MPE-1 5 - MPE-1 5 356.00 29.19 356.00 23.75 361.72 5.368 Centre Distance Pass - MPE-15 - MPE-15 - MPE-15 426.50 29.76 426.50 23.24 432.02 4,562 Ellipse Separation Pass - MPE-15 - MPE-15 - MPE-15 501.50 32.67 501.50 24.99 506.52 4.255 Clearance Factor Pass - MPE-1 6 - MPEAS - MPE-1 6 989.31 19685 989.31 106.30 950.08 22.800 Centre Distance Pass- MPE-16-MPE-16-MPE-16 1,001.50 194.91 1,001.50 186.26 961.58 22.536 Ellipse Separation Pass - MPE-1 6 - MPE-1 6 - MPE-1 6 1,501.50 232.19 1,501.50 219.17 1,430.47 17.835 Clearance Factor Pass- MPE-17-MPE-17-MPE-17 1,097.26 73.74 1,097.26 64.19 1,068.23 7.722 Centre Distance Pass - MPE-1 7 - MPE-1 7 - MPE-17 1,101.50 73.75 1,101.50 64.17 1,072.17 7.693 Ellipse Separation Pass - MPE-17 - MPE-17 - MPE-17 1,126.50 74.40 1,126.50 64.59 1,094.87 7.588 Clearance Factor Pass - MPE-18 - MPE-18 - MPE-18 26.50 150.03 26.50 148.68 36.43 111.191 Centre Distance Pass - MPE-18 - MPE-18 - MPEA8 101.50 150.17 101.50 148.37 110.91 83.569 Ellipse Separation Pass - MPE-18 - MPE-18 - MPE-18 5,548.50 1,280.42 5,548.50 1,201.84 4,522.18 16.294 Clearance Factor Pass - MPE-1 9 - MPE-1 9 - MPE-1 9 919.92 120.42 919.92 113.85 006.56 18.342 Ellipse Separation Pass - 19 March, 2019 - 12'58 Page 3 of 10 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU E-38 - MPU E-38 wp09 473.14 117.23 473.14 112.71 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) 25.936 Centre Distance Pass - MPE-20-MPE-20AL1-MPE-20AL1 501.50 117.29 Reference Design: MPt E Pad - Plan: MPU E-38 - MPE-38 - MPU E-38 wpD9 112.56 511.70 24.772 Ellipse Separation Pass - MPE-20-MPE-20ALl-MPE-20AL1 Scan Range: 26.50 to 5,548.50 usft. Measured Depth. 1,092.98 5,548.50 997.79 4,707.19 11.482 Clearance Factor Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 2,500.00 usft MPE-20 - MPE-20ALl PB1 - MPE-20ALl Pat 473.14 117.23 473.14 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on 501.50 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (uaft) usft 998.01 4,707.19 MPE-1 9 - MPE-1 9 - MPE-1 9 5.548.50 429.50 5,548.50 345.93 4,801.84 5.139 Clearance Factor Pass - MPE-20 - MPE-20 - MPE-20 473.14 117.23 473.14 112.71 478.89 25.936 Centre Distance Pass- MPE-20-MPE-20-MPE-20 501.50 117.29 501.50 112.56 506.95 24.771 Ellipse Separation Pass - MPE-20 - MP&20 - MPE-20 4,726.50 86150 4,726.50 821.66 4,327.63 21.571 Clearance Factor Pass - MPE-20 - MPE-20A - MPE-20A 473.14 117.23 473.14 112.71 483.64 25.936 Centre Distance Pass - MPE-20-MPE-20A-MPE-20A 501.50 117.29 501.50 112.56 511.70 24.772 Ellipse Separation Pass - MPE-20- MPE-20A- MPE-20A 5,548.50 1,092.98 5,548.50 998.01 4,707.19 11.509 Clearance Factor Pass- MPE-20-MPE-20ALl-MPE-20ALI 473.14 117.23 473.14 112.71 483.64 25.936 Centre Distance Pass - MPE-20-MPE-20AL1-MPE-20AL1 501.50 117.29 501.50 112.56 511.70 24.772 Ellipse Separation Pass - MPE-20-MPE-20ALl-MPE-20AL1 5.548.50 1,092.98 5,548.50 997.79 4,707.19 11.482 Clearance Factor Pass - MPE-20 - MPE-20ALl PB1 - MPE-20ALl Pat 473.14 117.23 473.14 112.71 483.64 25.936 Centre Distance Pass - MPE-20 - MPE-20ALl PB1 - MPE-20ALl PBI 501.50 117.29 501.50 112.56 511.70 24.772 Ellipse Separation Pass - MPE-20 - MPE-20ALIPB1 - MPE-20ALl Pat 5,548.50 1,092.98 5,548.50 998.01 4,707.19 11.509 Clearance Factor Pass - MPE-21 - MPE-21 - MPE-21 1,853.42 117.43 1,853.42 106.42 1,847.38 10.671 Come Distance Paw - MPE-21-MPE-21-MPE-21 1,901.50 117.79 1,901.50 106.23 1,895.32 10.193 Ellipse Separation pass - MPE-21-MPE-21-MPE-21 2,151.50 138.00 2,151.50 122.53 2,138.62 8.920 Clearance Factor Pass - MPE-22-MPE-22-MPE-22 1,872.29 298.32 1,872.29 28288 1,935.06 18.378 Centra Distance Pass- MPE-22-MPE-22-MPE-22 1,876.50 298.32 1,876.50 282.06 1,938.70 18.341 Ellipse Separation Pass- MPE-22-MPE-22-MPE-22 2,026.50 309.49 2,D26.50 292.4 2,066.94 17.734 Clearance Factor Pass - MPE-23 - MPE-23 - MPE-23 1,103.74 10587 1,10374 96.17 1,087.06 10.908 Ellipse Separation Pass- MPE-23-MPE-23-MPE-23 1,201.50 110.05 1,20150 99.52 1,179.83 10,450 Clearance Factor Pass - MPE-24 - MPE-24 - MPE-24 315.11 8898 315.11 86.12 323.90 31.168 Centre Distance Pass - MPE-24 - MPE-24 - MPE-24 451.50 89.34 451.50 85.42 460.45 22.771 Ellipse Separation Pass - MPE-24 - MPE-24 - MPE-24 601.50 96.35 60150 91.48 606.70 19.781 Clearance Factor Pass - MPE-24 - MPE-24A - MPE-24A 315.11 88.98 315.11 8623 320.50 32.410 Centre Distance Pass - MPE-24 - MPE-24A - MPE-24A 451.50 89.34 45150 85.53 457.05 23.424 Ellipse Separation Pass - MPE-24 - MPE-24A - MPE-24A 601.50 96.35 601.50 91.59 603.30 20.235 Clearance Factor Pass- MPE-24-MPE-24ALl-MPE-24AL1 315.11 88.98 315.11 86.23 320.50 32.410 Centre Distance Pass - MPE-24 - MPE-24ALl - MPE-24ALl 451.50 89.34 451.50 85.53 457.05 23.424 Ellipse Separation Pass - MPE-24-MPE-24ALl-MPE-24AL1 601.50 96.35 601.50 91.59 603.30 20.233 Clearance Factor Pass - 19 March, 2019 - 12:58 Page 4 0f 10 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU E-38 - MPU E-38 wpO9 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: MMEPad - Plan: MPU E48 - MPE38 - MPU E38 wp09 Scan Range: 26.50 to 5,548.51) ..ft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 2,500.00 usft Measured Minimum §Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usR) (usN) (sift) (usR) ".ft MPE-25-MPE-25-MPE-25 614.97 207.76 614.97 202.86 620.98 42.402 Centre Distance Pass - MPE-25-MPE-25-MPE-25 651.50 207.88 651.50 202.81 657.57 41.026 Ellipse Separation Paw - MPE-25-MPE-25-MPE-25 976.50 244.94 976.50 237.98 955.72 35.223 Clearance Factor Pass- MPE-25-MPE-25A-MPE-25A 614.97 207.76 614.97 202.86 625.93 42.403 Centre Distance Paw - MPE-25-MPE-25A-MPE-25A 651.50 207.88 651.50 202.81 662.52 41.026 Ellipse Separation Pass - MPE-25-MPE-25A-MPE-25A 976.50 244.94 976.50 237.98 960.67 35.224 Clearance Factor Pass- MPE-25-MPE-251-1-MPE-251-1 614.97 207.76 614.97 202.86 620.98 42.402 Centre Distance Pass - MPE-25- MPE-251-1 - MPE-251-1 651.50 207.88 651.50 202.81 657.57 41.026 Ellipse Separation Pass - MPE-25-MPE-251-1-MPE-25L1 976.50 244.94 976.50 237.98 955.72 35.223 Clearance Factor Pass - MPE-25-MPE-25L1PBi-MPE-251-1P81 614.97 207.76 614.97 202.86 620.98 42.402 Centre Distance Pass - MPE-25-MPE-25L1PB1-MPE-25L1PS1 651.50 207.88 651.50 202.81 657.57 41.026 Ellipse Separation Pass - MPE-25-MPE-251-1 PBI-MPE-25L1 PBI 976.50 244.94 976.50 237.98 955.72 35.223 Clearance Factor Pass - MPE-25-MPE-25PB1-MPE-25PB1 614.97 207.76 614.97 202.75 620.98 41.477 Centre Distance Pass - MPE-25-MPE-25PB1-MPE-25P01 651.50 207.88 651.50 202.70 657.57 40.160 Ellipse Separation Pass - MPE-25-MPE-25PB1-MPE-25PB1 976.50 244.94 976.50 237.87 955.72 34.666 Clearance Factor Pass - MPE-25-MPE-25PB2-MPE-25PB2 614.97 207.76 614.97 202.86 620.98 42.402 Centre Distance Pass - MPE-25 - MPE-25PB2 - MPE-25PB2 651.50 207.88 651.50 202.81 657.57 41.026 Ellipse Separation Pass - MPE-25 - MPE-25PB2 - MPE-25PB2 976.50 244.94 976.50 237.98 955.72 35.223 Clearance Factor Pass - MPE-25-MPE-25PB3-MPE-25PB3 614.97 2117.76 614.97 202.86 620.98 42.402 Centre Distance Pass - MPE-25 - MPE-25PB3- MPE-25PB3 651.50 207.88 651.50 202.81 657.57 41.026 Ellipse Separation Pass - MPE-25 - MPE-25PB3 - MPE-25PB3 97650 24 A,I 976.50 237.98 955.72 35.223 Clearance Factor Pass - MPE-26 - MPE-26 - MPE-26 198.63 269.85 198.63 267.60 202.93 119.863 Centre Distance Pass - MPE-26 - MPE-26 - MPE-26 501.50 271.04 501.50 266.45 504.03 59.050 Ellipse Separation Pass- MPE-26-MPE-26-MPE-26 5,034.59 507.72 5,034.59 454.82 4,617.98 9.599 Clearance Factor Pass - MPE-30-MPE-30-MPE-30 986.40 275.52 98640 268.96 961.02 41.997 Centre Distance Pass- MPE-30-MPE-30-MPE-30 1,001.50 275.57 1,001.50 268.91 975.32 41.328 Ellipse Separation Pass - MPE-30-MPE-30-MPE-30 2,676.50 310.97 2,676.50 285.90 2,624.08 12.40D Clearance Factor Paw - MPE-30-MPE-30A-MPE3OA 986.40 275.52 986AO 268.96 961.02 41.995 Centre Distance Pass - MPE-30-MPE-30A-MPE10A 1,001.50 275.57 1,001.50 268.91 975.32 41.326 Ellipse Separation Pass - MPE-30-MPE-WA-MPE-30A 2,676.50 310.97 2,676.50 285.84 2,624.08 12.372 Clearance Factor Pass - 19 Marc01, 2019 - 12:58 Page 5 of 10 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU E-38 - MPU E-38 wp09 986.40 275.52 986.40 268.96 Closest Approach 3o Proximity Scan on Current Survey Data (North Reference) 41.995 Centre Distance Pass - MPE-30-MPE-WAPBI-MPE-30APB1 1,001.50 275.57 Reference Design: MPt E Pad - Plan: MPU E38-MPE38-MPU E38 Wp09 268.91 975.32 41.326 Ellipse Separation Pass- MPE-30-MPE-30APB1-MPE-30APB1 Scan Range: 26.50 to 5,548.50 usft. Measured Depth. 310.97 2,676.50 285.84 2,624.08 12.372 Clearance Factor Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 2,500.00 usft MPE-32 - MPE-32 - MPE-32 3,176.50 234.75 Measured Minimum (gMeasured Ellipse @Measured Clearance Summary Based on MPE-32 - MPE32 - MPE-32 Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Wall Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 3,252.53 203.14 MPE30-MPE-30AL1-MPE-300,1-1 986.40 275.52 986.40 268.96 961.02 41.996 CenUe Distance Pass - MPE30-MPE-30AL1-MPE-30AL1 1,001.50 275.57 1,001.50 268.91 975.32 41.327 Ellipse Separation Pass- MPE-30-MPE-30AL1-MPE-30AL1 2,676.50 310.97 2,676.50 285.87 2,624.08 12.386 Clearance Factor Pass- MPE30-MPE30ALIPBI-MPE-30AL1PB1 98640 275.52 986.40 268.96 961.02 41.995 Centre Distance Pass - MPE-30-MPE-30AL1PB1-MPE30AL1PB1 1,001.50 275.57 1,001.50 268.91 975.32 41.326 Ellipse Separation Pass - MPE-30- MPE30AL1PB1-MPE-30AL1PB1 2,676.50 310.97 2,676.50 285.84 2,624.08 12.372 Clearance Factor Pass - MPE30-MPE-30APB1-MPE30APB1 986.40 275.52 986.40 268.96 961.02 41.995 Centre Distance Pass - MPE-30-MPE-WAPBI-MPE-30APB1 1,001.50 275.57 1,001.50 268.91 975.32 41.326 Ellipse Separation Pass- MPE-30-MPE-30APB1-MPE-30APB1 2,676.50 310.97 2,676.50 285.84 2,624.08 12.372 Clearance Factor Pass - MPE-32 - MPE-32 - MPE-32 3,176.50 234.75 3,176.50 203.66 3,152.76 7.551 Clearance Factor Pass - MPE-32 - MPE32 - MPE-32 3,226.50 234.01 3,226.50 203.10 3,200.51 7.569 Ellipse Separation Pass - MPE-32 - MPE-32 - MPE-32 3,252.53 233.90 3,252.53 203.14 3.225.19 7.604 Centre Distance Pass - MPE-32 - MPE-321-1 - MPE-321-1 3,176.50 234.75 3,176.50 203.61 3,152.76 7.540 Clearance Factor Pass - MPE-32 - MPE-321-1 - MPE-321-1 3,226.50 234.01 3,226.50 203.06 3,200.51 7.559 Ellipse Separation Pass - MPE32 - MPE-321-1 - MPE-32LI 3,252.53 233.90 3,252.53 203.10 3,225.19 7.593 Centre Distance Pass - MPE-32- MPE32PB1 - MPE-32PB1 3,176.50 234.75 3,176.50 203.66 3,152.76 7.551 Clearance Factor Pass - MPE-32 - MPE-32PB1 - MPE-32PB1 3,226.50 234.01 3,226.50 203.10 3,200.51 7.569 Ellipse Separation Pass - MPE-32 - MPE-32PW - MPE-32PB1 3.252.53 233.90 3,252.53 203.14 3,225.19 7.604 Centre Distance Pass - MPE-33-MPE-33-MPE-33 5,54850 521.98 5,548.50 489.00 4,540.06 15.827 Clearance Factor Pass - MPU E -35 -MPU E -35 -MPU E-35 1,058.93 128.75 1,058.93 122.11 1,01271 19.388 Centre Distance Pass - MPU E -35 -MPU E -35 -MPU E-35 1,076.50 128.84 1,07650 122.11 1,029.06 19.130 Ellipse Separation Pass - MPU E -35 -MPU E -35 -MPU E35 5,548.50 883.53 5,548.50 802.04 5,950.11 10.842 Clearance Factor Pass - MPU E -35 -MPU E35 PBI -MPU E-35 PBi 1,058.93 128.75 1,058.93 122.11 1,012.71 19.388 Centre Distance Pass - MPU E -35 -MPU E35 PBi -MPU E-35 PSI 1,076.50 128.84 1,076.50 122.11 1,029.06 19.130 Ellipse Separa0on Pass - MPU E-35- MPU E-35 PB1 -MPU E-35 PBi 5,548.50 883.53 5,54850 802.05 5,950.11 10.843 Clearance Factor Pass- MPU E -36 -MPU E -36 -MPU E-36 872.70 157.11 872.70 149.82 816.90 21.563 Centre Distance Pass - MPUE36-MPU E -36 -MPU E36 901.50 157.23 901.50 149.80 841.67 21.162 Ellipse Separation Pass - MPUE36-MPU E -36 -MPU E-36 951.50 159.60 951.50 151.89 885.09 20.694 Clearance Factor Pass - MPU E36- MPU E-36PB1 - MPU E36P81 872.70 157.11 872.70 149.82 816.90 21.563 Centre Distance Pass - MPUE36-MPU E-36PB1-MPU E-36PB1 901.50 157.23 901.50 149.80 841.67 21.162 Ellipse Separation Pass - MPU E36 - MPU E-36PB1 -MPU E-36PBI 951.50 159.60 951.50 151.89 885.09 20.694 Clearance Factor Pass - 19 March, 2019 - 12:58 Page 6 of 10 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU E38 - MPU E-38 wpO9 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: MPt E Pad - Plan: MPU E-38-MPEJ8-MPU Ewe wpO9 Scan Range: 26.50 to 5,548.50 uaR. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutaN Is Unlimited. Max Ellipse Separation is 2,500.00 usft Measured Minimum ®Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usfl) (usfl) (usfl) (usR) usfl MPU EJ7-MPU E -37 -MPU E-37 947.76 15050 947.76 144.60 893.75 25.515 Centre Distance Pass - MPU E -37 -MPU E -37 -MPU E-37 951.50 150.51 951.50 144.60 897.06 25.441 Ellipse Separation Pass - MPU E -37 -MPU E -37 -MPU E-37 1,051.50 157.39 1,051.50 150.97 984.81 24.514 Clearance Factor Pass - MPU E-37- MPU E-37 PRI -MPU E37 Pat 947]6 150.50 947.76 144.60 893.75 25.515 Centre Distance Pass - MPU E-37- MPU E-37 Pat -MPU E�7 PBI 951.50 150.51 951.50 144.60 897.06 25.441 Ellipse Separation Pass - MPU E-37- MPU E-37 Pat -MPU E37 PBi 1,051.50 157.39 1,051.50 150.97 984.81 24.514 Clearance Factor Pass - Plan: MPU E40 - MPE40i - MPU E40 wp04 276.50 90.62 276.50 87.77 276.30 31.751 Centre Distance Pass - Plan: MPU E40-MPE-40i-MPU E40 wp04 326.50 90.83 326.50 87.60 325.50 28.109 Ellipse Separation Pass- Plan- MPUE40-MPE40i-MPU E -0O wp04 526.50 100.70 526.50 96.02 517.71 21.487 Clements Factor Pass - Prelim DualLalPlan :MPU E42-MPE42-MPE42w 532.47 201.83 532.47 196.73 535.50 39.606 Centre Distance Pass - Prelim Duall-atPlan :MPU E42-MPE42-MPE42w 576.50 201.97 576.50 196.64 580.47 37.884 Ellipse Separation Pass - Prelim DualLatPlan:MPUE42-MPE42-MPE42w 826.50 222.85 826.50 216.14 815.60 33.198 Clearance Factor Pass - Prelim Duall-atPlan: MPU Ed9 -MPU E -391 -MPU E-: 276.50 30.47 276.50 27.75 276.40 11.191 Camra Distance Pass - Prelim DuallalPlan:MPUE-39-MPU E -39i -MPU E-: 376.50 30.69 376.50 27.19 376.09 8.780 Ellipse Separation Pass - Prelim Duall-mPlan:MPU E -39 -MPU E -39i -MPU E-: 451.50 33.40 451.50 29.33 449.85 8.221 Clearer. Factor Pass - Prelim: MPU E -Pad Expansion Placeholder- Wellbore 276.50 120.19 276.50 117.33 312.30 42.105 Centre Distance Pass - Prelim:MPUE-Pad Expansion Placeholder- Wellbore 476.50 120.69 476.50 116.28 512.05 27.372 Ellipse Separation Pass - Prelim:MPUE-Pad Expansion Placeholder- Wellbore 751.50 134.24 751.50 128.43 782.36 23.116 Clearer. Factor Pass - Rig: MPU E41 - MPU E41 - MPU E41 359.87 59.50 359.87 56.25 360.34 18.354 Centre Distance Pass - Rig: MPU E41 - MPU E41 - MPU E41 401.50 59.68 401.50 M 13 401.60 16,783 Ellipse Separation Pass - Rig: MPU E41 - MPU E41 - MPU E41 501.50 63.93 501.50 59.62 498.39 14Z10 Clearance Factor Pass - Rig: MPU E41 - MPU E41 - MPU E41 wp04 276.50 60.28 276.50 57.43 276.50 21.117 Centre Distance Pass - Rig: MPU E41 - MPU E41 - MPU E41 wp04 376.50 60.42 376.50 M.79 376.15 16.658 Ellipse Separation Pass - Rig: MPU E41 - MPU E41 - MPU E41 wp04 501.50 64.80 501.50 60.24 498.31 14.198 Clearance Factor Pass - 19 March, 2019 - 12:58 Page 7 of 10 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-38 - MPU E-38 wp09 From )usk) 26.50 500.00 5.549.00 To (-eft) 500.00 MPU E-38wp09 5,549.00 MPU E-38 wp09 15,788.90 MPU E-38 wp09 SuiveylPlan Ellipse error terms are correlated across survey tool tie on points. Calculated ellipses incerporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 2_Gyro-NS-GC_D611 collar 2_MWD,lFR2+MS+Sag 2 MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point 19 March, 2019 - 12:58 Page B of 10 COMPASS REFERENCE INFORMATION -OEfA1LSP;in:MNE-]8 N+D 19]](NM(»NCOM161 .V.4u 2nrcW maewl.IN99 wawa: ww Pu.: MPus.Oe, Tnm N.m (w RPUEE®ae coos Dsa: zl.e9 HAL.UBURTON Project: Milne Pointl Site: M Pt Pad avry o.ull^e Well: Plan: MPU E-38 wma R.b•aa. Weaa. M.a.am 9.we w.a.a: Edew9z 6ea04a. +N --s .F.•u' Iwnu Eaus 1•I'e �relwa< Wellbore: MPE-38 Awb M," "am O—;ue o0o II.. �1599I0 1F1w 11 ]0.9]'I1.N Rru. n'I'A' Plan: MPU E-38 wp09 sul9vEV PROGRAM NO GLDeu FlLTER: using user aefiaee eelwtlan arul«.Ie cmwv ® Dale' 001&09-MWA0,00 Valleaba: Y WmOA: 1fi 50 TO 15]00.90 Ladder Ladder/S. F. Plots Oe FI Fmm DepN To S.i, len Tool CASING DiA1L3 2_GymN5GC D9wlhr 2850 500.00 MPU Ede uy09 (MPE30) N— 2) 500.00 $ BOD MPU E-30 yD (MPEde) MND+IFft2+Na 5 g 0 4 4 U200 55 8 0 9SB 959"x @ 1/4" of 5549.00 15]6890 MPU Ede u909 (MPEie) 2MND+IFR2+Ms+5a9 44]OM 4121]0 IP89.90 5-519 6i�6"+81/!' ' UL �-IfiO.OD MPE-21 L. --- �o MPE-1 � 0o MK -3 A MPE 20I It". MPE- 6 Y t MPE-30AL1 T X0120.00 __ e MPU E IaceM1OICei MPE- 4AL1 M E24 { e M PENA - W ' OL , 90.00 -_ O .-' 0 M4 U E40 1pa b uI 60.00 MPE- C3 I MIPE-4}APB1! P I v MP E-39 xq0! MIRE - 5 MPE- 4 0 30 00- 0 U W E-15- 0.00 0 300 600 900 1200 1500 1900 2100 24W 2700 30110 3300 3600 3900 4200 4500 4800 5100 5400 5700 Measured Depth (600 usft/in) 4.90 - - - - 9 3.00 A Collision Risk Procetlures R'eq. '� 2.00 n Collision Avcidance Req. N No -Go Zone -Stop Dulling 1.00 I i I NOERRORS 0.00 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5)00 Measured Depth (600 usfUin) Hilcorp Alaska, LLC Milne Point M Pt E Pad Plan: MPU E-38 MPE-38 MPU E-38 wp09 Sperry Drilling Services Clearance Summary Anticollision Report 19 March, 2019 Closest Approach 30 Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt E Pad -Plan: MPU E-38 -hi - MPU E38 wp09 Well Coordinates. 6,016,081.06 IN, 569,265.12 E (]0° 27' 15.45" N, 149. 26' 05.19" W) Datum Height: MPE-38 wpO2 KBE @ 48.30usft Scan Range: 5,548.50 to 15,788.90 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 2,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: Scan Type: 2500 r HALLIBURTON Sperry Drilling Services Hileorp Alaska, LLC HA LLI BU RTON Milne Point Anticollision Report for Plan: MPU E-38 - MPU E-38 wp09 Closest Approach 3D Proximity Scan an Current Survey Data (North Reference) Reference Design: MPt E Pad - Plan: MPU E-38 - MPE-38 - MPU EJB wp09 Scan Range: 5,548.50 to 15,788.90 usR. Measured Depth. Scan Radius Is Unlimited. Clearance Factorcutoff Is Unlimited. Max Ellipse Separation is 2,500.00 usR Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usfl) (usfl) (usfl) (usR) usfl M Pt A Pad MPA -0I -MPA -0I -MPA -01 11,103.89 1,295.53 11,103.89 1,109.69 4,364.69 6.971 Centre Distance Pass. MPA -0I -MPA -0I -MPA -01 11,123.50 1,295.68 11,123.50 1,109.34 4,364.13 6.954 Ellipse Separation Pass - MPA -0I -MPA -0I -MPA -01 11,248.50 1,303.57 11,248.50 1,114.83 4,360.52 6.907 Clearance Factor Pass - MPA -02 -MPA -02 -MPA -02 11,085.63 969.18 11,085.63 823.66 4,645.38 6.660 Centre Distance Pass - MPA -02 -MPA -02 -MPA -02 11,148.50 971.17 11,148.50 821.79 4,657.36 6.501 Ellipse Separation Pass - MPA -02 -MPA -02 -MPA -02 11,373.50 1,010.11 11,373.50 848.46 4,692.16 6.249 Clearance Factor Pass - MPA -02 -MPA -02A -MPA -02A 10,620.47 1,22333 10,620.47 1,185.97 3,725.00 32.744 Ellipse Separation Pass - MPA -02 -MPA -02A -MPA -02A 11,448.50 1,477.40 11,448.W 1,419.52 3,725.00 25.529 Clearance Factor Pass - MPA -03 -MPA -03 -MPA -03 11,726.45 949.99 11,726.45 716.05 4,671.30 4.061 Clearance Factor Pass - M Pt C Pad MPU C41-MPC41-MPC41 - - - - - MPU C41-MPC4I-MPC-01 - MPU C41-MPC4I-MPC41 - MPU C41-MPC41 L1-MPC41L1 - - - MPU C41-MPC41 Lt-MPC41L1 -- - MPU C41-MPC41 L1 -MPC 11-1 --- - MPU 641-MPC41L2-MPC41U -- -- MPU C11-MPC41L2-MPC41L2 -- - MPU C41-MPC41PB1-MPC41PBI 15,091.89 1,MA7 15,091.89 774.48 8,766.00 2.920 Centre Distance Pass - MPU CJI-MPC4I PBI -MPC4I PBI 15,223.50 1,188.17 15,223.50 760.45 8,766.00 2.778 Ellipse Separation Pass - MPU C41-MPC41PB1-MPC4I PBI 15,398.50 1,226.34 15,398.50 776.12 8,766.00 2324 Clearance Factor Pass - MPU C41-MPC41 PB2-MPC41PB2 MPU C41-MPC41PB2-MPC41PB2 - MPU C41-MPC41PB2-MPC-0iPB2 - M Pt E Pad MPE-03 - MPE-03 - MPE43 7,138.82 863.98 7,138.82 785.14 5,261.06 10.960 Centre Distance Pass - 19 March, 2019 -1Z59 Page 2 o/6 COMPASS HALLIBURTON Anticollision Report for Plan: MPU E-38 - MPU E-38 wp09 Hilcorp Alaska, LLC Milne Point Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: MPt E Pad - Plan: MPU E38-MPE38-MPU E418 wp09 Scan Range: 5,540.50 to 15,780.90 daft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation Is 2,500.00 usft Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (waft) (usft) (usft) (usft) usft MPE-03 - MPE-03 - MPE-03 7,198.50 865.23 7,198.50 783.66 5,299.23 10.607 Ellipse Separation Pass - MPE-03-MPE-03-MPE-03 7,623.50 942.27 7,623.50 844.41 5,572.50 9.629 Clearance Factor Pass - MPE-13 - MPE-138 - MPE-13B -. MPE-13-MPE-13B-MPE13B - - - MPE-13-MPE-13B-MPE-138 - MPE-18 - MPE-18 - MPE-18 7,148.50 439.18 7,148.50 253.86 5,598.59 2.370 Clearance Factor Pass- MPE-18-MPE-18-MPE-18 7,172.97 438.76 7,172.97 253.87 5,613.17 2.373 Centre Distance Pass - MPE-19-MPE-19-MPE-19 5,923.50 221.22 5,923.50 108.16 4,976.06 1.957 Clearance Factor Pass- MPEA9-MPE-19-MPE-19 5,948.50 218.61 5.948.50 106.69 4,986.44 1.957 Ellipse Separation Pass - MPE-19 - MPE-19 - MPE-19 5,963.77 218.16 5,963.77 107.79 4,992]9 1.977 Centre Distance Pass- MPE-20-MPE-20-MPE-20 5,548.50 1,292.53 5,548.50 1,249.25 4,489.02 29.865 Clearance Factor Pass - MPE-20 - MPE-20A- MPE-20A 7,252.70 817.70 7,252.70 617.78 6,156.69 4.090 Centre Distance Pass - MPE-20-MPE-20A-MPE-20A 7,673.50 825.22 7,673.50 596.87 6,543.75 3.614 Ellipse Separation Pass - MPE-20 - MPE-20A - MPE-20A 10.673.50 1,499.18 10,673.50 1.052.52 9,451.69 3.356 Clearance Factor Pass - MPE-20-MPE-20AL1-MPE-20AL1 7,069.40 855.48 7,069.40 695.18 5,952.28 5.337 Centre Distance Pass - MPE-20-MPE-20AL1-MPE-20AL1 7,123.50 856.19 7,123.50 694.49 5,983.38 5.295 Ellipse Separation Pass - MPE-20-MPE-20AL1-MPE-20AL1 7,248.50 865.17 7,248.50 700.76 6,049.44 5.262 Clearance Factor Pass - MPE-20-MPE-20AL1 Pet -MPE-20AL1 Pet 6,791.37 858.11 6,791.37 707.75 5,679.78 5.707 Can" Distance Pass- MPE-20-MPE-20AL1PB1-MPE-20AL1PB1 6,798.50 858.14 6,798.50 707.75 5,679.78 5.706 Ellipse Separation Pass - MPE-20-MPE-20ALiPB1-MPE-20AL1P61 7,298.50 922.96 7,298.50 741.02 6,067.00 5.073 Clearance Factor Pass - MPE-26 - MPE-26 - MPE-26 5,548.50 700.93 5,548.50 655.17 4,784.17 15.320 Clearance Factor Pass - MPE33 - MPE33 - MPE-33 5,927.78 442.06 5,927.78 372.42 4,762.86 6.348 Centre Distance Pass - MPE-33-MPE33-MPE-33 5,998.50 445.77 5,998.50 367.26 4,800.21 5.678 Ellipse Separation Pass- MPE-33-MPE-33-MPE-33 6,198.50 494.94 6,198.50 396.49 4,902.95 5.027 Cleamnce Factor Pass- MPU E -35 -MPU E -35 -MPU E35 6.263,17 864.93 6,263.17 76940 6,669.75 9,054 Centre Distance Pace - MPU E35 -MPU E -35 -MPU E-35 14,62350 1,184.16 14,623.50 716.83 15,000.00 2.534 Ellipse Separation Pass - MPU E -35 -MPU E35 -MPU E35 14,648.50 1,185.00 14,648.50 717.19 15,000.00 2.533 Clearance Factor Pass - MPU E -35 -MPU E-35 P01 -MPU E-35 PBi 6,295.97 866.83 6,295.97 770.18 6,702.41 8.969 Centre Distance Pass- MPUE-35-MPU E-35 Pet -MPU E-35 PB1 6,573.50 870.08 6,573.50 740.25 6,954.00 6.702 Ellipse Separation Pass - MPU E -35 -MPU E-35 PBi - MPU E-35 PBi 6,623.50 873.01 6,623.50 742.22 6,954.00 6.675 Clearance Factor Pass - 19 March, 2019 - 12:59 Page 30/6 COMPASS NALLIBURTON Anticollision Report for Plan: MPU E-38 - MPU E-38 ti Survey tool oroamm From (uslt) 26.50 500.00 5,549.00 To (ue11) 500.00 MPU E-38 wp09 5,549.00 MPU E-38 wp09 15,788.90 MPU E-38 wpD9 Survey/Plan Ellipse error teems are wralated across survey tool tieon points. Calculated ellipses incorporate sunam snore. Separation is the al distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles I (Distanw Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 2_Gyho-NS-GC_Dnll collar 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag Hilcorp Alaska, LLC Milne Point 19 March, 2019 - 12.59 Page 4 o16 COMPASS ALLIBURTON PIO)eOC Milne Point REFERENCE INFORMATION .DElAR5:p4a:APU M)B AADIA27(u CONCONUSI Alokabllea welr6E)vekmrvs: wEl>W: Awu Ey T.ua. wIlrvnlq .�.+.: Mve v.m rceeaaN mn awed 1.•a. zl.sp Site: MPtEPad M nnnn=a Well: Plan: MPU E-38 "°` ux�:w,r` umm x l4ae.5omn Dsalm.9 goo � Wellbore: MPE-38 m': No wleaiue s69us ro'zr lsa46+N ur z6515e! Plan: MPU.EJB 1W09 OURVEYPROGaAM NO GLOBQ FILTER: Uaifgpzer tl5788. aeledan dfYle^M cnbrie ® 1180.00— Da41018'ROGROaB9:00 VaWebL: Yss Verabn: 2050TD 15)00.90 Ladder/ S.F. Plats OepN From nep. To Surve01u, Tool CASNG DETAILS also SC0.00 MPU Ed: wf091MPE. ) ] Gy SGC ntlll wllar ND Wass MD Biot N_ PH(2of2) 50e.W SSIB.00 MPU E-3 w091MPEJ8) 3_MWDAFR2:MSKap 9450.30 440200 SSG8.50 9-50 95M"x121/4' 554900 15]8890 MPUE-38 y91MFE-Va IMWD<FR2bMs�8aB WOW "21]0 1578890 6518 659'x8 N3' � � 1 .. � I � POiiP01 Ili i I c N150.00- 0 PC nl I o i' II. I I 9o 1zo.0o o _MPE-130 N W m 60.00 U MPC 41L2 O I I 1 3003— U III SII II oAa 1 II l woo 6500 7000 7500 8000 8500 won 0500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 Measured Depth (1000 Wain) 400 LL—V � 3 00 o_ v y 200 Collision Risk Procedures Req. Collision Avoidance Req. 1.00 -. NO-GO Zone -Stop Drilling NOERRORS I I D.DD Boo 6500 7000 7500 8000 0500 8000 8500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 Measured Depth (1000 usftlin) Transform Points Source coordinate system State Plane 1927 -.Kaska Zone 4 Datum: NAD 1927 - North America Datum of 1927 (Mean) Target coordinate system Albers Equal Area (-154) Datum: NAD 1927- North America Datum of 1927 (Mean) iType values iMo the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to popy and Ctd+V to paste. Then click on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish Cancel Help X TRANSMITTAL LETTER CHECKLIST WELL NAME: M P (A. r� _39 PTD: a 19 -- 0 a eL Development Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: M t / ht- PO 1 h'"("' POOL: J`�G Y0.�2(/' 81a -At' Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50 --- from records, data and logs acquired for well name on permit . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of / well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, ✓ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 PTD#:2190520 Company H LCORP ALASKA LLC Initial Class/Type Well Name: MILNE PT UNIT E-38 Program SER Well bore seg ❑ SER/PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached .... - .. _ NA Commissioner: DCommissioner Date ate 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - 3 Un[que well, name and number . . . . . . . .... . ... . . . . . . . . .......... - Yes - - - ..... 4 Well located in a defined pool- - - - - - - - - - - - - - - - Yes _ - - . . . . . ............ . . . . . . . . 5 Well located proper distance from drilling unitboundary- - - - - - - - - - - - - - - - - - - - - - -Yes ... - - _ - - - - - - - - - _ - - _ . _ ... - - - - - - - 6 Well Jocated proper distance from other wells.............. . . - . - .... _Yes- 7 Sufficient acreage available in drilling unit- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - _ - - - - _ - ............ - - - - - - - - - - - - - 8 Jf deviated, is wellbore platincluded- ... .... - ....... 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 administrative.approval - - - - - - - - - - - - - - - - - - - ---- - Yes 13 Can permit be approved before 15-day wait Yes DLB 4/8/2019 ................ . 14 Well located within area and strata authorized by-Injection Order # (put 10# in comments).(For. Yes - - - - - - - - - AID 10B.012- - 15 All wells.within 114.mile area of review identified (For service well only)............... Yes- --- ----------- 16 Pre-produced injector; duration of pre production less than 3 months (For service well only) - _ Yes _ . - ....... . 17 Nonconven. gas conforms to AS31,05:03%. t.A),(j,2.A-D) . . . ....... . . . . . . . . . ....NA 18 Conductor string.provided - - - - - - - - - - - - - - - - - - - - - - - - - - - ------------ - - Yes - - - - - - 20" conductor setat 107 ft - - - - - - _ .. _ -- Engineering 19 Surface casing, protects allknown USDWs _ _ _ _ - _ - - _ - - NA _ - - - NO aquifers... - - - - - - - - - - - - - - 20 CMT vol adequate to circulate on conductor_$ surf csg _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ __ Yes - .......... _ . 21 CMT.vol adequate to tie-in long string to surf csg..... ...................... Yes - _ - _ using 2 stage cement.. ES at 250Q ft and ..... 22 CMT-will coverall known productive horizons_ - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - ............... . - - - - - - 23 Casing designs adequate for C, T, B8-permafrost - - - - - - _ - - - - - - - - - - - - - -Yes ... - BTC calculations supplied, 24 Adequate tankage or reserve pit - - - - - - - - - - - - Yes - Rig has steel pits.. ,all waste to be transported to approved disposal well. - - - 25 Jfa.re-drill, has a10-403 for abandonment been app- roved.................... ..NA.--.----------- ---.-.-.........-..-_---..---._---..-..-.. 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - _ - - Yes - - . close approach to C-41 lataerals.. Well is P & Ad in SB-sands, 27 If diverter required, does it meet regulations. _ .. _ . _ . - _ _ . _ . Yes - - - - - - - - - - ------- - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling fluid program schematic& equip Jist adequate..... . . . . . . . ........... . . Yes - _ - - Max form pressure= 1959.psi.(6.5 ppg EMW) will drill lateral with 8.9- 9.5 ppg mud) .... . GLS 4/11/2019 29 BOPE.5, do they meet regulation ----- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - _ - _ HAK 1 (Innovation) has 13 5/8".5000 psi WP BOPS - - - - - - 30 BOPE-press rating appropriate; test to (put psig in comments)- - - - - - - - - - - - - - - - - Yes .... MASP =1513 psi - Will test BOPS to 3000 psi - - - - - - - 31 Choke, manifold complies w/API_RP-53(May 84)_ ... - - _ . . . . . ..... . . . . Yes 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ - - _ ............. - - - - - - - - -- 33 Is presence of 1-12S gas probable - - - - - - - - No........ H2$ not expected ., Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - - Yes ...... 1/4 mile AOR completed. -No-issues.. 35 Permit can be issued w/o hydrogen_ sulfide measures . ... . ....... . . . . . . . ..... Yes - - _ - - _ - H28 not anticipated from drilling of offset wells; however, rig will have 1-12S sensors and alarms. Geology 36 Date. presented on potential overpressure zones .. . ... . . . . . . . ......... . Yes . . . . . . . - - - - Appr Date 37 Seismic analysis of shallow gas zones- - - - - - - - - - - - - - _ NA . .... ..... - - - - - .. DLB 4/8!2019 38 d i d eabecondition survey-(If off-shore - _ S-)---------------------------- NA ...... ----- -- - - - - - - - - - - - - - - - - - - - ............. --. 39 Contactname/phone for weekly- progress reports- [exploratory only]................. NA...... ____--_--_-._..-_-_-......_.-------.-----.-_------ Geologic Engineering Public OA sand injector.. Using ICD and swell packers. GLS Commissioner: D Date: Commissioner: DCommissioner Date ate 1,Ls gk
