The URL can be used to link to this page

Home My WebLink About219-109MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-203 MILNE PT UNIT S-203 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 S-203 50-029-23644-00-00 219-109-0 W SPT 3832 2191090 2000 744 745 745 745 280 2200 2141 2134 INITAL P Adam Earl 8/3/2025 MIT-OA tested as per Sundry # 325-149 to 2000psi 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 S-203 Inspection Date: Tubing OA Packer Depth 580 928 934 936IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250804070638 BBL Pumped:1.5 BBL Returned:1.5 Monday, September 22, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-203 MILNE PT UNIT S-203 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 S-203 50-029-23644-00-00 219-109-0 W SPT 3832 2191090 2000 746 746 746 746 288 553 545 541 INITAL P Adam Earl 8/3/2025 MIT-IA tested as per Sundry # 325-149 to 2000psi 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 S-203 Inspection Date: Tubing OA Packer Depth 580 2176 2091 2070IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250804065917 BBL Pumped:1.2 BBL Returned:1.2 Monday, September 22, 2025 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MPS-203 PTD: 2191090 Convert to Injector Date:Friday, August 15, 2025 9:12:53 AM Attachments:image002.png image003.png MPU S-203 SCHEMATIC 6-2-2020.pdf From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, August 6, 2025 4:06 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: MPS-203 PTD: 2191090 Convert to Injector Mel/Chris, MPS-203 was recently converted from JP to PWI injector per sundry 325-149, and due to its tieback completion design both an MIT-IA and MIT-OA were required per sundry after bringing it on injection. Both witnessed MIT’s passed on 8/3/25. Below is an email chain between the OE and Mel pertaining to the MIT’s for background. Can you please provide clarity on what your expectation is for what MIT needs to be completed for the 4 year test? As we will need to place a time duration on one or both of the MIT’s for tracking purposes. Based on below comments from Mel, I am planning to track only a witnessed MIT-OA on the 4 year clock unless directed otherwise. The WBS is attached for reference. Thanks for your feedback, Ryan Thompson Milne/Islands/WNS Well Integrity Engineer 907-564-5005 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, July 22, 2025 11:17 AM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: doa aogcc prudhoe bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL] RE: MP S-203 PTD: 219-109 Convert to Injector Ryan, It is the liner top packer that should be tested to assure no out of zone injection. For general well integrity it would be good to know if the injection tubing packer is a proven barrier to know that the IA is isolated from the reservoir, although AOGCC will not require witnessed pressure testing of the injection tubing packer (i.e. the IA). Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC inspectors From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Tuesday, July 22, 2025 9:40 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MP S-203 PTD: 219-109 Convert to Injector Mel- The COA calls for a Witnessed MIT-IA and MIT-OA. We do not usually do a witnessed MIT-OA test on new or converted Injectors, just an MIT-IA. 1. I wanted to confirm the need for a witnessed MIT-OA? 2. If both tests are needed, can we perform a single MIT-OA test and that would satisfy both the IA and OA test? Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this 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 ordata. 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. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this 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 ordata. 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. _____________________________________________________________________________________ Revised By: TDF 6/2/2020 SCHEMATIC Milne Point Unit Well: MPU S-203 Last Completed: 9/19/19 PTD: 219-109 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 215 / X-52 / Weld N/A Surface 107’N/A 9-5/8"Surface 40 / L-80 / TXP SR 8.835 Surface 5,355’0.0758 7-5/8”Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 5,208’0.0459 4-1/2”Liner 150μ Screens 13.5 / L-80 / Hydril 625 3.920 5,204’9,800’.0149 TUBING DETAIL 3-1/2"Tubing 9.3/ L-80 / EUE-8rd 2.992 Surface 5,239’0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4" Stg 1 – Lead - 392 sx Extenda Cem / Tail – 396 sx Swift Cem Stg 2 –Lead –604sx Perm Cem / Tail – 270 sx Class G (160 bbls to surface) 8-1/2”Cementless Screen Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 260’ Max Hole Angle = 94.8 TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23644-00-00 Completion Date: 9/19/19 4-1/2” SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 11 5,231’4,834’5,688’3,821’ 7 9,115’3,663’9,408’3,691’ JEWELRY DETAIL No.Top MD Item ID 1 22’Tubing Hanger (3-1/2” TC-II Top & Btm) 2.867” 2 4,378’3.5” Discharge Pressure Gauge Mandrel (Discharge Gauge)2.875” 3 4,388’3.5” CMD Sliding Sleeve 2.813” 4 4,399’3.5” Gauge Mandrel w/ ¼” Wire (Intake Gauge)2.875” 5 4,421’3.5” X Nipple (2.813” Packing Bore) 2.813” 6 4,468’7-5/8” x 3.5” FHL Retrievable Packer 2.885” 7 4,490’3.5” XN Nipple 2.750” 8 5,239’3.5” Mule shoe 2.867” Lower Completion 9 5,204’BOT SLZXP LT Packer / Liner Hanger 4-1/2” x 9-5/8”6.190” 10 5,208’7-5/8” Tieback Assy.6.151” 11 5,226’7” H563 x 4.5” 625 L-80 XO 3.830” 12 9,795’WIV Valve LTC BxB (1” Ball on Seat/Closed)- 4-1/2” Screens LINER DETAIL Jts Top (MD)Top (TVD)Btm (MD)Btm (TVD) 82 5,688’3,821’9,115’3,663’ 7 9,428’3,694’9,722’3,721’ From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MPS-203 PTD: 2191090 Convert to Injector Date:Friday, August 15, 2025 9:13:08 AM Attachments:image001.png image002.png From: Wallace, Chris D (OGC) Sent: Friday, August 15, 2025 9:12 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: MPS-203 PTD: 2191090 Convert to Injector Ryan, AOGCC’s maximum MITIA interval is 4 years, and in this well it looks like a passing MITOA would basically test the entire 7-5/8” and 9-5/8” casings. So after Hilcorp’s review of the authorized zones (and authorized comingling or not), Hilcorp should propose via an administrative approval request, a testing and monitoring program that is at least as stringent as a 4 year MITIA, and ensures fluids are confined to their authorized injection zone including assumption that any barrier failure can be detected by monitoring during the time period between barrier testing. I do not see additional requirements imposed via AIO 10D or ERIO 7 or ERIO 7.001 (ERIO 9.001 was written on the Sundry 325-149 conditions or approval in error). AOGCC memorializes testing requirements that differ from a routine 4 year MITIA by utilizing the Area Injection Order (AIO) administrative approval (AA) process. Our database works better if we utilize the AA process rather than a Sundry process. The Sundry process is more transactional (request work, complete work, report work, next) and so for required long duration repeat testing you should request an AA with the identified regulations that a variance/waiver is requested for and what Hilcorp’s proposed alternative testing/monitoring process is to ensure protection of underground sources of drinking water while injecting (as per the underground injection control program). For this well, under AIO 10D (5/6/2025), I see: a tubing packer at 4468 ft while injection is at 5231 ft. So packer is 763 ft above injection, which doesn’t meet the 20 AAC 25.412(b) requirement of 200 ft BUT was allowed, in general, by AIO 10D Rule 10. an OA packer at 5204 ft which theoretically could allow detection of a 7-5/8” casing leak below the otherwise unmonitorable 4468 ft packer. Hilcorp may have SCADA on this well for continuous monitoring and alarms with remote shut in capabilities. If the entire zone below the 9-5/8” casing is authorized for injection that is good. If not, Hilcorp will have to detail how it limits the injection to the authorized zone, or if commingling is allowed – how the injection is allocated to each of the authorized zones. If the 9-5/8” cementing was questionable, a cement bond log evaluation or Hilcorp may demonstrate all injection is going to the approved injection zones/below upper confining layer of pool via a waterflow or temperature/oxygen activation log. Historically, for high set packer depth wells, we do a 2 yr MITT and 2 yr MITIA. For a MITOA we could do a 2 or 4 yr test. Looking at MPU S-203 most of the tubing above the 7-5/8”x 3.5” packer is monitorable by the IA, and below the packer is?? Looking at the IA integrity, above the 7-5/8”x 3.5” packer is monitorable by the OA, and below the 7-5/8”x 3.5” packer is also monitorable by the IA. The AOGCC database can accommodate multiple testing schedules, and we do insert the most frequent testing as the reminder, and use comments for the other required testing(s) and frequency. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of theintended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintendedrecipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 orchris.wallace@alaska.gov. From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, August 6, 2025 4:06 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: MPS-203 PTD: 2191090 Convert to Injector Mel/Chris, MPS-203 was recently converted from JP to PWI injector per sundry 325-149, and due to its tieback completion design both an MIT-IA and MIT-OA were required per sundry after bringing it on injection. Both witnessed MIT’s passed on 8/3/25. Below is an email chain between the OE and Mel pertaining to the MIT’s for background. Can you please provide clarity on what your expectation is for what MIT needs to be completed for the 4 year test? As we will need to place a time duration on one or both of the MIT’s for tracking purposes. Based on below comments from Mel, I am planning to track only a witnessed MIT-OA on the 4 year clock unless directed otherwise. The WBS is attached for reference. Thanks for your feedback, Ryan Thompson Milne/Islands/WNS Well Integrity Engineer 907-564-5005 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, July 22, 2025 11:17 AM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: doa aogcc prudhoe bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL] RE: MP S-203 PTD: 219-109 Convert to Injector Ryan, It is the liner top packer that should be tested to assure no out of zone injection. For general well integrity it would be good to know if the injection tubing packer is a proven barrier to know that the IA is isolated from the reservoir, although AOGCC will not require witnessed pressure testing of the injection tubing packer (i.e. the IA). Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC inspectors From: Ryan Lewis <ryan.lewis@hilcorp.com> Sent: Tuesday, July 22, 2025 9:40 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MP S-203 PTD: 219-109 Convert to Injector Mel- The COA calls for a Witnessed MIT-IA and MIT-OA. We do not usually do a witnessed MIT-OA test on new or converted Injectors, just an MIT-IA. 1. I wanted to confirm the need for a witnessed MIT-OA? 2. If both tests are needed, can we perform a single MIT-OA test and that would satisfy both the IA and OA test? Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this 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 ordata. 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. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this 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 ordata. 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. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Water Injector 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,470'N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Liner 8,540psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4,468MD/ 3,698TVD & 5,204MD/ 3,832TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 4-1/2"4,596' 5,208' Perforation Depth MD (ft): 9,800' See Schematic See Schematic 3-1/2" 5,355' 5,208' 107' 20" 9-5/8" 7-5/8" 5,355' N/A 9,020psi 5,750psi 6,890psi 3,836' 3,833' 3,730' Length Size Proposed Pools: 107' 107' 9.3/ L-80 / EUE-8rd TVD Burst 5,239' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL380109 & ADL380110 219-109 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23644-00-00 Hilcorp Alaska LLC N/A AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 6/1/2025 FHL Ret. & BOT SLZXP and N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT S-203 Milne Point Field Ugnu Undefined N/A 3,896' 9,795' 3,729' 833 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:53 pm, Mar 14, 2025 325-149 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.03.14 11:29:33 - 08'00' Taylor Wellman (2143) DSR-4/14/25 * AOGCC to witness MIT-IA and MIT-OA to 2000 psi after 10 days of stabilized injection. Injection not authorized until ERIO 9.001 is issued. MGR17MAR25 10-404 A.Dewhurst 21MAY25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.10 08:48:29 -08'00'06/10/25 RBDMS JSB 061025 Convert to PWI Well: MPU S-203 Date: 03/06/2025 Well Name:MPU S-203 API Number:50-029-23644-00-00 Current Status:On Production Pad:MP S-Pad Estimated Start Date:6/1/2025 Rig:SL Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:219-109 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1,154 psi @ 3,670’ TVD BH gauge 8/23/24 (EMW = 6.1 ppg) Maximum Expected BHP:1,200 psi @ 3,670’ TVD (EMW = 6.3 ppg) MPSP:833 psi (0.1 psi/ft gas gradient) Brief Well Summary: MP S-203 was drilled and completed in September 2019 as a JP producer in the Ugnu sand. The well was BOL but is making significantly less oil than predicted. A pressure build up showed the well to have a large skin. The well is currently on production. We are drilling S-204 producer and want to convert this to a Polymer injector. Notes Regarding Wellbore Condition x The 7-5/8” casing passed a 3,500 psi PT for 30 minutes on 8/18/24. x This well has no offset injection support Objective: Convert to Injector. Pull the JP, close the sliding sleeve. Slickline: 1. RU slickline. 2. Pull jet pump from sliding sleeve at 4,388’ MD. 3. Shift the sliding sleeve at 4,388’ MD closed. 4. RD HES slickline. Fullbore: 1. RU LRS. Pressure test equipment 250 psi low and 2,500 psi high. 2. MIT-IA 2,000 psi for 30 minutes, charted. 3. RDMO Attachments: 1. Current Schematic 2. Proposed Schematic 3. AOR 4. AOGCC to witness MIT-IA and MIT-OA to 2000 psi after 10 days of stabilized injection. _____________________________________________________________________________________ Revised By: TDF 6/2/2020 SCHEMATIC Milne Point Unit Well: MPU S-203 Last Completed: 9/19/19 PTD: 219-109 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 215 / X-52 / Weld N/A Surface 107’N/A 9-5/8"Surface 40 / L-80 / TXP SR 8.835 Surface 5,355’0.0758 7-5/8”Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 5,208’0.0459 4-1/2”Liner 150ђ Screens 13.5 / L-80 / Hydril 625 3.920 5,204’9,800’.0149 TUBING DETAIL 3-1/2"Tubing 9.3/ L-80 / EUE-8rd 2.992 Surface 5,239’0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4" Stg 1 – Lead - 392 sx Extenda Cem / Tail – 396 sx Swift Cem Stg 2 – Lead – 604 sx Perm Cem / Tail – 270 sx Class G (160 bbls to surface) 8-1/2”Cementless Screen Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 260’ Max Hole Angle = 94.8 TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23644-00-00 Completion Date: 9/19/19 4-1/2” SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 11 5,231’4,834’5,688’3,821’ 7 9,115’3,663’9,408’3,691’ JEWELRY DETAIL No.Top MD Item ID 1 22’Tubing Hanger (3-1/2” TC-II Top & Btm) 2.867” 2 4,378’3.5” Discharge Pressure Gauge Mandrel (Discharge Gauge)2.875” 3 4,388’3.5” CMD Sliding Sleeve 2.813” 4 4,399’3.5” Gauge Mandrel w/ ¼” Wire (Intake Gauge)2.875” 5 4,421’3.5” X Nipple (2.813” Packing Bore) 2.813” 6 4,468’7-5/8” x 3.5” FHL Retrievable Packer 2.885” 7 4,490’3.5” XN Nipple 2.750” 8 5,239’3.5” Mule shoe 2.867” Lower Completion 9 5,204’BOT SLZXP LT Packer / Liner Hanger 4-1/2” x 9-5/8”6.190” 10 5,208’7-5/8” Tieback Assy.6.151” 11 5,226’7” H563 x 4.5” 625 L-80 XO 3.830” 12 9,795’WIV Valve LTC BxB (1” Ball on Seat/Closed)- 4-1/2” Screens LINER DETAIL Jts Top (MD)Top (TVD)Btm (MD)Btm (TVD) 82 5,688’3,821’9,115’3,663’ 7 9,428’3,694’9,722’3,721’ _____________________________________________________________________________________ Revised By: TDF 6/2/2020 PROPOSED Milne Point Unit Well: MPU S-203 Last Completed: 9/19/19 PTD: 219-109 TD =11,470’(MD) /TD =3,896’ (TVD) 4 20” Orig. KB Elev.: 26.7’ / GL Elev.: 36.7’ 7-5/8” 6 7 9-5/8” 1 2 3 See Screen/ Solid Liner Detail PBTD =9,795’ (MD) / PBTD =3,729’ (TVD) 9-5/8” ‘ES’ Cementer @ 2,093’ MD 5 4-1/2” Shoe @ 9,800’12 812 9/10 11 3-1/2” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 215 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP SR 8.835 Surface 5,355’ 0.0758 7-5/8” Tieback 29.7 / L-80 / Hyd 521 6.875 Surface 5,208’ 0.0459 4-1/2” Liner 150ђ Screens 13.5 / L-80 / Hydril 625 3.920 5,204’ 9,800’ .0149 TUBING DETAIL 3-1/2" Tubing 9.3/ L-80 / EUE-8rd 2.992 Surface 5,239’ 0.0087 OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 12-1/4" Stg 1 –Lead - 392 sx Extenda Cem / Tail –396 sx Swift Cem Stg 2 – Lead – 604 sx Perm Cem / Tail – 270 sx Class G (160 bbls to surface) 8-1/2” Cementless Screen Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 260’ Max Hole Angle = 94.8 TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gen V GENERAL WELL INFO API: 50-029-23644-00-00 Completion Date: 9/19/19 4-1/2”SOLID LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 11 5,231’ 4,834’ 5,688’ 3,821’ 7 9,115’ 3,663’ 9,408’ 3,691’ JEWELRY DETAIL No. Top MD Item ID 1 22’ Tubing Hanger (3-1/2” TC-II Top & Btm) 2.867” 2 4,378’ 3.5” Discharge Pressure Gauge Mandrel (Discharge Gauge) 2.875” 3 4,388’3.5” CMD Sliding Sleeve - CLOSED 2.813” 4 4,399’ 3.5” Gauge Mandrel w/ ¼” Wire (Intake Gauge) 2.875” 5 4,421’ 3.5” X Nipple (2.813” Packing Bore) 2.813” 6 4,468’ 7-5/8” x 3.5” FHL Retrievable Packer 2.885” 7 4,490’ 3.5” XN Nipple 2.750” 8 5,239’ 3.5” Mule shoe 2.867” Lower Completion 9 5,204’ BOT SLZXP LT Packer / Liner Hanger 4-1/2” x 9-5/8” 6.190” 10 5,208’ 7-5/8” Tieback Assy. 6.151” 11 5,226’ 7” H563 x 4.5” 625 L-80 XO 3.830” 12 9,795’ WIV Valve LTC BxB (1” Ball on Seat/Closed) - 4-1/2” Screens LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 82 5,688’ 3,821’ 9,115’ 3,663’ 7 9,428’ 3,694’ 9,722’ 3,721’ " I ®([[ ĺŕϙĺċ ČĲŪ ϼa"Ͻ ĺŕϙĺċ ČĲŪ a ϼ«"Ͻ ĺŕϙĺċ ôıôĲť ϼa"Ͻ ĺŕϙĺċ ôıôĲť ϼ«"Ͻ ČĲŪϙa ťÍťŪŜ ¾ĺĲÍīϙIŜĺīÍťĖĺĲ ͑͏͑ϱ͖͐͒ ͔͏ϱ͏͑͘ϱ ͑͒͐͏͏ϱ͏͏ϱ͏͏ aϙϱ͏͔ iϙŘĺîŪèôŘ ͓Ϡ͔͓͗ ͒Ϡ͔͗͘ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͖ϱ͔ϯ͗Г ÍŜĖĲČϡϙēôƅϙŕŪıŕôîϙ͘͘͏ϙææīŜϙĺċϙ͐͏ϟ͖ŕŕČϙīôÍîϙÍĲîϙ͓͒ϙææīŜϙĺċ ͔͐ϟ͗ŕŕČϙťÍĖīϙèôıôĲťϟϙēôƅϙŘôŕĺŘťôîϙ͐͏͏ϙææīŜϙĺċϙèĺĲťÍıĖĲÍťôîϙèôıôĲť ÍĲîϙ͕͏ϙææīŜϙĺċϙČĺĺîϙ͐͏ϟ͖ŕŕČϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèôϟ ͑͏͒ϱ͐͏͘ ͔͏ϱ͏͑͘ϱ ͕͑͒͐͒ϱ͏͏ aϱ͏͕ ēŪťϙIĲ ͓Ϡ͔͔͗ ͓Ϡ͕͐͒ ͒Ϡ͔͔͖Д ͒Ϡ͐͏͓Д īĺŜôî ͖ГϙèÍŜĖĲČϡϙŕŪıŕôîϙ͔͓ϙææīŜϙĺċϙ͔͐ϟ͕ϙŕŕČϟϙϙēôƅϙæŪıŕôîϙťēôϙŕīŪČϙſĖťēϙ͖͏͏ ŕŜĖϙĺŽôŘϙèĖŘèŪīÍťĖĲČϙŕŘôŜŜŪŘôϟϙϙ@ĺĺîϙèôıôĲťϙÍťϙťĺŕϙĺċϙīĺČČĖĲČϙîôŕťē ϼťŪæĖĲČϙťÍĖīϽϙ͓Ϡ͏͑͗Дϙa" ͑͏͒ϱ͐͑͒ ͔͏ϱ͏͑͘ϱ ͕͑͒͐͗ϱ͏͏ aϱ͏͗ iĲīĖĲô ͓Ϡ͓͔͒ ͓Ϡ͔͏͐ ͑Ϡ͖͏͏Д ͑Ϡ͔͒͗Д īĺŜôî ͖ϱ͔ϯ͗Г ÍŜĖĲČϡϙēôƅϙŕŪıŕôîϙ͘͘͏ϙææīŜϙĺċϙ͐͏ϟ͖ŕŕČϙīôÍîϙÍĲîϙ͓͒ϙææīŜϙĺċ ͔͐ϟ͗ŕŕČϙťÍĖīϙèôıôĲťϟϙēôƅϙŘôŕĺŘťôîϙ͐͏͏ϙææīŜϙĺċϙèĺĲťÍıĖĲÍťôîϙèôıôĲť ÍĲîϙ͕͏ϙææīŜϙĺċϙČĺĺîϙ͐͏ϟ͖ŕŕČϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèôϟϙ[ĺČϙôŜťϙi ͑Ϡ͖͏͏Дϙa" ͑͏͒ϱ͐͑͒ ͔͏ϱ͏͑͘ϱ ͕͑͒͐͗ϱ͖͏ aϱ ͏͗͐ æÍĲîĺĲôî ͓Ϡ͓͔͒ ͓Ϡ͔͏͐ bϯ bϯ bϯ ͑͏͑ϱ͓͐͐ ͔͏ϱ͏͑͘ϱ ͑͒͏͒͘ϱ͏͏ aϱ͐͒ iĲīĖĲô ͓Ϡ͕͐͐ ͓Ϡ͔͐͗ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͖ГϙèÍŜĖĲČϡϙŕŪıŕôîϙ͘͏͏ϙææīŜϙĺċϙ͐͏ϟ͖ϭϙīôÍîÍĲîϙČĺťϙèôıôĲťϙťĺϙŜŪŘċÍèôϙÍť ͖͑͏ϙææīŜϟϙϙŪıŕôîϙ͖͒ϙææīŜϙĺċϙ͔͐ϟ͗ϙŕŕČϟϙϙēôƅϙīĺŜťϙŘôťŪŘĲŜϙſĖťēϙ͑͘ϙææīŜ īôċťϙĖĲϙƲŪŜēϟϙôıôĲťϙîĖîϙĲĺťϙċÍīīϙĺŪťϙĺċϙťēôϙŘĖŜôŘϙæŪťϙŜťÍƅôîϙŜťÍťĖèϟ [ĺČČôîϙĖĲťôŘŽÍīϙŜēĺſôîϙČĺĺîϙèôıôĲťϙŪŕϙťĺϙ͒Ϡ͔͗͏Дϙa"ϟ ͑͏͒ϱ͓͖͐ ͔͏ϱ͏͑͘ϱ ͖͕͑͒͐ϱ͏͏ aϱ͑͑ æÍĲîĺĲôî ͔Ϡ͓͑͗ ͔Ϡ͓͐͐ ͒Ϡ͓͗͘Д ͒Ϡ͐͘͘Д īĺŜôî ͖ϱ͔ϯ͗ГϙèÍŜĖĲČϡϙŕŪıŕôîϙ͕͒ϙææīŜϙĺċϙ͔͐ϟ͗ϙŕŕČϟ ēôƅϙæŪıŕôîϙťēôϙŕīŪČϙſĖťē ͐Ϡ͏͏͏ϙŕŜĖϙĺŽôŘϙèĖŘèŪīÍťĖĲČϙŕŘôŜŜŪŘôϟϙϙēôϙīĖĲôŘϙſÍŜϙċŪīīƅϙèôıôĲťôîϙĺƯϙŪŕϙ ťēŘĺŪČēϙŜèŘôôĲôîϙīĖĲôŘϙťĺϙ͔Ϡ͑͏͗Дϙa"ϟ ͑͏͒ϱ͏͒͗ ͔͏ϱ͏͑͘ϱ ͓͑͒͐͑ϱ͏͏ aϱ͓͑ æÍĲîĺĲôî ͓Ϡ͖͖͘ ͓Ϡ͒͑͗ ͑Ϡ͖͓͗Д ͑Ϡ͕͓͑Д īĺŜôî ͖ϱ͔ϯ͗ГϙèÍŜĖĲČϙŘÍĲϙťĺϙ͔Ϡ͏͓͑Дϙa"ϙÍĲîϙèôıôĲťϙťĺŕϙèÍīèŪīÍťôîϙÍťϙ͑Ϡ͖͓͗Д ͑͏͒ϱ͏͒͗ ͔͏ϱ͏͑͘ϱ ͓͑͒͐͑ϱ͖͏ aϱ ͓͑͐ æÍĲîĺĲôî ͓Ϡ͖͖͘ ͓Ϡ͒͑͗ bϯ bϯ bϯ ͑͏͒ϱ͏͒͗ ͔͏ϱ͏͑͘ϱ ͓͑͒͐͑ϱ͖͐ aϱ ͓͑͑ æÍĲîĺĲôî ͓Ϡ͖͖͘ ͓Ϡ͒͑͗ bϯ bϯ bϯ ͑͏͒ϱ͏͕͐ ͔͏ϱ͏͑͘ϱ ͔͑͒͐͏ϱ͏͏ aϱ͕͑ iĲīĖĲô ͔Ϡ͏͖͒ ͔Ϡ͏͒͘ ͓Ϡ͏͓͓Д ͒Ϡ͏͖͒Д īĺŜôî ͖Г èÍŜĖĲČϙŘÍĲϙťĺϙ͔Ϡ͓͒͘Дϙa"ϙÍĲîϙèôıôĲťϙťĺŕϙèÍīèŪīÍťôîϙÍťϙ͒Ϡ͔͔͒Дϟϙϙ[ĺČϙôŜť iϙ͓Ϡ͏͓͓Дϙa"ϟ ͑͏͑ϱ͏͓͐ ͔͏ϱ͏͑͘ϱ ͑͒͏͕͕ϱ͏͏ aϱ͒͐ iĲīĖĲô ͖Ϡ͕͑͑ ͖Ϡ͒͑͐ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͖ГèÍŜĖĲČϡϙ@ĺťϙæÍèħϙ͒͐͑ϙææīŜϙĺċϙČĺĺîϙèôıôĲťϙťĺϙŜŪŘċÍèôϟϙϙ[ĺČϙĖĲîĖèÍťôŜ ŽÍŘƅĖĲČϙèôıôĲťϙŗŪÍīĖťƅϙŪŕϙťĺϙ͖Ϡ͐͏͏Дϙa"ϙϼĺŕϙĺċϙīĺČϙĖĲťôŘŽÍīϽ ͑͏͕ϱ͖͐͑ ͔͏ϱ͏͑͘ϱ ͑͒͐͑͒ϱ͏͐ aϱ͒͒ ēŪťϙIĲ ͓Ϡ͕͓͑ ͓Ϡ͕͕͖ ͒Ϡ͖͏͏Д ͒Ϡ͔͐͒Д īĺŜôî ͖ГϙèÍŜĖĲČϙŘÍĲϙťĺϙ͔Ϡ͓͕͘Дϙa"ϙÍĲîϙèôıôĲťϙťĺŕϙèÍīèŪīÍťôîϙÍťϙ͑Ϡ͖͐͐Дϟϙϙ[ĺČϙôŜť iϙ͒Ϡ͖͏͏Гϟ ͑͑͐ϱ͏͓͓ ͔͏ϱ͏͑͘ϱ ͕͓͑͒͘ϱ͏͏ aϱ͓͓ iĲīĖĲô ͓Ϡ͒͐͑ ͓Ϡ͓͓͒ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͘ϱ͔ϯ͗ГϙèÍŜĖĲČϡϙ͑͒͏ϙææīŜϙĺċϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèô ͑͑͐ϱ͏͓͑ ͔͏ϱ͏͑͘ϱ ͕͑͒͒͘ϱ͏͏ aϱ͓͔ iĲīĖĲô ͓Ϡ͕͗͘ ͓Ϡ͘͏͏ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͘ϱ͔ϯ͗ГϙèÍŜĖĲČϡϙ͕͖͐ϙææīŜϙĺċϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèô ͑͑͐ϱ͏͓͔ ͔͏ϱ͏͑͘ϱ ͕͔͑͒͘ϱ͏͏ aϱ͓͕ iĲīĖĲô ͓Ϡ͖͖͒ ͓Ϡ͖͖͕ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͘ϱ͔ϯ͗ГϙèÍŜĖĲČϡϙ͑͑͐ϙææīŜϙĺċϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèô ͑͑͐ϱ͏͓͔ ͔͏ϱ͏͑͘ϱ ͕͔͑͒͘ϱ͖͏ aϱ ͓͕͐ æÍĲîĺĲôî ͓Ϡ͖͖͒ ͓Ϡ͖͖͕ bϯ bϯ bϯ ͑͑͐ϱ͏͓͖ ͔͏ϱ͏͑͘ϱ ͕͕͑͒͘ϱ͏͏ aϱ͓͖ iĲīĖĲô ͔Ϡ͕͐͐ ͔Ϡ͑͐͘ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͘ϱ͔ϯ͗Г èÍŜĖĲČϡϙ͒͒͒ϙææīŜϙĺċϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèô ͑͑͐ϱ͏͓͖ ͔͏ϱ͏͑͘ϱ ͕͕͑͒͘ϱ͖͏ aϱ ͓͖͐ æÍĲîĺĲôî ͔Ϡ͕͐͐ ͔Ϡ͑͐͘ bϯ bϯ bϯ ͑͑͐ϱ͏͓͘ ͔͏ϱ͏͑͘ϱ ͕͖͑͒͘ϱ͏͏ aϱ͓͗ iĲīĖĲô ͔Ϡ͔͖͕ ͔Ϡ͕͕͓ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͘ϱ͔ϯ͗Г èÍŜĖĲČϡϙ͒͑͑ϙææīŜϙĺċϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèô ͑͑͐ϱ͏͓͘ ͔͏ϱ͏͑͘ϱ ͕͖͑͒͘ϱ͖͏ aϱ ͓͗͐ æÍĲîĺĲôî ͔Ϡ͔͖͕ ͔Ϡ͕͕͓ bϯ bϯ bϯ ͑͑͏ϱ͏͖͐ ͔͏ϱ͏͑͘ϱ ͕͕͑͒͘ϱ͏͏ aϱ͔͕ æÍĲîĺĲôî ͓Ϡ͓͑͘ ͓Ϡ͔͑͒ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͘ϱ͔ϯ͗ГϙèÍŜĖĲČϡϙ͔͐ϙææīŜϙĺċϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèô ͑͑͏ϱ͏͐͒ ͔͏ϱ͏͑͘ϱ ͕͕͕͑͒ϱ͏͏ aϱ͔͖ iĲīĖĲô ͓Ϡ͕͒͐ ͓Ϡ͒͑͘ ŪŘċÍèô ŪŘċÍèô īĺŜôî ͘ϱ͔ϯ͗ГϙèÍŜĖĲČϡϙ͑͑͏ϙææīŜϙĺċϙèôıôĲťϙŘôťŪŘĲôîϙťĺϙŜŪŘċÍèô DATA SUBMITTAL COMPLIANCE REPORT 1//1�14/2020 Permit to Drill 2191090 Well Name/No. MILNE PT UNIT S-203 f .py� VO Operator Hilcorp Alaska LLC API No. 50-029.23644-00-00 Pvn'' MD 11470 TVD 3896 Completion Date 9/19/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION! Mud Log I L �� O.(rA' I/ Samples / Directional Survey Yes J YP- DATA INFORMATION List of Logs Obtained: ROP/ABG/DGR/EWR/ADR 2"/5" MD/ P81, PB2...ABG/DGR/EWR/ADR 2"/5" TVD/ PB1, PB2 (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 31450 Digital Data 100 11470 11/22/2019 Electronic Data Set, Filename: MPU S-203 LWD Final.las ED C 31450 Digital Data 5345 11433 11/22/2019 Electronic Data Set, Filename: MPU S-203 ADR Quadrants All Curves.las ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 LWD Final MD.cgm ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 LWD Final TVD.cgm ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203—Definitive Survey Report.pdf ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203_DSR.txt ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203_GIS.txt ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 LWD Final MD.emf ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 LWD Final TVD.emf ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 Geosteedng.dlis ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 Geosteedng.ver ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 LWD Final MO.pdf ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 LWD Final TVD.pdf ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 LWD Final MD.tif ED C 31450 Digital Data 11/22/2019 Electronic File: MPU S-203 LWD Final TVD.tif Log 31450 Log Header Scans 0 0 2191090 MILNE PT UNIT S-203 LOG HEADERS Log 31451 Log Header Scans 0 0 2191090 MILNE PT UNIT S-203 P131 LOG HEADERS ED C 31451 Digital Data 100 9787 11/22/2019 Electronic Data Set, Filename: MPU S-203PB1 LWD Final.las AOGCC Page I o(9 Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191090 Well Name/No. MILNE PT UNIT S-203 MD 11470 TVD 3896 Completion Date 9/19/2019 ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31451 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data A0 Gcc Operator Hilcorp Alaska LLC API No. 50.029-23644-00-00 Completion Status 1 -OIL Current Status t -OIL UIC No 5345 9749 11/22/2019 Electronic Data Set, Filename: MPU S-203PB1 ADR Quadrants All Curves.las 11/22/2019 Electronic File: MPU S-203PB1 LWD Final MD.cgm 11/22/2019 Electronic File: MPU S-203PB1 LWD Final TVD.cgm 11/22/2019 Electronic File: MPU S-203PB1 Definitive Survey Report.pdf 11/22/2019 Electronic File: MPU S-203PB1 DSR.txt 11/22/2019 Electronic File: MPU S-203PB1 GIS.txt 11/22/2019 Electronic File: MPU S-203PB1 LWD Final MD.emf 11/22/2019 Electronic File: MPU S-203PB1 LWD Final TVD.emf 11/22/2019 Electronic File: MPU S -2031P81 Geosteering.dlis 11/22/2019 Electronic File: MPU S-203PB1 Geosteering.ver 11/22/2019 Electronic File: MPU S-203PB1 LWD Final MO.pdf 11/22/2019 Electronic File: MPU S -203P61 LWD Final TVD.pdf 11/22/2019 Electronic File: MPU S-203PB1 LWD Final MD.tif 11/22/2019 Electronic File: MPU S-203PB1 LWD Final TVD.tif 100 11377 11/20/2019 Electronic Data Set, Filename: MPU S -203P132 LWD Final.las 5345 11340 11/20/2019 Electronic Data Set, Filename: MPU S-203PB2 ADR Quadrants All Curves.las 11/20/2019 Electronic File: MPU S-203PB2 LWD Final MD.cgm 11/20/2019 Electronic File: MPU S-203PB2 LWD Final TVD.cgm 11/20/2019 Electronic File: MPU S-203PB2_Definitive Survey Report.pdf 11/20/2019 Electronic File: MPU S-203PB2_DSR.txt 11/20/2019 Electronic File: MPU S-203PB2 GIS.txt Page 2 of 9 Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191090 Well Name/No. MILNE PT UNIT S-203 MD 11470 TVD 3896 ED C 31452 Digital Data Operator Hilcorp Alaska LLC Completion Date 9/19/2019 Completion Status 1 -011 - ED -OIL ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data ED C 31452 Digital Data Log 31452 Log Header Scans 0 0 ED C 31453 Digital Data 90 11489 ED C 31453 Digital Data 90 9787 ED C 31453 Digital Data 90 9787 ED C 31453 Digital Data 90 11377 ED C 31453 Digital Data 90 11400 ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data AOGCC Page 3 of 9 API No. 50-029-23644-00-00 Current Status 1 -OIL UIC No 11/20/2019 Electronic File: MPU S -203P62 LWD Final MD.emf 11/20/2019 Electronic File: MPU S-203PB2 LWD Final TVD.emf 11/20/2019 Electronic File: MPU S -203P62 Geosteering.dlis 11/20/2019 Electronic File: MPU S -203P62 Geosteering.ver 11/20/2019 Electronic File: MPU S -203P82 LWD Final MD.pdf 11/20/2019 Electronic File: MPU S-203PB2 LWD Final TVD.pdf 11/20/2019 Electronic File: MPU S-203PB2 LWD Final MD.tif 11/20/2019 Electronic File: MPU S-203PB2 LWD Final TVD.tif 2191090 MILNE PT UNIT S-203 P62 LOG HEADERS 11/20/2019 Electronic Data Set, Filename: S-203.1as 11/20/2019 Electronic Data Set, Filename: MPS203-PB1 LASfile 105'-9787'.Ias 11/20/2019 Electronic Data Set, Filename: S-203 PB1.las 11/20/2019 Electronic Data Set, Filename: MPS203-PB2 LASfile 105'-11377'.las 11/20/2019 Electronic Data Set, Filename: S-203 PB2.las 11/20/2019 Electronic File: MPS -203 Nabors AM Report 08- 24-2019.pdf 11/20/2019 Electronic File: MPS -203 Nabors AM Report 08- 25-2019.pdf 11/20/2019 Electronic File: MPS -203 Nabors AM Report 08- 26-2019.pdf 11/20/2019 Electronic File: MPS -203 Nabors AM Report 08- 27-2019.pdf 11/20/2019 Electronic File: MPS -203 Nabors AM Report 08- 28-2019.pdf 11/20/2019 Electronic File: MPS -203 Nabors AM Report 08- 29-2019.pdf Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191090 Well Name/No. MILNE PT UNIT S-203 Operator Hilcorp Alaska LLC API No. 50.029-23644-00-00 MD 11470 TVD 3896 Completion Date 9/19/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 08- 30-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 08- 31-2019.pdf, ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 01-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 02-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 03-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 04-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 05-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 07-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 08-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 09-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 10-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 11-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 12-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Nabors AM Report 09- 13-2019.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S203.dbf ED C 31453 Digital Data 11/20/2019 Electronic File: s203.hdr ED C 31453 Digital Data 11/20/2019 Electronic File: S203.mdx ED C 31453 Digital Data 11/20/2019 Electronic File: s203r.dbf ED C 31453 Digital Data 11/20/2019 Electronic File: s203r.mdx ED C 31453 Digital Data 11/20/2019 Electronic File: S203SCL.DBF ED C 31453 Digital Data 11/20/2019 Electronic File: S203_SCL.MDX AOGCC Page 4 of 9 Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191090 Well Name/No. MILNE PT UNIT S-203 Operator Hilcorp Alaska LLC API No. 50-029-23644-00-00 MD 11470 TVD 3896 Completion Date 9/19/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 31453 Digital Data 11/20/2019 Electronic File: S203_TVD.DBF ED C 31453 Digital Data 11/20/2019 Electronic File: S203_TVD.mdx ED C 31453 Digital Data 11/20/2019 Electronic File: MPU S-203 - Final Well Report.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Sin Drilling Dynamics Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Sin Formation Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Sin Gas Ratio Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Sin LW D Combo Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Drilling Dynamics Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Formation Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Gas Ratio Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - LW D Combo Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Sin Drilling Dynamics Log MO.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Sin Formation Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Sin Gas Ratio Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Sin LW D Combo Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Drilling Dynamics Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203- Formation Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - Gas Ratio Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 - LW D Combo Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S203.dbf ED C 31453 Digital Data 11/20/2019 Electronic File: S203.DBF_CustScl-txt ED C 31453 Digital Data 11/20/2019 Electronic File: s203.hdr ED C 31453 Digital Data 11/20/2019 Electronic File: S203.mdx ED C 31453 Digital Data 11/20/2019 Electronic File: s203r.dbf ED C 31453 Digital Data 11/20/2019 Electronic File: s203r.mdx AUGCC Page 5 of 9 Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191090 Well Name/No. MILNE PT UNIT S-203 Operator Hilcorp Alaska LLC API No. 50-029-23644-00-00 MD 11470 TVD 3896 Completion Date 9/19/2019 Completion Status I -OIL Current Status 1 -OIL UIC No ED C 31453 Digital Data 11/20/2019 Electronic File: S203_SCL.DBF ED C 31453 Digital Data 11/20/2019 Electronic File: S203_SCL.MDX ED C 31453 Digital Data 11/20/2019 Electronic File: S203_TVD.DBF ED C 31453 Digital Data 11/20/2019 Electronic File: S203_TVD.mdx ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PB1 - Sin Drilling Dynamics Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PB1 - 5in Formation Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PBI - 5in Gas Relic Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 P131 - 5in LWD Combo Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 P131 - Drilling Dynamics Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PB1 - Formation Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PBI - Gas Ratio Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 P131 - LWD Combo Log MD.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PB1 - Sin Drilling Dynamics Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PB1 - Sin Formation Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PB1 - Sin Gas Ratio Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PBI - Sin LWD Combo Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 P81 - Drilling Dynamics Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PBI - Formation Log MO.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PB1 - Gas Ratio Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S-203 PB1 - LWD Combo Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S203.dbf AOGCC Page 6 of 9 Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/14/2020 Permit to Drill 2191090 well Name/No. MILNE PT UNIT S-203 Operator Hilcorp Alaska LLC MD 11470 TVD 3896 Completion Date 9/19/2019 Completion Status 1 -OIL ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data ED C 31453 Digital Data AOGCC Page 7 of 9 API No. 50-029-23644-00-00 Current Status 1 -OIL UIC No 11/20/2019 Electronic File: S203.DBF CustScl.txt 11/20/2019 Electronic File: s203.hdr 11/20/2019 Electronic File: S203.mdx 11/20/2019 Electronic File: s203r.dbf 11/20/2019 Electronic File: s203r.mdx 11/20/2019 Electronic File: S203 SCL.DBF 11/20/2019 Electronic File: 5203 SCL.MDX 11/20/2019 Electronic File: S203 TVD.DBF 11/20/2019 Electronic File: S203 TVD.mdx 11/20/2019 Electronic File: S203 PB2 - Sin Drilling Dynamics Log MD.pdf 11/20/2019 Electronic File: 5203 PB2 - Sin Formation Log MD.pdf 11/20/2019 Electronic File: S203 PB2 - Sin Gas Ratio Log MD.pdf 11/20/2019 Electronic File: 5203 PB2 - Sin LW D Combo Log MD.pdf 11/20/2019 Electronic File: 5203 PB2 - Drilling Dynamics Log MD.pdf 11/20/2019 Electronic File: S203 PB2 - Formation Log MD.pdf 11/20/2019 Electronic File: S203 PB2 - Gas Ratio Log MD.pdf 11/20/2019 Electronic File: S203 PB2 - LW D Combo Log MD.pdf 11/20/2019 Electronic File: 5203 PB2 - Sin Drilling Dynamics Log MD.tif 11/20/2019 Electronic File: S203 PB2 - Sin Formation Log MD.tif 11/20/2019 Electronic File: S203 PB2 - Sin Gas Ratio Log MD.tif 11/20/2019 Electronic File: 5203 PB2 - Sin LW D Combo Log MD.tif Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/1412020 Permit to Drill 2191090 Well Name/No. MILNE PT UNIT S-203 Operator Hilcorp Alaska LLC API No. 50-029-23644-00-00 MD 11470 TVD 3896 Completion Date 9/19/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 31453 Digital Data 11/20/2019 Electronic File: S203 PB2 - Drilling Dynamics Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S203 P132 - Formation Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S203 PB2 - Gas Ratio Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: S203 P132 - LWD Combo Log MD.tif ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Show Report 1_5400'- 9350'.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Show Report 2_9400- 9870.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Show Report 3_10030'- 10110'.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Show Report 4_10850'- 10870'.pdf ED C 31453 Digital Data 11/20/2019 Electronic File: MPS -203 Show Report 5_11160'- 11230'.pdf Log 31453 Log Header Scans 0 0 2191090 MILNE PT UNIT S-203 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report nlDirectional / Inclination Data 0Y Production Test Informatio Y NA Mechanical Integrity Test Information Y / NA Geologic Markers/Tops YO Daily Operations Summary COMPLIANCE HISTORY Completion Date: 9/19/2019 Release Date: 8/9/2019 Description Date Comments Mud Logs, Image Files, Digital DataoY / NA Composite Logs, Image, Data FilesoY Cuttings Samples Y /9 Core Chips Y/& Core Photographs Y/ A Laboratory Analyses Y / AOGCC Page 8 of 9 Tuesday, January 14, 2020 DATA SUBMITTAL COMPLIANCE REPORT 1/1412020 Permit to Drill 2191090 Well Name/No. MILNE PT UNIT S-203 Operator Hilcorp Alaska LLC MD 11470 TVD 3896 Completion Date 9/1912019 Completion Status 1 -OIL Current Status 1 -OIL Comments: Compliance Reviewed By:,__� API No. 50-029-23644-00-00 UIC No Date: / // y /2zO—b AOGCC Page 9 of 9 Tuesday, January 14. 2020 Ililrurp %Ia Am' LL(. Date: 11/20/2019 De-, a Oudean Hilcorp Alaska, LLL 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 Makana Bender 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU S-203 (219-109 MPU S-203 �/ 1 8/2019 11 i 21 AM MPU S-203 PB1 Filefolder MPU S-203PB2 MPU S-203 PB2 10/28/20191:35 PM Filefolder CD 1 : HALLIBURTON FINAL DATA _Log Viewers 9/18/201911:21 AM Filefolder MPU S-203 �/ 1 8/2019 11 i 21 AM Filefolder MPDS-203PB1 9/1U20191121AM Filefolder MPU S-203PB2 9/161201911:21 AM Filefolder CD 2: NABORS FINAL MUDLOG DATA Daily Reports 10128./20191:35 PM Filefolder DML Data 1 0128/201 9 1:35 PM Filefolder Final Well Report 1 D/2812019 PM File folder LAS Data 10/28/20191:35 PM Filefolder Log PDFs 10/28/20191:35 PM Filefolder Log TIFFS 10/26120191:35 PM Filefolder S-203 PB1 Logs and Data 10.128'2D191:36 PM File folder S-203 PB2 Logs and Data 10/28/20191:36 PM Filefolder Show Reports 10/28+20191:35 PM Filefolder 2 19 109 31450 RECEIVED NOV 2 0 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Date: 11/20/2019 Debra Oudean Hilcorp Alaska, LLC 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 Makana Bender 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU S-203 (219-109 MPU S-203 91161201911:21 AM Filefolder MPU S-203 PB1 MPU S-203PB2 R/1 61201 9 11:21 AM Filefolder LAS Data 1C,/29,/20191:35 PM Filefolder Log PDFs lVH/20191:35PM Filefolder MPU S-203 PB2 S-203 PBl Logs and Data 10126;"20191:36 PM Filefolder CD 1 : HALLIBURTON FINAL DATA Log Viewers WM'201911:21 APO Filefolder MPU S-203 91161201911:21 AM Filefolder MPU S -203P61 9116/201911:21 AM Filefolder MPU S-203PB2 R/1 61201 9 11:21 AM Filefolder CD 2: NABORS FINAL MUDLOG DATA Daily Reports 10126,120191:35 PM Filefolder DML Data 1 012612 01 9 1:35 PM Filefolder Final Well Report 1 CV22J2019 1:35 PM Filefolder LAS Data 1C,/29,/20191:35 PM Filefolder Log PDFs lVH/20191:35PM Filefolder Log TIFFS 10126+20191:35 PM Filefolder S-203 PBl Logs and Data 10126;"20191:36 PM Filefolder S-203 PB2 Logs and Data 10+126/2015 1:36 PM Filefolder Show Reports 10/26/20191:35 PM Filefolder 2 19 109 3 145 1 REOUVE NOV 2 0 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 r.. I / Date: 11/20/2019 i Debra Oudean Hilcorp Alaska, LLC 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 Makana Bender 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU S-203 (219-109 MPU S-203 Rr`[K01911:21AM Filefolder MPU S-203 PB1 MPU S-2031382 c%18,!201911:21 AM Filefolder MPU S-203 PB2 Daily Reports I'' £::10191:35 PM Filefolder DML Data 1::26x20191:35 PM Filefolder Final Well Report 10!28.!20191:35 PM Filefolder CD 1 : HALLIBURTON FINAL DATA Log Viewers 9/1K01911:21AM Filefolder MPU S-203 Rr`[K01911:21AM Filefolder MPU S-203PBI 9/16/2019 11:21 AM Filefolder MPU S-2031382 c%18,!201911:21 AM Filefolder CD 2: NABORS FINAL MUDLOG DATA Daily Reports I'' £::10191:35 PM Filefolder DML Data 1::26x20191:35 PM Filefolder Final Well Report 10!28.!20191:35 PM Filefolder LAS Data 10/26/20191:35 PM Filefolder Log PDFs 10.,28/20191:35 PM File folder Log TIFFS 10'28.x20191:35 PM Filefolder S-203 PBl Logs and Data 1 CV28/20191:36 PM Filefolder S-203 PBZ Logs and Data 10x28,!20191:36 PM Filefolder Show Reports 10'26x20191:35 PM Filefolder 219109 3 145 2 REG"NED NOV 2 0 2013 AO G CC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 P, , Date: 11/20/2019 r Debra Oudean Hilcorp Alaska, LLC 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 Makana Bender 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU S-203 (219-109 MPU S-203 9;`15201911:21 AM File folder MPU S-203 PB1 MPU S-203PB2 9;`1e1(201011:21 AM File folder MPU S-203 PB2 Log PDFs 1028.720191:35 PM File folder CD 1 : HALLIBURTON FINAL DATA _Log Viewers 9115/201911:21 AM File folder MPU S-203 9;`15201911:21 AM File folder MPU S -203P61 9/18,7201911:21 AM Filefolder MPU S-203PB2 9;`1e1(201011:21 AM File folder CD 2: NABORS FINAL MUDLOG DATA Daily Reports 10!'26/20191:35 PM File folder DML Data 1Cl/28r20191:35 PlA File folder Final Well Report 1Gr"28x20191:35 PM File folder LAS Data 10,72820191:35 PM File folder Log PDFs 1028.720191:35 PM File folder Log TIFFS 102F720191:35 PM File folder S-203 PBl Logs and Data 10128;`20191:36 PM File folder S-203 PB2 Logs and Data 1028120191:36 PM File folder Show Reports 1028.720191:35 PM File folder 2 19 109 3 145 3 RECEIVED NOV 2 0 2019 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory ❑ GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: -I Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: Hilcorp Alaska, LLC Aband.: 9/19/2019 219-109 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: August 24, 2019 15. API Number: 50-029-23644-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 3228' FSL, 503' FEL, Sec 12, T12N, R10E, UM, AK September 11, 2019 MPU S-203 Top of Productive Interval: 9. Ref Elevations: KB: 63.4' , 17. Field / Pool(s): Milne Point Field 1897' FSL, 1931' FEL, Sec 12, T12N, R10E, UM, AK GL: 36.7' BF: 36.7' * Ugnu Undefined ' Total Depth: 10. Plug Back Depth MD1 VD: 18. Property Designation: 1939' FSL, 2437' FEL, Sec 11, T12N, R10E, UM, AK 9,795' MD / 3,729' TVD ' ADL380109 / ADL380110 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 565507 y- 5999892 Zone- 4 11. Total Depth MD/TVD: 11,470' MD / 3,896' TVD 19. DNR Approval Number: LONS 01-001 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: TPI: x- 564092 y- 5998548 ' Zone- 4 Total Depth: x- 558306 y- 5998544 ' Zone- 4 N/A 1,850' MD / 1,709' TVD 5. Directional or Inclination Survey: Yes � (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary RECEIVED ROP/ABG/DGR/EWR/ADR 2"/5" MD / PB1, PB2 ABG/DGR/EWR/ADR 2"/5" TVD / PB1, PB2 OCT 0 8 2019 AQGGG 23, CASING, LINER AND CEMENTING RECORD CASING WT. PER FT SETTING DEPTH MD SETTING DEPTH TVDAMOUNT HOLE SIZE CEMENTING RECORD PULLED GRADE TOP BOTTOM TOP BOTTOM 20" 215# X-52 Surface 107' Surface 107' 42" ±270 ft3 Stg 1 L - 392 sx / T - 396 sx 9-5/8" 40# L-80 Surface 5,355' Surface 3,836' 12-1/4" Sig 2 L - 604 sx / T - 270 sx 160 bbls 7-5/8" 29.7# L-80 Surface 5,208' Surface 3,832' Tieback Tieback Assy. 4-1/2" 13.5# L-80 5,204' 9,800' 3,832' 3,731' 8-1/2" Screens w/ Swell Pkrs 24. Open to production or injection? Yes Q No ❑ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDfTVD) If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 3-1/2" 5,239' 4,468' MD / 3,701' TVD ""' See attached wellbore schematic for Screen / Solid Liner Detail Liner run on 9/16/19 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. COMPLETION Was hydraulic fracturing used during completion? Yes ❑ No DrTE, Per 20 AAC 25.283 (i)(2) attach electronic and printed information Zo(9 DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED VERIFIED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 9/28/2019 Jet Pump Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 10/4/2019 24 Test Period 491., 51.6 74.1 N/A 150.9 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 239 2751 24 -Hour Rate .♦ 491 51.6 74.1 13.6 Form 10407 Revised 512017 OlDON PAGE 2 to Z0t9 S'bYit0'l/cilhIl /```/)IZO 110RBD&OCT 8q[SDI(A 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MDfrVD, Fromffo), 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 Q If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 1,850' 1,709' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval UG MB 5,688' 3,821' information, including reports, per 20 AAC 25.071. SVi 2,580' • 2,331' LA3 4,233' 3,599' LAi 4,372' 3,664' MA 4,873' 3,801' UG MB 5,089' 3,824' i UG MD 9,400' 3,718' Formation at total depth: UG MD r 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report, OH Sidetrack Summary. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I 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: cclin era hilcor .COr11 Authorized Contact Phone: 777-8389 Signature: — Date: 10 • ZO Icy INSTRUCTIONS General: This form and the required attachm s provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only K . Alaska- IA.0 Ong. IB Ekv.:26.7/ 6L EIev.:35Y Milne Point Unit Well: MPU 5-203 SCHEMATIC Last Completed: 9/19/19 PTD: 219-109 TREE & WELLHEAD Tree Cameron 3-1/8" 5M Wellhead FMC Gent/ TD= 11,470'(MD) /TD = 3,896' (TVD) PBID= 9,795' (MD) / PBTD = 3,725 (TVD) OPEN HOLE / CEMENT DETAIL Conductor ±270 ft3 Wt/Grade/Conn Sig 1— Lead - 392 sx Extenda Cem / Tail — 396 sx Swift Cem 12-1/4" Stg 2—Lead-604 sx Perm Cem/Tail-270 sx Class BPF (160 bbls to surface) 8-1/2" Cementless Screen Liner in 8-1/2" hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 215 / X-52 / Weld N/A Surface 107' N/A 9-5/8" Surface 40/L-80/TXP SR 8.835 Surface 5,355' 0.0758 7-5/8" Tieback 29.7 / L-80 / Hyd 5216.875 6 Surface 5,208' 0.0459 4-1/2" Liner SSOp Screens 13.5 / L -SO / Hydril 625 3.920 5,204' 9,800' .0149 TUBING DETAIL 3-1/2" Tubing 9.3/ L-80 / EUE-8rd 1 2.992 1 Surface 5,239' 0.0087 WELL INCLINATION DETAIL KOP @ 260' Maz Hole Angle = 94.8 IEWELRY DETAIL No. Top MD Item Btm (TVD) 1 22' Tubing Hanger (3-1/2" TC -II Top & Btm) 2 4,378' 3.5" Discharge Pressure Gauge Mandrel (Discharge Gauge) 3,691' 3 4,388' 3.5" CMD SlidingSleeve 4 4,399' 3.5" Gauge Mandrel w/ Y" Wire (Intake Gauge) V2.813" 5 4,421' 3.5" X Nipple (3.813" Packing Bore) 6 4,468' 7-5/8" x 3.5" FHL Retrievable Packer 7 4,490' 3.5" XN Nipple 8 5,239' 3.S"Muleshoe Lower Completion 9 5,204' BOT SLZXP LT Packer/Liner Hanger 4-1/2'x9-5/8" 6.190" 10 5,208' 7-5/8" Tieback Assy. 6.151" 11 5,226' 7" H563 x 4.5" 625 L-80 XO 3.830" 12 9,795' WIV Valve LTC BZB (1" Ball on Seat/Closed) - 4-1/2" SOLID LINER DETAIL Top (MD) Top (TVD) Eton (MD) Btm (TVD) 5,231' 4,834' 5,688' 3,821' 9,115' 3,663 9,408' 3,691' 4-1/2" Screens LINER DETAIL Its Top (MD) Top (TVD) Elton (MD) 82 5,688' 3,821' 9,115' 93�663' 7 9,428' 3,694' 9,722' GENERAL WELL INFO API: 50-029-23644-00-00 Completion Date: 9/19/19 Edited By: CID 9-20-2019 MPU S-203 OH Sidetrack Summary PBI I PB2 TD 9,787' MD / 3,647' TVD I 11,377' MD / 3,783' TVD KOP 8,073' MD 8,800' MD Date 9/4/2019 9/10/2019 PTD: 219-109 / API: 50-029-23644-00-00 Hilcorp Energy Company Composite Report Well Name: MP S-203 Field: Milne Point County/State: North Slope Burough, Alaska (LAT/LONG): svation (RKB): API #: Spud Date: Job Name: 1914120D MPU S-203 Drilling Contractor Innovation APE #: Activity Date 8/21/2019 Ops Summary PJSM Move all Mods F/ E Pad to S Pad W/ Peak. Clean up E Pad ,PJSM Spot Sub Mod over E-203. Crane up parts connex and move Sperry Box on top of Pit Mod. Crane up Iron Roughneck onto rig floor. Lay Matt Boards for the rest of the rig. Unload misc truck loads F/ E Pad. Spot Cattle chute, Pipe Shed, Pit Mod and Gen Mod. 8/22/2019 PJSM Cont. spotting Gen Mod. M/U all lines and inner connects. Start steam, air and water around rig. Scope up Derrick and bridle down. Spot Cutting Box.;PJSM Clean and clear rig floor and set bridle lines back. Install Iron Roughneck on pedestal W/ Top Drive. SIMOPS Spot Mud Logger unit and unload trucks F/ E Pad.;PJSM Wire in Iron Roughneck control station. Get measurements for hydraulic hoses for Iron Roughneck. Cut old brackets out of Derrick. Re assemble handling Equip. Begin N/U Stack. Cont. painting in Pits.;PJSM Cont. N/U Stack. C/O Tongs and weight buckets on rig floor. Cont. painting in Pits. 8/23/2019 Work on rig acceptance checklist. Troubleshoot and fix electrical hookups for Iron Roughneck. Adjust hydraulics and function test IR (good). Re -assemble handling equipment dressed w/ new dies. Continue N/U diverter system. N/U Knife valve and 16" diverter line. Modify overboard discharge line. RID satellite camp and shop.;Continue N/U diverter system. 4 pt stack, cont install 16" line. Continue modify overboard line and re -assembly handling equipment. Spot satellite camp and shop. Power up same. Continue working on rig acceptance checklist. Finish rigging up mudloggers equipment.;PJSM Cont. putting together Diverter pieces. Cont assembling and painting handling Equip. Install long Mouse Hole in Rotary Table. Disconnect Knife Valve and close Annular. Manipulate Iron Roughneck for areas of use. Obtain IRKS Annular 11.5', GIRL 267. Install short Mouse Hole.;Load and process 5" HWDP in Pipe Shed. Bring on 290 bbl Spud Mud to Pits. Rig Crew perform SOP on functions on Iron Roughneck. Went to high line power @ 20:00, went back to Gen power at 23:00 due to Turbine issues W/ operations. SIMOPS Cont off loading trucks F/ E Pad and staging around pad.;PJSM Cont. working on rig acceptance check list. Rig Crew perform SOP on functions on Iron Roughneck. Check TRQ of Iron Roughneck W/ rig tongs and TDS. Perform hazard hunt with oncoming crew. C/O Hydraulic Elevators to manuals due to fittings. SIMOPS Function test Equip in Pits and Mud Pumps.; PJSM P/U M/U 5" INC 50 D.P. F/ Pipe Shed using Iron Roughneck and rack back in Derrick 30 stands (60 Jnts). Drift W/ 3.126'.;Daily hauled 0 bbl, to G&I total = 0 bbis Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 0 bbls H2O from B -Pad Creek total = 720 bbis Lost 0 hips to formation Total fluid lost 0 bbls Total Metal 0 Ib 8/24/2019 Rig accepted 0 06:00 hes. PIU and rack back a total of 84 stands 5" NC50, S-135, 19.5# drill pipe. Drift 3.125". PIU and rack back 6 stds 5" HWDP wl jars. UD mousehole. Hook up koomey lines and adjust annular psi to 1400. Finish installing last 2 sections of diverter line and place containment.;Load 290 btaps 8.8# spud mud in pits.;Finish assembly of handling equipment. R/U floor for BHA w/ 3' tongs. Change IR heads for 8" tools.;Bring BHA components to rig floor and stage. M/U 12-1/4" Kymera w/ 1.5° mtr. RIH on HWDP to tag depth of 105' (107' btm conductor). POOH to 40' and park.;PJSM, Perform diverter test wl 5" HW DP. Knife valve open @ 3 sec, Annular closed @ 7 sec. Test gas alarms 10/20 H2S, 20/40 LEL. Koomey drawdown - 3000 psi start, drawdown 2000 psi, 200 psi Inc 17 sec, full charge @ 51 sec, 6 bottle avg @ 2333 psi. AOGCC waived witness by Adam Earl via email.;Flood conductor wl H2O. Check for leaks on flowline (none observed). Shut IBOP and PIT lines to 3k (Test good). Bleed off psi and open IBOP.;PJSM Check torque on Wash Pipe after PT. Good.;Pre spud meeting with all parties. Discuss well control, evacuation, broaching and emergency situations.;PJSM Drill F/ 105' to 315' MD. 414 GPM, 620 PSI, 50 RPM, TO ON 1.7K, TO OFF 0.7K, WOB 4K, F/O 64%, PIU 51 K. SLK 51 K, ROT 51 K. Drill 2' and PIU and swap to 8.8 ppg Spud Mud. Rigged blacked out at 19:30 maybe due to PLC mode W/ 17% power, was able to Gens going on PLC mode.; Re tighten drag chain belt due to break in. CBU.;PJSM POOH on Elevators F/ 315' to 33' MD. No losses observed. PIU 51K, SLK 50K.;PJSM for BHA and loading source. PIU M/U BHA components to 12.25" Kymera Bit and 1.5° Mud Motor, 8" Pony Collar, 8" DM Collar, 8" DGR, 8" EWR-P4 Collar, 8" PWD, 8" HCIM, 8" ALD Collar, 8" CTN Collar, 8" TM Collar and UBHO to 138' MD. Performed RFO 2.63/8.04=117.76°. Orientate UBHO as per Sperry.;PJSM Spot Pollard ELine unit. R/U ELine sheave in Derrick and bring Gyro tools to rig floor. SIMOPS Down load Sperry MWD tools.;PJSM Discuss loading Nuclear source for MWD. PIU first stand 5" HWDP shallow hole test MWD tools. Rack back 5" HWDP. Install Nuclear source as per Sperry MWD rep onsite. PIU M/U NM FC RIH to 199' MD.;Daily hauled 114 table to G&I total = 114 bbis Hauled 0 bbis H2O from A -Pad reserve total = 0labs, Hauled 130 bale H2O from B -Pad Creek total = 850 btals Lost 0 bbis to formation Total fluid lost 0 We Total Metal 0 Ib 8 /2 512 01 9 Wash and ream down F/ 196'- T/ 315' MD. 405 gpm, 450 psi, 59% flow.;Drlg 12.25" hole F/ 315'- TI 636 MD, 450 gpm, 1020 psi on, 880 psi off, 40 rpm, 4k tq, 8k wob, 58% flow. 70k upldn/rot. Continue Gyro between connections (SDI w/ Pollard). Mostly sand/clay at shakers. KOP @ 321'w/152* az.;Drlg 12.25" hole F/ 636'- T/1100' MD (464' total/77' ROP), 450 gpm, 1240 psi on, 275 psi diff, 60 rpm, 6k tq, 2k tq off, 9k wob, 57% flow. 81 k up/73k do/78k rot. Continue Gyro between connections (SDI w/ Pollard). Mostly sand/clay at shakers. BR 20' each stand.;PJSM Rotate/ Slide ahead 12.25" Hole F/ 1,100' to 1,524' MD (1,431' TVD) 424' total (70.7' AROP) 500 GPM, 1,410 PSI, 60 RPM, TRQ ON 5.5K, TRQ OFF 3K, WOB 7K, F/O 61 %, Max Gas 82U, ECD 10.02, MW 9.1 ppg. PIU 86K, SLK 76K, ROT 80K. Wipe/ream 30' every connection. Gyro every stand.;Obtained clean MWD surveys @ 1,280', 1,342' & 1,406'MD. Last Gyro survey at 1,240' MD, Gyro on standby to ensure good surveys. At 1,280' MD saw good separation F/ 5-39 W/ 54' CC. Cont. build 4°1100 to 1,450' MD, hold 32° Inc, 133° Azi.;PJSM Rotate/ Slide ahead 12.25" Hole F/ 1,524' to 1,969' MD (1,805' TVD) 445' total (74' AROP) 500 GPM, 1,410 PSI, 60 RPM, TRQ ON 7K, TRQ OFF 6K, WOB 8-14K, F/O 58%, Max Gas 91 U, ECD 9.8, MW 9.2 ppg. PIU 105K, SLK 74K, ROT 87K. Wipe/ream 30' every connection.;Reamed out dog leg F/ 1,906'to 1,842' MD 3X. Released Gyro at 03:30. Hole unloaded Clay and Sand at -1,600' MD increased H2O F/ 40 bph to 50 bph. MW increased to 9.3 ppg, current MW 9.2 ppg. Both Centrifuges on. C/O Hydraulic Elevators to manuals due Hydraulic fitting.;Distance to WP#7: 27.86', 22.95' High, 15.8' Left. Slide Hrs 5.61, Rot Hrs 3.37.;Daily hauled 460 bbis to G&I total = 574 bbis Hauled 0 bbis H2O from A -Pad reserve total = 0 bbls Hauled 650 bbis H2O from B -Pad Creek total = 1,500 bbis Lost 0 bbis to formation Total fluid lost 0 bbis Total Metal 0 Ib 8126/2019 Rotate / Slide ahead 12.25" Hole F/ 1969'- T/2575' MD (2324' TVD) 606' total (101' AROP) 500 GPM, 1,420 PSI, 60 RPM, TRQ ON 6.5K, TRQ OFF 5.8K, WOB 7K, F/O 61 %, Max Gas 798u, ECD 10.1, MW 9.2 ppg. P/U 117K, SIO 84K, ROT 97K. Backream full stands. Permafrost @ 1850' MD 11708' TVD.;Started our drop turn at 2,133' MD 4°/100.;Rotate / Slide ahead 12.25" Hole F/ 2575'- T/3200' MD (2859 TVD) 625' total (104' AROP) 500 GPM, 1,600 PSI, 60 RPM, TRQ ON 8.2K, TRQ OFF 6.6K, WOB 7K, F/O 61 %, Max Gas 430u, ECD 10.1, MW 9.2 ppg. P/U 137K, S/O 91 K, ROT 110K. Backream full stands.;Slart build and turn with 4°/100 from 2921'.;PJSM Rotate/ Slide ahead 12.25" Hole F/ 3,200' to 3,720' MD(3,28T TVD) 520' total (87' AROP) 550 GPM, 1,900 PSI, 70 RPM, TRQ ON 11.51K, TRQ OFF 9.3K, WOB 14K, FIG, 61 %, Max Gas 229U, ECD 9.8, MW 9.1 ppg. P/U 151 K, SLK 92K, ROT 112K. Back ream full stands.;At 3,440' MD close approach to 5-41 81' CC. Cont. directional build turn 4°1100. At 3,300' MD dumped and dilute 290 bbis for weight and Temp.;Rotate/ Slide ahead 12.25" Hole F/ 3,720' to 4,100' MD(3,526 TVD) 380' total (64' AROP) 525 GPM, 1,720 PSI, 70 RPM, TRQ ON 10-13K, TRQ OFF 11-14K, WOB 6-18K, F/O 62%, Max Gas 205U, ECD 9.7, MW 9.15 ppg. P/U 157K, SLK 89K, ROT 113K. Back ream full stands.;Cont.directional build turn 4'1100. Motor output was between 5 - 7°/100 for this interval.;Distance to WP#7: 224, 6.03' High, 21.57' Left. Slide Hrs 6.36, Rot Hrs 4.26.;Daily hauled 1,380 bbis to G&I total = 1,954 bible Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 1,300 bbls H2O from B -Pad Creek total = 2,800 bbis Lost 0 bbls to formation Total fluid lost 0 bbis Total Metal 0 lb 8127/2019 PJSM Rotatel Slide ahead 12.25" Hole F/ 4,100'to 4,579' MO (3,734' TVD) 479 total (79.8' AROP) 525 GPM, 1,775 PSI, 70 RPM, TRQ ON 10-14K, TRQ OFF 12-14K, WOB 8-16K, F/O 61 %, Max Gas 1,777U, ECD 9.8, MW 9.2 ppg. P/U 161 K, SLK 92K, ROT 118K. Back ream full stands.;Cont. build turn 4'/100.;PJSM Rotate/ Slide ahead 12.25" Hole F/ 4.579' to 5,085' MD (3,817' TVD) 506 total (84.3' AROP) 525 GPM, 1,805 PSI, 70 RPM, TRQ ON 13K, TRQ OFF 12-15K, WOB 14K, F/O 58%, Max Gas 1,398U, ECD 9.76, MW 9.2 ppg. P/U 157K, SLK 86K, ROT 113K. Back ream full stands.;Continue build turn 4°/100 as per directional plan. Motor yield is 5-9°1100. Inclination was built to 84.70' at 4904'. At 4958' drop to 83° and hold to 5150'. Then build to 91.50° with 6.00" doglegs.; Rotate/ Slide ahead 12.25" Hole F/ 5,085' to 5,364' MD (3,830' TVD) 279' total (69.8' AROP) 475 GPM, 1,590 PSI, 70 RPM, TRQ ON 15K, TRQ OFF 14K, WOB 9K, F/O 55%, Nabors Max Gas 4,065U, IRig Max Gas 2,125U, ECD 9.93, MW 9.3 ppg. P/U 163K, SLK 81 K, ROT 1101K. Back ream full stands.;At 5086' build at 5100' to 88° and hold for 1 stand, build to 91' to target TD @ 5364 for casing shoe at 5354'. At 5105' Logs showed entering MB sand. Geo requests build to 91° at TD. Survey at 5287 yielded a 5.6° dogleg from 37' of slide.Ream stand twice survey at 5287' dogleg was reduced to 2.56°.; Rotated to TD of 5364' survey at 5309' showed a 3.56° Dogleg over 23' for a motor yield of 9.7. Bit is at 91.5° (projected) at TO based on motor yield.;PJSM Obtain final MWD survey 5,309' MD, 89.58° Inc, 272.45° Azi. Monitor well 10 Min, static. POOH on elevators F/ 5,364' to 5,080' MD above MB Sand. No lasses. P/U 163K, SLK 81K. Saw 5-10K drag POOH. SIMOPS clean Shakers W/ Condent due to oil build up.;PJSM Break Circ. Rot/ Rec F/ 5,080' to 5,020' MD Screened down to 140's on Shakers to handle flow rate. Staged pumps up to 475 GPM, 1,340 PSI, 80 RPM, TRQ 12-15K, F/O 56%, P/U 163K, SLK 81K, ROT 110K. ECD 9.89. Nabors Max Gas 3,418U, IRig Max Gas 1,183U.;Nabors gas measures all gas including Methane and is 5,000U for 100%. [Rig gas only measures Methane and S,OOOU for 100%.;PJSM Cont. CBU F/ 5,020' MD staging pumps up to 550 GPM. Rack one stand back Pump 50 bbl, 9.15 ppg 310 Vis Sweep. CBU F/ 5,020' to 4,961' MD 550 GPM, 1,700 PSI, 70 RPM, TRQ 13-15K, F/O 58%, ECD 9.6, ROT 111K, P/U 154K, SLK 86K. Sweep back 700 Stks (43 bbls) early no increase.; PJSM RIH on elevators F/ 4,961' to 5,364' MD. Wash down last 30' to bottom. No issue. P/U 164K, SLK 80K.;PJSM BROOH F/ 5,364'to 4,198' MD. 550 GPM, 1,720 PSI, 70-80 RPM, TRQ 12-14K, Nabors Max Gas 324U, IRig Max Gas 21 U, ECD 9.9, P/U 165K, SLK 87K, ROT 114K. Pull speed 15-25 FPM as hole dictates. No Iosses.;Distance to WP#7: 11.06, 9.76' Low, 5.21' Right Slide Hrs 4.67, Rot Hrs 3,16;Daily hauled 1,261 bbls to G&I total = 3,215 bbis Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 1,040 bbis H2O from B -Pad Creek total = 3,840 bbis Lost 0 bbls to formation Total fluid lost 0 bbls Total Metal 0 Ib 8/2 812 01 9 PJSM BROOH F/ 4,196 to 1,842' MD. 550 GPM, 1,400 PSI, 80 RPM, TRQ 6-91K, Nabors Max Gas 197U, IRig Max Gas 21 U, ECD 10.3, P/U 118K, SLK 77K, ROT 90K. Pull speed 30-40 FPM as hole dictates. CBU @ 2,000' MD. No losses.;PJSM BROCH F/ 1,842' to 572' MD. 550 GPM, 1,420 PSI, 80 RPM, TRQ 7K, Nabors Max Gas 22U, IRig Max Gas 3U, ECD 10.41, P/U 120K, SLK 66K, ROT 84K. Attempt to pull on elevators at 572' pulled over 15K. Cont BROOH F/ 572' to 350' MD. pulling into tight spots W/ 20K TRQ spikes. 450 GPM,;880 PSI, 60 RPM, TRQ 3-20K. Shakers started running over at 1,500' MD stopped and Circ but Shakers really never stopped running over. How ever ECD's dropped to 10.14 ppg.;POOH on elevators F/ 350' to 199' MD. Monitor well, static. P/U 85K, SLK 58K. No Iosses.;PJSM UD NM FC. Remove Nuclear Source as per Sperry MWD and DD onsite. Down load MWD tools. Monitor well on TT, static.;PJSM UD BHA #1 components as per MWD/DD onsite. Bit Grade 0 -3 -BT -T -E -1 -LT -TD. Bit had one broken tooth on the tapper missing button on a cone. Monitor well on TT, Static loss about 2 bph.;Clean and clear rig floor of BHA components.;PJSM Load remaining 9 5/8" Csg in Pipe Shed to complete tally. Bring 75 Centralizers to rig floor. RID 5" Elevators and R/U Weatherford Volant tool to Top Drive. Remove inspection hatches and clean flow line and possum belly. Install casing bushings and bring Csg handling Euip to rig floor.;PJSM Finish R/U Csg elevators, Volant and handling Equip.;PJSM Grease Crown, Blocks, Wash Pipe, Top Drive, Drawworks and Spinners.;PJSM M/U Shoe Track. Shoe, FC, Baffle Adapter to 160' MD. Baker Loc Shoe Track. Check Floats and set Bypass in W/ Halliburton and Co Rep onsite. TRQ 9 518" to 20,960 ft/lb.Monitor well, static loss about 2 bph.;RIH 9 5/8" L-80 40# Csg F/ 160' to 636 MD. Torque to 21 K. PIU 53K, SLK 53K. Calc Disp 6 bbis, actual -2 bbls. Lost 8 bbls.;Daily hauled 624 bbis to G&I total = 3,839 bbls Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 650 bible H2O from B -Pad Creek total = 4,490 bbls Lost 0 bbis to formation Total fluid lost 0 bbls Total Metal 0 Ib 40 8/29/2019 RIH on elevators with 9 5/8" Cso f/ 630'- 1630. Encounter tight spots through permafrost and Wash/Ream casing from 1630' to 1984' @ 5 bpm/150 psi, 10 rpm/4-6.5K Tq,. RIH on elevators from 1984' to 2350'. PUW 119K, SOW 87K, Lost 19 bbls.;CBU x2 from 2350'. Stage pumps to 7 bpm. Lost 10 bbls on circulation.; PJSM Cont. RIH 9.625" L-80 409 TXP BTC F/ 2,350' to 5,355' MD as per tally. Fill every 5 Jnts, break Cric every 15 Jnts., TRO to 21 K. P/U 240K, SLK 118K. Calc Disp 46 bbis, actual 27 bbis, lost 19 bbis. Went to High line power at 16:00.;PJSM Start conditioning for cement job <20YP. Break circ, staging up to 7 bpm. 545 PSI, reciprocating F/ 5,359'to 5,324' MD. P/U 213, SLK 120K Set drill TRQ to 18K and Rot 5 RPM. Circ 1.5X BU and shutdown and monitor well for 30 min, static. Start Circ. staging up to 7 bpm,. No Iosses.;R/D Weatherford Power Tongs and Long Bails, Clear Rig of 9 5/8" handling Equip.;Start Circ. staging up to 7 bpm, 545 PSI,. SIMOPS Crane oft 20' center section of 16" Diverter and stage Halliburton Pump Truck and 290 bbl Vac for rinse. Reinstall W/ Crane. AOGCC Guy Cook waived witness.;Cont. conditioning Mud, Rot and Rec F/ 5,359' to 5,324' Broke over at 280 Circ 7 bpm, 545 PSI, P/U 214K, SLK 115K. Shut down and R/U cement line to Volant. Cont, conditioning mud for cement. Halliburton R/U Water and cement line. Remove cement plug from low torque at mud manifold on the rig floor.; PJSM for cement job W/ all parties. MW 9.45 ppg, 20 YP in and out. Blow down TO and cement line. Halliburton fill lines WI 5 bbl H2O, PT 1,000 PSI low and 4,000 PSI. Kick out set @ 500/ 4,000. Pump 53 bbis 10.0 ppg Tuned Spacer W/ Red Dye and 0.5 ppb Pol-E-Flake at 4 bpm, 213 PSI.;Drop Bypass Bottom Plug W/ HAL and Co Rep onsfte. Pump Lead 132 bbl 12.0 ooa 315 sx ExtendaCem 2.349 ft/sk at 4.5 bpm, 297 PSI. Pum Tail 82 bbl 15.8 400 sx SwiftCem 1.157 ft/sk at 4.3 bpm. 715 PSI. DropShu w/ 20 bbls H2O;then turn over to rig. Rig pump 208 bbis 9.45 ppg spud mud, 6 bpm, 370 PSI. HAL Disp 80 bbis H2O at 4 bpm 370 PSI. Rig Disp 91.9 bbls 9.45 ppg spud mud, 6 bpm, 759 psi. Rot & Rec the whole job at 1-2 RPM 15K, P/U 255K. SLK 108K. Parked in tension W/ 215K.;Reduced rate last 10 bbls to 3 bpm, y'Y FCP 640 psi, increased to 1,150 PSI. Plug bumped 2.96 bbls over Calc. Held for 5 minutes, check floats - good. CIP @ 05:15 Full returns throughout iob. Pressure up to 2,879 PSI to open ES cementer. Circulate at 6 bpm 330 PSI.;Circulate at 6 bpm 330 PSI. Over boarded when Poly Flake was seen at surface, Cement was seen 400 strokes late 18 bbis back at surface. Dumped 248 bbls.;Daily hauled 556 bbls to G&I total = 4,395 bbis Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 260 bbls H2O from B -Pad Creek total = 4,750 bbis Lost 66 bbls to formation Total fluid lost 66 bbis Total Metal 0 It, 8/30/2019 CBUx3 thru stage tool @ 2093'. 6 bpm, 495 psi. Very little contaminated mud on 2nd BU. clean on 3rd BU.;Ddan Stack, fill with black water, disconnect Knife Valve Hyd Hoses, work bag, drain and repeat. Drain stack, shut Annular & ensure no CMT on top of Annular. Pump black water @ 10 bpm thru bleeder and .a ,1 flush flow line. Reconnect Knife valve hyd hoses.;Continue to circulate thru stage tool while prepping for 2nd stage cmt. Process 5" DP in Shed. Fill and heat y H2O tanks. Prep cellar for N/D-NIU. Prep Pits for 2nd stage.;PJSM on pumping 2nd stage CMT.;HES pump 5 bbls water, PT 4000 psi., Pump 57 bbis 10# y clean spacer at 4 bpm/266 psi w/ 4# red dye first 10 bbis. Mix and pump 281 bbis (604 sxs) 10.7 ooa Arct cCem lead cement at 5 bpm/555 psi Pump lead cement until Spacer w/Cmt seen at surface. Mix and pump 56.2 bbls 270 sxs 15.8 viao S '. Drop closing plu . Displace with 20 bbis H2O followed by 140 bbis of 9.5 ppg drilling fluid at 6.5 bpm/775 psi.;Slow rate to 3 bpm last 20 bbis with FCP 510 psi. Bum pedalculated. Pressure up to 1500 psi to close ES cementer, positive indication of closure observed. Held pressure for 5 minute. Bleed back and confirm ES cement closed.;160 bbis green cement returned to surface. No losses. CIP at 16:OO.;PJSM Drain Stack and rinse W/ Black Water. Disconnect Knife Valve Hydraulic hoses and function Bag. Circ. Black Water through cement lines. Remove inspection hatches on flow line and clean.;PJSM Clean out 9 5/8" Casg. Remove Mouse Hole. Remove Volant and put on 9 5/8" Elevators. Hook up Bridge cranes to Stack and remove chains. Remove Diverter sections W/ Crane. SIMOPS Clean Pits.;Lift Stack and install -Slips in 9 5/8" as per NOS Rep and witnessed by Co Rep Set in slips 150K Rough cut Csg and LID. (Cut 27.94') Remove 9 5/8" Elevators and install 5". Set Stack back down and Johnny Whack W/ Black Water. Blow down Top Drive.;PJSM Remove last three sections of diverter line. Remove Knife Valve and Riser. PIU and set back stack on pedestal and secure. Remove Diverter Tee and Speed Head F/ Sub. Make final cut on 9 5/8" Csg. (0.80') Dress 9 5/8" Csg for well head. SIMOPS Cont cleaning Pits and process 5" D.P.;PJSM Remove 4" conductor valves and install caps. Install 9 5/8" slip lock heads. Test seal void to 500 PSI 5 Min, 2,475 PSI for 10 min. Set tubing spool on slip lock head. SIMOPS Cont. cleaning Pits and processing 5" D.P. in Pipe Shed.;Daily hauled 1,765 bbis to G&I total = 6,160 bbis Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 780 bbis H2O from B -Pad Creek total = 5,530 bbis Lost 66 bbis to formation Total fluid lost 66 bbls Total Metal 0 Ib 8/31/2019 PJSM Install DCA and set BOPE. Install MPD RCD on BOPE. Install companion flange on annulus and install MPD hard lines. SIMOPS Clean and clear rig floor. Bring up split Bushings and trip nipple. Finish cleaning Pits. Cont processing 5" D.P.;PJSM Finish installing MPD RCD and hard lines. Secure ROPE. Install drip pan, Choke and Kill lines. Remove MPD test cap. Install Riser. Center BOPE. Hook up Kearney lines. SIMOPS start taking on 8.9 ppg Bandril N onto Phs.;PJSM PIU M/U 5" test Jnts, side entry sub, TIW, Dart Valve and RIH W/ test plug. Flood lines and cycle out air in system.;PJSM Shell test to 150 PSI low/ 3,00 PSI high. Notice leak on DS Blind Ram door, Kill line flange and MBD clamp. Bled off Press and tightened all. Good.;PJSM Test Wl 5" & 3.5" test jnl. 250 PSI low and 3,000 PSI high 5 min on chart. Tested Choke Manifold 1-15, 5" Dart, 5" TIW, Dart, Upper and lower IBOP, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke, Upper and lower VRB Rams (2,875" X 5.5") Blind Rams.;Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms.Koomey draw drown Initial System 3,150 PSI, Manifold 1,450 PSI, Annular 1,490 PSI, after System 1,500 PSI, Man 1,500 PSI, Annular 1,430 PSI. 200 PSI increase 24 Sec, full charge 84 sec.;Nitrogen 6 bottle average 2,333 PSI. Witnessed by AOGCC Lou Laubenstein.;PJSM RID BOPE test Equip.;PJSM Remove riser and install testing head.;Daily hauled 228 bbis to G&I total = 6,388 bbis Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 130 bbis H2O from B -Pad Creek total = 5,660 bbis Lost 0 bbls to formation Total fluid lost 66 bbis Total Metal 0 Ib 9/1/2019 Install MPD Test Head, flood lones to MPD Unit. Test MPD Equipment to 250/1000. Test good.; Remove MPD Test Plug, Install trip nipple. Obtain RKB's. Install Mouse Hole. Blow down choke and Kill.;Pull Test Plug. Install 9" ID Wear Bushing. RILDS.;PJSM pickup and makeup 8.5" Cleanout BHA. WU 8.5" tricone XR+XP Smith bit, SperryDrill Lobe 617 motor with 1.5 bend, (2) joints HWDP, Jars, (9) joints HWDP. Total Length = 405.96.;Drift, pick up and single in the hole with 5" drill pipe from 405' to 2050'. fill pipe, Rib and tag soft cmt @ 2080'. PUW 90K, SOW 70K.;Establish parameters 400 gpm/515 psi, 40 rpms/4 ft-lbs, PUW 75K, SOW 75K, ROT W 80K. Drill up cmt & ES cementer from 2080' to 2098', 400 gpm/615 psi, 40rpms/4.4Kft-lbs, WOB 5-12K. Work through multiple times with pumps/rotary and no pumps/rotary - clean. CBU and Blow down Top Drive.;Continue to Single in 8.5" mtr cleanout assy on 5", 19.5# NC50 drill pipe F/ 2100 to 3904'. PUW 125K, SOW 85K, (Picked up 110 jts total).;RIH W/ elevators F/ Derrick F/ 3,094' to 5,174' MD P/U 150K, SLK 62K.;Circ and cond mud CBU 2X Rot & Rao F/ 5,174'to 5,110' MD. Stage pumps up to 400 GPM, 615 PSI, 25 RPM, TRQ 4.5K. Mud weight in and out 9.0 ppg.;PJSM R/U test Equip. MIU TIW and Head Pin. Test 9 5/&'40# L-80 to 2,500 PSI for 30 min on chart. 3.56 bbls pumped, bled back 3.4 bbls. R/D lest Equip. Blow down Choke Manifold and Iines.;PJSM Wash down F/ 5,074' to TOC at 5,201' MD . Drill cement and shoe track at 400 GPM, 600 PSI, 40 RPM, TRQ 12K, WOB 5- 12K, F/O 50%. Baffle, FC and Shoe on depth. PIU 158K, SLK 82K, ROT 112K.;Drill 8.5" hole F/ 5,364' to 5,384'MD 400 GPM, 600 PSI, 40 RPM, TRQ 13.5K, WOB 5-6K, F/O 50%. P/U 158K, SLK 82K, ROT 112K.;PJSM Rot & Rec F/ 5,384' to 5,333' MD. Displace F/ 9.0 ppg Spud Mud to 8.9 ppg BariDril-N. Pump 8.9 ppg 40 bbl 135 Vls Spacer chased W/ 387 bbls BariDril-N taking all return overboard. 8-10 bpm, 640 PSI, 40 RPM, TRQ 12K, F/O 50%.;PJSM UD Working single. Check weights in and out 8.9 ppg. Monitor well for 10 Min, static. R/U lest Equip. Press. up to 668 PSI 2.23 bbls bled back 1.7 bbls. FIT 12.25 EMW.;Daily hauled 342 bbls to G&I total = 6,730 bbls Hauled 0 bbls H2O from A-Pad reserve total = 0 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5,790 bbls Lost 0 bbls to formation Total fluid lost 66 bbls Total Metal 0 lb 9/2/2019 R/D test Equipment. UD single (in String) R/U Gyro Sheave, P/U M/U TIW and xo to Pollard Pump in sub, R/U Cement Hose to same. Stab Gyro tool and RIH to 4200'. Pump down from 4200'to 4925'. (Top of HWDP) Make multiple attempts to RIH past 4859 with no success.;POOH Logging Gyro Surveys from 4846'. R/D Gyro and Pollard E-Line equipment.;P/U single, Monitor well, pump slug and TOH from 5324' to 3280'. P/U 150K, SLK 62K. Calc Disp 13.4 bbls, actual 15.3 bbls. Lost 1.9 bbls.;PJSM Service rig. Grease Crown Sheaves, Bloaks, Iron Roughneck and Drawworks. C/O battery on frame extend sensor. Monitor well on TT, no Iosses.;Cont. POOH on elevators F13,331' to 405' MD. P/U 85K, SLK 47K. Calc Disp 44.6 bbls, actual 52.9 bbls, lost 8.3 bbls. Pulled through ES without issue.;PJSM UD 8 Jnts 5" HWDP and 6 3/4" StrataForce Mud Motor W/ 8.5" Smith XR-PS Tri Cone Bit. Bit was grade a 1-1-NO-A-E-1-NO BHA.;PJSM Clean and clear rig floor. Stage BHA 3 components on rig floor. Load shed W/ 6 3/4" BHA components.;PJSM P/U M/U BHA #3 8.5" NOV SKS616M-Ji D PDC, 8.5" NOV NRP, Geo Pilot 7600 140C 18KSI, 6.75" ADR/HCIM Collar, 6.75" DM Collar, 8.5" ILS, 6.75" DGR Collar, 6.75" PWD Collar, 6.75" ALD Collar, 8.5" I.S.I6.75" CTN Collar & 6.75" TM Collar to 118' MD. Download MWD tools at rig floor.;Swapped to GEN power at 21:40 due to Operations turbine issues.; PJSM Finish down loading MWD tools. P/U M/U 6 3/4" Float Sub and lea 6.75" NM FC. Shallow hole test MWD tools. Load nuclear source. Cont P/U 1 ea 6.75" NM FC, 6 314" Float Sub, 2 as 5" HWDP, 6.75" SLB Jars and lea 5" HWDP total 310' MD. P/U 52K, SLK 53K;PJSM Single in hole BHA 93 W 5" D.P. F/ Pipe Shed F/ 310'to 3,000' MD. Break in seals on Geo Pilot at 2,537' MD. (10, 20, 30, 40, 50 RPM) Send down links, good. Rabbit from Skate (3.125"). Filling every 2,500'. P/U 110K, SLK 82K. No Iosses.;Daily hauled 585 bbls to G&I total= 7,315 bbls Hauled 260 bbls H2O from A-Pad reserve total = 260 bbls Hauled 0 bbls H2O from B-Pad Creek total = 5,790 bbls Lost 0 bbls to formation Total fluid lost 66 bbls Total Metal 0 Ib 9/3/2019 Continue to Single in hole with 5" DP from 3000' to 5234'. Fill pipe every 2500', Drift w/3.125, PUW 149K, SOW 82K.;PJSM, Hang Blocks. Cut 62'-10 Waps, 2890' left on Drum. Check Brakes-All with in Spec. Rig back on Hi Line Power @ 09:OO.;PJSM, Grease Crown, Blocks, Top Drive, Wash pipe, IBOP and Drawworks, Check Oil in top drive, level good.;PJSM w/ Beyond and Crew. Remove riser, stab and install RCD Bearing onto Double. M/U and Install into RCD Head. Line up and pump 2 bpm check for leaks. All good.;Continue to single in hole from 5234', Set Dn 10K @ 5334'.;Wash down f/5334' to 5384'. 500 gm/1300 psi, PU 152K, $O, 75K, Rot 105K.;Ddll 8-1/2" hole from 5384' to 5942', total 558' (AROP 112 fph); 500 gpm/1300 psi, WOB 7-10K, 120 rpms/13Kft- Ibs. Max gas 2,216 units, ECD's 10.12 ppg EMW with 8.95 ppg mud. PUW 145K, SOW 74K, ROTW 100K.;Drill 8-1/2" hole from 5942' to 6800', total 858' (AROP 143 fph); 500 gpm/1360 psi, WOB 6-10K, 130 rpms/14Kft-lbs on bottom 14.5K-ft-lbs Off. Max gas 2,153 units, ECD's 10.22 ppg EMW with 9.0 ppg mud. PUW 150K, SOW 67K, ROTW 100K.;Drill 8-1/2" hole from 6800' to 7500', total 700' (AROP 117 fph); 540 gpm/1580 psi, WOB 6-12K, 135 rpms/16.5Kft-lbs on bottom 16K-ft-lbs Off. Max gas 2,333 units, ECD's 10.0 ppg EMW with 9.0 ppg mud. PUW 165K, SOW 64K, ROTW 98K.;No faults have been crossed so far this lateral. 13 concretions have been drilled so far for a total footage of 25' (1.2% of the lateral). Distance to WP07 25.57', 24.9' high, 5.83' right.; Daily hauled 519 bbls to G&I total = 7,834 bbls Hauled 130 bbls H2O from A-Pad reserve total = 650 bbls Hauled 130 bbls H2O from B-Pad Creek total = 5,920 bbls 9/4/2019 Lost 0 bbls to formation Total fluid lost production section = 0 blols Drill 8-1/2" hole from 7500'to 8264' MD (367T TVD), total 764' (AROP 127 fph); 540 gpm/1600 psi, WOB 6-16K, 130 rpms/18.51(ft-lbs on bottom 18.5K-ft-lbs Off. Max gas 2,270 units, ECD's 10.4 ppg EMW with 9.0 ppg mud. PUW 195K, SOW 48K, ROTW 99K.;Drill 8-1/2" hole from 8264' to 8964' MD, total 700' (AROP 117 fph); 540 gpm/1666 psi, WOB 9-12K, 125 rpmsJ19.SKft-lbs on bottom 19.5K-ft-lbs Off. Max gas 2,171 units, ECD's 10.56 ppg EMW with 9.0 ppg mud. PUW 192K, SOW 49K, ROTW 97K. Begin dropping angle at 8310' to lower MB sands in;anticipation of fault at 8562'. No fault observed by 8750'; increase angle to re-acquire target sand within MS.;Drill 8-1/2" hole from 8964'to 9787' MD, total 82T (AROP 149 fph); 540 gpm/1860 psi, WOB 5-7K, 140 rpms/18Kft-lbs on bottom 18.5K-ft-lbs Off. Max gas 2,559 units, ECD's 11.1 ppg EMW with 9.0 ppg mud. PUW 178K, ROTW 97K. Lost slack off weight at 9155'. Observe better quality sands from 8930';to 9000', suspect fault at 8920'. Begin dropping angle to re-acquire. Target sands not acquired and exited MB sands and entered MD sands at 9648' exhibited by gamma spike.;Pumped tandem low vis/wt, high vis/wt sweep at 9780', continue circulating sweep out of hole 540 gpm/1860 psi, 140 rpms/18.5Kft-lbs. 10% increase in cuttings, 40bbls late. Monitor well through MPD, 11 psi increase in 5 minutes continually decreasing after opening and closing choke, no flow - static;Attempt to POOH from 9727'to 9700', observe hole swabbing. BROOH from 9700' to 8073'. 540 gpm/1690 psi, 100 rpms/16Kft-lbs. PUW 176K, SOW 64K, ROTW 101 K.;Sidetrack wall bore at 8073' to 8116; 540 gpm/1580psi, 120 rpms/l6Kft-lbs, WOB 2-5K. Initial TF 158° drilling 30 fph. Gain 0.5" separation by 8079' increase ROP to 60fph while rolling TF to the right. Max Gas 387U, ECD 10.5 ppg. PUW 176K, SOW 64K, ROTW 100K.;32 concretions have been drilled so far for a total footage of 88' (2.0% of the lateral). 1 sidetrack (PB from 8073' to 978T) Distance to WP07: 95, 9.63' High, 0.28' Right;Daily hauled 684 bbls to G&I total = 8,518 bbls Hauled 0 bbls H2O from A-Pad reserve total = 650 bbls Hauled 780 bbls H2O from B-Pad Creek total = 6,700 bbls Lost 0 bbls to formation Total fluid lost production section = 0 bbls 9/5/2019 Drill 8-1/2" hole from 8116' to 8773' MD, total 657' (AROP 110 fph); 540 gpm/1710 psi, WOB 6-14K, 145 rpms/19Kft-lbs on bottom 18.SK-ft-lbs Off. Max gas 2,424 units, ECD's 10.6 ppg EMW with 9.2 ppg mud. PUW 181 K, SOW 48K, ROTW 97K.;Drill 8-1/2" hole from 8773' to 9473' MD, total 700' (AROP 117 fph); 540 gpm/1845 psi, WOB 6-11 K, 120 rpms/19.5Kft-lbs on bottom 20K -ft -lbs Off. Max gas 1,815 units, ECD's 11.1 ppg EMW with 9.2 ppg mud. PUW 178K, SOW 48K, ROTW 92K.;Drill 6-112" hole from 9473'to 10,234' MD, total 761' (AROP 127 fph); 540 gpm/1960 psi, WOB 6-14K, 120 rpms/l7Kft-lbs on bottom 18.5K -ft -lbs Off. Attempt to incr rotary, lose MWD detection above 120 rpms. Max gas 1,784 units, ECD's 11.1 ppg EMW with 9.3 ppg mud. PUW 185K, ROTW 92K. Lost SOW 9473'.;Drill 8-1/2" hole from 10,234' to 10,580' MD, total 346' (AROP 115 fph); 540 gpm/1920 psi, WOB 6-14K, 140 rpms/17.50-lbs on bottom 17K -ft -lbs Off. Max gas 2,125 units, ECD's 112 ppg EMW with 9.3 ppg mud. PUW 165K, ROTW 92K. Crossed fault at 10,524 placing the bit into a wet sand.;CBU, while building sweep. Pump tandem low vis/wt, high vis/wt 10% increase in cuttings on time. 540 gpm/1920 psi, 140 rpms/16Kft-lbs, reciprocating pipe and racking back from 10,553 to 10,425'. Discussed options with town.;Continue drilling 8-1/2" hole to log sands from 10,580' to 10,614' MD, total 34' (AROP 68 fph); 540 gpm/1880 psi, 140 rpms/16.5Kft-Ibs on bottom 17K -ft -lbs Off, WOB 6-12K. Max gas 137 units, ECD's 11.1 ppg EMW wfth 9.3 ppg mud. PUW 159K, SOW 49K, ROTW 91 K.;38 concretions have been drilled so far this lateral for a total length of 106'(2.0%) of the lateral. Distance to WP#07 21.15', 21.03' high, 2.26' Left.;Daily hauled 570 bbis to G&I total = 9,088 bbis Hauled 0 bbls H2O from A -Pad reserve total = 650 bbis Hauled 260 bbis H2O from B -Pad Creek total = 6,960 bbis 9/6/2019 Lost 0 bbis to formation Total fluid lost productign section = 0 bbl Monitor well through MPD choke, static. BROOH from 10,614' to 9980' at 540 9pm/1910 psi, 140 rpms/150-Ibs. ECD 10.9 ppg EMW with 9.25 ppg mud. PUW 153K, SOW N/A, ROTW 92K.;Wash and ream from 9980' to 10,614' at 540 gpm/1790 psi, 55 rpms/13Kft-lbs. PUW 151 K, SOW N/A, ROTW 95K.;Cominue drilling 8-1/2" hole to log ILD' sands from 10,614'to 10,820', total 206' (AROP 103fph) at 540 gpm12000 psi, 140 rpms/17.50-Ibs on, I6.5Kft- Ibs oft. WOB 11-14K. ECD 11.29 psg EMW. PUW 146K, SOW N/A, ROTW 91 K.;Continue drilling 8-1/2" hole to log'LD' sands from 10,820' to 11,377', total 557' (AROP 111fph) at 540 gpm/2050 psi, 140 rpms/19Kft-lbs on, 18.51(ft-Ibs off. W084 -6K. ECD 11.43 psg EMW with 9.2 ppg mud. PUW 148K, SOW N/A, ROTW 95K.;Circulate hole clean 1.5x BU at 540 gpm/1580 psi, 120 rpms/19Kft-lbs reciprocating pipe. Obtain SPR's. Monitor well through MPD choke, static.;BROOH from 11,37T to 9409' at 540 gpm/1880 psi, 140 rpms/l8.5Kft-lbs. PUW 145K, SOW 50K, ROTW 96K.;Cont. to BROOH from 9409' to 7500' at 540 gpm/1785 psi, 140 rpms/15.5Kft-lbs. PUW 133K, SOW 68K, ROTW 98K. 15-30 fpm as hole dictates.; Distance to WP#07 113', 110.45' Low, 28.83' Left.; Daily hauled 513 bbls to G&I total = 9,601 bbls Hauled 0 bble H2O from A -Pad reserve total = 650 bbls Hauled 0 bbls H2O from B -Pad Creek total = 6,960 bbis Hauled 650 bbls from CFP Total hauled from CFP = 1170 9/7/2019 Lost 0 bbis to formation Total fluid lost Production section = 0 bbis Cont. to BROOH from 7500' to 5339' at 540 gpm/1585 psi, 140 rpms/12Kft-lbs. Max gas 152U, ECD 10.3 ppg. PUW 131 K, SOW 84K, ROTW 106K. 15-30 fpm as hole dictates.;Pump tandem to vis/wt, high vis/wt sweep 200% increase in cuttings.;PJSM. Open 2" drain on beyond RCD - no flow. Remove RCD bearing and install trip nipple.;Pump dry job, BD TO. POOH from 5339' to 310'. Observe calculated displacement on tripJJD 5" HWDP, jars and flex collars. Pull sources. Attempt to download MWD, unable to read ADR, ALD tools. IJD BHA. Bit grade 4 -3 -DL -C -X -I -BT -FM. Bit Sleeve was 1/8" under gauge. Significant wear on both stabilizers. The Blades on the ALD showed undercutting on the leading edge of the blades.;Service rig. Grease /inspect crown, blocks, top drive. Perform derrick inspection. Clean and clear rig floor.;Rig up Weatherford power tongs. Change out pipe handling equipment. RIH with float shoe and 2 joints of 4-1/2" 625W, 13.5ppf, L-80 liner to 84'. Check floats -good.; RIH with 4.5" 13.5 ppg 625W liner from 84' to 1069. M/U pup joint. BHKA disconnect and BHKA adapter. PUW 48K, SOW 48K.;R/D Weatherford power tongs. Change out pipe handling equipment.;M/U 1 stand drill pipe. Fill Liner and pump 10 extra bbis. RIH with liner on drill pipe from 1062' to 2525'. PUW 75K, SOW 71 K.; Daily hauled 285 bbls to G&I total= 9,886 bbls Hauled 0 bbis H2O from A -Pad reserve total = 650 bbls Hauled 0 bbls H2O from B -Pad Creek total = 6,960 bbis Hauled 390 bbls from CFP Total hauled from CFP = 1560 Lost 0 bbis to formation Total fluid lost production section = 0 bola 9/8/2019 Cont. to RIH with liner on drill pipe from 2525' to 5327'. Drifting drill pipe. PUW 15K, SOW 89K.;Circulate bottoms up, staging pumps up to 7 bpm/285 psi.;Cont. to RIH with liner on drill pipe from 5327' to 7298'. Drifting drill pipe. PUW 133K, SOW 89K.;Cont. to RIH with liner on drill pipe from 7298' to 10,668'. Drilling drill pipe. PUW 140K. Lost down wt at 10,688'. Establish circulation and wash liner down from 10,688 to 11,369'.;CBU x 2 reciprocating pipe. Stage pumps up to 7 bpm/480 psi. Prep for cement job, rig up cementers, build spacer. M/U head pin and cement hose. PUW 155K, SOW63K.;Cement as per detail. Halliburton flood lines and pump 5 bbls of water. PT lines 1000/4000 psi -good. Rig pump 30 bbls spacer at 5 bpm/480 psi. Halliburton mix and pump 92.5 bbis of 15.8 ppg cement at 4.7 bpm/628psi. Drop disconnect dart. Pump 5 bbis clean spacer followed by;168 bbls (171 calc.) 9.2 ppg drilling fluid at 4.75bpm/650 psi. Bump plug and pressure up to 2580, observe disconnect release. CIP at 23:44. No losses obsewed.;Pick up and observe 11 K drop in weight (PUW 144K). POOH from 10,304'to 9987' at 30 fpm.;Circulate and condition mud. Establish circulation at(i bpm/375 psi, 60 psi less than with liner prior to cementing. Drop drill pipe wiper ball and circulate bottoms up x 2 staging up toll bpm/742 psi. Observe slight cement contamination just prior to bottoms up.;Monitor well, static. Attempt to POOH on elevators from 9987', observe hole swabbing. Pump out of hole from 9987'to 8463' at 6 bpm/340 psi, pulling 100 fpm. POOH on elevators from 8463' to 8272'. PUW 156K, SOW 75K.;Daity hauled 57 bbis to G&I total= 9,886 bbls Hauled 0 bbls H2O from A -Pad reserve total = 650 bbis Hauled 0 bbis H2O from B -Pad Creek total = 6,960 bbis Hauled 0 bible from CFP Total hauled from CFP = 1560 Lost 0 bbls to formation Total fluid lost production section = 0 bbis 9/9/2019 POOH on elevators from 8272'to 5282'. PUW 145K, SOW 80K.;Circulate annular volume 12 bpm/495 psi. Pump dry job. Blow down top drive, install stripping rubber.;Cont. to POOH on elevators from 5282' to surface. Break out BHKA disconnect. Calc hole fill 70.2 bbls, actual 83.4.;Service rig: grease/inspect crown, blocks, top drive. Perform derrick inspection. Clean and clear rig floor.;Prep to PIU BHA. mobilize components to rig floor. Install hydraulic elevators.;M/U BHA 4, RSS driling assembly as per DD/MWD. Plug in and upload tools. Shallow pulse test - good. Install sources. PIU HWDP and drill collars to 310'.;RIH with drilling assembly to 5296', fill pipe every 2509. PUW 130K, SOW 75K. Calc displacement: 42.9 bbls, actual 40.8 bols.; Fill pipe and circulate annular volume breaking in Geo -Pilot 450 gpm/1075 psi. B/D top drive.;Slip and cut 62' of drilling line while monitoring well on trip tank. Check drawworks brake gaps (within spec). Conduct wobble test on crown sheave.;Pull trip riser. Install RCD bearing. Break circulation at 2 bpm and check for leaks - good.;RIH with RSS drilling assembly from 5296' to 8391'. Fill pipe at 6991'. Set down at 7460' with 30K, work through twice. PUW 150K lost down wt at 8391'.;Daily hauled 231 bbis to G&I total = 10,117 bola Hauled 0 bbls H2O from A -Pad reserve total = 650 bbls Hauled 0 bbis H2O from B -Pad Creek total = 6,960 bbis Hauled 260 bbls from CFP Total hauled from CFP = 1820 Lost 0 bbls to formation Total fluid lost Production section = 0 bbls 9/10/2019 Wash down from 8391' to 8800' at 50O gpm/1620 psi. PUW 154K, SOW 47K.;Sidetmok wellbore: Control drill at 30 fph from 8809to 8837' at 500 gpm/1580 psi, 120 rpms/17Kft-lbs on, 16.51(ft-lbs off. WOB BK. Max gas 60U. ECD 10.4 ppg EMW with 9.2 ppg drilling fluid. PUW 148K, SOW 56K, ROTW 98K.; Drill 8-1/2" hole from 883T to 9091', total 254' (AROP 85 fph) at 540 gpm/1875psi, 120 rpms/17Kft-Ibs on, 16.7Kft-Ibs off. WOB 8-12K. Max gas 1157U. ECD 10.8 ppg EMW with 9.2 ppg drilling fluid. PUW 144K, SOW 54K, ROTW 96K.;DHII 8-112" hole from 9091'to 9726', total 635' (AROP 106 fph) at 540 gpm/1990psi, 140 rpms/21 Kft-lbs on, 20Kft-Ibs off. WOB 12-15K. Max gas 2227U. ECD 10.94 ppg EMW with 9.2 ppg drilling fluid. PUW 165K, ROTW 98K. Lost SOW at 9599'. Observe slight losses 955U - 9650'; increase background.;LCM to 10.5 ppb with Baracarb 25; losses healed up.;Drill 8-1/2" hole from 9726' to 10,043', total 317' (AROP 53 fph) at 540 gpm/2025psi, 140 rpms/21.5Kft-lbs on, 21 Kft-Ibs off. WOB 14-16K. Max gas 1450U. ECD 10.95 ppg EMW with 9.2 ppg drilling fluid. PUW 178K, ROTW 97K.;Drill 8-1/2" hole from 10,043' to 10,425', total 382' (AROP 64 fph) at 540 gpm/2140psi, 140 rpms/21.5Kft-lbs on, 19.4Kft-lbs off. WOB 14-18K. Max gas 1617U. ECD 11.2 ppg EMW with 9.25 ppg drilling fluid. PUW 166K. ROTW 98K.;One fault has been crossed so far in the motherbore at 8920' 40 concretions have been drilled in the motherbore for a total footage of 147' (2.90/) of the lateral. 2 sidetracks: PBI - 8073'- 9787', PB2 8800' - 10304' (TOL) Distance from WP#11: 7.87', 2.73' Low, 7.39' RighTDaily hauled 342 bbls to G&I total = 10,459 bbis Hauled 0 bbis H2O from A -Pad reserve total = 650 bbis Hauled 0 bbis H2O from B -Pad Creek total = 6,960 bbis Hauled 520 bbls from CFP tanks Total = 2340 I 41 to fiorMatjQ0 Total fluid lost production �action = 41 blak 9/11/2019 ost bbIs Drill 6-1/2" hole from 10,425' to 10,807', total 382(AROP 64 fph) at 540 gpm/2180psi, 140 rpms/21 Kft-lbs on, 19.51<11-Ibs off. WOB 14-18K. Max gas 592u. ECD 11.4 ppg EMW with 9.25 ppg drilling fluid. PUW 188K, ROTW 95K. 52 bbl Io/hi vis nut plug sweep @ 10,577'(800 stk late / no inc).;Drill 8-1/2" hole dropping in section holding ^84° inclination from 10,807to 11,252', total 445' (AROP 74 fph) 475 gpm / 1775psi, 120 rpms/23Kft-lbs on, 23Kft-Ibs off. WOB 10-12K. Max gas 1575u. ECD 11.3 ppg EMW with 9.3 ppg drilling fluid. PUW 195K, ROTW 98K.;DNII ahead dropping in section to better determine stratigraphic location of wellbore as per geo. Drilled wet sand (MB) @ 10,843' MD / 3,810' TVD.;Drill 8-1/2" hole from 11,252' to 11,443', total 191' (AROP 32 fph) at 540 gpm/2160psi, 140 rpms/21 Kft-Ibs on, 22Kft-lbs off. WOB 18-22K. Max gas 830u. ECD 11.27ppg EMW with 9.3 ppg drilling fluid. PUW 195K, ROTW 95K. Vary parameters (pump rate, rpms) to attempt and increase ROP with no success.;Drill 8-1/2" hole from 11,443! to 11,470', total 37' (AROP 19 fph) at 540 gpm/2150psi, 140 rpms/22Kft-lbs on, 201(ft-Ibs off. WOB 14-24K. Max gas 85u. ECD 11.1 ppg EMW with 9.3 ppg drilling fluid. PUW 170K, ROTW 101 K.;Pump low vis/nut plug sweep at 11,443 and 11,470' just off bottom rotating to clean bit, no increase in ROP. TD called at 11,470'.;Build low vis sweep while circulating. Rack one stand back. Pump tandem low vis/wt and High vis/wt sweep (10% increase, 1000 strokes late) and circulate hole clean at 540 gpm/1950 psi, 140 rpms/16Kft-lbs. Obtain SPR's. Monitor well through MPD.;BROOH from 11,443' to 10,934' at 540 gpm/2023 psi, 140rpms/14Kft-Ibs 30-35 fpm. Max gas 60U. ECD 11.0 ppg. PUW 160K, SOW 60K, ROTW 101 K.;Two fault has been crossed so far in the motherbore at 8920', 10,654 40 concretions have been drilled in the motherbore for a total footage of 14T (2.4%) of the lateral. 2 sidetracks: PBI - 8073' - 9787', PB2 8800' - 10304' (TOL) Distance to WP#11 90.58', 89.12' low, 16.16' Right.;Daily hauled 399 bbis to G&I total = 10,858 bible Hauled 0 bbis H2O from A -Pad reserve total = 650 bbls Hauled 0 bbls H2O from B -Pad Creek total = 6,960 bbis Hauled 780 bbls from CFP tanks Total = 3120 Lost 17 bible to formation Total fluid lost production section = 58 bbis 9/12/2019 Continue BROOH F/ 10,934' - T/ 7882' MD. 540 gpm/1740 psi, 140rpmsfl OKft-lbs 30-40 fpm. Max gas 811 u. ECD 11.0 ppg. PIU 135K, S/O 68K, ROT 101 K.;Continue BROOH F/ 7882' - T/ 5335MD. 540 gpm/1750 psi, 140rpms/9.5Kft-Ibs 30-40 fpm. Max gas 240u. ECD 10.3 ppg. P/U 130K, S/O 80K, ROT 102K. Attempt to POOH on elevators at 5475', pulled tight. Slow rotary to 20 rpms to pull BHA through shoe.;Pump 45 bible high vis sweep (10% increase on time) at 540 gpmM650psi, 80 rpm/4100 ft -lbs. Monitor well, static.;Pull RCD bearing. Install trip nipple.;Attempt to POOH on elevators from 5335', observe swabbing. Pump out of hole to 516U while building low vis/nut plug sweep.; Pump 55 bbis low vis sweep with 20 ppb nut plug at 550 gpm/1570 psi, 100 rpmst4200 ft-Ibs.;Aftempt to POOH on elevators, observe swabbing. Pump out of hole to 4638' at 252 gpm. Continue to POOH on elevators from 4638' to 2537', calculated hole fill observed. PUW 121 K.;Cont. to POOH from 2537' to 310'. Calculated hole fill observed.;UD BHA. UD HWDP, jars and flex collars. Remove sources. UD flex collars, download MWD tools. Continue UD MWD tools. Bit grade 3-5-BT-A-X-I-CT-TD.;Service rig: grease inspect crown, blocks, top drive. SimOps: Clean and clear rig floor of BHA components. PIU handling equipment for 3-1/2" cement stinger. Remove hydraulic elevators.;Daily hauled 48 bible to G&I total = 10,906 bbis Hauled 0 bbis H2O from A -Pad reserve total = 650 bbis Hauled 0 bbis H2O from B -Pad Creek total = 6,960 bbis Hauled 390 bbis from CFP tanks Total = 3510 9113/2019 Lost 0 bbis to formation Total fluid lost production section = 58 bbls Clean and clear rig floor. Remove BHA 4 components from floor. C/O handling equipment to 3.5".;M/U wear bushing running tool on jt 5" dp. RIH and "J" in retrieval tool. BOLDS and pull wear bushing. UD and B/O same.;PJSM, M/U 3.5" cement diffuser shoe and RIH w! 3.5" EUE, 8rd, L-80 tubing to 994' (32 total its including shoe it). M/U 3.5" x NC50 crossover (Total BHA length 995.38'). Drift while picking up w/ 2.867". Sym Ops - begin rigging down Can Rig Mudloggers, MPD equipment. Released onsite Geos.;RIH w/ 3.5" cement stinger easy on 5" NC50, S-135,19.5# drill pipe F/ 995 - T/ 4175' MD. 98k up, 90k dn.;Continue RIH w/ 3.5" cement stinger assy on 5" NC50, 5-135, 19.5# drill pipe F/ 4175 - T/ tag depth 11,470' MD. 4k set do and counted stands to verify depth (good). 149k up, 71k dn. Trip went well with no issues passing sidetrack pts. Calculated displacement for trip.;UD top single of std #165. M/U 10' w/ 5' pup on top. Install side entry w/ TIW. M/U swings w/ double block valves and connect cmt lines. Break circulation and stage up while reciprocating pipe to 10 bpm, 1330 psi. 141 k up, 72k dn. No losses observed while circ. No gas observed @ btms up.;PJSM. Flood lines with 5 bbis H2O. PT lines 1100 psi/4000 psi - good. Rig pump 25 bbis 11.5 ppg Clean Spacer at 3 bpm/235 psi, HES pump 61.5 bbis of 15.8 ppg Class G cement at 4 bpm/750 psi, 7 bbis spacer at 5.5 bpm/460 psi. Rig pumped 123 bbis drilling fluid at 7 bpm/950 psi, placing 5.8 bbls;cement on backside. Pump out of hole laying in cement with 40% excess at 3.5 bpm/300 psi pulling 35 fpm from 11.470' to 10,842'. PUW 154K, SOW 80K. Continue pumping over -displacing at 4 bpm pulling 25 fpm to 10,550'. Estimated TOC 10842'. CIP at 22:35. No Iosses.;Circulate hole clean staging pumps up to 13 bpm/1050 psi reciprocating pipe. Observe spacer and trace cement at bottoms up. PUW 141K, SOW 81 K.;Wash down from 10,550'to 10820' at 3bpm/ 248 psi. PUW 150K, SOW 70K. Rig upside entry sub, TIW and cement Iine.;Break circulation Rig pump 37 bible 11.5 ppg Clean Spacer at 3 bpm/170 psi, HES pump 61.5 bbis of 15.8 ppg Class G cement at 5 bpm/950 psi, 7 bible spacer at 4 bpm/150 psi. Rig pumped 113 bbis drilling fluid at 8 bpm/1150 psi, placing 5.8 bbis cement on backside.;Pump out of hole laying in cement with 40% excess at 3.5 bpm/275 psi pulling 35 fpm from 10,820' to 10,220'. PUW 151 K, Continue pumping over -displacing at 4.5 bpm pulling 30fpm to 9934'. Estimated TOC 10220'. CIP at 05:15. No losses.; Daily hauled 129 bbis to G&I total= 10,906 bbis Hauled 0 bbis H2O from A -Pad reserve total = 650 bbls Hauled 0 bbis H2O from B -Pad Creek total = 6,960 bbis Hauled 130 bbis from CFP tanks Total = 3640 Lost 0 bbis to formation Total fluid lost production section = 58 bbis 9/14/2019 Continue circulating and condition mud @ 9934' to 9871' reciprocating pipe. 12.8 bpm, 1175 psi, 53% F/O. 136k up, 81k on. Saw spacer and trace of cmt @ btms up. Overboard 130 bbls contaminated mud. Circulate a total of 2x btms up. Shut do and monitor well (static).;PJSM, POOH 5 stds wet (no swabbing) F/ 9934' - T/ 9616' MD. Pump dry job, install stripping rubbers and blow down TDS. Continue trip out F/ 9616- T/ 5226' MD w/ no issues. Hole took proper displacement. 126k up, 96k dn.;M/U upper test plug on working single. Tq plug to string (21k tq). Drain stack, RIH and landout upper test plug on depth (22.95') w/ 61 k string wt hanging in wellhead. B/O and UD working single. R/U BOP test equipment Test BOPE's 250/3000 psi on 5" and 3.5" test joints. AOGCC right to witness waived by Jeff Jones. No failures. Accumulator draw down: initial 3100 psi, final 1550 psi. First 200 psi recharge 22 secs, full recharge 83 secs. 6 N2 bottles with ay. 2366 psi. Test gas alarms, PVT systems, flow.;Rig down test tools, breakdown test joint. Slowdown TD, kill and choke lines. RIH with working single and makeup to test joint. Pull test plug with string, PUW 126K. Breakout test joint.;Service rig: grease/inspect crown, spinners, TO, draw works.;RIH from 5226'to 9909. Wash down from 9909to 10,234' at 2 bpm/150 psi. Tag hard cement at 10,234'x 2 with 10K.;PJSM on displacement, prep for displacement, clean suction screens while CBU 8bpm/328 psi. Pump chem train (3) SAPP pills followed by 25 bbls LB each and displace to 9.1 ppg lubricated brine at initially 81opm/330 psi slowing to 5.5 bpm/230 psi to maintain volume in pits.;Go to closed loop system and continue circulating additional bottoms up 10 bpm/440 psi slowing to 5 bpm/210psi as shakers can handle. Obtain three passing PST tests - one at possum belly, two under shakers.;Daily hauled 464 bbls to G&I total = 11,370 bbls Hauled 0 bbls H2O from A -Pad reserve total = 650 bbls Hauled 0 bbls H2O from B -Pad Creek total = 6,960 bbls Hauled 0 bbls from CFP tanks Total = 3640 Lost 0 bbls to formation Total fluid lost production section = 58 bbls 9/15/2019 Continue circulating and conditioning lubricated brine while rot/recip pipe. 6k tq 12-3 rpm, Reduce rate from 10 bpm to 5 bpm due to screens blinding off. 122k up, 91 k dn, 407 psi. Obtain SPR's, Monitor well (static).;POOH racking back in derrick F/ 10220'- T/ 9646 MD. 137k up, 81 k dn.;PJSM, UD excess 5" dp F/ 9648' - T/ 4558' MD. 106k up, 98k dn.;Continue UD 5" dp F/ 4558' - T/ 995' MD. C/O handling equipment to 3.5". POOH to surface. UD 32 jts of 3.5" EUE 8rd cement stinger. 7 bbls total loss for trip out.;Clean and clear rig floor. Prep and organize completion jewelry in pipe shed as per tally.;Service traveling equipment, drawworks, IR. Inspect TDS.; Pickup Weatherford 4.5" pipe handling equipment, rig up power tongs, elevators. Complete liner running checklist. Install wear bushing. Build safety joint.;PJSM Run 4.5" lower completion: Pickup float shoe/WIV, JNT/Packoff. RIH with 4.5" 13.5# LBO 625W completion J tti as per tally to 4569'. TO connections to 9600 ft -lbs. Calculated displacement observed. PUW 91K, SOW 71 K.;Clean and clear rig floor. C/O pipe handling equipment for 2-3/8" PH6. C/O power tong dies. Install false table. M!U safety joint.;Pick up slick joint with ball seat. Pick up drift and RIH with 2-3/8" PH6 §, inner string as per tally to 892'.;Daily hauled 1321 bbls to G&I total = 12,691 bbls v 47 Hauled 0 bbls H2O from A -Pad reserve total = 650 bbls Hauled 0 bbls H2O from B -Pad Creek total = 6,960 bbls Hauled 0 bbis from CFP tanks Total = 3640 Lost 0 blobs to formation Total fluid lost production section = 58 bbls 9/16/2019 Continue pick up 2-3/8" PH6 inner string F/ 892' - T/ 4548' MD 1.66" drift, 3.1 k tq on connections. Proper displacement for trip. 57k up, 47k dn. Sent post 9- 14-19 BOP test report to AOGCC @ 7:12 am.;No go out @ 4548' on depth wl 10k 2x to verify tag. Spaceout - UD jts 146 & 147. M/U xo, 2.1', 4.07', 4.16', 6.08', 12.12' pups, swivel and liner hanger assy as per BOT rep w/ total length of 4.5" liner assy 4595.69' MD.;C/O handling equipment. R/D Weatherford power tongs and equipment. Verify pipe count in derrick (83 stds of 5" DP). Obtain parameters - 113k up, 97k do w/ both 4.5" and inner string. rpms/tq = 10/3.5k, 20/3.6k tq, 30/3.8k tq. 1.5bpm/265 psi, 3bpm/580psi, 4bpm/900psi.;RIH w/ 4.5" lower completion on 5" drill pipe out of derrick F/ 4569 - T/ 9800' w/ 4.5" 625 Wedge, 13.5#, L-80 liner. Work pipe down to 9822' and pickup to 9800'. PUW 143K, SOW 69K.;Circulate drill string volume at 4 bpm11050 psi. PUW 143K, SOW 69K.;Drop 1-1/8" OD Phenolic ball and pump down, at 93 bbls (106 bbls drill string volume) observe 150 psi increase, but still circulating. Attempt to get ball on seat, from 2 - 5.5 bpm, with and without rotation. Attempt to work pipe while pumping. Pump 3 x drill string volume, with no other pressure.;increase. Discuss options with town. Shut rams and pressure up on backside to 140 psi to ensure float shoe holding. Drop 1.5" OD back up ball and pump down, land on ball seat on 2-3/8" slick stick. Pressure up to set packer at 2650 psi and neutralize at 4100 psi, good indication.;Slack off to block wt. Pick up and observe travel at 133K (10K less than with liner - pipe full). Shut UPR's and PT packer to 1500 psi for 10 minutes - good. Pick up to expose packoff in liner running tool. Pressure up to 4950 psi to shear out ball seat shear disk. PUW 127K with disk sheared.;TOL 5204.31'.;Blow down choke and kill lines. Monitor well, static. POOH laying down 10 joints to 9440' with calculated hole fill.; Kuukpik Drilling turnover to Parker Drilling for labor contract on Innovation rig at OO:OO.;Well swapped to completion AFE at OO:OO.;Daily hauled 114 bbls to G&I total= 12,805 bbls Hauled 0 blols H2O from A -Pad reserve total = 650 bbls Hauled 0 bbls H2O from B -Pad Creek total = 6,960 bbls Hauled 260 bbls from CFP tanks Total = 3900 Lost 0 bbls to formation Total fluid lost production section = 58 bbls U Well Name: MP S-203 Field: Milne Point County/State: (LAT/LONG): avation (RKB): API #: Hilcorp Energy Company Composite Report Spud Date: Job Name: 1914120C MPU S-203 Completion Contractor AFE #: AFE $' 45 bpm/1900 5-10fpm 9116/2019 POOH laying down drill pipe from 9440' to 5242'; PUW off bottom 126K. Establish circulation and wash through liner top at psi pulling from 5228' to 5178'. Continue to POOH to 5115' Cut and slip88' of drill line. 9/17/2019 Continue cut and slip drilling line (88'). Calibrate block position.,POOH laying down 5" dp F/ 5115'- T/ 4600' MD. 58k up/ 58k dn.,PJSM, C/O handling equipment from 5" to 2-3/8". M/U 5" safety jt w/ xo to PHS and stage in pipeshed. R/U Weatherford casing equipment w/ double stack power tongs. UD Baker LRT. Cont trip outlaying down 2-318" PH6 drill pipe from 4600' to 3697' MD. 50k up/dn.,Continue laying down remaining 2-3/8" PH6 inner string F/ 3697' to surface. BIO and UD circ sub, ball seat and slick stick assy. Clean and clear rig floor. RID Weatherford power tongs and all 2-3/8" handling equipment., Remove wear bushing. Set test plug C/O upper pipe rams VBR's to 7-518" fixed body. Button up ram doors and rig up to test top rams wl7-5/8" test jt. 250/3000 w/ 5 min hold on each. Chart and record same. Sym ops - Load and process 7-518" tieback string in shed., PJSM R/U Weatherford Power (, r t' Tongs and 7.625" handling Equip. Service Skate. Complete casing checklist.,PJSM P/U 7.375" Tie Back Assy M/U to 7.626'29.7#. W521 inner string. RIH I� to 1,992' MD. TRQ turn to 10.1 K. P/U 73K, SLK 70K. Calc disp 23 bible, actual 14 bible. Lost 9 bbls.,PJSM RIH 7.625" 29.7#, W521 inner string F/ 1,992' to 5,200' MD. TRQ tum to 10.1 K. P/U 150K, SLK 111 K. Tag NoGo 2X W/ 10K. Visually observed seals engage W/ 3K drag up and down. Lay down joint 130. Did not need any pups. TOL at 5200.63'. NoGo is 2.03' off. Mule Shoe at 5208.21' MD. 7.58' swallowed of seals.,P/U WU Hanger and landing joint. Land as per NOS on sight. Calc. disp 58.5 bbls, actual 38.7 bbls. Lost 19.8 bbls.,PJSM R/U to reverse circ. Close Annular and press up 9 5/8" X 7 5/8" to 500 PSI hold for 15 min. Bled down Press to 300 PSI and pulled up 6' and visually saw Press drop to expose holes on tie back. 911 812 01 9 PJSM Disolace out lubricated br ne On 7-5/9'x 9-5/8" annul d 7-518" canileb to 9.1 filtered brine_ 7 bpm, 350 psi w/ total displacement of 350 bbls-Reduce annular psi to 600. Shut annular and lineup to reverse circulate. Freeze protect 7-5/8!'x 9-5/8" annulus w/ 56 bbls Cl 9.1 ppg brine, followed by 49 bbls diesel @ 4 bpm, 225 psi ICP, 440 psi FCP. Strip down and landout hanger on depth with seals 2' off "No Go". Landout w/ 76k string wt on hanger.,B/O and UD landing it. M/U packoff on running tool and landout same on depth. Verify land depth w/ lockdown. RILDS and test hanger void 250/3000 w/ 15 min on high (test good). Pressure test CIA to 1000 psi w/ 30 min. 1.4 bbls pumped/ 1.4 bbls bled back. Test good., PJSM, Shut blind rams, lockout koomey and bleed off same. C/O upper rams from 7-518" casing rams to 2-7/8" x 5.5" VBR's. Inspect and seal up stack. Recharge system wl no issues noted. R/U BOP test equipment wl 3.5" test jt. Flood system and test upper rams 250/3000 wl 5 min hold on each. Chart and record same. R/D and ^ �,r B/D test equipment.,PJSM R/U Weatherford 3.5" tools and Equip. Load rig floor of Cannon Clamps. RIU SLB Sheave and spooler. Load shed W/ 3.5" �L,• completion jewelry., PJSM PIU M/U Muleshoe cut joint W/ locator at collar, XN Nipple 2.75" ID, 47D2 FHL Packer Assy, X Nipple 2.813" ID, SLB Gauge %kv Mandrel, 3.5" CMD Sliding sleeve assy and 3.5" 9.3# L-80 EUE 8rd Tubing to 3,766 MD W/ Gauge control line and Cannon Clamps per tally.. PIU 63K, SLK 55K. TRQ to 3.2K.,Test Gauge Mandrel to 5,000 PSI and conductivity every 1,000' as per SLB onsite.,PJSM Cont. RIH 3.5" Tubing as per tally and Gauge control line F/ 3,766' to 5,260' MD. P/U 71 K, SLK 58K. P/U to kick out Jnts was hung up on 3.5" NoGo to bottom of Tie Back Seal Assy. Worked W/ 10K over pull and started pumping at 6 bpm, 320 PSI to get free. UD Jnts 167 & 166. Add 1 ea 10.12' Pup for space out.,P/U WU Hanger and 5" D.P. landing Jnt. Terminate Gauge Line through Hanger. Land Hanger as per NOS. Set depth 5,239.10' MD W/ 15.82' swallow in 4.5" Liner. RILDS. Ran 81 Cannon Clamps, 2 single clamps & 2 stand off clamps. 9/19/2019 PJSM Reverse Circ 85 bbls Diesel FP down 7 5/8" X 3.5" annulus at 4 bpm, 250 PSI, FCP 670 PSI. Flush lines with 10 bbis 9.1 ppg Brine.,Drop 1.5" Stabilizer arm and 1.312" ball rod down 3.5" tubing. Staged pumps up to 5 bpm, 890 PSI. Pumped away 23.2 bbls. Cycled pumps to seat ball and rod up to 6 bpm. Ball on seat. Stage up pumps 3/4 bpm to 1,500 PSI Packer set at 2,000 PSI. Cont to Press up to 3,500 PSI and hold for 30 min, bleed off tubing to 2000 psi Press test 7 5/6'X 3.5" annulus W/ Packer to 3,500 PSI for 30 min all charted. SIMOPS SLB and Weatherford Equip.,NOS set BPV. Flush BOPE lines and Top Drive W/ H2O. Blow down all lines. Pull Mouse Hole.,PJSM Drain BOPE. Disconnect Choke and Kill Line. Disconnect Beyond hard lines. Remove ` Drip Pan. Pull riser to rig floor. Set BOPE on pedestal and secure. Remove 13 5/8" X 11" DSA. SIMOPS Clean Pits. Inspect Mud Pumps.,PJSM NIL Tree as per NOS. Test Void to 5,000 PSI. SLB terminate and test guage line. Top Gauge 911124, BHP 1,768.34 PSI, 71.41' F, Bottom Gauge #11125, BHP 1,773.78 PSI, 71.48° F.,Test Tree to 500 PSI low 5 min and 5,000 PSI high for 15 Min, good. Swap out TNC and set BPV. Secure Tree and clean cellar.,PJSM Bridle up and scope down Derrick. P/U 157K, SLK 126K. SIMOPS blow down H2O.,PJSM Prep for rig move. Pull Cutting Box, secure cellar, blow down H2O and Steam lines, Prep roofs and all Mods for truck. Rig released @ 00:00 to MPU K-44. Hilcorp Milne Point M Pt S Pad MPU S-203 500292364400 Alaska, LLC Sperry Drilling Definitive Survey Report 16 September, 2019 HALLIBURTON Sperry Drilling Company: Hilcorp Alaska, LLC Project: Milne Point Site: M PIS Pad Well: MPU 5-203 Wellbore: MPU 5-203 Design: MPU 5-203 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU 5-203 MPU 5-203 Actual RKB @ 63.40usft MPU 5-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU 5-203 Well Position +NI -S +E/ -W Position Uncertainty Wellbore MPU 5-203 Magnetics Model Name 0.00 usft Northing: 5,999,892.50 usfl 0.00 usft Easting: 565,507.81 usfl 0.00 usft Wellhead Elevation: usft Sample Date Declination (1) BGGM2018 9/612019 16.51 Design MPU 5-203 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +N/ -S (usft) (usft) 26.70 0.00 Latitude: 70° 24'36.560 N Longitude: 149° 27'59.733 W Ground Level: 36.70 usft Dip Angle Field Strength (`) (nT) 80.92 57,413.59642017 Tie On Depth: 8,777.46 +E/ -W Direction (usft) (I 0.00 270.04 Survey Program Date 9/13/2019 From TO (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 68.88 4,846.77 MPU 5-203PB1 SDI Gyro (MPU 5-203PI 2_Gyro-NS-CT_Drill pipe H037Ga: Continuous on wireline in drill pipe 09/02/2019 4,904.94 5,309.42 MPU S-203PB1 MWD+IFR2+MS+Sag(12_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 0812612019 5,405.95 8,014.58 MPU 5-203PB1 MWD+IFR2+MS+Sag (12_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 09/03/2019 8,073.00 8,777.46 MPU 5-203PB2 MWD+MS+Sag (3) (MPI 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 09/05/2019 8,800.00 11,413.74 MPU 5-203 MWD+IFR2+MS+Sag (4) (M 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 09/06/2019 Survey MD Inc Azi (usft) (') (1 26.70 0.00 0.00 88.88 0.55 81.39 96.58 0.49 80.28 100.00 0.48 79.04 110.00 0.44 74.05 120.00 0.45 70.91 130.00 0.46 75.26 140.00 0.47 78.77 150.00 0.48 76.25 160.00 0.47 81.08 9/162019 12:30:50PM Page 2 COMPASS 5000.15 Build 91 Map Map Vertical TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 26.70 -36.70 0.00 0.00 5,999,892.50 565,507.81 0.00 0.00 UNDEFINED 88.88 25.48 0.04 0.30 5,999,892.55 565,508.10 0.88 -0.30 2_Gyro-NS-CT_Drill pipe (1) 96.58 33.18 0.06 0.36 5,999,892.56 565,508.17 0.79 -0.35 2_Gyro-NS-CT_Drill pipe (1) 100.00 36.60 0.06 0.39 5,999,892.56 565,508.20 0.42 -0.39 2 Gyro-NS-CT_Drill pipe (1) 110.00 46.60 0.08 0.47 5,999,892.58 565,508.28 0.57 -0.47 2_Gyro-NS-CT_Drill pipe (1) 120.00 56.60 0.10 0.54 5,999,892.61 565,508.35 0.26 -0.54 2_Gyro-NS-CT Dnll pipe (1) 130.00 66.60 0.13 0.62 5,999,892.63 565,508.43 0.36 -0.62 2_Gyro-NS-CT_Drill pipe (1) 140.00 76.60 0.14 0.70 5,999,892.65 565,508.51 0.30 -0.70 2_Gyro-NS-CT_Drill pipe (1) 150.00 86.60 0.16 0.78 5,999,892.67 565,508.59 0.23 -0.78 2_Gyro-NS-CT_Drill pipe (1) 160.00 96.60 0.18 0.86 5,999,892.69 565,508.67 0.41 -0.86 2_Gyro-NS-CT_Drill pipe (1) 9/162019 12:30:50PM Page 2 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU S-203 Design: MPU 5-203 Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Survey Vertical Easting DLS Section (ft) ('1100') (ft) Survey Tool Name 565,508.75 0.58 -0.95 2_Gyro-NS-CT_Drill pipe (1) 565,508.85 0.50 -1.04 2_Gyro-NS-CT_Ddll pipe (1) Map MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing (usft) (°) (') (usft) (usft) (usft) (usft) (ft) 170.00 0.51 86.04 170.00 106.60 0.19 0.95 5,999,892.70 180.00 0.56 86.69 180.00 116.60 0.19 1.04 5,999,892.70 190.00 0.57 89.34 190.00 126.60 0.20 1.14 5,999,892.71 200.00 0.57 92.35 199.99 136.59 0.20 1.24 5,999,892.71 210.00 0.62 95.61 209.99 146.59 0.19 1.34 5,999,892.70 220.00 0.68 94.50 219.99 156.59 0.18 1.45 5,999,892.69 230.00 0.78 93.98 229.99 166.59 0.17 1.58 5,999,892.68 240.00 0.86 94.26 239.99 176.59 0.16 1.72 5,999,892.67 250.00 0.94 97.58 249.99 186.59 0.14 1.88 5,999,892.66 260.00 1A2 98.39 259.99 196.59 0.12 2.05 5,999,892.64 270.00 1.09 95.90 269.99 206.59 0.10 2.23 5,999,892.62 280.00 1.17 96.05 279.99 216.59 0.08 2.43 5,999,892.60 290.00 1.26 98.12 289.98 226.58 0.05 2.64 5,999,892.57 300.00 1.29 97.86 299.98 236.58 0.02 2.86 5,999,892.54 310.00 1.39 98.65 309.98 246.58 -0.02 3.09 5,999,892.51 320.00 1.62 102.87 319.97 256.57 -0.07 3.35 5,999,892.46 330.00 1.80 105.15 329.97 266.57 -0.14 3.64 5,999,892.39 340.00 1.92 105.56 339.96 276.56 -0.22 3.95 5,999,892.31 350.00 2.06 107.17 349.96 286.56 -0.32 4.28 5,999,892.22 360.00 2.26 108.85 359.95 296.55 -0.44 4.64 5,999,892.10 370.00 2.50 110.77 369.94 306.54 -0.58 5.03 5,999,891.96 380.00 2.69 114.01 379.93 316.53 -0.75 5.45 5,999,891.80 390.00 2.78 115.60 389.92 326.52 -0.95 5.88 5,999,891.60 400.00 3.00 113.75 399.91 336.51 -1.16 6.34 5,999,891.39 410.00 3.66 113.11 409.89 346.49 -1.39 6.88 5,999,891.17 420.00 4.33 113.73 419.87 356.47 -1.67 7.51 5,999,890.90 430.00 4.80 114.18 429.84 366.44 -1.99 8.24 5,999,890.58 440.00 5.28 114.21 439.80 376.40 -2.35 9.04 5,999,890.23 450.00 5.72 114.19 449.75 386.35 -2.75 9.92 5,999,889.84 460.00 6.04 114.72 459.70 396.30 -3.17 10.85 5,999,889.42 470.00 6.36 115.34 469.64 406.24 -3.63 11.83 5,999,888.98 480.00 6.68 115.56 479.58 416.18 -4.12 12.85 5,999,888.50 490.00 6.98 115.86 489.50 426.10 4.63 13.92 5,999,887.99 500.00 7.32 116.19 499.43 436.03 -5.18 15.04 5,999,887.45 510.00 7.65 116.71 509.34 445.94 -5.76 16.21 5,999,886.88 520.00 8.00 117.37 519.25 455.85 -6.38 17.42 5,999,886.28 530.00 8.41 117.90 529.15 465.75 -7.04 18.69 5,999,885.62 540.00 8.77 118.82 539.03 475.63 -7.75 20.00 5,999,884.93 550.00 9.18 119.74 548.91 485.51 -8.51 21.36 5,999,884.18 560.00 9.68 120.46 558.78 495.38 -9.33 22.78 5,999,883.37 Well MPU 5-203 MPU 5-203 Actual RKB @ 63.40usft MPU 5-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) ('1100') (ft) Survey Tool Name 565,508.75 0.58 -0.95 2_Gyro-NS-CT_Drill pipe (1) 565,508.85 0.50 -1.04 2_Gyro-NS-CT_Ddll pipe (1) 565,508.95 0.28 -1.14 2_Gyro-NS-CT_Drill pipe (1) 565,509.05 0.30 -1.24 2_Gyro-NS-CT_Drill pipe (1) 565,509.15 0.60 -1.34 2_Gyro-NS-CT_Dnll pipe (1) 565,509.26 0.61 -1.45 2_Gyro-NS-CT_Drill pipe (1) 565,509.39 1.00 -1.58 2_Gyro-NS-CT_Dnll pipe (1) 565,509.53 0.80 -1.72 2_Gyro-NS-CT_Dnll pipe (1) 565,509.69 0.95 -1.88 2_Gyro-NS-CT Drill pipe (1) 565,509.86 0.81 -2.05 2_Gyro-NS-CT_Drill pipe (1) 565,510.04 0.84 -2.23 2_Gyro-NS-CT_Dnll pipe (1) 565,510.24 0.80 -2.43 2_Gyro-NS-CT_Drill pipe (1) 565,510.45 1.00 -2.64 2_Gyro-NS-CT_Drill pipe (1) 565,510.67 0.31 -2.86 2_Gyro-NS-CT_Drill pipe (1) 565,510.90 1.02 -3.09 2 -Gyro -NS -CT Drill pipe (1) 565,511.16 2.55 -3.35 2_Gyro-NS-CT_Drill pipe (1) 565,511.45 1.92 -3.64 2_Gyro-NS-CT_Drill pipe (1) 565,511.76 1.21 -3.95 2_Gyro-NS-CT_Drill pipe (1) 565,512.10 1.51 4.28 2_Gyro-NS-CT_Drill pipe (1) 565,512.46 2.10 -4.64 2_Gym-NS-CT_Dnll pipe (1) 565,512.85 2.53 5.03 2_Gyro-NS-CT_0611 pipe (1) 565,513.27 2.40 -5.45 2_Gyro-NS-CT_Drili pipe (1) 565,513.70 1.18 -5.88 2_Gyre-NS-CT_Drill pipe (1) 565,514.16 2.39 -6.34 2_Gym-NS-CT_Drill pipe (1) 565,514.70 6.61 -6.88 2_Gyro-NS-CT_Drill pipe (1) 565,515.34 6.71 -7.52 2_Gyro-NS-CT_Dnll pipe (1) 565,516.07 4.71 -8.24 2_Gyro-NS-CT_Drill pipe (1) 565,516.87 4.80 -9.04 2_Gyra-NS-CT_DdII pipe (1) 565,517.75 4.40 -9.92 2_Gyro-NS-CT_Drill pipe (1) 565,518.69 3.25 -10.85 2_Gyro-NS-CT_Drill pipe (1) 565,519.67 3.27 -11.83 2_Gyro-NS-CT_Dnll pipe (1) 565,520.70 3.21 -12.86 2_Gyro-NS-CT_Dnll pipe (1) 565,521.77 3.02 -13.93 2_Gyro-NS-CT_Ddil pipe (1) 565,522.90 3.42 -15.05 2_Gyro-NS-CT Drill pipe (1) 565,524.07 3.37 -16.21 2_Gyro-NS-CT_Drill pipe (1) 565,525.29 3.61 -17.43 2_Gyro-NS-CT_Drill pipe (1) 565,526.56 4.17 -18.69 2_Gyro-NSCT_Drill pipe (1) 565,527.88 3.85 -20.01 2_Gyro-NS-CT_Drill pipe (1) 565,529.24 4.34 -21.37 2 -Gyro -NS -CT Drill pipe (1) 565,530.67 5.14 -22.79 2_Gyro-NS-CT_Drill pipe (1) 9/16/2019 12:30:50PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU S-203 Design: MPU 5-203 Survey MD Inc Azi TVD TVDSS +NlS (usft) (1) V) (usft) (usft) (usft) 570.00 10.15 121.60 568.63 505.23 -10.22 580.00 10.65 122.60 578.46 515.06 -11.18 590.00 11.12 123.30 588.28 524.88 -12.21 600.00 11.52 124.58 598.09 534.69 -13.31 610.00 11.87 125.87 607.88 544.48 -14.48 620.00 12.18 126.20 617.66 554.26 -15.70 630.00 12.70 126.83 627.43 564.03 -16.98 640.00 13.15 128.25 637.17 573.77 -18.35 650.00 13.49 129.75 646.90 583.50 -19.80 660.00 13.91 130.61 656.62 593.22 -21.32 670.00 14.57 131.42 666.31 602.91 -22.94 680.00 15.03 132.23 675.98 612.58 -24.64 690.00 15.39 133.26 685.63 622.23 -26.42 700.00 15.77 134.23 695.26 631.86 -28.28 710.00 16.15 135.23 704.88 641.48 -30.22 720.00 16.57 136.24 714.47 651.07 -32.23 730.00 17.06 137.39 724.04 660.64 -34.34 740.00 17.49 138.39 733.59 670.19 -36.55 750.00 17.89 138.86 743.12 679.72 -38.83 760.00 18.16 139.60 752.63 689.23 -41.17 770.00 18.33 140.36 762.13 698.73 -43.57 780.00 18.58 140.87 771.61 708.21 -46.01 790.00 18.81 141.12 781.08 717.68 48.50 800.00 18.97 141.91 790.55 727.15 -51.04 810.00 19.16 142.45 800.00 736.60 -53.62 820.00 19.25 143.29 809.44 746.04 -56.24 830.00 19.37 144.51 818.88 755.48 -58.91 840.00 19.55 145.25 828.31 764.91 -61.64 850.00 19.64 145.87 837.73 774.33 -64.40 860.00 19.75 146.67 847.14 783.74 -67.21 870.00 19.88 147.23 856.55 793.15 -70.05 880.00 19.99 147.59 865.95 802.55 -72.92 890.00 20.03 147.98 875.35 811.95 -75.82 900.00 20.18 148.24 884.74 821.34 -78.73 910.00 20.40 148.41 894.12 830.72 -81.69 920.00 20.56 148.68 903.49 840.09 -84.67 930.00 20.78 148.93 912.84 849.44 -87.69 940.00 21.07 149.05 922.18 858.78 -90.75 950.00 21.27 149.29 931.51 868.11 -93.85 960.00 21.51 149.50 940.82 877.42 -96.99 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU 5-203 MPU 5-203 Actual RKB @ 63.40usft MPU 5-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA 9/16/2019 12:30:50PM Page 4 COMPASS 5000.15 Build 91 Map Map Vertical +EI -W Northing Easting DLS Section (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 24.25 5,999,882.49 565,532.15 5.09 -24.26 2_Gyro-NS-CT_Drill pipe (1) 25.78 5,999,881.55 565,533.69 5.32 -25.79 2_Gyro-NS-CT_Dnll pipe (1) 27.37 5,999,880.53 565,535.28 4.88 -27.38 2_Gyro-NS-CT_Dnll pipe (1) 29.00 5,999,879.45 565,536.92 4.72 -29.00 2_Gyro-NS-CT_Drill pipe (1) 30.65 5,999,878.30 565,538.58 4.37 -30.66 2_Gyro-NS-CT_Drill pipe (1) 32.34 5,999,877.08 565,540.28 3.18 -32.35 2_Gyro-NS-CT_Drill pipe (1) 34.07 5,999,875.82 565,542.02 5.37 -34.08 2_Gyro-NS-CT_Drill pipe (1) 35.84 5,999,874.47 565,543.81 5.51 -35.85 2_Gyro-NS-CT_Dnll pipe (1) 37.63 5,999,873.04 565,545.61 4.85 -37.64 2_Gyro-NS-CT_Dnll pipe (1) 39.44 5,999,871.52 565,547.43 4.67 -39.45 2_Gyro-NS-CT Drill pipe (1) 41.29 5,999,869.93 565,549.30 6.89 41.31 2_Gyro-NS-CT_Drill pipe (1) 43.20 5,999,868.24 565,551.22 5.04 43.22 2_Gyro-NS-CT_Drill pipe (1) 45.12 5,999,866.48 565,553.16 4.50 -45.14 2_Gyro-NS-CT_Drill pipe (1) 47.06 5,999,864.64 565,555.12 4.61 -47.08 2_Gyro-NS-CT_Dnll pipe (1) 49.02 5,999,862.72 565,557.09 4.69 49.04 2_Gyro-NS-CT_Drill pipe (1) 50.98 5,999,860.72 565,559.07 5.07 -51.01 2_Gyro-NS-CT_Drill pipe (1) 52.96 5,999,858.63 565,561.07 5.92 -52.99 2_Gyro-NS-CT Drill pipe (1) 54.95 5,999,856.44 565,563.08 5.23 -54.98 2_Gyro-NS-CT_Drill pipe (1) 56.96 5,999,854.18 565,565.11 4.25 -56.99 2_Gyre-NS-CT_Drill pipe (1) 58.98 5,999,851.85 565,567.15 3.54 -59.01 2 Gyro -NS -CT Drill pipe (1) 61.00 5,999,849.47 565,569.18 2.92 -61.03 2_Gyro-NS-CT_Drill pipe (1) 63.00 5,999,947.05 565,571.21 2.98 -63.04 2_Gyro-NS-CT_Drill pipe (1) 65.02 5,999,844.57 565,573.25 2.44 -65.06 2 Gyro-NS-CT_Drill pipe (1) 67.04 5,999,842.06 565,575.29 3.02 -67.07 2_Gyrc-NS-CT_Drill pipe (1) 69.04 5,999,839.49 565,577.31 2.59 -69.08 2_Gyro-NS-CT_Ddil pipe (1) 71.02 5,999,836.89 565,579.32 2.91 -71.06 2_Gyro-NS-CT_Drill pipe (1) 72.97 5,999,834.23 565,581.29 4.21 -73.01 2_Gyro-NS-CT_Drill pipe (1) 74.89 5,999,831.53 565,583.23 3.05 -74.93 2_Gyro-NS-CT_Drill pipe (1) 76.79 5,999,828.78 565,585.15 2.27 -76.83 2_Gyro-NS-CT_Dnll pipe (1) 78.66 5,999,825.99 565,587.05 2.91 -78.70 2_Gyro-NS-CT_Ddll pipe (1) 80.51 5,999,823.17 565,588.92 2.30 -80.55 2_Gyro-NS-CT_Drill pipe (1) 82.34 5,999,820.31 565,590.78 1.65 -82.39 2_Gyro-NS-CT_Drill pipe (1) 84.17 5,999,817.43 565,592.63 1.39 -84.22 2_Gyra-NS-CT_Drill pipe (1) 85.98 5,999,814.53 565,594.47 1.75 -86.04 2_Gyro-NS-CT_Dnll pipe (1) 87.80 5,999,811.60 565,596.32 2.28 -87.86 2_Gyro-NS-CT_Drill pipe (1) 89.63 5,999,808.63 565,598.17 1.86 -89.69 2_Gyro-NS-CT_Drill pipe (1) 91.46 5,999,805.62 565,600.02 2.37 -91.52 2_Gyro-NS-CT_Drill pipe (1) 93.30 5,999,802.58 565,601.89 2.93 -93.36 2_Gyro-NS-CT_Dnll pipe (1) 95.15 5,999,799.49 565,603.77 2.18 -95.21 2_Gyro-NS-CT_Drill pipe (1) 97.00 5,999,796.37 565,605.65 2.52 -97.07 2_Gyro-NS-CT_Drill pipe (1) 9/16/2019 12:30:50PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU 5-203 MPU S-203 MPU S-203 Local Coordinate Reference: Well MPU 5-203 TVD Reference: MPU S-203 Actual RKB @ 63.40usft MD Reference: MPU S-203 Actual RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 970.00 21.84 149.39 950.11 886.71 -100.17 98.88 5,999,793.21 565,607.56 3.32 -98.95 2_Gyro-NS-CT_Drill pipe (1) 980.00 22.12 149.13 959.39 895.99 -103.39 100.80 5,999,790.01 565,609.50 2.96 -100.87 2_Gyro-NS-CT_Drill pipe (1) 990.00 22.49 148.91 968.64 905.24 -106.64 102.75 5,999,786.77 565,611.48 3.79 -102.82 2_Gyro-NS-CT_Drill pipe (1) 1,000.00 22.92 148.63 977.86 914.46 -109.94 104.75 5,999,783.49 565,613.51 4.43 -104.83 2_Gyro-NS-CT_Drill pipe (1) 1,010.00 23.14 148.27 987.07 923.67 -113.28 106.80 5,999,780.17 565,615.59 2.61 -106.88 2_Gyro-NS-CT_Dnll pipe (1) 1,020.00 23.32 147.93 996.25 932.85 -116.63 108.88 5,999,776.85 565,617.70 2.24 -108.96 2_Gyra-NS-CT_Dnll pipe (1) 1,030.00 23.74 147.56 1,005.42 942.02 -120.00 111.01 5,999,773.49 565,619.86 4.45 -111.10 2_Gyro-NS-CT_Drill pipe (1) 1,040.00 24.08 147.08 1,014.57 951.17 -123.41 113.20 5,999,770.10 565,622.08 3.92 -113.29 2_Gym-NS-CT_Ddll pipe (1) 1,050.00 24.39 146.49 1,023.68 960.28 -126.85 115.45 5,999,766.68 565,624.36 3.93 -115.54 2_Gym-NS-CT_Drill pipe (1) 1,060.00 24.93 145.96 1,032.77 969.37 -130.31 117.77 5,999,763.24 565,626.71 5.84 -117.86 2_Gym-NS-CT Drill pipe (1) 1,070.00 25.36 145.50 1,041.82 978.42 -133.83 120.16 5,999,759.75 565,629.13 4.72 -120.26 2_Gyra-NS-CT_Drill pipe (1) 1,080.00 25.66 144.90 1,050.85 987.45 -137.36 122.62 5,999,756.23 565,631.62 3.96 A22.72 2_Gym-NS-CT_Dnll pipe (1) 1,090.00 26.06 144.33 1,059.85 996.45 -140.92 125.15 5,999,752.70 565,634.18 4.71 -125.24 2_Gyro-NS-CT_Drill pipe (1) 1,100.00 26.42 143.92 1,068.82 1,005.42 -144.50 127.74 5,999,749.14 565,636.80 4.03 -127.84 2_Gyro-NS-CT_Drill pipe (1) 1,110.00 26.65 143.51 1,077.76 1,014.36 -148.10 130.38 5,999,745.56 565,639.47 2.94 -130.48 2 Gyro-NS-CT_Drill pipe (1) 1,120.00 26.95 143.03 1,086.69 1,023.29 -151.72 133.08 5,999,741.97 565,642.20 3.70 -133.18 2_Gym-NS-CT_Dnll pipe (1) 1,130.00 27.22 142.64 1,095.59 1,032.19 -155.34 135.83 5,999,738.37 565,644.98 3.23 -135.94 2_Gym-NS-CT_Orill pipe (1) 1,140.00 27.33 142.23 1,104.48 1,041.08 -158.98 138.62 5,999,734.76 565,647.81 2.18 -138.73 2_Gyro-NS-CT_Drill pipe (1) 1,150.00 27.53 141.67 1,113.36 1,049.96 -162.60 141.46 5,999,731.16 565,650.68 3.26 -141.57 2_Gyro-NS-CT_Drill pipe (1) 1,160.00 27.88 141.20 1,122.21 1,058.81 A66.24 144.36 5,999,727.55 565,653.61 4.13 -144.48 2_Gyro-NS-CT Drill pipe (1) 1,170.00 28.03 140.66 1,131.04 1,067.64 -169.88 147.31 5,999,723.94 565,656.59 2.94 -147.43 2_Gyro-NS-CT_Drill pipe (1) 1,180.00 28.16 140.08 1,139.87 1,076.47 -173.51 150.32 5,999,720.34 565,659.63 3.02 -150.44 2_Gyro-NS-CT_Drill pipe (1) 1,190.00 28.41 139.63 1,148.67 1,085.27 -177.13 153.37 5,999,716.74 565,662.72 3.29 -153.50 2 Gyro-NS-CT_Drill pipe (1) 1,200.00 28.48 139.31 1,157.46 1,094.06 -180.75 156.47 5,999,713.15 565,665.84 1.68 -156.59 2_Gym-NS-CT_Drill pipe (1) 1,210.00 28.46 138.97 1,166.25 1,102.85 -184.35 159.59 5,999,709.57 565,668.99 1.63 -159.72 2_Gyro-NS-CT_Drill pipe (1) 1,220.00 28.82 138.65 1,175.03 1,111.63 -187.96 162.74 5,999,705.99 565,672.18 3.91 -162.87 2_Gyro-NS-CT Drill pipe (1) 1,230.00 28.92 138.46 1,183.79 1,120.39 -191.58 165.94 5,999,702.40 565,675.41 1.36 -166.07 2_Gym-NS-CT_Dnl1 pipe (1) 1,240.00 29.01 138.33 1,192.54 1,129.14 -195.20 169.15 5,999,698.81 565,678.65 1.10 -169.29 2_Gyro-NS-CT_Drill pipe(1) 1,250.00 29.18 138.21 1,201.28 1,137.88 -198.83 172.39 5,999,695.21 565,681.92 1.80 -172.53 2_Gyro-NS-CT_Drill pipe (1) 1,260.00 29.38 138.03 1,210.00 1,146.60 -202.47 175.66 5,999,691.60 565,685.22 2.19 -175.80 2_Gyro-NS-CT Drill pipe (1) 1,270.00 29.57 137.79 1,218.70 1,155.30 -206.12 178.95 5,999,687.98 565,688.55 2.24 -179.10 2_Gyro-NS-CT_Ddll pipe (1) 1,280.00 29.90 137.60 1,227.39 1,163.99 -209.79 182.29 5,999,684.34 565,691.92 3.43 -182.44 2_Gym-NS-CT_Dnll pipe (1) 1,290.00 30.29 137.43 1,236.04 1,172.64 -213.49 185.68 5,999,680.67 565,695.34 3.99 -185.83 2_Gym-NS-CT_Drill pipe (1) 1,300.00 30.62 137.20 1,244.66 1,181.26 -217.21 189.12 5,999.676.97 565,698.81 3.50 -189.27 2_Gyro-NS-CT_Drill pipe (1) 1,310.00 31.07 136.99 1,253.24 1,189.84 -220.97 192.61 5,999,673.25 565,702.33 4.63 -192.76 2_Gyrc-NS-CT_Dnll pipe (1) 1,320.00 31.49 136.75 1,261.79 1,198.39 -224.76 196.16 5,999,669.49 565,705.91 4.38 -196.31 2_Gyro-NS-CT_Drill pipe (1) 1,330.00 31.82 136.48 1,270.30 1,206.90 -228.57 199.76 5,999,665.71 565,709.55 3.59 -199.92 2_Gyro-NS-CT_Drill pipe (1) 1,340.00 32.17 136.24 1,278.78 1,216.38 -232.41 203.42 5,999,661.91 565,713.24 3.72 -203.58 2_Gym-NS-CT_Dnll pipe (1) 1,350.00 32.55 135.93 1,287.23 1,223.83 -236.26 207.13 5,999,658.09 565,716.98 4.15 -207.30 2_Gyro-NS-CT_Dnll pipe (1) 1,360.00 32.81 135.74 1,295.65 1,232.25 -240.14 210.89 5,999,654.25 565,720.78 2.80 -211.06 2_Gym-NS-CT_Ddll pipe (1) 9/16/2019 12:30:50PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU S-203 MPU S-203 MPU S-203 Local Co-ordinate Reference: Well MPU S-203 TVD Reference: MPU S-203 Actual RKB @ 63.40usft MD Reference: MPU S-203 Actual RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,370.00 3299 135.64 1,304.04 1,240.64 -244.02 214.69 5,999,550.39 565,724.61 1.88 -214.86 2_Gyro-NS-CT_Ddll pipe (1) 1,380.00 33.25 135.46 1,312.42 1,249.02 .247.92 218.51 5,999,646.53 565,728.47 2.78 -218.69 2_Gyro-NS-CT_Ddll pipe (1) 1,390.00 33.42 135.36 1,320.77 1,257.37 -251.84 222.37 5,999,642.65 565,732.36 1.79 -222.55 2_Gyro-NS-CT_Drill pipe (1) 1,400.00 33.43 135.40 1,329.12 1,265.72 .255.76 226.24 5,999,638.76 565,736.26 0.24 -226.42 2_Gyro-NS-CT_Drill pipe (1) 1,410.00 33.61 135.30 1,337.46 1,274.06 -259.69 230.12 5,999,634.87 565,740.18 1.88 -230.30 2_Gyro-NS-CT_Drill pipe (1) 1,420.00 33.71 135.22 1,345.78 1,282.38 -263.62 234.02 5,999,630.96 565,744.11 1.09 -234.21 2_Gyro-NS-CT_Drill pipe (1) 1,430.00 33.61 135.09 1,354.10 1,290.70 .267.55 237.93 5,999,627.07 565,748.06 1.23 -238.12 2_Gym-NS-CT Drill pipe (1) 1,440.00 33.74 134.87 1,362.43 1,299.03 -271.47 241.85 5,999,623.19 565,752.01 1.78 -242.04 2_Gyro-NS-CT_Dnll pipe (1) 1,450.00 33.89 134.67 1,370.73 1,307.33 -275.39 245.80 5,999,619.30 565,756.00 1.87 .246.00 2_Gyro-NS-CT_Drill pipe (1) 1,460.00 33.78 134.42 1,379.04 1,315.64 -279.30 249.77 5,999,615.43 565,760.00 1.77 -249.97 2_Gyro-NS-CT_13rill pipe (1) 1,470.00 33.77 134.15 1,387.35 1,323.95 .283.18 253.75 5,999,611.58 565,764.01 1.50 -253.95 2_Gyro-NS-CT_Dn1l pipe (1) 1,480.00 33.82 133.91 1,395.66 1,332.26 -267.04 257.75 5,999,607.75 565,768.04 1.43 -257.95 2_Gyro-NS-CT_Drill pipe (1) 1,490.00 33.75 133.71 1,403.98 1,340.58 -290.89 261.76 5,999,603.94 565,772.09 1.31 .261.97 2_Gyro-NS-CT_Drill pipe (1) 1,500.00 33.71 133.66 1,412.29 1,348.89 -294.73 265.78 5,999,600.14 565,776.14 0.49 -265.99 2_Gyro-NS-CT_Drill pipe (1) 1,510.00 33.89 133.52 1,420.60 1,357.20 -298.57 269.81 5,999,596.34 565,780.20 1.96 -270.02 2_Gyro-NS-CT_Dnll pipe (1) 1,520.00 33.73 133.45 1,428.91 1,365.51 -302.39 273.85 5,999,592.55 565,784.27 1.65 .274.06 2_Gyro-NS-CT_Ddll pipe (1) 1,530.00 33.40 133.50 1,437.24 1,373.84 -306.20 277.86 5,999,588.78 565,788.32 3.31 -278.07 2_Gyro-NS-CT_Dri1l pipe (1) 1,540.00 33.41 133.44 1,445.59 1,382.19 -309.99 281.85 5,999,585.03 565,792.34 0.35 -282.07 2_Gyro-NS-CT_Dnll pipe (1) 1,550.00 33.22 133.45 1,453.95 1,390.55 -313.76 285.84 5,999,581.29 565,796.36 1.90 -286.06 2_Gyro-NS-CT_Drill pipe (1) 1,560.00 32.83 133.62 1,462.33 1,398.93 -317.52 289.79 5,999,577.57 565,800.35 4.01 -290.01 2_Gyro-NS-CT_Drill pipe (1) 1,570.00 32.79 133.64 1,470.74 1,407.34 .321.26 293.71 5,999,573.86 565,804.30 0.41 -293.94 2_Gyro-NS-CT_Drill pipe (1) 1,580.00 32.70 133.65 1,479.15 1,415.75 -324.99 297.63 5,999,570.16 565,808.25 0.90 -297.86 2_Gyro-NS-CT_Dnll pipe (1) 1,590.00 32.53 133.70 1,487.57 1,424.17 -328.71 301.53 5,999,566.48 565,812.18 1.72 -301.76 2_Gyro-NS-CT_Drill pipe (1) 1,600.00 32.58 133.74 1,496.00 1,432.60 -332.43 305.42 5,999,562.79 565,816.10 0.54 -305.65 2_Gyro-NS-CT Dnll pipe (1) 1,610.00 32.58 133.83 1,504.43 1,441.03 -336.16 309.30 5,999,559.10 565,820.02 0.48 -309.54 2_Gyro-NS-CT_Dnll pipe (1) 1,620.00 32.43 133.86 1,512.86 1,449.46 -339.88 313.18 5,999,555.41 565,823.93 1.51 -313.42 2_Gyro-NS-CT_Ddil pipe (1) 1,630.00 32.43 133.88 1,521.30 1,457.90 -343.59 317.05 5,999,551.73 565,827.83 0.11 -317.28 2_Gyn -NS-CT_Drill pipe (1) 1,640.00 32.51 134.05 1,529.74 1,466.34 .347.32 320.91 5,999,548.04 565,831.72 1.21 -321.15 2 Gyro -NS -CT Dnll pipe (1) 1,650.00 32.33 134.19 1,538.18 1,474.78 -351.05 324.76 5,999,544.34 565,835.60 1.95 -325.00 2_Gym-NS.CT_Drill pipe (1) 1,660.00 32.18 134.37 1,546.63 1,483.23 -354.78 328.58 5,999,540.65 565,839.46 1.78 .328.83 2_Gym-NS-CT_Dri11 pipe (1) 1,670.00 32.16 134.48 1,555.10 1,491.70 -358.51 332.38 5,999,536.96 565,843.29 0.62 -332.63 2_Gyro-NS-CT_Drill pipe (1) 1,680.00 31.91 134.59 1,563.58 1,500.18 -362.23 336.16 5,999,533.27 565,847.10 2.57 -336.42 2_Gyro-NS-CT_Drill pipe (1) 1,690.00 31.63 134.77 1,572.08 1,508.68 -365.93 339.91 5,999,529.60 565,850.88 2.96 -340.16 2_Gyro-NS.CT_Drill pipe (1) 1,700.00 31.57 134.81 1,580.60 1,517.20 -369.62 343.62 5,999,525.94 565,854.63 0.64 -343.88 2_Gym-NS-CT Drill pipe (1) 1,710.00 31.34 134.88 1,589.13 1,525.73 .373.30 347.32 5,999,522.30 565,858.36 2.33 -347.59 2_Gyro-NS-CT_Dnll pipe (1) 1,720.00 31.06 135.01 1,597.68 1,534.28 -376.96 350.99 5,999,518.67 565,862.06 2.88 -351.25 2_Gyro-NS-CT_Ddll pipe (1) 1,730.00 31.08 134.92 1,606.25 1,542.85 -380.61 354.64 5,999,515.05 565,865.74 0.51 -354.91 2_Gyro-NS-CT_Drill pipe (1) 1,740.00 30.98 134.80 1,614.81 1,551.41 -384.24 358.30 5,999,511.45 565,869.43 1.18 -358.56 2_Gyro-NS-CT_Dnll pipe (1) 1,750.00 30.79 134.60 1,623.40 1,560.00 -387.85 361.95 5,999,507.87 565,873.11 2.16 -362.22 2_Gyro-NS-CT_Dri1l pipe (1) 1,760.00 30.84 134.34 1,631.98 1,568.58 -391.44 365.60 5,999,504.32 565,876.79 1.42 -365.87 2_Gyro-NS-CT_Dnll pipe (1) 91162019 12:30:50PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilwrp Alaska, LLC Local Coordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU 5-203 Survey Calculation Method: Minimum Curvature Design: MPU S-203 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (o) (o) (usft) (usft) (usft) (usft) (ft) (ft) (olloo') (ft) Survey Tool Name 1,770.00 30.93 134.19 1,640.57 1,577.17 -395.03 369.28 5,999,500.77 565,880.50 1.18 -369.55 2_Gyro-NS-CT_Dnii pipe (1) 1,780.00 30.91 133.91 1,649.15 1,585.75 -398.60 372.97 5,999,497.23 565,884.23 1.45 -373.25 2_Gyro-NS-CT_Drill pipe (1) 1,790.00 31.12 133.50 1,657.72 1,594.32 -402.16 376.69 5,999,493.70 565,887.98 2.98 -376.98 2_Gyro-NS-CT_Drill pipe (1) 1,800.00 31.34 133.21 1,666.27 1,602.87 405.72 380.46 5,999,490.17 565,891.78 2.66 -380.75 2_Gyro-NS-CT_Drill pipe (1) 1,810.00 31.50 132.78 1,674.80 1,611.40 409.27 384.28 5,999,486.65 565,895.63 2.75 -384.56 2_Gyro-NS-CT Dnll pipe (1) 1,820.00 31.82 132.16 1,683.31 1,619.91 -412.82 388.15 5,999,483.14 565,899.53 4.56 -388.44 2_Gyro-NS-CT_Drill pipe (1) 1,830.00 32.25 131.63 1,691.79 1,628.39 -416.36 392.10 5,999,479.64 565,903.51 5.14 392.39 2_Gyro-NS-CT_Drill pipe (1) 1,840.00 32.55 131.08 1,700.23 1,636.83 -419.90 396.12 5,999,476.13 565,907.56 4.21 -396.41 2_Gyro-NS-CT_Drill pipe (1) 1,850.00 32.95 130.46 1,708.64 1,645.24 -423.43 400.22 5,999,472.64 565,911.69 5.22 400.51 2_Gyro-NS-CT Drill pipe (1) 1,860.00 33.47 129.95 1,717.01 1,653.61 -426.97 404.40 5,999,469.14 565,915.90 5.90 -404.70 2_Gyro-NS-CT_Drill pipe (1) 1,870.00 33.83 129.50 1,725.33 1,661.93 430.51 408.66 5,999,465.63 565,920.19 4.38 -408.96 2_Gyro-NS-CT_Ddll pipe (1) 1,880.00 34.15 129.06 1,733.63 1,670.23 434.05 412.99 5,999,462.13 565,924.55 4.04 413.29 2_Gyro-NS-CT Drill pipe (1) 1,890.00 34.55 128.76 1,741.88 1,678.48 -437.59 417.38 5,999,458.63 565,928.97 4.34 -417.69 2 Gyro-NS-CT_Drill pipe (1) 1,900.00 34.80 128.67 1,750.11 1,686.71 -441.15 421.82 5,999,455.11 565,933.44 2.55 -422.13 2_Gyro-NS-CT_Dnll pipe (1) 1,910.00 34.86 128.65 1,758.31 1,694.91 -444.72 426.28 5,999,451.58 565,937.93 0.61 -426.59 2_Gyro-NS-CT_Ddll pipe (1) 1,920.00 35.01 128.66 1,766.51 1,703.11 -448.29 430.75 5,999,448.04 565,942.43 1.50 A31.06 2 -Gym -NS -CT -Drill pipe(1) 1,930.00 35.06 128.74 1,774.70 1,711.30 -451.88 435.23 5,999,444.49 565,946.95 0.68 -435.55 2_Gyro-NS-CT_Drill pipe (1) 1,940.00 34.99 128.77 1,782.89 1,719.49 455.48 439.71 5,999,440.94 565,951.45 0.72 440.02 2_Gyro-NS-CT_Drill pipe (1) 1,950.00 35.11 128.79 1,791.08 1,727.68 -459.07 444.18 5,999,437.38 565,955.96 1.21 -444.50 2_Gyro-NS-CT_Ddll pipe (1) 1,960.00 35.16 128.84 1,799.25 1,735.85 -462.68 448.67 5,999,433.82 565,960.48 0.58 -448.99 2 -Gyro -NS -CT Drill pipe (1) 1,970.00 34.99 128.92 1,807.44 1,744.04 -466.29 453.14 5,999,430.25 565,964.98 1.76 -453.47 2_Gyro-NS-CT_Drill pipe (1) 1,980.00 34.95 129.00 1,815.63 1,752.23 .469.89 457.60 5,999,426.68 565,969.47 0.61 -457.93 2_Gyro-NS-CT_Dnll pipe (1) 1,990.00 34.97 129.15 1,823.83 1,760.43 -473.50 462.05 5,999,423.11 565,973.95 0.88 -462.38 2_Gyro-NS-CT_Drill pipe (1) 2,000.00 34.78 129.31 1,832.03 1,768.63 -477.12 466.48 5,999,419.54 565,978.41 2.11 -466.81 2_Gyro-NS-CT_Drill pipe (1) 2,010.00 34.61 129.42 1,840.25 1,776.85 -480.73 470.88 5,999,415.96 565,982.84 1.81 -471.21 2_Gyro-NS-CT_Dnll pipe (1) 2,020.00 34.61 129.41 1,848.48 1,785.08 -484.34 475.26 5,999,412.40 565,987.26 0.06 -475.60 2_Gyro-NS-CT_Drill pipe (1) 2,030.00 34.40 129.53 1,856.72 1,793.32 487.94 479.64 5,999,408.83 565,991.66 2.21 -479.98 2_Gyro-NS-CT_Drill pipe (1) 2,040.00 34.19 129.59 1,864.99 1,801.59 491.53 483.98 5,999,405.28 565,996.04 2.13 -484.32 2_Gyro-NS-CT_Drill pipe (1) 2,050.00 34.37 129.58 1,873.25 1,809.85 495.11 488.32 5,999,401.73 566,000.41 1.80 -488.67 2_Gyro-NS-CT_Dnll pipe (1) 2,060.00 34.33 129.69 1,881.50 1,818.10 -498.71 492.67 5,999,398.17 566,004.79 0.74 -493.02 2_Gyro-NS-CT_Drill pipe (1) 2,070.00 34.22 129.70 1,889.77 1,826.37 -502.31 497.00 5,999,394.62 566,009.15 1.10 -497.35 2_Gyro-NS-CT_Drill pipe (1) 2,080.00 34.37 129.70 1,898.03 1,834.63 -505.91 501.34 5,999,391.05 566,013.52 1.50 -501.69 2_Gyro-NS-CT Drill pipe (1) 2,090.00 34.30 129.98 1,906.29 1,842.89 -509.52 505.67 5,999,387.48 566,017.88 1.23 -506.03 2_Gyro-NS-CT_Dnll pipe (1) 2,100.00 34.01 130.07 1,914.56 1,851.16 -513.13 509.97 5,999,383.91 566,022.21 3.09 -510.33 2_Gyro-NS-CT_Drill pipe (1) 2,110.00 34.09 130.16 1,922.85 1,859.45 -516.73 514.25 5,999,380.34 566,026.53 0.95 -514.61 2_Gyro-NS-CT_Drill pipe (1) 2,120.00 33.99 130.48 1,931.13 1,867.73 -520.36 518.52 5,999,376.76 566,030.83 2.05 -518.89 2_Gyro-NS-CT_Drill pipe (1) 2,130.00 33.56 130.94 1,939.45 1,876.05 -523.98 522.74 5,999,373.17 566,035.07 5.00 -523.10 2_Gyro-NS-CT_Drlll pipe (1) 2,140.00 33.39 131.43 1,947.79 1,884.39 -527.61 526.89 5,999,369.58 566,039.25 3.19 -527.26 2_Gyro-NS-CT_Drill pipe (1) 2,150.00 33.23 132.05 1,956.15 1,892.75 -531.27 530.99 5,999,365.96 566,043.38 3.76 -531.36 2_Gyro-NS-CT_Drill pipe (1) 2,160.00 32.90 132.83 1,964.53 1,901.13 -534.95 535.01 5,999,362.31 566,047.44 5.39 -535.38 2_Gyro-NS-CT_Dnll pipe (1) 9/162019 12:30:50PM Page 7 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Paint TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU 5-203 Survey Calculation Method: Minimum Curvature Design: MPU S-203 Database: NORTH US+CANADA Survey Map Map MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS (usft) (') (`) (usft) (usft) (usft) (usft) (ft) (ft) ('1100•) 2,170.00 32.62 133.75 1,972.94 1,909.54 -538.66 538.95 5,999,358.64 566,051.41 5.71 2,180.00 32.60 134.35 1,981.36 1,917.96 -542.41 542.82 5,999,354.92 566,055.32 3.24 2,190.00 32.44 134.98 1,989.79 1,926.39 -546.19 546.65 5,999,351.18 566,059.17 3.75 2,200.00 32.15 135.60 1,998.24 1,934.84 -549.98 550.41 5,999,347.42 566,062.97 4.40 2,210.00 32.20 136.03 2,006.71 1,943.31 -553.80 554.12 5,999,343.63 566,066.71 2.34 2,220.00 31.94 136.74 2,015.18 1,951.78 -557.65 557.78 5,999,339.82 566,070.41 4.58 2,230.00 31.62 137.67 2,023.68 1,960.28 -561.51 561.36 5,999,335.99 566,074.02 5.85 2,240.00 31.60 138.15 2,032.20 1,968.80 -565.40 564.87 5,999,332.13 566,077.56 2.52 2,250.00 31.41 138.70 2,040.73 1,977.33 -569.31 568.34 5,999,328.25 566,081.07 3.45 2,260.00 31.11 139.27 2,049.27 1,985.87 -573.23 571.74 5,999,324.37 566,084.51 4.21 2,270.00 31.12 139.71 2,057.84 1,994.44 -577.15 575.10 5,999,320.47 566,087.90 2.28 2,280.00 30.90 140.38 2,066.41 2,003.01 -581.10 578.41 5,999,316.55 566,091.24 4.09 2,290.00 30.51 141.20 2,075.00 2,011.60 -585.06 581.64 5,999,312.62 566,094.50 5.72 2,300.00 30.39 141.85 2,083.62 2,020.22 -589.03 584.79 5,999,308.68 566,097.69 3.51 2,310.00 30.25 142.45 2,092.26 2,028.86 -593.01 567.89 5,999,304.72 566,100.82 3.34 2,320.00 29.94 143.03 2,100.91 2,037.51 -597.00 590.92 5,999,300.76 566,103.89 4.25 2,330.00 29.77 143.61 2,109.58 2,046.18 -601.00 593.90 5,999,296.79 566,106.90 3.35 2,340.00 29.75 144.22 2,118.26 2,054.86 -605.01 596.82 5,999,292.81 566,109.86 3.03 2,350.00 29.39 145.14 2,126.96 2,063.56 -609.03 599.67 5,999,288.81 566,112.75 5.79 2,360.00 29.06 146.19 2,135.69 2,072.29 -613.07 602.43 5,999,284.80 566,115.53 6.10 2,370.00 29.10 146.74 2,144.43 2,081.03 -617.12 605.11 5,999,280.77 566,118.26 2.70 2,380.00 28.97 147.19 2,153.17 2,089.77 -621.19 607.76 5,999,276.73 566,120.94 2.54 2,390.00 28.78 147.64 2,161.93 2,098.53 -625.25 610.36 5,999,272.68 566,123.57 2.89 2,400.00 28.93 148.17 2,170.69 2,107.29 -629.34 612.92 5,999,268.62 566,126.17 2.97 2,410.00 28.65 149.02 2,179.45 2,116.05 -633.45 615.43 5,999,264.53 566,128.72 4.96 2,420.00 28.32 150.18 2,188.24 2,124.84 -637.57 617.85 5,999,260.44 566,131.17 6.44 2,430.00 28.38 150.97 2,197.04 2,133.64 -641.70 620.18 5,999,256.32 566,133.54 3.80 2,440.00 28.25 151.62 2,205.84 2,142.44 -645.86 622.46 5,999,252.18 566,135.85 3.35 2,450.00 27.98 152.27 2,214.66 2,151.26 -650.02 624.68 5,999,248.04 566,138.10 4.08 2,460.00 28.16 152.81 2,223.49 2,160.09 -654.20 626.84 5,999,243.89 566,140.31 3.11 2,470.00 28.26 153.75 2,232.30 2,168.90 -658.42 628.97 5,999,239.69 566,142.47 4.55 2,480.00 27.86 154.92 2,241.12 2,177.72 -662.66 631.01 5,999,235.46 566,144.54 6.80 2,490.00 27.72 155.78 2,249.97 2,186.57 -666.90 632.95 5,999,231.24 566,146.53 4.25 2,500.00 27.69 156.55 2,258.82 2,195.42 -671.15 634.83 5,999,227.01 566,148.44 3.59 2,510.00 27.57 157.31 2,267.68 2,204.28 -675.41 636.65 5,999,222.76 566,150.30 3.72 2,520.00 27.41 158.08 2,276.55 2,213.15 -679.68 638.40 5,999,218.50 566,152.09 3.90 2,530.00 27.35 158.75 2,285.43 2,222.03 -683.96 640.09 5,999,214.24 566,153.81 3.14 2,540.00 27.05 159.64 2,294.33 2,230.93 -688.23 641.72 5,999,209.99 566,155.48 5.05 2,550.00 26.66 160.80 2,303.25 2,239.85 -692.48 843.24 5,999,205.75 566,157.04 6.53 2,560.00 26.62 161.51 2,312.19 2,248.79 -696.73 644.69 5,999,201.52 566,158.53 3.21 Vertical Section (ft) Survey Tool Name -539.33 2_Gyro-NS-CT_Drill pipe (1) -543.20 2_Gyro-NS-CT_Dnll pipe (1) -547.03 2_Gyro-NS-CT_Ddll pipe (1) -550.79 2_Gyro-NS-CT_Dnll pipe (1) -554.50 2_Gyro-NS-CT_Drill pipe (1) -558.17 2_Gyro-NS-CT_Drill pipe (1) -561.75 2 Gyro-NS-CT_Drill pipe (1) -565.27 2_Gym-NS-CT Dnll pipe (1) -568.74 2 Gyro-NS-CT_Drill pipe (1) -572.14 2_Gyro-NSCT_Ddll pipe (1) -575.50 2_Gyro-NS-CT_Drill pipe (1) -578.82 2_Gyro-NS-CT Dnll pipe (1) -582.05 2_Gyro-NS-CT_Drill pipe (1) -585.20 2_Gyro-NS-CT_Dnll pipe (1) -588.30 2_Gyra-NS-CT_Dnll pipe (1) -591.34 2 Gyro-NS-CT_Drill pipe (1) -594.32 2_Gyro-NS-CT_Drill pipe (1) -597.24 2_Gyro-NS-CT_Drill pipe (1) -600.10 2 Gyro -NS -CT Drill pipe (1) -502.86 2_Gyro-NS-CT_Drill pipe (1) -605.54 2_Gym-NS-CT_Drill pipe (1) -608.19 2 Gyro-NS-CT_Ddll pipe (1) -610.80 2_Gyro-NS-CT_Drill pipe (1) -613.36 2_Gyro-NS-CT_Drill pipe (1) -615.88 2_Gyro-NS-CT Drill pipe (1) -618.29 2_Gyro-NS-CT_Drill pipe (1) -620.63 2_Gyro-NS-CT_Drill pipe (1) -622.91 2_Gyro-NS-CT_Drill pipe (1) -625.13 2_Gyro-NS-CT_Dnll pipe (1) -627.30 2_Gyro-NS-CT_Drill pipe (1) -629.43 2_Gyro-NS-CT Drill pipe (1) -631.47 2_Gyro-NS-CT_Drill pipe (1) -633.42 2_Gyro-NS-CT_Drll pipe (1) -635.30 2_Gyro-NS-CT_DdIl pipe (1) -637.12 2_Gyro-NS-CT Drill pipe (1) -638.87 2_Gyro-NS-CT_Drill pipe (1) -640.57 2_Gyro-NS-CT_Drill pipe (1) -642.20 2_Gyro-NS-CT_Dri1l pipe (1) -643.73 2_Gyro-NS-CT_Drill pipe (1) -645.18 2_Gyro-NS-CT_Dnll pipe (1) 9116/1019 12:30:50PM Page 8 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU S-203 Project: Milne Point ND Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU S-203 Survey Calculation Method: Minimum Curvature Design: MPU S-203 Database: NORTH US+CANADA Survey�- Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 2,570.00 26.37 162.17 2,321.14 2,257.74 -700.97 646.08 5,999,197.29 566,159.95 3.86 -646.57 2_Gyno NS-CT_Dnll pipe (1) 2,580.00 26.06 162.86 2,330.11 2,266.71 -705.18 647.41 5,999,193.09 566,161.32 4.35 -647.90 2_Gyro-NS-CT_Dn1l pipe (1) 2,590.00 26.17 163.39 2,339.09 2,275.69 -709.39 648.69 5,999,188.89 566,162.63 2.58 -649.18 2_Gym-NS-CT_Drill pipe (1) 2,600.00 26.11 164.21 2,348.07 2,284.67 -713.62 649.92 5,999,184.67 566,163.90 3.66 -650.42 2_Gyrc-NS-CT_Drill pipe (1) 2,610.00 25.97 165.30 2,357.05 2,293.65 -717.86 651.07 5,999,180.45 566,165.09 4.99 -651.57 2_Gyro-NS-CT_Drll pipe (1) 2,620.00 26.11 166.05 2,366.04 2,302.64 -722.11 652.16 5,999,176.20 566,166.21 3.58 -652.66 2_Gym-NS-CT_Drill pipe (1) 2,630.00 26.10 166.81 2,375.02 2,311.62 -726.39 653.19 5,999,171.94 566,167.28 3.35 -653.70 2_Gym-NS-CT_Dn1l pipe (1) 2,640.00 26.09 167.73 2,384.00 2,320.60 -730.68 654.16 5,999,167.66 566,168.29 4.05 -654.67 2_Gyro-NS-CT_13rill pipe (1) 2,650.00 26.26 168.50 2,392.97 2,329.57 -735.00 655.07 5,999,163.35 566,169.24 3.80 -655.58 2_Gyro-NS-CT_Drill pipe (1) 2,660.00 26.42 169.43 2,401.93 2,338.53 -739.35 655.92 5,999,159.00 566,170.12 4.43 -656.43 2_Gym-NS-CT_Dr11l pipe (1) 2,670.00 26.42 170.58 2,410.89 2,347.49 -743.73 656.69 5,999,154.63 566,170.93 5.12 -657.21 2_Gyro-NS-CT_Drill pipe (1) 2,680.00 26.52 171.63 2,419.84 2,356.44 -748.14 657.38 5,999,150.23 566,171.66 4.79 -657.90 2_Gyro-NS-CT_Dnll pipe (11 2,690.00 26.69 172.31 2,428.78 2,365.38 -752.57 658.00 5,999,145.80 566,172.33 3.49 -658.53 2_Gyro-NS-CT_Ddli pipe (1) 2,700.00 26.68 173.08 2,437.72 2,374.32 -757.02 658.58 5,999,141.35 566,172.94 3.46 -659.10 2_Gyro-NS-CT_Drill pipe (1) 2,710.00 26.69 173.77 2,446.65 2,383.25 -761.49 659.09 5,999,136.90 566,173.49 3.10 -659.62 2_Gyro-NS-CT_Dnll pipe (1) 2,720.00 26.80 174.27 2,455.58 2,392.18 -765.96 659.56 5,999,132.43 566,174.00 2.50 -660.09 2_Gym-NS-CT_Dnll pipe (1) 2,730.00 26.62 175.55 2,464.51 2,401.11 -770.44 659.96 5,999,127.95 566,174.44 6.03 -660.49 2_Gyro-NS-CT_Dn1l pipe (1) 2,740.00 26.32 177.37 2,473.47 2,410.07 -774.89 660.23 5,999,123.51 566,174.75 8.65 860.77 2_Gyro-NS-CT 13611 pipe (1) 2,750.00 26.29 178.22 2,482.43 2,419.03 -779.31 660.40 5,999,119.08 566,174.96 3.78 860.95 2_Gym-NS-CT Drill pipe (1) 2,760.00 26.20 178.79 2,491.40 2,428.00 -783.73 660.52 5,999,114.66 566,175.11 2.68 -661.07 2_Gyro-NS-CT_Drill pipe (1) 2,770.00 26.01 179.59 2,500.38 2,436.98 -788.13 660.58 5,999,110.26 566,175.21 4.00 -661.13 2_Gyro-NS-CT_Drill pipe (1) 2,780.00 26.04 180.40 2,509.37 2,445.97 -792.52 660.58 5,999,105.88 566,175.25 3.57 861.13 2_Gyro-NS-CT_Ddli pipe (1) 2,790.00 25.88 181.21 2,518.36 2,454.96 -796.90 660.52 5,999,101.50 566,175.23 3.89 -661.08 2_Gyro-NS-CT_Drill pipe (1) 2,800.00 25.56 182.19 2,527.37 2,463.97 -801.24 660.39 5,999,097.16 566,175.14 5.32 -660.95 2_Gym-NS-CT_Drill pipe (1) 2,810.00 25.51 183.40 2,536.39 2,472.99 -805.54 660.18 5,999,092.86 566,174.97 5.24 -660.74 2_Gyro-NS-CT_Dnll pipe (1) 2,820.00 25.42 184.54 2,545.42 2,482.02 809.83 659.88 5,999,088.56 566,174.71 4.98 -660.45 2_Gyro-NS-CT_Drill pipe (1) 2,830.00 25.32 185.76 2,554.45 2,491.05 -814.10 659.50 5,999,084.29 566,174.36 5.32 -660.07 2_Gym-NS-CT_Drill pipe (1) 2,840.00 25.37 186.84 2,563.49 2,500.09 -818.35 659.03 5,999,080.04 566,173.93 4.65 -659.60 2_Gym-NS-CT_Drill pipe (1) 2,850.00 25.51 187.79 2,572.52 2,509.12 -822.61 658.48 5,999,075.77 566,173.42 4.31 -659.06 2_Gyro-NS-CT_Drill pipe (1) 2,860.00 25.47 189.57 2,581.55 2,518.15 -826.87 657.83 5,999,071.51 566,172.81 7.67 -658.41 2_Gyro-NS-CT_Drill pipe (1) 2,870.00 25.59 190.97 2,590.57 2,527.17 -831.11 657.06 5,999,067.27 566,172.08 6.15 -657.64 2 Gym -NS -CT Drill pipe (1) 2,880.00 25.78 191.93 2,599.58 2,536.18 -835.36 656.20 5,999,063.01 566,171.25 4.57 -656.79 2_Gyr-NS-CT_Dnll pipe (1) 2,890.00 25.88 192.79 2,608.58 2,545.18 -839.61 655.27 5,999,058.75 566,170.36 3.88 -655.86 2_Gym-NS-CT_Dn1l pipe (1) 2,900.00 26.01 193.57 2,617.58 2,554.18 -843.87 654.27 5,999,054.48 566,169.40 3.65 -654.86 2_Gyro-NS-CT Dnll pipe (1) 2,910.00 26.28 194.29 2,626.55 2,563.15 -848.15 653.21 5,999,050.19 566,168.37 4.17 853.80 2_Gyro-NS-CT_Drill pipe (1) 2,920.00 26.63 195.53 2,635.51 2,572.11 -852.45 652.07 5,999,045.88 566,167.27 6.54 -652.66 2_Gyro-NS-CT_Drill pipe (1) 2,930.00 26.66 197.21 2,644.44 2,581.04 -856.76 650.80 5,999,041.57 566,165.04 7.54 851.40 2_Gyro-NS-CT_Drlll pipe (1) 2,940.00 27.02 198.31 2,653.37 2,589.97 -861.05 649.43 5,999,037.26 566,164.70 6.13 -650.03 2_Gyro-NS-CT_Dnll pipe (1) 2,950.00 27.24 199.17 2,662.27 2,598.87 -865.37 647.96 5,999,032.93 566,163.27 4.50 -648.56 2_Gyro-NS-CT_Driil pipe (1) 2,960.00 27.45 199.97 2,671.15 2,607.75 -869.70 646.42 5,999,028.58 566,161.77 4.23 -647.03 2_Gyro-NSCT_Dnll pipe (1) 9/162019 12:30:50PM Page 9 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU S-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU S-203 Survey Calculation Method: Minimum Curvature Design: MPU S-203 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) C) (°) (usft) (usft) (usft) (usft) (ft) (ft) 01001) (ft) Survey Tool Name 2,970.00 28.05 200.71 2,680.00 2,616.60 -874.07 644.80 5,999,024.21 56060.19 6.92 -645.41 2_Gyro-NS-CT_Dnli pipe (1) 2,980.00 28.21 201.61 2,688.82 2,625.42 -878.46 643.10 5,999,019.79 566,158.53 4.53 -643.71 2_Gyro-NS-CT_Drill pipe (1) 2,990.00 28.34 202.84 2,697.63 2,634.23 -882.85 641.31 5,999,015.39 566,156.78 5.97 -641.92 2_Gyro-NS-CT_Drill pipe (1) 3,000.00 28.68 203.79 2,706.41 2,643.01 -887.23 639.42 5,999,011.00 566,154.93 5.67 -640.04 2_Gyro-NS-CT_Drill pipe (1) 3,010.00 28.97 204.44 2,715.17 2,651.77 -891.63 637.45 5,999,006.58 566,152.99 4.27 -638.07 2_Gyro-NS-CT_Drili Pipe (1) 3,020.00 29.05 205.04 2,723.92 2,660.52 -896.04 635.42 5,999,002.16 566,151.00 3.02 -636.05 2_Gyro-NS-CT_Drill pipe (1) 3,030.00 29.37 205.65 2,732.65 2,669.25 -900.45 633.33 5,998,997.73 566,148.95 4.37 -633.96 2_Gyro-NS-CT_Drill pipe (1) 3,040.00 29.47 206.37 2,741.36 2,677.96 -904.86 631.18 5,998,993.30 566,146.84 3.68 -631.81 2_Gyro-NS-CT_Drill pipe (1) 3,050.00 29.42 207.36 2,750.07 2,686.67 -909.25 628.96 5,998,988.89 566,144.66 4.89 -629.59 2_Gyro-NS-CT_DnIl pipe (1) 3,060.00 29.48 208.52 2,758.77 2,695.37 -913.59 626.65 5,998,984.53 566,142.39 5.73 -627.29 2_Gyro-NS-CT Drill pipe (1) 3,070.00 29.76 209.37 2,767.47 2,704.07 -917.91 624.26 5,998,980.18 566,140.04 5.05 -624.90 2_Gyro-NS-CT_Drill pipe (1) 3,080.00 29.75 210.08 2,776.15 2,712.75 -922.22 621.80 5,998,975.85 566,137.61 3.53 -622.44 2_Gyro-NS-CT_Drill Pipe (1) 3,090.00 29.79 210.84 2,784.83 2,721.43 -926.50 619.28 5,998,971.55 566,135.13 3.79 -619.93 2_Gyro-NS-CT_Drill pipe (1) 3,100.00 30.04 211.58 2,793.50 2,730.10 -930.77 616.70 5,998,967.26 566,132.59 4.46 -617.35 2_Gyro-NS-CT_Drill pipe (1) 3,110.00 30.13 212.58 2,802.15 2,738.75 -93502 614.04 5,998,962.99 566,129.96 5.09 -614.69 2_Gyro-NS-CT_Dnll pipe (1) 3,120.00 30.04 213.74 2,810.80 2,747.40 -939.21 611.29 5,998,958.77 566,127.26 5.88 -611.95 2_Gym-NS-CT_Drill pipe (1) 3,130.00 30.47 214.55 2,819.44 2,756.04 -943.38 608.47 5,998,954.58 566,124.47 5.93 -609.12 2_Gyro-NS-CT_Dn1l pipe (1) 3,140.00 30.39 215.36 2,828.06 2,764.66 -947.53 605.56 5,998,950.40 566,121.60 4.18 -606.23 2_Gyro-NS-CT_Drill pipe (1) 3,150.00 30.35 216.16 2,836.69 2,773.29 -951.64 602.61 5,998,946.28 566,118.68 4.06 -603.27 2_Gyro-NS-CT_Drill pipe (1) 3,160.00 30.52 216.86 2,845.31 2,781.91 -955.71 599.60 5,998,942.18 566,115.71 3.93 -600.26 2_Gyro-NS-CT Drill pipe (1) 3,170.00 30.68 217.62 2,853.92 2,790.52 -959.76 596.51 5,998,938.10 566,112.66 4.19 597.18 2_Gyro-NS-CT_Drill pipe (1) 3,180.00 30.72 218.50 2,862.52 2,799.12 -963.78 593.37 5,998,934.05 566,109.55 4.51 -594.04 2_Gyro-NS-CT_Drill pipe (1) 3,190.00 30.94 219.32 2,871.11 2,807.71 -967.77 590.15 5,998,930.04 566,106.37 4.74 -590.82 2_Gyro-NS-CT_Drill pipe (1) 3,200.00 31.20 220.07 2,879.67 2,816.27 -971.74 586.85 5,998,926.04 566,103.11 4.66 -587.53 2_Gyro-NS-CT_Drill pipe (1) 3,210.00 31.28 220.59 2,888.22 2,824.82 -975.69 583.50 5,998,922.06 566,099.78 2.81 -584.18 2_Gyro-NS-CT_Drill pipe (1) 3,220.00 31.50 221.13 2,896.76 2,833.36 -979.63 580.09 5,998,918.09 566,096.41 3.57 -580.77 2_Gyro-NS-CT_Ddil pipe (1) 3,230.00 31.88 221.60 2,905.27 2,841.87 -983.57 576.62 5,998,914.11 566,092.98 4.53 -577.30 2_Gyro-NS-CT_Drill pipe (1) 3,240.00 32.09 222.20 2,913.75 2,850.35 -987.52 573.08 5,998,910.14 566,089.47 3.81 -573.77 2_Gyr -NS-CT_Dnll pipe (1) 3,250.00 32.21 222.90 2,922.22 2,858.82 -991.44 569.48 5,998,906.19 566,085.91 3.91 -570.17 2_Gyre-NS-CT_Drill pipe (1) 3,260.00 32.73 223.46 2,930.65 2,867.25 -995.35 565.81 5,998,902.24 566,082.27 6.01 -566.50 2_Gyro-NS-CT_Drill pipe (1) 3,270.00 32.99 223.99 2,939.05 2,875.65 -999.27 562.06 5,998,898.29 566,078.56 3.88 -562.75 2 Gyro-NS-CT_Drill pipe (1) 3,280.00 33.05 224.45 2,947.44 2,884.04 -1,003.18 558.26 5,998,894.35 566,074.79 2.58 -558.96 2_Gyro-NS-CT_Drill pipe (1) 3,290.00 33.37 224.70 2,955.80 2,892.40 -1,007.08 554.41 5,998,890.42 566,070.98 3.48 -555.11 2_Gyro-NS-CT_Drill pipe (1) 3,300.00 33.58 225.03 2,964.15 2,900.75 -1,010.99 550.52 5,998,886.48 566,067.12 2.78 -551.23 2 Gyro-NS-CT_Dnll pipe (1) 3,310.00 33.58 225.45 2,972.48 2,909.08 -1,014.88 546.59 5,998,882.55 566,063.23 2.32 -547.30 2_Gyro-NS-CT_Drill pipe (1) 3,320.00 33.82 225.78 2,980.80 2,917.40 -1,018.76 542.63 5,998,878.63 566,059.30 3.02 -543.34 2_Gyro-NS-CT Drill pipe (1) 3,330.00 33.98 226.10 2,989.10 2,925.70 -1,022.64 538.62 5,998,874.72 566,055.33 2.40 -539.33 2_Gyro-NS-CT_Drill pipe (1) 3,340.00 33.96 226.24 2,997.39 2,933.99 -1,026.51 534.59 5,998,870.81 566,051.33 0.81 -535.31 2_Gym-NS-CT_Ddil pipe (1) 3,350.00 34.16 226.32 3,005.67 2,942.27 -1,030.38 530.54 5,998,866.91 566,047.32 2.05 -531.26 2_Gyro-NS-CT_Dn11 pipe (1) 3,360.00 34.40 226.53 3,013.94 2,950.54 -1,034.26 526.46 5,998,862.99 566,043.27 2.68 -527.18 2 Gyro-NS-CT_Dnll pipe (1) 9/16/2019 12:30:50PM Page 10 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU 5-203 MPU 5-203 MPU 5-203 Local Co-ordinate Reference: Well MPU 5-203 TVD Reference: MPU S-203 Actual RKB @ 63.40usft MD Reference: MPU S-203 Actual RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi ND TVDSS +N1S +EI -W Northing Easting DLS Section (usft) (') V) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 3,370.00 34.52 226.76 3,022.18 2,958.78 -1,038.15 522.35 5,998,859.07 566,039.19 1.77 -523.07 2_Gyro-NS-CT_Dhll pipe (1) 3,380.00 34.77 227.05 3,030.41 2,967.01 -1,042.03 518.20 5,998,855.15 566,035.08 2.99 -518.92 2_Gyro-NS-CT_Ddll pipe (1) 3,390.00 35.11 227.39 3,038.61 2,975.21 -1,045.92 513.99 5,998,851.22 566,030.91 3.92 -514.72 2_Gyro-NS-CT_Drill pipe (1) 3,400.00 35.35 227.95 3,046.77 2,983.37 -1,049.81 509.73 5,998,847.30 566,026.68 4.02 -510.46 2_Gyro-NS-CT_Drlll pipe (1) 3,410.00 35.67 228.52 3,054.92 2,991.52 -1,053.68 505.40 5,998,843.40 566,022.38 4.60 -506.13 2_Gyro-NS-CT_Dnll pipe (1) 3,420.00 36.12 229.27 3,063.02 2,999.62 -1,057.53 500.98 5,998,839.50 566,017.99 6.29 -501.72 2_Gyro-NS-CT_Dnll pipe (1) 3,430.00 36.47 229.99 3,071.08 3,007.68 -1,061.36 496.47 5,998,835.63 566,013.52 5.51 497.21 2 Gyro-NS-CT_DO pipe (1) 3,440.00 36.78 230.71 3,079.10 3,015.70 -1,065.17 491.87 5,998,831.79 566,008.96 5.30 -492.62 2_Gyrc-NS-CT Drill pipe (1) 3,450.00 37.34 231.18 3,087.08 3,023.68 -1,068.97 487.19 5,998,827.95 566,004.31 6.28 -487.94 2_Gyro-NS-CT_Drill pipe (1) 3,460.00 37.66 231.71 3,095.01 3,031.61 -1,072.76 482.43 5,998,824.11 565,999.59 4.54 483.18 2_Gyro-NS-CT_Drill pipe (1) 3,470.00 37.84 232.17 3,102.92 3,039.52 -1,076.54 477.61 5,998,820.30 565,994.80 3.34 478.36 2_Gyro-NS-CT_Drill pipe (1) 3,480.00 38.26 232.44 3,110.80 3,047.40 -1,080.30 472.74 5,998,816.49 565,989.96 4.52 -473.49 2_Gyro-NS-CT Dnll pipe (1) 3,490.00 38.65 232.71 3,118.63 3,055.23 -1,084.08 467.80 5,998,812.66 565,985.05 4.25 -468.55 2_Gyro-NS-CT_Dnll pipe (1) 3,500.00 38.87 233.05 3,126.43 3,063.03 -1,087.86 462.81 5,998,808.84 565,980.09 3.06 -463.56 2_Gyro-NS-CT_Drili pipe (1) 3,510.00 39.35 233.30 3,134.18 3,070.78 -1,091.64 457.76 5,998,805.02 565,975.08 5.05 -458.52 2_Gyro-NS-CT_D611 pipe (1) 3,520.00 39.66 233.55 3,141.90 3,078.50 -1,095.43 452.65 5,998,801.18 565,970.00 3.48 -453.41 2_Gyro-NS-CT_Drill pipe (1) 3,530.00 39.92 233.79 3,149.58 3,086.18 -1,099.23 447.49 5,998,797.35 565,964.88 3.02 -448.26 2_Gyro-NS-CT_Drill pipe (1) 3,540.00 40.35 234.10 3,157.23 3,093.83 -1,103.02 442.28 5,998,793.51 565,959.70 4.74 -443.05 2_Gyro-NSCT_Drill pipe (1) 3,550.00 40.77 234.51 3,164.83 3,101.43 -1,106.81 437.00 5,998,789.67 565,954.46 4.97 -437.77 2_Gyro-NS-CT Dnll pipe (1) 3,560.00 40.97 234.89 3,172.39 3,108.99 -1,110.59 431.66 5,998,785.84 565,949.15 3.19 -432.43 2_Gyro-NS-CT_Driil pipe (1) 3,570.00 41.24 235.27 3,179.92 3,116.52 -1,114.36 426.27 5,998,782.03 565,943.79 3.68 -427.05 2_Gyro-NS-CT_Dnll pipe (1) 3,580.00 41.72 235.60 3,187.42 3,124.02 -1,118.11 420.81 5,998,778.23 565,938.37 5.27 -421.59 2_Gyro-NS-CT_Drill pipe (1) 3,590.00 41.97 235.97 3,194.87 3,131.47 -1,121.87 415.30 5,998,774.43 565,932.89 3.51 -416.08 2_Gyro-NS-CT_Drill pipe (1) 3,600.00 42.07 236.35 3,202.29 3,138.89 -1,125.59 409.74 5,998,770.65 565,927.36 2.73 410.52 2 -Gym -NS -CT Ddll pipe(1) 3,610.00 42.47 236.63 3,209.69 3,146.29 -1,129.31 404.13 5,998,766.89 565,921.79 4.42 -404.92 2_Gyro-NS-CT_Dnll pipe (1) 3,620.00 42.58 237.07 3,217.06 3,153.66 -1,133.00 398.47 5,998,763.14 565,916.16 3.17 -399.26 2_Gyro-NS-CT_Drill pipe (1) 3,630.00 42.72 237.67 3,224.42 3,161.02 -1,136.66 392.76 5,998,759.44 565,910.49 4.30 -393.56 2_Gyre-NS-CT_Dnll pipe (1) 3,640.00 42.99 238.05 3,231.75 3,168.35 -1,140.27 387.00 5,998,755.77 565,904.76 3.74 -387.80 2_Gyno-NS-CT_Drill pipe (1) 3,650.00 43.18 238.45 3,239.05 3,175.65 -1,143.87 381.20 5,998,752.13 565,898.99 3.33 -381.99 2_Gyro-NS-CT Drill pipe (1) 3,660.00 43.17 238.88 3,246.35 3,182.95 -1,147.43 375.35 5,998,748.52 565,893.17 2.94 -376.15 2_Gyro-NS-CT_Dnll pipe (1) 3,670.00 43.59 239.23 3,253.61 3,190.21 -1,150.96 369.46 5,998,744.94 565,887.32 4.84 -370.26 2_Gyro-NS-CT_D611 pipe (i) 3,680.00 44.05 239.79 3,260.83 3,197.43 -1,154.47 363.49 5,998,741.37 565,881.38 6.02 -364.30 2_Gyro-NS-CT_Drili pipe (1) 3,690.00 44.29 240.42 3,268.00 3,204.60 -1,157.94 357.45 5,998,737.84 565,875.37 5.00 -358.26 2_ Gyro-NS-CT_Drill pipe (1) 3,700.00 44.75 240.99 3,275.13 3,211.73 -1,161.38 351.34 5,998,734.36 565,869.29 6.09 -352.15 2 Gyro-NS-CT_Drill pipe(1) 3,710.00 45.21 241.49 3,282.21 3,218.81 -1,164.78 345.14 5,998,730.91 565,863.12 5.80 -345.96 2_Gyro-NS-CT_Drill pipe (1) 3,720.00 45.49 242.00 3,289.23 3,225.83 -1,168.14 338.88 5,998,727.48 565,856.89 4.58 -339.69 2_Gyro-NS-CT_Dnll pipe (1) 3,730.00 45.86 242.50 3,296.22 3,232.82 -1,171.47 332.54 5,998,724.10 565,850.58 5.15 -333.36 2_Gyro-NS-CT_Drill pipe (1) 3,740.00 46.25 242.92 3,303.16 3,239.76 -1,174.78 326.15 5,998,720.74 565,844.22 4.94 -326.97 2_ Gyra-NSCT_Drill pipe (1) 3,750.00 46.46 243.46 3,310.06 3,246.66 -1,178.04 319.69 5,998,717.42 565,837.79 4.44 -320.51 2_Gyro-NS-CT_Drlll pipe (1) 3,760.00 46.67 244.04 3,316.94 3,253.54 -1,181.25 313.18 5,998,714.15 565,831.30 4.71 -314.00 2 -GYM -NS -CT Dnll pipe (1) 9/162019 12:30.'50PM Page 11 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU S-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKS @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU S-203 Survey Calculation Method: Minimum Curvature Design: MPU S-203 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) V) (`) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 3,770.00 47.13 244.42 3,323.77 3,260.37 -1,184.43 306.60 5,998,710.92 565,824.76 5.37 -307.43 2 Gyro-NS-CT_Drill pipe (1) 3,780.00 47.31 244.83 3,330.56 3,267.16 -1,187.57 299.97 5,998,707.72 565,818.15 3.51 -300.80 2_Gyro-NS-CT_Ddll pipe (1) 3,790.00 47.37 245.30 3,337.34 3,273.94 -1,190.67 293.30 5,998,704.56 565,811.51 3.51 -294.13 2_Gyro-NS-CT_Drill pipe (1) 3,800.00 48.01 245.61 3,344.07 3,280.67 -1,193.74 286.57 5,998,701.43 565,804.81 6.80 -287.41 2_Gyro-NS-CT_Drill pipe (1) 3,810.00 48.30 245.96 3,350.74 3,287.34 -1,196.80 279.78 5,998,698.32 565,798.05 3.90 -280.61 2_Gyro-NS-CT_Drill pipe (1) 3,820.00 48.54 246.25 3,357.38 3,293.98 -1,199.83 272.94 5,998,695.23 565,791.24 3.24 -273.78 2 Gyro-NS-CT_Drill pipe (1) 3,830.00 49.09 246.55 3,363.96 3,300.56 -1,202.84 266.04 5,998,692.15 565,784.37 5.95 -266.88 2_Gyro-NS-CT_Drill pipe (1) 3,840.00 49.18 246.91 3,370.51 3,307.11 -1,205.83 259.10 5,998,689.10 565,777.45 2.87 -259.94 2_Gyro-NS-CT_Drill pipe (1) 3,850.00 49.18 247.24 3,377.04 3,313.64 -1,208.78 252.13 5,998,686.10 565,770.50 2.50 -252.97 2_Gyro-NS-CT_Drill pipe (1) 3,860.00 49.48 247.48 3,383.56 3,320.16 -1,211.70 245.13 5,998,683.12 565,763.53 3.51 -245.97 2_Gyro-NS-CT_Drill pipe (1) 3,870.00 49.74 247.88 3,390.04 3,326.64 -1,214.59 238.08 5,998,680.16 565,756.51 4.01 -238.93 2_Gyr -NS-CT-Drill pipe (1) 3,880.00 49.90 248.30 3,396.49 3,333.09 -1,217.44 230.99 5,998,677.25 565,749.45 3.59 -231.84 2_Gyro-NS-CT_Dfill pipe (1) 3,890.00 50.30 248.66 3,402.91 3,339.51 -1,220.25 223.85 5,998,674.37 565,742.34 4.86 -224.71 2_Gyro-1\18-CT Drill pipe (1) 3,900.00 50.73 249.01 3,409.26 3,345.86 -1,223.04 216.66 5,998,671.52 565,735.16 5.08 -217.51 2_Gyro-NS-CT_Drill pipe (1) 3,910.00 50.86 249.41 3,415.59 3,352.19 -1,225.79 209.41 5,998,668.71 565,727.95 3.36 -210.27 2_Gyro-NS-CT_Drill pipe (1) 3,920.00 51.08 249.76 3,421.88 3,358.48 -1,228.50 202.13 5,998,665.94 565,720.69 3.50 -202.99 2_Gyro-NS-CT_Drill pipe (1) 3,930.00 51.66 250.02 3,428.13 3,364.73 -1,231.19 194.80 5,998,663.19 565,713.38 6.15 -195.66 2_Gyro-NS-CT_Drill pipe (1) 3,940.00 51.87 250.47 3,434.31 3,370.91 -1,233.84 187.40 5,998,660.47 565,706.01 4.11 -188.27 2_Gyro-NS-CT_Drill pipe (1) 3,950.00 52.01 250.95 3,440.48 3,377.08 -1,236.44 179.97 5,998,657.80 565,698.60 4.03 -180.84 2_Gyro-NS-CT_Drill pipe (1) 3,960.00 52.85 251.26 3,446.58 3,383.18 -1,239.01 172.47 5,998,655.17 565,691.13 8.75 -173.34 2_Gyro-NS-CT_Drill pipe (1) 3,970.00 52.75 251.66 3,452.62 3,389.22 -1,241.54 164.92 5,998,652.57 565,683.60 3.34 -165.79 2_Gyro-NS-CT_Drill pipe (1) 3,980.00 52.79 252.08 3,458.67 3,395.27 -1,244.02 157.36 5,998,650.03 565,676.05 3.37 -158.22 2_Gyro-NS-CT_Drill pipe (1) 3,990.00 53.33 252.44 3,464.68 3,401.28 -1,246.45 149.74 5,998,647.53 565,668.46 6.12 -150.61 2_Gyro-NS-CT_Drill pipe (1) 4,000.00 53.58 252.89 3,470.64 3,407.24 -1,248.85 142.07 5,998,645.06 565,660.82 4.40 -142.95 2_Gyro-NS-CT_Drill plpe (1) 4,010.00 53.69 253.25 3,476.57 3,413.17 -1,251.19 134.37 5,998,642.65 565,653.14 3.10 -135.24 2_Gyro-NS-CT_Dnl1 pipe (1) 4,020.00 54.17 253.65 3,482.45 3,419.05 -1,253.50 126.62 5,998,640.28 565,645.41 5.79 -127.50 2_Gyro-NS-CT_Drill pipe (1) 4,030.00 54.47 254.15 3,488.29 3,424.89 -1,255.75 118.82 5,998,637.96 565,637.63 5.05 -119.69 2_Gyro-NS-CT_Drill pipe (1) 4,040.00 54.55 254.48 3,494.09 3,430.69 -1,257.95 110.98 5,998,635.69 565,629.81 2.80 -111.86 2 -Gyro -NS -CT -Drill pipe (1) 4,050.00 54.92 254.71 3,499.87 3,436.47 -1,260.12 103.11 5,998,633.45 565,621.96 4.15 -103.99 2_Gyro-NS-CT_13611 pipe (1) 4,060.00 55.35 254.95 3,505.58 3,442.18 -1,262.26 95.19 5,998,631.24 565,614.06 4.73 -96.07 2_Gyro-NS-CT Drill pipe (1) 4,070.00 55.35 255.22 3,511.27 3,447.87 -1,264.38 87.24 5,998,629.05 565,606.13 2.22 -88.12 2_Gyro-NS-CT_Drill pipe (1) 4,080.00 55.44 255.54 3,516.95 3,453.55 -1,266.46 79.27 5,998,626.90 565,598.18 2.78 -80.16 2_Gyro-NS-CT_Drill pipe (1) 4,090.00 56.11 255.83 3,522.57 3,459.17 -1,268.50 71.26 5,998,624.79 565,590.19 7.12 -72.15 2_Gyro-NS-CT_Drill pipe (1) 4,100.00 56.09 256.08 3,528.15 3,464.75 -1,270.52 63.21 5,998,622.71 565,582.16 2.08 -64.10 2_Gyro-NS-CT_Drill pipe(1) 4,110.00 56.08 256.30 3,533.73 3,470.33 -1,272.50 55.15 5,998,620.65 565,574.12 1.83 -56.04 2_Gyro-NS-CT_Drill pipe (1) 4,120.00 56.69 256.47 3,539.26 3,475.86 -1,274.46 47.06 5,998,618.62 565,566.04 6.26 -47.95 2 Gyro-NS-CT_Drill pipe (1) 4,130.00 56.88 256.78 3,544.74 3,481.34 -1,276.39 38.92 5,998,616.62 565,557.92 3.22 -39.81 2_Gyro-NS-CT_Drill pipe (1) 4,140.00 56.94 257.07 3,550.20 3,486.80 -1,278.29 30.76 5,998,614.65 565,549.78 2.50 -31.65 2_ Gyro-NS-CT_Drill pipe (1) 4,150.00 57.83 257.24 3,555.59 3,492.19 -1,280.16 22.55 5,998,612.71 565,541.58 9.01 -23.44 2 Gyro-NS-CT_Drill pipe (1) 4,160.00 58.26 257.47 3,560.88 3,497.48 -1,282.02 14.27 5,998,610.78 565,533.32 4.72 -15.16 2_Gyro-NS-CT_Drill pipe (1) 9/16/2019 12:30:50PM Page 12 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU S-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU S-203 Survey Calculation Method: Minimum Curvature Design: MPU S-203 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (') M (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 4,170.00 58.14 257.72 3,566.15 3,502.75 -1,283.85 5.97 5,998,608.88 565,525.04 2.44 5.86 2_Gyro-NS-CT_Drill pipe (1) 4,180.00 58.60 257.87 3,571.40 3,508.00 -1,285.65 -2.36 5,998,607.01 565,516.73 4.77 1.46 2_Gyro-NS-CT_Drill pipe (1) 4,190.00 59.09 257.99 3,576.57 3,513.17 -1,287.44 -10.72 5,998,605.14 565,508.38 5.01 9.82 2_Gyro-NS-CT_Drill pipe (1) 4,200.00 59.24 258.18 3,581.70 3,518.30 -1,289.21 -19.13 5,998,603.30 565,499.99 2.22 18.23 2_Gyro-NS-CT_Dnll pipe (1) 4,210.00 59.82 258.38 3,586.77 3,523.37 -1,290.96 -27.56 5,998,601.47 565,491.57 6.05 26.66 2_Gyro-NS-CT_Dnll pipe (1) 4,220.00 60.42 258.62 3,591.75 3,528.35 -1,292.69 -36.06 5,998,599.67 565,483.09 6.35 35.16 2_Gyn -NS-CT-Drill pipe (1) 4,230.00 60.58 258.79 3,596.67 3,533.27 -1,294.39 44.60 5,998,597.89 565,474.57 2.18 43.69 2 Gym-NS-CT_Drill pipe (1) 4,240.00 60.95 258.95 3,601.56 3,538.16 -1,296.08 -53.16 5,998,596.13 565,466.03 3.95 52.25 2_Gyro-NS-CT_Dnll pipe (1) 4,250.00 61.43 259.11 3,606.38 3,542.98 -1,297.74 -61.76 5,998,594.39 565,457.44 5.00 60.85 2_Gyro-NS-CT_Drill pipe (1) 4,260.00 61.46 259.32 3,611.16 3,547.76 -1,299.39 -70.39 5,998,592.67 565,448.83 1.87 69.48 2_Gyro-NS-CT_Dnll pipe (1) 4,270.00 61.37 259.50 3,615.94 3,552.54 -1,301.00 -79.02 5,998,590.98 565,440.21 1.82 78.11 2_Gyro-NS-CT_Drill pipe (1) 4,280.00 61.83 259.59 3,620.70 3,557.30 -1,302.60 -87.67 5,998,589.31 565,431.58 4.67 86.76 2_Gyro-NS-CT_Drill pipe (1) 4,290.00 61.81 259.78 3,625.42 3,562.02 -1,304.18 -96.34 5,998,587.65 565,422.92 1.69 95.43 2_Gyro-NS-CT_Ddll pipe (1) 4,300.00 61.69 259.97 3,630.15 3,566.75 -1,305.72 -105.01 5,998,586.03 565,414.26 2.06 104.10 2_Gyro-NS-CT_Dnll pipe (1) 4,310.00 62.45 260.09 3,634.84 3,571.44 -1,307.25 -113.72 5,998,584.42 565,405.57 7.67 112.80 2_Gyro-NS-CT_Drill pipe (1) 4,320.00 62.67 260.26 3,639.45 3,576.05 -1,308.77 -122.46 5,998,562.83 565,396.84 2.67 121.55 2_Gyro-NS-CT_Drill pipe (1) 4,330.00 62.50 260.40 3,644.05 3,580.65 -1,310.26 -131.21 5,998,581.26 565,388.11 2.11 130.30 2_Gyro-NS-CT_Drill pipe (I) 4,340.00 63.22 260.42 3,648.61 3,585.21 -1,311.74 -139.99 5,998,579.71 565,379.35 7.20 139.07 2_Gyro-NS-CT_Drill pipe (1) 4,350.00 63.37 260.51 3,653.11 3,589.71 -1,313.22 -148.80 5,998,578.15 565,370.55 1.70 147.88 2_Gyro-NS-CT_Drill pipe (1) 4,360.00 63.26 260.61 3,657.60 3,594.20 -1,314.69 -157.61 5,998,576.61 565,361.75 1.42 156.69 2_Gyro-NS-CT_Dnll pipe (1) 4,370.00 63.73 260.68 3,662.06 3,598.66 -1,316.14 -166.44 5,998,575.07 565,352.94 4.74 165.52 2_Gyro-NS-CT_Drill pipe (1) 4,380.00 64.19 260.78 3,666.45 3,603.05 -1,317.59 -175.31 5,998,573.55 565,344.08 4.69 174.39 2_Gyro-NS-CT_Drill pipe (1) 4,390.00 64.40 260.89 3,670.79 3,607.39 -1,319.02 -184.20 5,998,572.04 565,335.20 2.32 183.28 2_Gyro-NS-CT_Drill pipe (1) 4,400.00 65.07 260.96 3,675.06 3,611.66 -1,320.45 -193.13 5,998,570.53 565,326.28 6.73 192.21 2_Gyro-NS-CT_Will pipe (1) 4,410.00 65.67 260.99 3,679.22 3,615.82 -1,321.88 -202.11 5,998,569.03 565,317.32 6.01 201.19 2_Gyro-NS-CT_Dnll pipe (1) 4,420.00 65.82 261.06 3,683.33 3,619.93 -1,323.30 -211.12 5,998,567.53 565,308.33 1.63 210.19 2_Gyro-NS-CT_Dnll pipe (1) 4,430.00 66.04 261.17 3,687.41 3,624.01 -1,324.71 -220.14 5,998,566.04 565,299.32 2.42 219.21 2 -Gym -NS -CT -Drill pipe (1) 4,440.00 67.11 261.22 3,691.38 3,627.98 -1,326.11 -229.20 5,998,564.55 665,290.27 10.71 228.28 2_Gyro-NS-CT Drill pipe (1) 4,450.00 67.55 261.43 3,695.24 3,631.84 -1,327.51 -238.33 5,998,563.08 565,281.16 4.81 237.40 2_Gyro-NS-CT_Dnll pipe (1) 4,460.00 67.62 261.66 3,699.05 3,635.65 -1,328.86 -247.47 5,998,561.64 565,272.03 2.24 246.54 2_Gyro-NS-CT_Drill pipe (1) 4,470.00 68.65 261.74 3,702.78 3,639.38 -1,330.20 -256.65 5,998,560.22 565,262.86 10.33 255.72 2_Gyro-NS-CT_Drill pipe (1) 4,480.00 68.68 261.84 3,706.41 3,643.01 -1,331.53 -265.87 5,998,558.81 565,253.65 0.98 264.94 2_Gyro-NS-CT_Drill pipe (1) 4,490.00 68.53 261.91 3,710.06 3,646.66 -1,332.85 -275.09 5,998,557.42 565,244.45 1.64 274.16 2_Gyro-NS-CT_Drill pipe (1) 4,500.00 69.42 261.91 3,713.65 3,650.25 -1,334.16 -284.33 5,998,556.02 565,235.22 8.90 283.40 2 Gyro-NS-CT_0611 pipe (1) 4,510.00 69.72 262.00 3,717.14 3,653.74 -1,335.48 -293.61 5,998,554.63 565,225.95 3.12 292.68 2_Gyro-NS-CT_Drill pipe (1) 4,520.00 69.70 262.14 3,720.61 3,657.21 -1,336.77 -302.90 5,998,553.25 565,216.67 1.33 301.97 2_Gyro-NS-CT_Drill pipe (1) 4,530.00 70.23 262.20 3,724.03 3,660.63 -1,338.05 -312.21 5,998,551.89 565,207.38 5.33 311.27 2_Gyro-NS-CT_Dnll pipe (1) 4,540.00 70.50 262.30 3,727.39 3,663.99 -1,339.32 -321.54 5,998,550.54 565,198.06 2.86 320.60 2_Gyro-NS-CT_Drill pipe (1) 4,550.00 70.51 262.39 3,730.73 3,667.33 -1,340.58 -330.88 5,998,549.20 565,188.73 0.85 329.95 2_Gyro-NS-CT_Drill pipe (1) 4,560.00 70.90 262.52 3,734.04 3,670.64 -1,341.81 -340.24 5,998,547.88 565,179.38 4.09 339.30 2_Gyro-NS-CT_Drill pipe (1) 9/162019 12:30:50PM Page 13 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU S-203 Survey Calculation Method: Minimum Curvature Design: MPU 5-203 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,570.00 71.59 262.71 3,737.25 3,673.85 -1,343.03 -349.63 5,998,546.58 565,170.01 7.13 348.69 2_Gyro-NS-CT_Dnll pipe (1) 4,580.00 71.62 262.98 3,740.41 3,677.01 -1,344.21 -359.04 5,998,545.32 565,160.60 2.58 358.11 2_Gyro-NS-CT_Drill pipe (1) 4,590.00 72.01 263.18 3,743.53 3,680.13 -1,345.36 -368.48 5,998,544.09 565,151.18 4.34 367.54 2 Gyro-NS-CT_Drill pipe (1) 4,600.00 72.84 263.28 3,746.55 3,683.15 -1,346.48 -377.94 5,998,542.88 565,141.73 8.35 377.00 2_Gyro-NS-CT_Drill pipe (1) 4,610.00 72.99 263.42 3,749.49 3,686.09 -1,347.59 -387.44 5,998,541.69 565,132.24 2.01 386.50 2_Gyro-NS-CT_Dnll pipe (1) 4,620.00 73.11 263.53 3,752.40 3,689.00 -1,348.68 -396.94 5,998,540.52 565,122.75 1.60 396.00 2_Gym-NS-CT_Drill pipe (1) 4,630.00 74.32 263.61 3,755.20 3,691.80 -1,349.75 -406.48 5,998,539.36 565,113.22 12.12 405.54 2 Gyra-NS-CT_DrIl pipe (1) 4,640.00 74.88 263.79 3,757.86 3,694.46 -1,350.81 -416.06 5,998,538.22 565,103.65 5.86 415.12 2_Gyro-NS-CT_Drll pipe (1) 4,650.00 75.60 263.89 3,760.41 3,697.01 -1,351.85 425.68 5,998,537.10 565,094.05 7.26 424.73 2_Gyro-NS-CT_Drill pipe (1) 4,660.00 76.70 263.95 3,762.80 3,699.40 -1,352.87 435.33 5,998,535.99 565,084.40 11.02 434.39 2_Gyro-NS-CT_Dnll pipe (1) 4,670.00 77.11 264.07 3,765.07 3,701.67 -1,353.89 445.02 5,998,534.89 565,074.73 4.26 444.07 2_Gym-NS-CT_DnIl pipe (1) 4,680.00 76.93 264.18 3,767.31 3,703.91 -1,354.89 454.71 5,998,533.80 565,065.04 2.09 453.76 2_Gym-NS-CT_Drill pipe (1) 4,690.00 77.48 264.19 3,769.53 3.706.13 -1,355.88 464.41 5,998,532.73 565,055.35 5.50 463.47 2_Gyro-NS-CT_Drill pipe (1) 4,700.00 77.73 264.26 3,771.67 3,708.27 -1,356.86 474.13 5,998,531.66 565,045.64 2.59 473.18 2_Gym-NS-GT_Dnll pipe (1) 4,710.00 77.86 264.33 3,773.79 3,710.39 -1,357.83 483.85 5,998,530.61 565,035.93 1.47 482.91 2_Gyro-NS-CT_Dnll pipe (1) 4,720.00 78.48 264.36 3,775.84 3,712.44 -1,358.80 493.59 5,998,529.56 565,026.20 6.21 492.65 2_Gyro-NS-CT_Drill pipe (1) 4,730.00 78.81 264.36 3,777.81 3,714.41 -1,359.76 -503.35 5,998,528.51 565,016.45 3.30 502.40 2_Gyro-NS-CT_Drlll pipe (1) 4,740.00 78.95 264.33 3,779.74 3,716.34 -1,360.73 -513.12 5,998,527.46 565,006.70 1.43 512.17 2_Gyro-NS-CT_Drill pipe (1) 4,750.00 79.20 264.29 3,781.63 3,718.23 -1,361.70 -522.89 5,998,526.40 564,996.94 2.53 521.94 2 Gyro-NS-CT_Dnll pipe (1) 4,760.00 79.39 264.28 3,783.49 3,720.09 -1,362.68 -532.66 5,998,525.33 564,987.17 1.90 531.71 2_Gyro-NS-CT_Drill pipe (1) 4,770.00 79.33 264.31 3,785.34 3,721.94 -1,363.65 542.44 5,998,524.27 564,977.40 0.67 541.49 2_Gym-NS-CT_Drill pipe (1) 4,780.00 79.36 264.33 3,787.18 3,723.78 -1,364.63 -552.22 5,998,523.21 564,967.63 0.36 551.27 2_Gyro-NS-CT_Drill pipe (1) 4,790.00 79.87 264.30 3,788.99 3,725.59 -1,365.60 -562.01 5,998,522.15 564,957.85 5.11 561.06 2_Gyro-NS-CT_Drill pipe (1) 4,800.00 80.01 264.44 3,790.73 3,727.33 -1,366.57 -571.81 5,998,521.10 564,948.06 1.96 570.85 2_Gym-NS-CT_DnIl pipe (1) 4,810.00 80.31 264.65 3,792.44 3,729.04 -1,367.50 -581.62 5,998,520.08 564,938.26 3.64 580.66 2_Gyro-NS-CT_Drill pipe (1) 4,820.00 81.50 264.81 3,794.02 3,730.62 -1,368.41 -591.45 5,998,519.08 564,928.44 12.00 590.49 2_Gyro-NS-CT_Drill pipe (1) 4,830.00 82.17 265.01 3,795.44 3,732.04 -1,369.29 -601.31 5,998,518.12 564,918.59 6.99 600.35 2 Gyro -NS -CT Dnll pipe (1) 4,840.00 82.82 265.28 3,796.75 3,733.35 -1,370.13 -611.19 5,998,517.19 564,908.72 7.03 610.23 2_Gyro-NS-CT_Drill pipe (1) 4,846.77 83.36 265.31 3,797.56 3,734.16 -1,370.68 -617.89 5,998,516.58 564,902.03 7.99 616.93 2_Gym-NS-CT_Dnll pipe (1) 4,904.94 84.70 268.40 3,803.62 3,740.22 -1,373.85 -675.64 5,998,512.91 564,844.30 5.76 674.69 2_MWD+IFR2+MS+Sa9(2) 4,968.52 83.38 269.42 3,810.22 3,746.82 -1,375.05 -736.87 5,998,511.15 564,781.10 2.62 737.91 2 MWD+IFR2+MS+Sag (2) 5,032.31 83.39 270.41 3,817.57 3,754.17 -1,375.15 -802.23 5,998,510.50 564,717.75 1.54 801.27 2_MWD+IFR2+MS+Sag (2) 5,096.62 84.01 271.22 3,824.62 3,761.22 -1,374.24 -866.15 5,998,510.85 564,653.83 1.58 865.19 2_MWD+IFR2+MS+Sag (2) 5,159.75 86.43 272.63 3,829.88 3,766.48 -1,372.13 -929.01 5,998,512.41 564,590.95 4.43 928.06 2_MWD+IFR2+MS+Sag(2) 5,223.17 87.16 272.57 3,833.43 3,770.03 -1,369.25 -992.27 5,998,514.73 564,527.68 1.15 991.31 2_MWD+IFR2+MS+Sag (2) 5,286.77 88.78 272.34 3,835.68 3,772.28 -1,366.53 -1,055.77 5,998,516.89 564,464.17 2.57 1,054.82 2_MWD+IFR2+MS+Sag (2) 5,309.42 89.58 272.45 3,836.01 3,772.61 -1,365.58 -1,078.40 5,998,517.64 564,441.53 3.57 1,077.44 2_MWD+IFR2+MS+Sag (2) 5,405.95 90.42 275.41 3,836.01 3,772.61 -1,358.97 -1,174.69 5,998,523.41 564,345.20 3.19 1,173.74 2_MWD+IFR2+MS+Sag (3) 5,469.78 90.73 275.77 3,835.37 3,771.97 -1,352.75 -1,238.21 5,998,529.07 564,281.63 0.74 1,237.27 2_MWD+IFR2+MS+Sag (3) 5,532.85 92.70 276.11 3,833.48 3,770.08 -1,346.23 -1,300.91 5,998,535.04 564,218.88 3.17 1,299.97 2_MWD+IFR2+MS+Sag (3) 9/16/2019 12:30:50PM Page 14 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU 5-203 Survey Calculation Method: Minimum Curvature Design: MPU 5-203 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 5,597.02 94.56 277.08 3,829.42 3,766.02 -1,338.87 -1,364.53 5,998,541.84 564,155.21 3.27 1,363.59 2_MWD+IFR2+MS+Sag (3) 5,660.62 94.80 276.89 3,824.23 3,760.83 -1,331.17 -1,427.44 5,998,548.99 564,092.23 0.48 1,426.51 2_MWD+IFR2+MS+Sag (3) 5,724.27 94.62 274.95 3,819.00 3,755.60 .1,324.62 -1,490.54 5,998,554.98 564,029.09 3.05 1,489.61 2_MWD+IFR2+MS+Sag(3) 5,787.86 93.94 273.43 3,814.25 3,750.85 -1,319.99 -1,553.78 5,998,559.06 563,965.82 2.61 1,552.86 2_MWD+IFR2+MS+Sag(3) 5,851.07 93.81 272.21 3,809.98 3,746.58 -1,316.89 -1,616.77 5,998,561.61 563,902.81 1.94 1,615.85 2_MWD+IFR2+MS+Sag(3) 5,914.97 93.81 270.41 3,805.74 3,742.34 -1,315.43 -1,680.51 5,998,562.51 563,839.07 2.81 1,679.59 2_MWD+IFR2+MS+Sag(3) 5,978.65 93.38 270.07 3,801.74 3,738.34 -1,315.16 -1,744.06 5,998,562.22 563,775.52 0.86 1,743.14 2_MWD+IFR2+MS+Sag (3) 6,041.96 93.94 269.52 3,797.70 3,734.30 -1,315.39 -1,807.24 5,998,561.44 563,712.35 1.24 1,806.32 2_MWD+IFR2+MS+Sag (3) 6,105.55 93.75 268.65 3,793.44 3,730.04 .1,316.40 -1,870.68 5,998,559.87 563,648.93 1.40 1,869.76 2_MWD+IFR2+MS+Sag (3) 6,169.10 93.01 267.26 3,789.69 3,726.29 -1,318.67 -1,934.07 5,998,557.05 563,585.56 2.47 1,933.15 2_MWD+IFR2+MS+Sag(3) 6,232.57 93.08 266.24 3,786.32 3,722.92 -1,322.26 -1,997.35 5,998,552.90 563,522.32 1.61 1,996.43 2 MWD+IFR2+MS+Sag (3) 6,296.24 93.26 267.74 3,782.80 3,719.40 -1,325.60 -2,060.83 5,998,549.01 563,458.88 2.37 2,059.91 2_MWD+IFR2+MS+Sag (3) 6,360.35 93.94 270.05 3,778.77 3,715.37 -1,326.83 -2,124.80 5,998,547.21 563,394.93 3.75 2,123.87 2_MWD+IFR2+MS+Sag (3) 6,423.88 93.75 271.25 3,774.51 3,711.11 -1,326.11 -2,188.18 5,998,547.37 563,331.55 1.91 2,187.26 2_MWD+IFR2+MS+Sag (3) 6,487.23 93.88 270.93 3,770.30 3,706.90 -1,324.91 -2,251.38 5,998,548.02 563,268.35 0.54 2,250.46 2_MWD+IFR2+MS+Sag (3) 6,550.90 92.39 269.39 3,766.81 3,703.41 -1,324.73 -2,314.95 5,998,547.64 563,204.79 3.36 2,314.03 2_MWD+IFR2+MS+Sag (3) 6,614.58 92.52 268.20 3,764.09 3,700.69 -1,326.07 -2,378.56 5,998,545.75 563,141.20 1.88 2,377.63 2_MWD+IFR2+MS+Sag(3) 6,677.91 92.70 268.05 3,761.20 3,697.80 -1,328.14 -2,441.79 5,998,543.12 563,078.00 0.37 2,440.86 2_MWD+IFR2+MS+Sag(3) 6,741.22 92.52 268.15 3,758.32 3,694.92 -1,330.24 -2,505.00 5,998,540.47 563,014.81 0.33 2,504.07 2 MWD+IFR2+MS+Sag (3) 6,805.38 92.46 268.97 3,755.53 3,692.13 -1,331.85 -2,569.08 5,998,538.30 562,950.76 1.28 2,568.15 2_MWD+IFR2+MS+Sag(3) 6,869.91 93.26 270.58 3,752.31 3,688.91 -1,332.10 -2,633.52 5,998,537.48 562,886.32 2.78 2,632.59 2_MWD+IFR2+MS+Sag(3) 6,932.41 93.51 271.12 3,748.62 3,685.22 -1,331.18 -2,695.91 5,998,537.86 562,823.94 0.95 2,694.98 2_MWD+IFR2+MS+Sag(3) 6,996.29 93.38 271.12 3,744.78 3,681.38 -1,329.93 -2,759.66 5,998,538.54 562,760.18 0.20 2,758.73 2_MWD+IFR2+MS+Sag (3) 7,060.39 93.57 273.98 3,740.90 3,677.50 -1,327A8 .2,823.57 5,998,540.83 562,696.25 4.46 2,822.64 2_MWD+IFR2+MS+Sag (3) 7,124.04 93.20 272.09 3,737.14 3,673.74 -1,323.72 -2,887.02 5,998,543.64 562,632.79 3.02 2,886.09 2_MWD+IFR2+MS+Sag(3) 7,187.73 92.58 271.81 3,733.93 3,670.53 -1,321.56 -2,950.59 5,998,545.24 562,569.20 1.07 2,949.67 2_MWD+IFR2+MS+Sag(3) 7,251.10 92.40 270.68 3,731.17 3,667.77 -1,320.18 -3,013.88 5,998,546.06 562,505.91 1.80 3,012.96 2_MWD+IFR2+MS+Sag (3) 7,314.34 92.45 271.04 3,728.50 3,665.10 .1,319.23 -3,077.06 5,998,546.46 562,442.73 0.57 3,076.14 2_MWO+IFR2+MS+Sag (3) 7,377.83 93.01 270.51 3,725.47 3,662.07 -1,318.38 -3,140.47 5,998,546.76 562,379.32 1.21 3,139.55 2_MWD+IFR2+MS+Sag (3) 7,441.46 92.46 269.24 3,722.44 3,659.04 -1,318.51 -3,204.03 5,998,546.06 562,315.77 2.17 3,203.11 2_MWD+IFR2+MS+Sag (3) 7,505.37 92.58 268.01 3,719.63 3,656.23 -1,320.05 -3,267.86 5,998,543.97 562,251.97 1.93 3,266.93 2_MWD+IFR2+MS+Sag (3) 7,568.58 91.96 268.52 3,717.12 3,653.72 -1,321.96 -3,330.99 5,998,541.51 562,188.86 1.27 3,330.06 2_MWD+IFR2+MS+Sag(3) 7,632.65 91.78 268.81 3,715.03 3,651.63 -1,323.45 -3,395.01 5,998,539.45 562,124.86 0.53 3,394.08 2_MWD+IFR2+MS+Sag(3) 7,695.33 92.70 268.58 3,712.58 3,649.18 -1,324.88 -3,457.62 5,998,537.48 562,062.27 1.51 3,456.70 2 MWD+IFR2+MS+Sag(3) 7,760.12 94.00 269.27 3,708.80 3,645.40 -1,326.09 -3,522.29 5,998,535.70 561,997.62 2.27 3,521.36 2_MWD+IFR2+MS+Sag (3) 7,823.60 93.44 269.94 3,704.68 3,641.28 .1,326.53 -3,585.63 5,998,534.70 561,934.29 1.37 3,584.70 2_MWD+IFR2+MS+Sag(3) 7,887.44 93.14 270.49 3,701.01 3,637.61 -1,326.29 -3,649.37 5,998,534.38 561,870.56 0.98 3,648.44 2_MWD+IFR2+MS+Sag(3) 7,950.58 93.57 270.79 3,697.32 3,633.92 -1,325.58 -3,712.39 5,998,534.54 561,807.54 0.83 3,711.47 2_MWD+IFR2+MS+Sag (3) 8,014.58 94.00 269.86 3,693.09 3,629.69 -1,325.22 -3,776.25 5,998,534.34 561,743.69 1.60 3,775.33 2_MWD+IFR2+MS+Sag (3) 8,073.00 94.23 270.30 3,688.90 3,625.50 -1,325.14 3,834.52 5,998,533.91 561,685.42 0.85 3,833.59 2_MWD+IFR2+MS+Sag(4) 9/16/2019 12:30:50PM Page 15 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU S-203 Actual IRKS @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU S-203 Survey Calculation Method: Minimum Curvature Design: MPU S-203 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) ("1100') (ft) Survey Tool Name 8,140.98 92.08 272.05 3,685.16 3,621.76 -1,323.75 -3,902.38 5,998,534.71 561,617.56 4.08 3,901.45 2_MWD+IFR2+MS+Sag(4) 8,204.54 92.27 273.98 3,682.75 3,619.35 -1,320.41 -3,965.80 5,998,537.49 561,554.12 3.05 3,964.88 2_MWD+IFR2+MS+Sag (4) 8,268.53 93.20 275.79 3,679.69 3,616.29 -1,314.96 -4,029.48 5,998,542.37 561,490.40 3.18 4,028.56 2_MWD+IFR2+MS+Sag (4) 8,332.06 93.44 276.35 3,676.02 3,612.62 -1,308.26 -4,092.55 5,998,548.53 561,427.28 0.96 4,091.63 2_MWD+IFR2+MS+Sag(4) 8,395.77 93.81 276.91 3,671.99 3,608.59 -1,300.92 4,155.71 5,998,555.31 561,364.07 1.05 4,154.80 2_MWD+IFR2+MS+Sag (4) 8,459.73 93.69 277.15 3,667.80 3,604.40 -1,293.11 -4,219.05 5,998,562.57 561,300.66 0.42 4,218.15 2_MWD+IFR2+MS+Sag(4) 8,522.96 93.26 276.24 3,663.97 3,600.57 -1,285.75 -4,281.73 5,998,569.37 561,237.93 1.59 4,280.83 2_MWD+IFR2+MS+Sag(4) 8,587.06 93.69 275.58 3,660.09 3,596.69 -1,279.16 4,345.37 5,998,575.40 561,174.24 1.23 4,344.48 2_MWD+IFR2+MS+Sag (4) 8,650.60 92.64 273.20 3,656.58 3,593.18 -1,274.30 -4,408.62 5,998,579.70 561,110.95 4.09 4,407.73 2_MWD+IFR2+MS+Sag (4) 8,716.22 92.03 270.09 3,653.90 3,590.50 -1,272.42 -4,474.16 5,998,581.01 561,045.41 4.83 4,473.27 2_MWD+IFR2+MS+Sag(4) 8,777.46 91.22 267.89 3,652.17 3,588.77 -1,273.50 -4,535.36 5,998,579.39 560,984.23 3.83 4,534.47 2_MWD+IFR2+MS+Sag (4) 8,80000 91.07 267.52 3,651.72 3,588.32 -1,274.40 -4,557.87 5,998,578.29 560,961.72 1.77 4,556.98 2_MWD+IFR2+MS+Sag(5) 8,842.05 89.06 267.09 3,651.67 3,588.27 -1,276.38 -4,599.88 5,998,575.95 560,919.74 4.89 4,598.98 2_MWD+IFR2+MS+Sag(5) 8,905.69 88.75 268.74 3,652.89 3,589.49 -1,278.70 -4,663.46 5,998,573.08 560,856+19 2.64 4,662.57 2_MWD+1FR2+MS+Sag (5) 8,968.82 87.70 269.19 3,654.84 3,591.44 -1,279.84 -4,726.55 5,998,571.38 560,793.12 1.81 4,725.65 2_MWD+IFR2+MS+Sag (5) 9,032.57 87.26 269.60 3,657.64 3,594.24 -1,280.51 -4,790.23 5,998,570.15 560,729.45 0.94 4,789.34 2_MWD+IFR2+MS+Sag(5) 9,096.11 85.35 269.80 3,661.74 3,598.34 -1,280.84 4,853.64 5,998,569.26 560,666.06 3.02 4,852.74 2 MWD+IFR2+MS+Sag (5) 9,158.46 83.99 269.63 3,667.53 3,604.13 -1,281.15 -4,915.71 5,998,568.41 560,603.99 2.20 4,914.82 2_MWD+IFR2+MS+Sag(5) 9,223.48 84.42 269.89 3,674.09 3,610.69 -1,281.42 -4,980.40 5,998,567.57 560,539.31 0.77 4,979.51 2_MWD+IFR2+MS+Sag(5) 9,286.82 84.29 269.49 3,680.33 3,616.93 -1,281.76 5,043.43 5,998,566.68 560,476.29 0.66 5,042.54 2_MWD+IFR2+MS+Sag (5) 9,348.57 84.98 270.67 3,686.10 3,622.70 -1,281.68 -5,104.91 5,998,566.23 560,414.82 2.21 5,104.01 2_MWD+IFR2+MS+Sag(5) 9,413.94 84.42 271.04 3,692.14 3,628.74 -1,280.70 -5,169.99 5,998,566.63 560,349.74 1.03 5,169.10 2_MWD+IFR2+MS+Sag(5) 9,477.58 83.74 270.99 3,698.70 3,635.30 -1,279.58 -5,233.28 5,998,567.19 560.286.45 1.07 5,232.39 2_MWD+IFR2+MS+Sag (5) 9,540.35 83.73 271.21 3,705.55 3,642.15 -1,278.39 -5,295.67 5,998,567.84 560,224.06 0.35 5,294.77 2_MWD+IFR2+MS+Sag(5) 9,604.44 84.92 271.33 3,711.89 3,648.49 -1,276.97 -5,359.43 5,998,568.70 560,160.30 1.87 5,358.53 2_MWD+IFR2+MS+Sag (5) 9,667.73 84.85 271.00 3,717.53 3,654.13 -1,275.69 5,422.45 5,998,569.43 560,097.27 0.53 5,421.56 2_MWD+IFR2+MS+Sag (5) 9,730.97 84.73 270.58 3,723.27 3,659.87 -1,274.82 -5,485.42 5,998,569.74 560,034.30 0.69 5,484.53 2_MWD+IFR2+MS+Sag (5) 9,793.88 84.55 269.55 3,729.15 3,665.75 -1,274.75 -5,548.06 5,998,569.26 559,971.67 1.66 5,547.17 2_MWD+IFR2+MS+Sag (5) 9,857.27 84.60 268.86 3,735.14 3,671.74 -1,275.63 -5,611.16 5,998,567.83 559,908.59 1.09 5,610.27 2_MWD+IFR2+MS+Sag (5) 9,920.75 84.48 268.05 3,741.18 3,677.78 -1,277.33 -5,674.33 5,998,565.58 559,845.44 1.28 5,673.43 2_MWD+IFR2+MS+Sag (5) 9,983.53 84.73 268.54 3,747.09 3,683.69 -1,279.19 -5,736.80 5,998,563.17 559,782.99 0.87 5,735.91 2_MWD+IFR2+MS+Sag(5) 10,047.59 84.61 269.86 3,753.04 3,689.64 -1,280.08 -5,800.58 5,998,561.72 559,719.24 2.06 5,799.68 2_MWD+IFR2+MS+Sag(5) 10,111.40 84.79 269.83 3,758.93 3,695.53 -1,280.25 -5,864.11 5,998,560.99 559.655.71 0.29 5,863.22 2_MWD+IFR2+MS+Sag (5) 10,175.22 84.60 268.75 3,764.83 3,701.43 -1,281.04 -5,927.65 5,998,559.65 559,592.18 1.71 5,926.76 2_MWD+IFR2+MS+Sag (5) 10,238.62 84.61 267.77 3,770.79 3,707.39 -1,282.96 -5,990.74 5,998,557.18 559,529.12 1.54 6,989.85 2_MWD+IFR2+MS+Sag(5) 10,302.53 85.10 267.91 3,776.52 3,713.12 -1,285.35 -6,054.35 5,998,554.22 559,465.54 0.80 6,053.45 2_MWD+IFR2+MS+Sag(5) 10,366.70 84.60 270.03 3,782.29 3,718.89 -1,286.50 -6,118.25 5,998,552.51 559,401.66 3.38 6,117.35 2_MWD+IFR2+MS+Sag(5) 10,430.19 84,66 270.67 3,788.23 3,724.83 -1,286.12 -6,181.46 5,998,552.34 559,338.46 1.01 6,180.56 2_MWD+IFR2+MS+Sag (5) 10,494.10 84.91 269.66 3,794.04 3,730.64 -1,285.93 -6,245.10 5,998,551.97 559,274.82 1.62 6,244.20 2 MWD+IFR2+MS+Sag (5) 10,557.85 87.27 268.99 3,798.38 3,734.98 -1,286.68 -6,308.69 5,998,550.66 559,211.24 3.85 6,307.79 2_MWD+IFR2+MS+Sag(5) 9/162019 12:30:50PM Page 16 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU S-203 MPU S-203 MPU S-203 Local Co-ordinate Reference: Well MPU S-203 TVD Reference: MPU S-203 Actual RKB @ 63.40usft MD Reference: MPU S-203 Actual RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA survey Map Map Vertical MD Inc Azi TvD TVDSS +NI -S +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,621.19 87.70 268.26 3,801.16 3,737.76 -1,288.20 -6,371.95 5,998,548.59 559,148.01 1.34 6,371.05 2_MWD+IFR2+MS+Sag (5) 10,685.15 87.70 268.19 3,803.73 3,740.33 -1,290.18 -6,435.83 5,998,546.05 559,084.15 0.11 6,434.93 2_MWD+IFR2+MS+Sag (5) 10,748.56 87.82 268.09 3,806.21 3,742.81 -1,292.24 -6,499.16 5,998,543.44 559,020.85 0.25 6,498.26 2_MWD+IFR2+MS+Sag (5) 10,812.15 87.95 268.79 3,808.55 3,745.15 -1,293.97 -6,562.68 5,998,541.15 558,957.35 1.12 6,561.78 2_MWD+IFR2+MS+Sag(5) 10,875.95 85.66 269.51 3,812.11 3,748.71 -1,294.91 -6,626.37 5,998,539.64 558,893.68 3.76 6,625.47 2_MWD+IFR2+MS+Sag (5) 10,939.74 84.48 269.71 3,817.59 3,754.19 -1,295.35 -6,689.92 5,998,538.66 558,830.14 1.88 6,689.02 2_MWD+IFR2+MS+Sag(5) 11,003.23 84.54 270.33 3,823.67 3,760.27 -1,295.32 -6,753.12 5,998,538.12 558,766.95 0.98 6,752.21 2_MWD+IFR2+MS+Sag(5) 11,067.03 81.99 270.36 3,831.15 3,767.75 -1,294.94 -6,816.47 5,998,537.95 558,703.60 4.00 6,815.57 2_MWD+IFR2+MS+Sag (5) 11,130.46 79.62 271.03 3,841.28 3,777.88 -1,294.19 -6,879.08 5,998,538.16 558,641.00 3.88 6,878.17 2_MWD+IFR2+MS+Sag (5) 11,194.19 78.42 271.93 3,853.42 3,790.02 -1,292.57 -6,941.62 5,998,539.22 558,578.45 2.34 6,940.72 2 MWD+IFR2+MS+Sag(5) 11,257.74 80.36 272.42 3,865.12 3,801.72 -1,290.20 -7,004.04 5,998,541.05 558,516.03 3.15 7,003.13 2_MWD+IFR2+MS+Sag (5) 11,321.21 82.55 272.21 3,874.55 3,811.15 -1,287.66 -7,066.75 5,998,543.03 558,453.30 3.47 7,065.85 2_MWD+IFR2+MS+Sag (5) 11,384.99 81.93 270.97 3,883.16 3,819.76 -1,285.91 -7,129.92 5,998,544.23 558,390.12 2.16 7,129.02 2 MWD+IFR2+MS+Sag(5) 11,413.74 80.81 270.53 3,887.48 3,824.08 -1,285.54 -7,158.34 5,998,544.35 558,361.70 4.18 7,157.44 2_MWD+IFR2+MS+Sag (5) 11,470.00 80.81 270.53 3,896.46 3,833.06 -1,285.02 -7,213.87 5,998,544.38 558,306.17 0.00 7,212.97 PROJECTEDto TD I" " „; Benjamin Hand ° Date: 09-16-2019 Checked By: Chelsea Wright j -• a m. Approved By: 1 9/162019 12:30:50PM Page 17 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU S-203PB1 500292364470 Sperry Drilling Definitive Survey Report 16 September, 2019 HALLIBURTON Sporry Drilling Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU 5-203PB1 Design: MPU 5-203PB1 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU 5-203 MPU 5-203 Actual IRKS @ 63.40usft MPU 5-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU S-203 Well Position +NIS +E/ -W Position Uncertainty Wellbore MPU 5-203PB1 Magnetics Model Name 0.00 usft Northing: 5,999,892.50 usft 0.00 usft Easting: 565,507.81 usft 0.00 usft Wellhead Elevation: usft Sample Date Declination (I BGGM2018 8/24/2019 16.53 Latitude: 70° 24'36.560 N Longitude: 149° 27'59.733 W Ground Level: 36.70 usft Dip Angle Field Strength (") (nT) 80.92 57,414.95005886 Design MPU S-203PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 26.70 Vertical Section: Depth From (TVD) +NIS +EI -W Direction (usft) (usft) (usft) (1) 26.70 0.00 0.00 270.04 Survey Program Date 9/13/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 88.88 4,846.77 MPU 5-203PB1 SDI Gyro (MPU 5-203PI 2_Gyro-NS-CT_Drill pipe H037Ga: Continuous on wireline in drill pipe 09/02/2019 4,904.94 5,309.42 MPU S-203PB1 MWD+IFR2+MS+Sag (1 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 08/26/2019 5,405.95 9,730.44 MPU 5-203PB1 MWD+IFR2+MS+Sag (22_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 09/03/2019 Survey Map Map Vertical MD Inc AA TVD TVDSS +N/ -S +E/ -W Northing Fasting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) ("110(1') (ft) Survey Tool Name 26.70 0.00 0.00 26.70 -36.70 0.00 0.00 5,999,892.50 565,507.81 0.00 0.00 UNDEFINED 88.88 0.55 81.39 88.88 25.48 0.04 0.30 5,999,892.55 565,508.10 0.88 -0.30 2_Gym-NS-CT_Drill pipe (1) 96.58 0.49 80.28 96.58 33.18 0.06 0.36 5,999,892.56 565,508.17 0.79 -0.36 2_Gym-NS-CT_Dnll pipe (1) 100.00 0.48 79.04 100.00 36.60 0.06 0.39 5,999,892.56 565,508.20 0.42 -0.39 2 Gyro-NS-CT_Drill pipe (1) 110.00 0.44 74.05 110.00 46.60 0.08 0.47 5,999,892.58 565,508.28 0.57 -0.47 2_Gyro-NS-CT_Dnll pipe (1) 120.00 0.45 70.91 120.00 56.60 0.10 0.54 5,999,892.61 565,508.35 0.26 -0.54 2 -Gyro -NS -CF -Drill pipe (1) 130.00 0.46 75.26 130.00 66.60 0.13 0.62 5,999,892.63 565,508.43 0.36 -0.62 2_Gym-NS-CT_Drill pipe (1) 140.00 0.47 78.77 140.00 76.60 0.14 0.70 5,999,892.65 565,508.51 0.30 -0.70 2_Gym-NS-CT_DnII pipe (1) 150.00 0.48 76.25 150.00 86.60 0.16 0.78 5,999,892.67 565,508.59 0.23 -0.78 2_Gyro-NS-CT_Dnll pipe (1) 160.00 0.47 81.08 160.00 96.60 0.18 0.86 5,999,892.69 565,508.67 0.41 -0.86 2_Gyro-NS-CT_Dnll pipe (1) 170.00 0.51 86.04 170.00 106.60 0.19 0.95 5,999,892.70 565,508.75 0.58 -0.95 2_Gym-NS-CT_Drill pipe (1) 180.00 0.56 86.69 180.00 116.60 0.19 1.04 5,999,892.70 565,508.85 0.50 -1.04 2_Gym-NS-CT_Drill pipe (1) 9/16/2019 12:14:44PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU S-203 MPU 5-203PB1 MPU 5-203PB1 Local Co-ordinate Reference: Well MPU 5-203 TVD Reference: MPU S-203 Actual RKB @ 63.40usft MD Reference: MPU 5-203 Actual RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (-liao-) (ft) Survey Tool Name 190.00 0.57 89.34 190.00 126.60 0.20 1.14 5,999,892.71 565,508.95 0.28 -1.14 2_Gyro-NS-CT_Ddil pipe (1) 200.00 0.57 92.35 199.99 136.59 0.20 1.24 5,999,892.71 565,509.05 0.30 -1.24 2_Gyro-NS-CT_Drll Pipe (1) 210.00 0.62 95.61 209.99 146.59 0.19 1.34 5,999,892.70 565,509.15 0.60 -1.34 2_Gyro-NS-CT_Drill pipe (1) 220.00 0.68 94.50 219.99 156.59 0.18 1.45 5,999,892.69 565,509.26 0.61 -1.45 2_Gyro-NS-CT_Dnll pipe (1) 230.00 0.78 93.98 229.99 166.59 0.17 1.58 5,999,892.68 565,509.39 1.00 -1.58 2_Gyr -NS-CT Dnll pipe (1) 240.00 0.86 94.26 239.99 176.59 0.16 1.72 5,999,892.67 565,509.53 0.80 -1.72 2_Gyro-NS-CT_Ddil pipe (1) 250.00 0.94 97.58 249.99 186.59 0.14 1.88 5,999,892.66 565,509.69 0.95 -1.88 2_Gyro-NS-CT_Drill pipe (1) 260.00 1.02 98.39 259.99 196.59 0.12 2.05 5,999,892.64 565,509.86 0.81 -2.05 2_Gyro-NS-CT_Drill pipe (1) 270.00 1.09 95.90 269.99 206.59 0.10 2.23 5,999,892.62 565,510.04 0.84 -2.23 2_Gyro-NS-CT_Drill pipe (1) 280.00 1.17 96.05 279.99 216.59 0.08 2.43 5,999,892.60 565,510.24 0.80 -2.43 2_Gyro-NS-CT_Drill pipe (1) 290.00 1.26 98.12 289.98 226.58 0.05 2.64 5,999,892.57 565,510.45 1.00 -2.64 2_Gyro-NS-CT_Drill pipe (1) 300.00 1.29 97.86 299.98 236.58 0.02 2.86 5,999,892.54 565,510.67 0.31 -2.86 2_Gyro-NS-CT_Drill pipe (1) 310.00 1.39 98.65 309.98 246.58 -0.02 3.09 5,999,892.51 565,510.90 1.02 -3.09 2_Gyro-NS-CT_Dn1l pipe (1) 320.00 1.62 102.87 319.97 256.57 -0.07 3.35 5,999,892.46 565,511.16 2.55 -3.35 2_Gyro-1,18-CT_Dnll pipe (1) 330.00 1.80 105.15 329.97 266.57 -0.14 3.64 5,999,892.39 565,511.45 1.92 -0.64 2_Gyro-NS-CT_Drill pipe (1) 340.00 1.92 105.56 339.96 276.56 -0.22 3.95 5,999,892.31 565,511.76 1.21 -3.95 2_Gyro-NS-CT_Drill pipe (1) 350.00 2.06 107.17 349.96 286.56 -0.32 4.28 5,999,892.22 565,512.10 1.51 4.28 2_Gyro-NS-CT_Drill pipe (1) 360.00 2.26 108.85 359.95 296.55 -0.44 4.64 5,999,892.10 565,512.46 2.10 -4.64 2_Gyro-NS-CT_Drill pipe (1) 370.00 2.50 110.77 369.94 306.54 -0.58 5.03 5,999,891.96 565,512.85 2.53 -5.03 2_Gym-NS-CT_Dnll pipe (1) 380.00 2.69 114.01 379.93 316.53 -0.75 5.45 5,999,891.80 565,513.27 2.40 -5.45 2_Gyro-NS-CT_Drill pipe (1) 390.00 2.78 115.60 389.92 326.52 -0.95 5.88 5,999,891.60 565,513.70 1.18 -5.88 2_Gyro-NS-CT_Drill pipe (1) 400.00 3.00 113.75 399.91 336.51 -1.16 6.34 5,999,891.39 565,514.16 2.39 -6.34 2_Gyro-NS-CT_Drill pipe (1) 410.00 3.66 113.11 409.89 346.49 -1.39 6.88 5,999,891.17 565,514.70 6.61 46.88 2_Gym-NS-CT_Dn11 pipe (1) 420.00 4.33 113.73 419.87 356.47 -1.67 7.51 5,999,890.90 565,515.34 6.71 -7.52 2_Gyro-NS-CT_Drill pipe (1) 43000 4.80 114.18 429.84 366.44 -1.99 8.24 5,999,890.58 565,516.07 4.71 -8.24 2_Gyro-NS-CT_Drill pipe (1) 440.00 5.28 114.21 439.80 376.40 -2.35 9.04 5,999,890.23 565,516.87 4.80 -9.04 2_Gyro-NS-CT_Drill pipe (1) 450.00 5.72 114.19 449.75 386.35 -2.75 9.92 5,999,889.84 565,517.75 4.40 -9.92 2 Gyro-NS-CT_Drill pipe (1) 460.00 6.04 114.72 459.70 396.30 -3.17 10.85 5,999,889.42 565,518.69 3.25 -10.85 2_Gyr -NS-CT-Drill pipe (1) 470.00 6.36 115.34 469.64 406.24 -3.63 11.83 5,999,888.98 565,519.67 3.27 -11.83 2_Gyro-NS-CT_13011 pipe (1) 480.00 6.68 115.56 479.58 416.18 -4.12 12.85 5,999,888.50 565,520.70 3.21 -12.86 2_Gyro-NS-CT Ddll pipe (1) 490.00 6.98 115.86 489.50 426.10 4.63 13.92 5,999,887.99 565,521.77 3.02 -13.93 2_Gyro-NS-CT_Dnll pipe (1) 500.00 7.32 116.19 499.43 436.03 -5.18 15.04 5,999,887.45 565,522.90 3.42 -15.05 2_Gyr-NS-CT_Drill pipe (1) 510.00 7.65 116.71 509.34 445.94 -5.76 16.21 5,999,886.88 565,524.07 3.37 -16.21 2_Gyro-NS-CT_Drill pipe (1) 520.00 8.00 117.37 519.25 455.85 -6.38 17.42 5,999,886.28 565,525.29 3.61 -17.43 2_Gyro-NS-CT_Dnll pipe (1) 530.00 8.41 117.90 529.15 465.75 -7.04 18.69 5,999,885.62 565,526.56 4.17 -18.69 2_Gyro-NS-CT_Dnll pipe (1) 540.00 8.77 118.82 539.03 475.63 -7.75 20.00 5,999,884.93 565,527.88 3.85 -20.01 2_Gym-NSCT_Ddll pipe (1) 550.00 9.18 119.74 548.91 485.51 -8.51 21.36 5,999,884.18 565,529.24 4.34 -21.37 2_Gyro-NSCT_Drill pipe (1) 560.00 9.68 120.46 558.78 495.38 -9.33 22.78 5,999,883.37 565,530.67 5.14 -22.79 2_Gyro-NS-CT_Drill pipe (1) 570.00 10.15 121.60 568.63 505.23 -10.22 24.25 5,999,882.49 565,532.15 5.09 -24.26 2_Gyro-NS-CT_Drill pipe (1) 580.00 10.65 122.60 578.46 515.06 -11.18 25.78 5,999,881.55 565,533.69 5.32 -25.79 2_Gyro-NS-CT_Drill pipe (1) 9/1612019 12:14:44PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU 3-203 North Reference: True Wellbore: MPU 5-203PB1 Survey Calculation Method: Minimum Curvature Design: MPU 5-203PB1 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 590.00 11.12 123.30 588.28 524.88 -12.21 27.37 5,999,880.53 565,535.28 4.88 -27.38 2_Gyro-NS-CT_Drill pipe (1) 600.00 11.52 124.58 598.09 534.69 -13.31 29.00 5,999,879.45 565,536.92 4.72 -29.00 2_Gyro-NS-CT_Drill pipe (1) 610.00 11.87 125.87 607.88 544.48 -14.48 30.65 5,999,878.30 565,538.58 4.37 -30.66 2_Gyro-NS-CT_Drill pipe (1) 620.00 12.18 126.20 617.66 554.26 -15.70 32.34 5,999,877.08 565,540.28 3.18 -32.35 2 Gyra-NS-CT_Drill pipe (1) 630.00 12.70 126.83 627.43 564.03 -16.98 34.07 5,999,875.82 565,542.02 5.37 -34.08 2_Gyro-NS-CT_Drill pipe (1) 640.00 13.15 128.25 637.17 573.77 -18.35 35.84 5,999,874.47 565,543.81 5.51 -35.85 2_Gyro-NS-CT_Drill pipe (1) 650.00 13.49 129.75 646.90 583.50 -19.80 37.63 5,999,873.04 565,545.61 4.85 -37.64 2_Gyro-NS-CT_Drill pipe (1) 660.00 13.91 130.61 656.62 593.22 -21.32 39.44 5,999,871.52 565,547.43 4.67 -39.45 2_Gyro-NS-CT_Drill pipe (1) 670.00 14.57 131.42 666.31 602.91 -22.94 41.29 5,999,869.93 565,549.30 6.89 -41.31 2_Gyro-NS-CT_Drill pipe (1) 680.00 15.03 132.23 675.98 612.58 -24.64 43.20 5,999,868.24 565,551.22 5.04 -43.22 2_Gyro-NS-CT_Drill pipe (1) 690.00 15.39 133.26 685.63 622.23 -26.42 45.12 5,999,866.48 565,553.16 4.50 45.14 2_Gyro-NS-CT_Drill pipe (1) 700.00 15.77 134.23 695.26 631.86 -28.28 47.06 5,999,864.64 565,555.12 4.61 47.08 2_Gyro-NS-CT_Dnll pipe (1) 710.00 16.15 135.23 704.88 641.48 -30.22 49.02 5,999,862.72 565,557.09 4.69 -49.04 2_Gyro-NS-CT_Drill pipe (1) 720.00 16.57 136.24 714.47 651.07 -32.23 50.98 5,999,860.72 565,559.07 5.07 -51.01 2_Gyro-NS-CT_Drill pipe (1) 730.00 17.06 137.39 724.04 660.64 -34.34 52.96 5,999,858.63 565,561.07 5.92 -52.99 2_Gyro-NS-CT_Dr11l pipe (1) 740.00 17.49 138.39 733.59 670.19 -36.55 54.95 5,999,856.44 565,563.08 5.23 -54.98 2 -Gym -NS -CT -Drill pipe (1) 750.00 17.89 138.86 743.12 679.72 -38.83 56.96 5,999,854.18 565,565.11 4.25 -56.99 2_Gyro-NS-CT_Dn1l pipe (1) 760.00 18.16 139.60 752.63 689.23 -41.17 58.98 5,999,851.85 565,567.15 3.54 -59.01 2_Gyro-NS-CT_Drill pipe (1) 770.00 18.33 140.36 762.13 698.73 43.57 61.00 5,999,949.47 565,569.18 2.92 -61.03 2_Gyro-NS-CT Drill pipe (1) 780.00 18.58 140.87 771.61 708.21 46.01 63.00 5,999,847.05 565,571.21 2.98 -63.04 2_Gyro-NS-CT_Ddll pipe (1) 790.00 18.81 141.12 781.08 717.68 48.50 65.02 5,999,844.57 565,573.25 2.44 -65.06 2_Gyro-NS-CT_Drill pipe (1) 800.00 18.97 141.91 790.55 727.15 -51.04 67.04 5,999,842.06 565,575.29 3.02 -67.07 2_Gyro-NS-CT_Drill pipe (1) 810.00 19.16 142.45 800.00 736.60 -53.62 69.04 5,999,839.49 565,577.31 2.59 -69.08 2_Gyrc-NS-CT_Drill pipe (1) 820.00 19.25 143.29 809.44 746.04 -56.24 71.02 5,999,836.89 565,579.32 2.91 -71.06 2_Gyro-NS-CT_Dnll pipe (1) 830.00 19.37 144.51 818.88 755.48 -58.91 72.97 5,999,834.23 565,581.29 4.21 -73.01 2_Gyro-NS-CT_Drill pipe (1) 840.00 19.55 145.25 828.31 764.91 -61.64 74.89 5,999,831.53 565,583.23 3.05 -74.93 2_Gyro-NS-CT Drill pipe (1) 850.00 19.64 145.87 837.73 774.33 -64.40 76.79 5,999,828.78 565,585.15 2.27 -76.83 2_Gyro-NS-CT_Dri1l pipe (1) 860.00 19.75 146.67 847.14 783.74 -67.21 78.66 5,999,825.99 565,587.05 2.91 -78.70 2_Gyro-NS-CT_Drill pipe (1) 870.00 19.88 147.23 856.55 793.15 -70.05 80.51 5,999,823.17 565,588.92 2.30 -80.55 2_Gyro-NS-CT_Drill pipe (1) 880.00 19.99 147.59 865.95 802.55 -72.92 82.34 5,999,820.31 565,590.78 1.65 -82.39 2_Gyro-NS-CT_Dnll pipe (1) 890.00 20.03 147.98 875.35 811.95 -75.82 94.17 5,999,817.43 565,592.63 1.39 -84.22 2_Gyro-NS-CT_Drill pipe (1) 900.00 20.18 148.24 884.74 821.34 -78.73 85.98 5,999,814.53 565,594.47 1.75 -86.04 2_Gyro-NS-CT_Ddil pipe (1) 910.00 20.40 148.41 894.12 830.72 -81.69 87.80 5,999,811.60 565,596.32 2.28 -87.86 2_Gyro-NS-CT_Drill pipe (1) 920.00 20.56 148.68 903.49 840.09 -84.67 89.63 5,999,808.63 565,598.17 1.86 -89.69 2 Gyro-NS-CT_Drill pipe (1) 930.00 20.78 148.93 912.94 849.44 -87.69 91.46 5,999,805.62 565,600.02 2.37 -91.52 2_Gyra-NS-CT Dnll pipe (1) 940.00 21.07 149.05 922.18 858.78 -90.75 93.30 5,999,802.58 565,601.89 2.93 -93.36 2_Gyro-NS-CT_Ddil pipe (1) 950.00 21.27 149.29 931.51 868.11 -93.85 95.15 5,999,799.49 565,603.77 2.18 -95.21 2_Gyro-NS-CT_Drill pipe (1) 960.00 21.51 149.50 940.82 877.42 -96.99 97.00 5,999,796.37 565,605.65 2.52 -97.07 2 Gyra-NS-CT_Drill pipe (1) 970.00 21.84 149.39 950.11 886.71 -100.17 98.88 5,999,793.21 565,607.56 3.32 -98.95 2_Gyro-NS-CT_Drill pipe (1) 980.00 22.12 149.13 959.39 895.99 -103.39 100.80 5,999,790.01 565,609.50 2.96 -100.87 2_Gyro-NS-CT_Drill pipe (1) 9/162019 12:14.44PM Page 4 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU S-203 Wellbore: MPU S-203PB1 Design: MPU S-203PB1 Survey Halliburton Definitive Survey Repoli Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU S-203 MPU S-203 Actual RKB @ 63.40usft MPU S-203 Actual RKB @ 63.40usft Tme Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (`1100-) (ft) Survey Tool Name 565,611.48 3.79 Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (1) (') (usft) (usft) (usft) (usft) (ft) 990.00 22.49 148.91 968.64 905.24 -106.64 102.75 5,999,786.77 1,000.00 22.92 148.63 977.86 914.46 -109.94 104.75 5,999,783.49 1,010.00 23.14 148.27 987.07 923.67 -113.28 106.80 5,999,780.17 1,020.00 23.32 147.93 996.25 932.85 -116.63 108.88 5,999,776.85 1,030.00 23.74 147.56 1,005.42 942.02 -120.00 111.01 5,999,773.49 1,040.00 24.08 147.08 1,014.57 951.17 -123.41 113.20 5,999,770.10 1,050.00 24.39 146.49 1,023.68 960.28 -126.85 115.45 5,999,766.68 1,060.00 24.93 145.96 1,032.77 969.37 -130.31 117.77 5,999,763.24 1,070.00 25.36 145.50 1,041.82 978.42 -133.83 120.16 5,999,759.75 1,080.00 25.66 144.90 1,050.85 987.45 -137.36 122.62 5,999,756.23 1,090.00 26.06 144.33 1,059.85 996.45 -140.92 125.15 5,999,752.70 1,100.00 26.42 143.92 1,068.82 1,005.42 -144.50 127.74 5,999,749.14 1,110.00 26.65 143.51 1,077.76 1,014.36 -148.10 130.38 5,999,745.56 1,120.00 26.95 143.03 1,086.69 1,023.29 -151.72 133.08 5,999,741.97 1,130.00 27.22 142.64 1,095.59 1,032.19 -155.34 135.83 5,999,738.37 1,140.00 27.33 142.23 1,104.48 1,041.08 -158.98 138.62 5,999,734.76 1,150.00 27.53 141.67 1,113.36 1,049.96 -162.60 141.46 5,999,731.16 1,160.00 27.88 141.20 1,122.21 1,058.81 -166.24 144.36 5,999,727.55 1,170.00 28.03 140.66 4,131.04 1,067.64 -169.88 147.31 5,999,723.94 1,180.00 28.16 140.08 1,139.87 1,076.47 -173.51 150.32 5,999,720.34 1,190.00 28.41 139.63 1,148.67 1,085.27 -177.13 153.37 5,999,716.74 1,200.00 28.48 139.31 1,157.46 1,094.06 -180.75 156.47 5,999,713.15 1,210.00 28.46 138.97 1,166.25 1,102.85 -184.35 159.59 5,999,709.57 1,220.00 28.82 138.65 1,175.03 1,111.63 -187.96 162.74 5,999,705.99 1,230.00 28.92 138.46 1,183.79 1,120.39 -191.58 165.94 5,999,702.40 1,240.00 29.01 138.33 1,192.54 1,129.14 -195.20 169.15 5,999,698.81 1,250.00 29.18 138.21 1,201.28 1,137.88 -198.83 172.39 5,999,695.21 1,260.00 29.38 138.03 1,210.00 1,146.60 -202.47 175.66 5,999,691.60 1,270.00 29.57 137.79 1,218.70 1,155.30 -206.12 178.95 5,999,687.98 1,280.00 29.90 137.60 1,227.39 1,163.99 -209.79 182.29 5,999,684.34 1,290.00 30.29 137.43 1,236.04 1,172.64 -213.49 185.68 5,999,680.67 1,300.00 30.62 137.20 1,244.66 1,181.26 -217.21 189.12 5,999,676.97 1,310.00 31.07 136.99 1,253.24 1,189.84 -220.97 192.61 5,999,673.25 1,320.00 31.49 136.75 1,261.79 1,198.39 -224.76 196.16 5,999,669.49 1,330.00 31.82 136.48 1,270.30 1,206.90 -228.57 199.76 5,999,665.71 1,340.00 32.17 136.24 1,278.78 1,215.38 -232.41 203.42 5,999,661.91 1,350.00 32.55 135.93 1,287.23 1,223.83 -236.26 207.13 5,999,658.09 1,360.00 32.81 135.74 1,295.65 1,232.25 -240.14 210.89 5,999,654.25 1,370.00 32.99 135.64 1,304.04 1,240.64 -244.02 214.69 5,999,650.39 1,380.00 33.25 135.46 1,312.42 1,249.02 -247.92 218.51 5,999,646.53 Well MPU S-203 MPU S-203 Actual RKB @ 63.40usft MPU S-203 Actual RKB @ 63.40usft Tme Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (`1100-) (ft) Survey Tool Name 565,611.48 3.79 -102.82 2_Gyro-NS-CT_Dnll pipe (1) 565,613.51 4.43 -104.83 2_Gyro-NS-CT_Drill pipe (1) 565,615.59 2.61 -106.88 2_Gyro-NS-CT_Drill pipe (1) 565,617.70 2.24 -108.96 2_Gyro-NS-CT_Drill pipe (1) 565,619.86 4.45 -111.10 2_Gyro-NS-CT_Drill pipe (1) 565,622.08 3.92 -113.29 2_Gyro-NS-CT_@ill pipe (1) 565,624.36 3.93 -115.54 2 Gyro-NS-CT_Dnll pipe (1) 565,626.71 5.84 -117.86 2_Gyro-NS-CT_Dn1l pipe (1) 565,629.13 4.72 -120.26 2_Gyro-NS-CT_Drill pipe (1) 565,631.62 3.96 -122.72 2_Gyro-NS-CT_Drill pipe (1) 565,634.18 4.71 -125.24 2_Gyro-NS-CT_Drill pipe (1) 565,636.80 4.03 -127.84 2 Gyro-NS-CT_Drill pipe (1) 565,639.47 2.94 -130.48 2_Gym-NS-CT_Dnll pipe (1) 565,642.20 3.70 -133.18 2 -Gyro -NS -CT -Drill pipe (1) 565,644.98 3.23 -135.94 2_Gyro-NS-CT_Doll pipe (1) 565,647.81 2.18 -138.73 2_Gyro-NSCT_Drill pipe (1) 565,650.68 3.26 -141.57 2Gyro-NS-CT_Drill pipe (1) 565,653.61 4.13 -144.48 2_Gyro-NS-CT_Dnil pipe (1) 565,656.59 2.94 -147.43 2_Gyro-NS-CT_Drill pipe (1) 565,659.63 3.02 -150.44 2_Gyro-NS-CT_Drill pipe (1) 565,662.72 3.29 -153.50 2_Gyro-NS-CT_Drill pipe (1) 565,665.84 1.68 -156.59 2_Gyro-NS-CT_Drill pipe (1) 565,668.99 1.63 -159.72 2_Gyro-NS-CT_Drill pipe (1) 565,672.18 3.91 -162.87 2_Gyro-NS-CT_Drill pipe (1) 565,675.41 1.36 -166.07 2_Gyro-NS-CT_Ddll pipe (1) 565,678.65 1.10 -169.29 2_Gyro-NS-CT_Drill pipe (1) 565,681.92 1.80 -172.53 2_Gyro-NS-CT_Drill pipe (1) 565,685.22 2.19 -175.80 2_Gyro-1\13-CT Dill pipe (1) 565,688.55 2.24 -179.10 2_Gyro-NS-CT_Dnll pipe (1) 565,691.92 3.43 -182.44 2_Gyro-NS-CT_Drill pipe (1) 565,695.34 3.99 -185.83 2_Gyro-NS-CT_Drill pipe (1) 565,698.81 3.50 -189.27 2_Gyro-NS-CT_Drill pipe (1) 565,702.33 4.63 -192.76 2_Gyro-NS-CT_Drill pipe (1) 565,705.91 4.38 -196.31 2_Gyro-NS-CT_Drill pipe (1) 565,709.55 3.59 -199.92 2_Gyro-NS-CT_Drill pipe (1) 565,713.24 3.72 -203.58 2_Gyro-NS-CT_Drill pipe (1) 565,716.98 4.15 -207.30 2_Gyro-NS-CT_Drill pipe (1) 565,720.78 2.80 -211.06 2_Gyro-NS-CT_Drill pipe (1) 565,724.61 1.88 -214.86 2_Gyro-NS-CT_D611 pipe (1) 565,728.47 2.78 -218.69 2_Gyro-NS-CT_Drill pipe (1) 9/16/2019 12:14:44PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU S-203 MPU S-203PB1 MPU S-203PB1 Local Co-ordinate Reference: Well MPU S-203 TVD Reference: MPU S-203 Actual RKB @ 63.40usft MD Reference: MPU S-203 Actual RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,390.00 33.42 135.36 1,320.77 1,257.37 -251.84 222.37 5,999,642.65 565,732.36 1.79 -222.55 2_Gyrc-NS-CT_Drill pipe (1) 1,400.00 33.43 135.40 1,329.12 1,265.72 -255.76 226.24 5,999,638.76 565,736.26 0.24 -226.42 2_Gyro-NS-CT_D611 pipe (1) 1,410.00 33.61 135.30 1,337.46 1,274.06 -259.69 230.12 5,999,634.87 565,740.18 1.88 -230.30 2_Gyro-NS-CT_Drill pipe (1) 1,420.00 33.71 135.22 1,345.78 1,282.38 -263.62 234.02 5,999,630.96 565,744.11 1.09 -234.21 2_Gyro-NS-CT_Drill pipe (1) 1,430.00 33.61 135.09 1,354.10 1,290.70 -267.55 237.93 5,999,627.07 565,748.06 1.23 -238.12 2_Gyro-NS-CT_Drill pipe (1) 1,440.00 33.74 134.87 1,362.43 1,299.03 -271.47 241.85 5,999,623.19 565,752.01 1.78 -242.04 2_Gyro-NS-CT_Ddll pipe (1) 1,450.00 33.89 134.67 1,370.73 1,307.33 -275.39 245.80 5,999,619.30 565,756.00 1.87 -246.00 2 Gyro-NS-CT_Drill pipe (1) 1,460.00 33.78 134.42 1,379.04 1,315.64 -279.30 249.77 5,999,615.43 565,760.00 1.77 -249.97 2_Gyro-NS-CT_Dnll pipe (1) 1,470.00 33.77 134.15 1,387.35 1,323.95 -283.18 253.75 5,999,611.58 565,764.01 1.50 -253.95 2_Gyro-NS-CT_Drill pipe (1) 1,480.00 33.82 133.91 1,395.66 1,332.26 -287.04 257.75 5,999,607.75 565,768.04 1.43 -257.95 2_Gyro-NS-CT_Drill pipe (1) 1,490.00 33.75 133.71 1,403.98 1,340.58 -290.89 261.76 5,999,603.94 565,772.09 1.31 -261.97 2_Gyro-NS-CT_Dnll pipe (1) 1,500.00 33.71 133.66 1,412.29 1,348.89 -294.73 265.78 5,999,600.14 565,776.14 0.49 -265.99 2_Gyro-NS-CT_Ddll pipe (1) 1,51000 33.89 133.52 1,420.60 1,357.20 -298.57 269.81 5,999,596.34 565,780.20 1.96 -270.02 2_Gyro-NS-CT_Drill pipe (1) 1,520.00 33.73 133.45 1,428.91 1,365.51 -302.39 273.85 5,999,592.55 565,784.27 1.65 -274.06 2_Gyro-NS-CT_Drill pipe (1) 1,530.00 33.40 133.50 1,437.24 1,373.84 -306.20 277.86 5,999,588.78 565,788.32 3.31 -278.07 2_Gyro-NS-CT_Ddil pipe (1) 1,540.00 33.41 133.44 1,445.59 1,382.19 -309.99 281.85 5,999,585.03 565,792.34 0.35 -282.07 2_Gyro-NS-CT Drill pipe (1) 1,550.00 33.22 133.45 1,453.95 1,390.55 -313.76 285.84 5,999,581.29 565,796.36 1.90 -286.06 2_Gyro-NS-CT_Dnll pipe (1) 1,560.00 32.83 133.62 1,462.33 1,398.93 -317.52 289.79 5,999,577.57 565,800.35 4.01 -290.01 2_Gyro-NS-CT_Drill pipe (1) 1,570.00 32.79 133.64 1,470.74 1,407.34 -321.26 293.71 5,999,573.86 565,804.30 0.41 -293.94 2_Gyro-NS-CT Drill pipe (1) 1,580.00 32.70 133.65 1,479.15 1,415.75 -324.99 297.63 5,999,570.16 565,808.25 0.90 -297.86 2_Gyro-NS-CT_Drill pipe (1) 1,590.00 32.53 133.70 1,487.57 1,424.17 -328.71 301.53 5,999,566.48 565,812.18 1.72 -301.76 2_Gyro-NS-CT_Drill pipe (1) 1,600.00 32.58 133.74 1,496.00 1,432.60 -332.43 305.42 5,999,562.79 565,816.10 0.54 -305.65 2_Gyro-NS-CT_Drill pipe (1) 1,610.00 32.58 133.83 1,504.43 1,441.03 -336.16 309.30 5,999,559.10 565,820.02 0.48 -309.54 2_Gyro-NS-CT_Drill pipe (1) 1,620.00 32.43 133.86 1,512.86 1,449.46 -339.88 313.18 5,999,555.41 565,823.93 1.51 -313.42 2_Gyro-NS-CT_DnIl pipe (1) 1,630.00 32.43 133.88 1,521.30 1,457.90 -343.59 317.05 5,999,551.73 565,827.83 0.11 -317.28 2_Gyro-NS-CT_Drill pipe (1) 1,640.00 32.51 134.05 1,529.74 1,466.34 -347.32 320.91 5,999,548.04 565,831.72 1.21 -321.15 2_Gyro-NS-CT_Drill pipe (1) 1,650.00 32.33 134.19 1,538.18 1,474.78 -351.05 324.76 5,999,544.34 565,835.60 1.95 -325.00 2_Gyro-NS-CT_Drill pipe (1) 1,660.00 32.18 134.37 1,546.63 1,483.23 -354.78 328.58 5,999,540.65 565,839.46 1.78 -328.83 2 Gyro-NS-GT_Drill pipe (1) 1,670.00 32.16 134.48 1,555.10 1,491.70 -358.51 332.38 5,999,536.96 565,843.29 0.62 -332.63 2_Gyro-NS-CT_Drill pipe (1) 1,680.00 31.91 134.59 1,563.58 1,500.18 -362.23 336.16 5,999,533.27 565,847.10 2.57 -336.42 2_Gyro-NS-CT_Drill pipe (1) 1,690.00 31.63 134.77 1,572.08 1,508.68 -365.93 339.91 5,999,529.60 565,850.88 2.96 -340.16 2_Gyro-NS-CT_Drill pipe (1) 1,700.00 31.57 134.81 1,580.60 1,517.20 -369.62 343.62 5,999,525.94 565,854.63 0.64 -343.88 2_Gyro-NS-CT Drill pipe (1) 1,710.00 31.34 134.88 1,589.13 1,525.73 -373.30 347.32 5,999,522.30 565,858.36 2.33 -347.59 2_Gyro-NS-CT_Drill Pipe (1) 1,720.00 31.06 135.01 1,597.68 1,534.28 -376.96 350.99 5,999,518.67 565,862.06 2.88 -351.25 2_Gyro-NS-CT Drill pipe (1) 1,730.00 31.08 134.92 1,606.25 1,542.85 -380.61 354.64 5,999,515.05 565,865.74 0.51 -354.91 2_Gyro-NS-CT_Dril pipe (1) 1,740.00 30.98 134.80 1,614.81 1,551.41 -384.24 358.30 5,999,511.45 565,869.43 1.18 -358.56 2_Gyro-NS-CT_Drill pipe (1) 1,750.00 30.79 134.60 1,623.40 1,560.00 -387.85 361.95 5,999,507.87 565,873.11 2.16 -362.22 2_Gyro-NS-CT_Drill pipe (1) 1,760.00 30.84 134.34 1,631.98 1,568.58 -391.44 365.60 5,999,504.32 565,876.79 1.42 -365.87 2_Gyro-NS-CT Drill pipe (1) 1,770.00 30.93 134.19 1,640.57 1,577.17 -395.03 369.28 5,999,500.77 565,880.50 1.18 -369.55 2_Gyro-NS-CT_Drill pipe (1) 1,780.00 30.91 133.91 1,649.15 1,585.75 -398.60 372.97 5,999,497.23 565,884.23 1.45 -373.25 2_Gyro-NS-CT_Drill pipe (1) 9/16/2019 12:14:44PM Page 6 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU 5-203PB1 Design: MPU 5-203PB1 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU 5-203 MPU S-203 Actual RKB @ 63.40usft MPU S-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA 91162019 12:14:44PM Page 7 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (1) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,790.00 31.12 133.50 1,657.72 1,594.32 -402.16 376.69 5,999,493.70 565,887.98 2.98 -376.98 2_Gyro-NS-CT_Drill pipe (1) 1,800.00 31.34 133.21 1,666.27 1,602.87 -405.72 380.46 5,999,490.17 565,891.78 2.66 -380.75 2_Gyro-NS-CT Drill pipe (1) 1,810.00 31.50 132.78 1,674.80 1,611.40 -409.27 384.28 5,999,486.65 565,895.63 2.75 -384.56 2_Gyro-NS-CT_Ddil pipe (1) 1,820.00 31.82 132.16 1,683.31 1,619.91 -412.82 388.15 5,999,483.14 565,899.53 4.56 -388.44 2_Gyro-NS-CT_Drill pipe (1) 1,830.00 32.25 131.63 1,691.79 1,628.39 416.36 392.10 5,999,479.64 565,903.51 5.14 -392.39 2_Gyro-NS-CT_Drill pipe (1) 1,840.00 32.55 131.08 1,700.23 1,636.83 -419.90 396.12 5,999,476.13 565,907.56 4.21 -396.41 2_Gyro-NS-CT_Dnll pipe (1) 1,850.00 32.95 130.46 1,708.64 1,645.24 423.43 400.22 5,999,472.64 565,911.69 5.22 -400.51 2_Gyro-NS-CT_Ddil pipe (1) 1,860.00 33.47 129.95 1,717.01 1,653.61 426.97 404.40 5,999,469.14 565,915.90 5.90 -404.70 2_Gyro-NS-CT_Drill pipe (1) 1,870.00 33.83 129.50 1,725.33 1,661.93 -430.51 408.66 5,999,465.63 565,920.19 4.38 -408.96 2 Gyro-NS-CT_DO pipe (1) 1,880.00 34.15 129.06 1,733.63 1,670.23 434.05 412.99 5,999,462.13 565,924.55 4.04 -413.29 2_Gyro-NS-CT_Dnll pipe (1) 1,890.00 34.55 128.76 1,741.88 1,678.48 -437.59 417.38 5,999,458.63 565,928.97 4.34 -417.69 2_Gyro-NS-CT_Dnll pipe (1) 1,900.00 34.80 128.67 1,750.11 1,686.71 -441.15 421.82 5,999,455.11 565,933.44 2.55 -422.13 2_Gyro-NS-CT Drill pipe (1) 1,910.00 34.86 128.65 1,758.31 1,694.91 -444.72 426.28 5,999,451.58 565,937.93 0.61 -426.59 2_Gyro-NS-CT_1)rill pipe (1) 1,920.00 35.01 128.66 1,766.51 1,703.11 -448.29 430.75 5,999,448.04 565,942.43 1.50 -431.06 2_Gyro-NS-CT Drill pipe (1) 1,930.00 35.06 128.74 1,774.70 1,711.30 -451.88 435.23 5,999,444.49 565,946.95 0.68 -435.55 2_Gyro-NS-CT_Dnll pipe (1) 1,940.00 34.99 128.77 1,782.89 1,719.49 455.48 439.71 5,999,440.94 565,951.45 0.72 -440.02 2_Gyro-NS-CT_Drill pipe (1) 1,950.00 35.11 128.79 1,791.08 1,727.68 459.07 444.18 5,999,437.38 565,955.96 1.21 .444.50 2_Gyro-NS-CT_Drill pipe (1) 1,960.00 35.16 128.84 1,799.25 1,735.85 -462.68 448.67 5,999,433.82 565,960.48 0.58 -448.99 2_Gyro-NS-CT_Drill pipe (1) 1,970.00 34.99 128.92 1,807.44 1,744.04 -466.29 453.14 5,999,430.25 565,964.98 1.76 -453.47 2 Gyro-NS-CT_Drill pipe (1) 1,980.00 34.95 129.00 1,815.63 1,752.23 -469.89 457.60 5,999,426.68 565,969.47 0.61 -457.93 2_Gyrc-NS-CT_DnIl pipe (1) 1,990.00 34.97 129.15 1,823.83 1,760.43 -473.50 462.05 5,999,423.11 565,973.95 0.88 -462.38 2_Gyro-NS-CT_Drill pipe (1) 2,000.00 34.78 129.31 1,832.03 1,768.63 -477.12 466.48 5,999,419.54 565,978.41 2.11 -466.81 2_Gyro-NS-CT_Dnll pipe (1) 2,010.00 34.61 129.42 1,840.25 1,776.85 -480.73 470.88 5,999,415.96 565,982.84 1.81 471.21 2_Gyro-NS-CT_Ddil pipe (1) 2,020.00 34.61 129.41 1,848.48 1,785.08 -484.34 475.26 5,999,412.40 565,987.26 0.06 -475.60 2_Gyro-1,19-CT_Drill pipe (1) 2,030.00 34.40 129.53 1,856.72 1,793.32 487.94 479.64 5,999,408.83 565,991.66 2.21 479.98 2_Gyro-NS-CT_Dnll pipe (1) 2,040.00 34.19 129.59 1,864.99 1,801.59 -491.53 483.98 5,999,405.28 565,996.04 2.13 484.32 2_Gyro-NS-CT_Drill pipe (1) 2,050.00 34.37 129.58 1,873.25 1,809.85 -495.11 488.32 5,999,401.73 566,000.41 1.80 -488.67 2_Gyro-NS-CT_Drill pipe (1) 2,060.00 34.33 129.69 1,881.50 1,818.10 -498.71 492.67 5,999,398.17 566,004.79 0.74 -493.02 2_Gyro-NS-CT_Dnll pipe (1) 2,070.00 34.22 129.70 1,889.77 1,826.37 -502.31 497.00 5,999,394.62 566,009.15 1.10 497.35 2 Gyro-NS-CT_DA pipe (1) 2,080.00 34.37 129.70 1,898.03 1,834.63 -505.91 501.34 5,999,391.05 566,013.52 1.50 -501.69 2_Gyro-NS-CT_Drill pipe (1) 2,090.00 34.30 129.88 1,906.29 1,842.89 -509.52 505.67 5,999,387.48 566,017.88 1.23 -506.03 2_Gyro-NS-CT Drill pipe(1) 2,100.00 34.01 130.07 1,914.56 1,851.16 -513.13 509.97 5,999,383.91 566,022.21 3.09 -510.33 2_Gyro-NS-CT_Drll pipe (1) 2,110.00 34.09 130.16 1,922.85 1,859.45 -516.73 514.25 5,999,380.34 566,026.53 0.95 514.61 2_Gyro-NS-CT_Drill pipe (1) 2,120.00 33.99 130.48 1,931.13 1,867.73 -520.36 518.52 5,999,376.76 566,030.83 2.05 -518.89 2_Gyro-NS-CT_Dnll pipe (1) 2,130.00 33.56 130.94 1,939.45 1,876.05 -523.98 522.74 5,999,373.17 566,035.07 5.00 -523.10 2 Gyro-NS-CT_Drill pipe (1) 2,140.00 33.39 131.43 1,947.79 1,884.39 -527.61 526.89 5,999,369.58 566,039.25 3.19 -527.26 2_Gyro-NS-CT_Drill pipe (1) 2,150.00 33.23 132.05 1,956.15 1,892.75 -531.27 530.99 5,999,365.96 566,043.38 3.76 -531.36 2_Gyro-NS-CT Drill pipe (1) 2,160.00 32.90 132.83 1,964.53 1,901.13 -534.95 535.01 5,999,362.31 566,047.44 5.39 -535.38 2_Gym-NS-CT_Drili pipe (1) 2,170.00 32.62 133.75 1,972.94 1,909.54 -538.66 538.95 5,999,358.64 566,051.41 5.71 -539.33 2_Gyro-NS-CT_Dnll pipe (1) 2,180.00 32.60 134.35 1,981.36 1,917.96 -542.41 542.82 5,999,354.92 566,055.32 3.24 -543.20 2_Gyro-NS-CT_Dnll pipe (1) 91162019 12:14:44PM Page 7 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU 5-203PBl Survey Calculation Method: Minimum Curvature Design: MPU S-203PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 2,190.00 32.44 134.98 1,989.79 1,926.39 -546.19 546.65 5,999,351.18 566,059.17 3.75 -547.03 2_Gyro-NS-CT Drill pipe (1) 2,200.00 32.15 135.60 1,998.24 1,934.84 -549.98 550.41 5,999,347.42 566,062.97 4.40 -550.79 2 Gyro-NS-CT_Drill pipe (1) 2,210.00 32.20 136.03 2,006.71 1,943.31 -553.80 554.12 5,999,343.63 566,066.71 2.34 -554.50 2_Gyro-NS-CT_Drill pipe (1) 2,220.00 31.94 136.74 2,015.18 1,951.78 -557.65 557.78 5,999,339.82 566,070.41 4.58 -558.17 2_Gyro-NS-CT_Drill pipe (1) 2,230.00 31.62 137.67 2,023.68 1,960.28 -561.51 561.36 5,999,335.99 566,074.02 5.85 -561.75 2_Gyro-NS-CT_Ddll pipe (1) 2,240.00 31.60 138.15 2,032.20 1,968.80 -565.40 564.87 5,999,332.13 566,077.56 2.52 -565.27 2_Gyro-NS-CT_0011 pipe (1) 2,250.00 31.41 138.70 2,040.73 1,977.33 -569.31 568.34 5,999,328.25 566,081.07 3.45 -568.74 2_Gyro-NS-CT_Drill pipe (1) 2,260.00 31.11 139.27 2,049.27 1,985.87 -573.23 571.74 5,999,324.37 566,084.51 4.21 -572.14 2_Gyro-NS-CT_Dnl1 pipe (1) 2,270.00 31.12 139.71 2,057.84 1,994.44 -577.15 575.10 5,999,320.47 566,087.90 2.28 -575.50 2_Gyro-NS-CT_Drill pipe (1) 2,280.00 30.90 140.38 2,066.41 2,003.01 581.10 578.41 5,999,316.55 566,091.24 4.09 -578.82 2_Gyro-NS-CT_Drill pipe (1) 2,290.00 30.51 141.20 2,075.00 2,011.60 -585.06 581.64 5,999,312.62 566,094.50 5.72 582.05 2_Gyro-NS-CT_Drill pipe (1) 2,300.00 30.39 141.85 2,083.62 2,020.22 -589.03 584.79 5,999,308.68 566,097.69 3.51 -585.20 2_Gyro-NS-CT_Dril pipe (1) 2,310.00 30.25 142.45 2,092.26 2,028.86 -593.01 587.89 5,999,304.72 566,100.82 3.34 -588.30 2_Gyro-NS-CT_Drill pipe (1) 2,320.00 29.94 143.03 2,100.91 2,037.51 -597.00 590.92 5,999,300.76 566,103.89 4.25 -591.34 2_Gyro-NS-CT_Drill pipe (1) 2,330.00 29.77 143.61 2,109.58 2,046.18 -601.00 593.90 5,999,296.79 566,106.90 3.35 -594.32 2_Gyro-NS-CT_Dnll pipe (1) 2,340.00 29.75 144.22 2,118.26 2,054.86 -605.01 596.82 5,999,292.81 566,109.86 3.03 -597.24 2_Gyr-NS-CT_Dnll Pipe (1) 2,350.00 29.39 145.14 2,126.96 2,063.56 509.03 599.67 5,999,288.81 566,112.75 5.79 -600.10 2_Gyro-NS-CT Drill pipe (1) 2,360.00 29.06 146.19 2,135.69 2,072.29 -613.07 602.43 5,999,284.80 566,115.53 6.10 -602.86 2_Gyro-NS-CT_Drill pipe (1) 2,370.00 29.10 146.74 2,144.43 2,081.03 -617.12 605.11 5,999,280.77 566,118.26 2.70 -605.54 2_Gyro-NS-CT_Dnll pipe (1) 2,380.00 28.97 147.19 2,153.17 2,089.77 -621.19 607.76 5,999,276.73 566,120.94 2.54 -608.19 2_Gyro-NS-CT_Ddli pipe (1) 2,390.00 28.78 147.64 2,161.93 2,098.53 -625.25 610.36 5,999,272.68 566,123.57 2.89 -610.80 2_Gym-NS-CT_Dnll pipe (1) 2,400.00 28.93 148.17 2,170.69 2,107.29 -629.34 612.92 5,999,268.62 566,126.17 2.97 -613.36 2_Gyro-NS-CT_Drill pipe (1) 2,410.00 28.65 149.02 2,179.45 2,116.05 -633.45 615.43 5,999,264.53 566,128.72 4.96 -615.88 2_Gyna-NS-CT_Drill pipe (1) 2,420.00 28.32 150.18 2,188.24 2,124.84 -637.57 617.85 5,999,260.44 566,131.17 6.44 -618.29 2_Gyro-NS-CT_Drill pipe (1) 2,430.00 28.38 150.97 2,197.04 2,133.64 -641.70 620.18 5,999,256.32 566,133.54 3.80 -620.63 2_Gyro-NS-CT_Drill pipe (1) 2,440.00 28.25 151.62 2,205.84 2,142.44 -645.86 622.46 5,999,252.18 566,135.85 3.35 -622.91 2_Gyra-NS-CT_Dnll pipe (1) 2,450.00 27.98 152.27 2,214.66 2,151.26 -650.02 624.68 5,999,248.04 566,138.10 4.08 -625.13 2_Gyro-NS-CT_Ddll pipe (1) 2,460.00 28.16 152.81 2,223.49 2,160.09 -654.20 626.84 5,999,243.89 566,140.31 3.11 -627.30 2_Gyro-NS-CT_Drill pipe (1) 2,470.00 28.26 153.75 2,232.30 2,168.90 -658.42 628.97 5,999,239.69 566,142.47 4.55 -629.43 2_Gyro-NS-CT_Drill pipe (1) 2,480.00 27.86 154.92 2,241.12 2,177.72 -662.66 631.01 5,999,235.46 566,144.54 6.80 -631.47 2_Gyro-NS-CT Drill Pipe (1) 2,490.00 27.72 155.78 2,249.97 2,186.57 -666.90 632.95 5,999,231.24 566,146.53 4.25 -633.42 2_Gyro-NS-CT_Drill pipe (1) 2,500.00 27.69 156.55 2,258.82 2,195.42 -671.15 634.83 5,999,227.01 566,148.44 3.59 -635.30 2_Gyro-NS-CT_Drill pipe (1) 2,510.00 27.57 157.31 2,267.68 2,204.28 -675.41 636.65 5,999,222.76 566,150.30 3.72 -637.12 2_Gyro-NS-CT_Drill pipe (1) 2,520.00 27.41 158.08 2,276.55 2,213.15 -679.68 638.40 5,999,218.50 566,152.09 3.90 -638.87 2_Gyro-NS-CT_Drill pipe (1) 2,530.00 27.35 158.75 2,285.43 2,222.03 -683.96 640.09 5,999,214.24 566,153.81 3.14 -640.57 2_Gyro-NS-CT_Drill pipe (1) 2,540.00 27.05 159.64 2,294.33 2,230.93 -688.23 641.72 5,999,209.99 566,155.48 5.05 -642.20 2_Gyrc-NS-CT Drill pipe (1) 2,550.00 26.66 160.80 2,303.25 2,239.85 -692.48 643.24 5,999,205.75 566,157.04 6.53 -643.73 2_Gyro-NS-CT_DrII pipe (1) 2,560.00 26.62 161.51 2,312.19 2,248.79 -696.73 644.69 5,999,201.52 566,158.53 3.21 -645.18 2_Gyro-NS-CT_Drill pipe (1) 2,570.00 26.37 162.17 2,321.14 2,257.74 -700.97 646.08 5,999,197.29 566,159.95 3.86 -646.57 2_Gym-NS-CT_Drill pipe (1) 2,580.00 26.06 162.86 2,330.11 2,266.71 -705.18 647.41 5,999,193.09 566,161.32 4.35 -647.90 2_Gyro-NS-CT_Drili pipe (1) 9/162019 12:14:44PM Page 8 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU S-203 Wellbore: MPU S-203PB1 Design: MPU S-203PB1 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU S-203 MPU S-203 Actual RKB @ 63.40usft MPU S-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting OLS Section (ft) Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) 2,590.00 26.17 163.39 2,339.09 2,275.69 -709.39 648.69 5,999,188.89 2,600.00 26.11 164.21 2,348.07 2,284.67 -713.62 649.92 5,999,184.67 2,610.00 25.97 165.30 2,357.05 2,293.65 -717.86 651.07 5,999,160.45 2,620.00 26.11 166.05 2,366.04 2,302.64 -722.11 652.16 5,999,176.20 2,630.00 26.10 166.81 2,375.02 2,311.62 -72639 653.19 5,999,171.94 2,640.00 26.09 167.73 2,384.00 2,320.60 -730.68 654.16 5,999,167.66 2,650.00 26.26 168.50 2,392.97 2,329.57 -735.00 655.07 5,999,163.35 2,660.00 26.42 169.43 2,401.93 2,338.53 -739.35 655.92 5,999,159.00 2,670.00 26.42 170.58 2,410.89 2,347.49 -743.73 656.69 5,999,154.63 2,680.00 26.52 171.63 2,419.84 2,356.44 -748.14 657.38 5,999,150.23 2,690.00 26.69 172.31 2,428.78 2,365.38 -752.57 658.00 5,999,145.80 2,700.00 26.68 173.08 2,437.72 2,374.32 -757.02 658.58 5,999,141.35 2,710.00 26.69 173.77 2,446.65 2,383.25 -761.49 659.09 5,999,136.90 2,720.00 26.80 174.27 2,455.58 2,392.18 -765.96 659.56 5,999,132.43 2,730.00 26.62 175.55 2,464.51 2,401.11 -770.44 659.96 5,999,127.95 2,740.00 26.32 177.37 2,473.47 2,410.07 -774.89 660.23 5,999,123.51 2,750.00 26.29 178.22 2,482.43 2,419.03 -779.31 660.40 5,999,119.08 2,760.00 26.20 178.79 2,491.40 2,428.00 -783.73 660.52 5,999,114.66 2,770.00 26.01 179.59 2,500.38 2,436.98 -788.13 660.58 5,999,110.26 2,780.00 26.04 180.40 2,509.37 2,445.97 -792.52 660.58 5,999,105.88 2,790.00 25.88 181.21 2,518.36 2,454.96 -796.90 660.52 5,999,101.50 2,800.00 25.56 182.19 2,527.37 2,463.97 -801.24 660.39 5,999,097.16 2,810.00 25.51 183.40 2,536.39 2,472.99 -805.54 660.18 5,999,092.86 2,820.00 25.42 184.54 2,545.42 2,482.02 -809.83 659.88 5,999,088.56 2,830.00 25.32 185.76 2,554.45 2,491.05 -814.10 659.50 5,999,084.29 2,840.00 25.37 186.84 2,563.49 2,600.09 -818.35 659.03 5,999,080.04 2,850.00 25.51 187.79 2,572.52 2,509.12 -822.61 658.48 5,999,075.77 2,860.00 25.47 189.57 2,581.55 2,518.15 -826.87 657.83 5,999,071.51 2,870.00 25.59 190.97 2,590.57 2,527.17 -831.11 657.06 5,999,067.27 2,880.00 25.78 191.93 2,599.58 2,536.18 -835.36 656.20 5,999,063.01 2,890.00 25.88 192.79 2,608.58 2,545.18 -839.61 655.27 5,999,058.75 2,900.00 26.01 193.57 2,617.58 2,554.18 -843.87 654.27 5,999,054.48 2,910.00 26.28 194.29 2,626.55 2,563.15 -848.15 653.21 5,999,050.19 2,920.00 26.63 195.53 2,635.51 2,572.11 -852.45 652.07 5,999,045.88 2,930.00 26.66 197.21 2,644.44 2,581.04 -856.76 650.80 5,999,041.57 2,940.00 27.02 198.31 2,653.37 2,589.97 -861.05 649.43 5,999,037.26 2,950.00 27.24 199.17 2,662.27 2,598.87 -865.37 647.96 5,999,032.93 2,960.00 27.45 199.97 2,671.15 2,607.75 -869.70 646.42 5,999,028.58 2,970.00 2805 200.71 2,680.00 2,616.60 -874.07 644.80 5,999,024.21 2,980.00 28.21 201.61 2,688.82 2,625.42 -878.46 643.10 5,999,019.79 Well MPU S-203 MPU S-203 Actual RKB @ 63.40usft MPU S-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting OLS Section (ft) (°1100') (ft) Survey Tool Name 566,162.63 2.58 -649.18 2_Gyro-NS-CT_Dnll pipe (1) 566,163.90 3.66 -650.42 2 Gyro-NS-CT_DrII pipe (1) 566,165.09 4.99 -651.57 2_Gyro-NS-CT_Drill pipe (1) 566,166.21 3.58 -652.66 2_Gyro-NS-CT_Drill pipe (1) 566,167.28 3.35 -653.70 2_Gym-NS-CT_Drill pipe (1) 566,168.29 4.05 -654.67 2_Gyro-NS-CT_Drill pipe (1) 566,169.24 3.80 -655.58 2 -Gyro -NS -CT D611 pipe (1) 566,170.12 4.43 -656.43 2_Gyro-NS-CT_Drill pipe (1) 566,170.93 5.12 -657.21 2_Gyro-NS-CT_13rill pipe (1) 566,171.66 4.79 -657.90 2_Gyro-NS-CT_Drill pipe (1) 566,172.33 3.49 -658.53 2_Gyro-NS-CT_Drill pipe (1) 566,172.94 3.46 -659.10 2 Gyro-NS-CT_DnII pipe (1) 566,173.49 3.10 -659.62 2_Gyro-NS-CT_Drill pipe (1) 566,174.00 2.50 -660.09 2 -Gyro -NS -CT Drill pipe(1) 566,174.44 6.03 -660.49 2_Gyro-NS-CT_Drill pipe (1) 566,174.75 8.65 -660.77 2_Gyro-NS-CT_Dn1l pipe (1) 566,174.96 3.78 -660.95 2_Gyro-NS-CT_Drill pipe (1) 566,175.11 2.68 -661.07 2_Gyro-NS-CT_Drill pipe (1) 566,175.21 4.00 -661.13 2_Gyro-NS-CT_Drill pipe (1) 566,175.25 3.57 -661.13 2_Gym-NS-CT_Drill pipe (1) 566,175.23 3.89 -661.08 2_Gyro-NS-CT_Dull pipe (1) 566,175.14 5.32 -660.95 2_Gyro-NS-CT_Drili pipe (1) 566,174.97 5.24 -660.74 2_Gyro-NS-CT_131111 pipe (1) 566,174.71 4.98 -660.45 2_Gyro-NS-CT_Dn11 pipe (1) 566,174.36 5.32 -660.07 2_Gyro-NS-CT_Drill pipe (1) 566,173.93 4.65 -659.60 2_Gyro-NS-CT_Drill pipe (1) 566,173.42 4.31 -659.06 2_Gyro-NS-CT_Drill pipe (i) 566,172.81 7.67 -658.41 2_Gym-NS-CT_Drill pipe (1) 566,172.08 6.15 -657.64 2_Gyro-NS-CT_Drill pipe (1) 566,171.25 4.57 -656.79 2_Gyro-NS-CT_Ddll pipe (1) 566,170.36 3.88 -655.86 2 Gyro-NS-CT_Drill pipe (1) 566,169.40 3.65 -654.86 2_Gyro-NS-CT_Drill pipe (1) 566,168.37 4.17 -653.80 2_Gym-NS-CT_Dnll pipe (1) 566,167.27 6.54 -652.66 2_Gyro-NS-CT_Drill pipe (1) 566,166.04 7.54 -651.40 2_Gyro-NS-CT_Drill pipe (1) 566,164.70 6.13 -650.03 2_Gyro-NS-CT_Drill pipe (1) 566,163.27 4.50 -648.56 2_Gyro-NS-CT_Drill pipe (1) 566,161.77 4.23 -647.03 2_Gyro-NS-CT_Dnll pipe (1) 566,160.19 6.92 -645.41 2_Gym-NS-CT_Drill pipe (1) 566,158.53 4.53 -643.71 2_Gym-NS-CT_Drill pipe (1) 9/1612019 12:14:44PM Page 9 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RK8 @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU 5-203PB1 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) (1) (`) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 2,990.00 28.34 202.84 2,697.63 2,634.23 -882.85 641.31 5,999,015.39 566,156.78 5.97 -641.92 2_Gyro-NS-CT_Drill pipe (1) 3,000.00 28.68 203.79 2,706.41 2,64301 -887.23 639.42 5,999,011.00 566,154.93 5.67 -640.04 2_Gyro-NS-CT_Drill pipe (1) 3,010.00 28.97 204.44 2,715.17 2,651.77 -891.63 637.45 5,999,006.58 566,152.99 4.27 -638.07 2 Gyro-NS-CT_Drill pipe (1) 3,020.00 29.05 205.04 2,723.92 2,660.52 -896.04 635.42 5,999,002.16 566,151.00 3.02 -636.05 2_Gyro-NS-CT_Drlll pipe (1) 3,030.00 29.37 205.65 2,732.65 2,669.25 -900.45 633.33 5,998,997.73 566,148.95 4.37 -633.96 2_Gyro-NS-CT_Drill pipe (1) 3,040.00 29.47 206.37 2,741.36 2,677.96 -904.86 631.18 5,998,993.30 566,146.84 3.68 -631.81 2_Gyro-NS-CT_Drill pipe (1) 3,050.00 29.42 207.36 2,750.07 2,686.67 -909.25 628.96 5,998,988.89 566,144.66 4.89 -629.59 2_Gyro-NS-CT_Drill pipe (1) 3,060.00 29.48 208.52 2,758.77 2,695.37 -913.59 626.65 5,998,984.53 566,142.39 5.73 -627.29 2_Gyro-NS-CT_Ddll pipe (1) 3,070.00 29.76 209.37 2,767.47 2,704.07 -917.91 624.26 5,998,980.18 566,140.04 5.05 -624.90 2_Gyro-NS-CT_Drill pipe (1) 3,080.00 29.75 210.08 2,776.15 2,712.75 -922.22 621.80 5,998,975.85 566,137.61 3.53 -622.44 2_Gyro-NS-CT_Drill pipe (1) 3,090.00 29.79 210.84 2,784.83 2,721.43 -926.50 619.28 5,998,971.55 566,135.13 3.79 -619.93 2_Gyro-NS-CT_Drill pipe (1) 3,100.00 30.04 211.58 2,793.50 2,730.10 -930.77 616.70 5,998,967.26 566,132.59 4.46 -617.35 2_Gyro-NS-CT_Drill pipe (1) 3,110.00 30.13 212.58 2,802.15 2,738.75 -935.02 614.04 5,998,962.99 566,129.96 5.09 -614.69 2_Gyro-NS-CT_Drill pipe (1) 3,120.00 30.04 213.74 2,810.80 2,747.40 -939.21 611.29 5,998,958.77 566,127.26 5.88 -611.95 2 -GYM -NS -CT Drill pipe(1) 3,130.00 30A7 214.55 2,819.44 2,756.04 -943.38 608.47 5,998,954.58 566,124.47 5.93 -609.12 2_Gyrc-NS-CT_Drill pipe (1) 3,140.00 30.39 215.36 2,828.06 2,764.66 -947.53 605.56 5,998,950.40 566,121.60 4.18 506.23 2_Gyro-NS-CT_Dnll pipe (1) 3,150.00 30.35 216.16 2,836.69 2,773.29 -951.64 602.61 5,998,946.28 566,118.68 4.06 -603.27 2_Gyro-NS-CT_Drill pipe (1) 3,160.00 30.52 216.86 2,845.31 2,781.91 -955.71 599.60 5,998,942.18 566,115.71 3.93 -600.26 2_Gyro-NS-CT_Drill pipe (1) 3,170.00 30.68 217.62 2,853.92 2,790.52 -959.76 596.51 5,998,938.10 566,112.66 4.19 -597.18 2_Gyro-NS-CT_Dnll pipe (1) 3,180.00 30.72 218.50 2,862.52 2,799.12 -963.78 593.37 5,998,934.05 566,109.55 4.51 -594.04 2_Gyro-NS-CT_Drill pipe (1) 3,190.00 30.94 219.32 2,871.11 2,807.71 -967.77 590.15 5,998,930.04 566,106.37 4.74 -590.82 2_Gym-NS-CT_Drill pipe (1) 3,200.00 31.20 220.07 2,879.67 2,816.27 -971.74 586.85 5,998,926.04 566,103.11 4.66 -587.53 2_Gyro-NS-CT_Drill pipe (1) 3,210.00 31.28 220.59 2,888.22 2,824.82 -975.69 583.50 5,998,922.06 566,099.78 2.81 -584.18 2_Gyro-NS-CT_Drill pipe (1) 3,220.00 31.50 221.13 2,896.76 2,833.36 -979.63 580.09 5,998,918.09 566,096.41 3.57 -580.77 2_Gyro-NS-CT_Drill pipe (1) 3,230.00 31.88 221.60 2,905.27 2,841.87 -983.57 576.62 5,998,914.11 566,092.98 4.53 -577.30 2_Gyro-NS-CT_Drill pipe (1) 3,240.00 32.09 222.20 2,913.75 2,850.35 -987.52 573.08 5,998,910.14 566,089.47 3.81 -573.77 2_Gyro-NS-CT_Dn1l pipe (1) 3,250.00 32.21 222.90 2,922.22 2,858.82 -991.44 569.48 5,998,906.19 566,085.91 3.91 -570.17 2_Gyro-NS-CT_Drill pipe (1) 3,260.00 32.73 223.46 2,930.65 2,867.25 -995.35 565.81 5,998,902.24 566,082.27 6.01 -566.50 2_Gyro-NS-CT_Drill pipe (1) 3,270.00 32.99 223.99 2,939.05 2,875.65 -999.27 562.06 5,998,898.29 566,078.56 3.88 -562.75 2_Gyro-NS-CT_Drill pipe (1) 3;280.00 33.05 224.45 2,947.44 2,884.04 -1,003.18 558.26 5,998,894.35 566,074.79 2.58 -558.96 2_Gyro-NS-CT_Dnll pipe (1) 3,290.00 33.37 224.70 2,955.80 2,892.40 -1,007.08 554.41 5,998,890.42 566,070.98 3.48 -555.11 2_Gyro-NS-CT_Drill pipe (1) 3,300.00 33.58 225.03 2,964.15 2,900.75 -1,010.99 550.52 5,998,886.48 566,067.12 2.78 -551.23 2_Gyro-NS-CT_Drill pipe (1) 3,310.00 33.58 225.45 2,972.48 2,909.08 -1,014.88 546.59 5,998,882.55 566,063.23 2.32 -547.30 2_Gyro-NS-CT_Drill pipe (1) 3,320.00 33.82 225.78 2,980.80 2,917.40 -1,018.76 542.63 5,998,878.63 566,059.30 3.02 -543.34 2_Gyro-NS-CT Drill pipe (1) 3,330.00 33.98 226.10 2,989.10 2,925.70 -1,022.64 538.62 5,998,874.72 566,055.33 2.40 -539.33 2_Gyro-NS-CT_Dnll pipe (1) 3,340.00 33.96 226.24 2,997.39 2,933.99 -1,026.51 534.59 5,998,870.81 566,051.33 0.81 -535.31 2_Gyro-NS-CT_Dnll pipe (1) 3,350.00 34.16 226.32 3,005.67 2,942.27 -1,030.38 530.54 5,998,866.91 566,047.32 2.05 531.26 2_Gyro-NS-CT_Drill pipe (1) 3,360.00 34.40 226.53 3,013.94 2,950.54 -1,034.26 526.46 5,998,862.99 566,043.27 2.68 -527.18 2_Gyro-NS-CT_Dnll pipe (1) 3,370.00 34.52 226.76 3,022.18 2,958.78 -1,038.15 522.35 5,998,859.07 566,039.19 1.77 -523.07 2_Gyro-NS-CT_Drill pipe (1) 3,380.00 34.77 227.05 3,030.41 2,967.01 -1,042.03 518.20 5,998,855.15 566,035.08 2.99 -518.92 2_Gyro-NS-CT_Drill pipe (1) 9/1612019 12: 14:44PM Page 10 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU 5-203PB1 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NlS +PJ -W Northing Easting DLS Section (usft) (°) (`) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,390.00 35.11 227.39 3,038.61 2,975.21 -1,045.92 513.99 5,998,851.22 566,030.91 3.92 -514.72 2_Gyro-NS-CT_Drill pipe (1) 3,400.00 35.35 227.95 3,046.77 2,983.37 -1,049.81 509.73 5,998,847.30 566,026.68 4.02 -510.46 2_Gyro-NS-CT_Drill pipe (1) 3,410.00 35.67 228.52 3,054.92 2,991.52 -1,053.68 505.40 5,998,843.40 566,022.38 4.60 -506.13 2_Gyro-NS-CT_Drill pipe (1) 3,420.00 36.12 229.27 3,063.02 2,999.62 -1,057.53 500.98 5,998,839.50 566,017.99 6.29 -501.72 2_Gyro-NS-CT_0nl1 pipe (1) 3,430.00 36.47 229.99 3,071.08 3,007.68 -1,061.36 496.47 5,998,835.63 566,013.52 5.51 -497.21 2_Gyro-NS-CT_Dril1 pipe (1) 3,440.00 36.78 230.71 3,079.10 3,015.70 -1,065.17 491.87 5,998,831.79 566,008.96 5.30 -492.62 2_Gyro-NS-CT_Dnl1 pipe (1) 3,450.00 37.34 231.18 3,087.08 3,023.68 -1,068.97 487.19 5,998,827.95 566,004.31 6.28 487.94 2_Gyro-NS-CT_Drill pipe (1) 3,460.00 37.66 231.71 3,095.01 3,031.61 -1,072.76 482.43 5,998,824.11 565,999.59 4.54 -483.18 2_Gyro-NS-CT_Drill pipe (1) 3,470.00 37.84 232.17 3,102.92 3,039.52 -1,076.54 477.61 5,998,820.30 565,994.80 3.34 -478.36 2_Gyro-NS-CT_Dnll pipe (1) 3,480.00 38.26 232.44 3,110.80 3,047.40 -1,080.30 472.74 5,998,816.49 565,989.96 4.52 -473.49 2_Gyro-NS-CT_Drili pipe (1) 3,490.00 38.65 232.71 3,118.63 3,055.23 -1,084.08 467.80 5,998,812.66 565,985.05 4.25 468.55 2_Gyro-NS-CT_Drill pipe (1) 3,500.00 38.87 233.05 3,126.43 3,063.03 -1,087.86 462.81 5,998,808.84 565,980.09 3.06 -463.56 2 Gyro-NS-CT_Drill pipe (1) 3,510.00 39.35 233.30 3,134.18 3,070.78 -1,091.64 457.76 5,998,805.02 565,975.08 5.05 -458.52 2_Gyro-NS-CT_Dnll pipe (1) 3,520.00 39.66 233.55 3,141.90 3,078.50 -1,095.43 452.65 5,998,801.18 565,970.00 3.48 -453.41 2_Gyro-NS-CT_Drill pipe (1) 3,530.00 39.92 233.79 3,149.58 3,086.18 -1,099.23 447.49 5,998,797.35 565,964.88 3.02 -448.26 2_Gyro-NSCT_Dnl1 pipe (1) 3,540.00 40.35 234.10 3,157.23 3,093.83 -1,103.02 442.28 5,998,793.51 565,959.70 4.74 443.05 2_Gyro-NS-CT_Drill pipe (1) 3,550.00 40.77 234.51 3,164.83 3,101.43 -1,106.81 437.00 5,998,789.67 565,954.46 4.97 437.77 2_Gyro-NS-CT_Drill pipe (1) 3,560.00 40.97 234.89 3,172.39 3,108.99 -1,110.59 431.66 5,998,785.84 565,949.15 3.19 -432.43 2_Gyro-NS-CT_Drill pipe (1) 3,570.00 41.24 235.27 3,179.92 3,116.52 -1,114.36 426.27 5,998,782.03 565,943.79 3.68 -427.05 2_Gyro-NS-CT_Dn1l pipe (1) 3,580.00 41.72 235.60 3,187.42 3,124.02 -1,118.11 420.81 5,998,778.23 565,938.37 5.27 421.59 2_Gyro-NS-CT_Drill pipe (1) 3,590.00 41.97 235.97 3,194.87 3,131.47 -1,121.87 415.30 5,998,774.43 565,932.89 3.51 416.08 2_Gyro-NS-CT_DdII pipe (1) 3,600.00 42.07 236.35 3,202.29 3,138.89 -1,125.59 409.74 5,998,770.65 565,927.36 2.73 -410.52 2_Gyro-NS-CT_Drill pipe (1) 3,610.00 42.47 236.63 3,209.69 3,146.29 -1,129.31 404.13 5,998,766.89 565,921.79 4.42 -404.92 2_Gyro-NS-CT_Drill pipe (1) 3,620.00 42.58 237.07 3,217.06 3,153.66 '-1,133.00 398.47 5,998,763.14 565,916.16 3.17 -399.26 2_Gyro-NS-CT_Dnll pipe (1) 3,630.00 42.72 237.67 3,224.42 3,161.02 -1,136.66 392.76 5,998,759.44 565,910.49 4.30 -393.56 2_Gyro-NS-CT_Drili pipe (1) 3,640.00 42.99 238.05 3,231.75 3,168.35 -1,140.27 387.00 5,998,755.77 565,904.76 3.74 -387.80 2_Gyro-NS-CT_Drill pipe (1) 3,650.00 43.18 238.45 3,239.05 3,175.65 -1,143.87 381.20 5,998,752.13 565,898.99 3.33 -381.99 2_Gyro-NS-CT_Drill pipe (1) 3,660.00 43.17 238.88 3,246.35 3,182.95 -1,147.43 375.35 5,998,748.52 565,893.17 2.94 -376.15 2_Gym-NSCT_Drill pipe (1) 3,670.00 43.59 239.23 3,253.61 3,190.21 -1,150.96 369.46 5,998,744.94 565,887.32 4.84 -370.26 2_Gyro-NS-CT_0611 pipe (1) 3,680.00 44.05 239.79 3,260.83 3,197.43 -1,154.47 363.49 5,998,741.37 565,881.38 6.02 -364.30 2_Gyro-NS-CT_Drill pipe (1) 3,690.00 44.29 240.42 3,268.00 3,204.60 -1,157.94 357.45 5,998,737.84 565,875.37 5.00 -358.26 2_Gyrc-NS-CT Drill pipe (1) 3,700.00 44.75 240.99 3,275.13 3,211.73 -1,161.38 351.34 5,998,734.36 565,869.29 6.09 -352.15 2_Gyro-NS-CT_Drill pipe (1) 3,710.00 45.21 241.49 3,282.21 3,218.81 -1,164.78 345.14 5,998,730.91 565,863.12 5.80 -345.96 2_Gyro-NS-CT_Dn1l pipe (i) 3,720.00 45.49 242.00 3,289.23 3,225.83 -1,168.14 338.88 5,998,727.48 565,856.89 4.58 -339.69 2_Gyro-NS-CT_DNII pipe (1) 3,730.00 45.86 242.50 3,296.22 3,232.82 -1,171.47 332.54 5,998,724.10 565,850.58 5.15 -333.36 2_Gyro-NS-CT_Dri1l pipe (1) 3,740.00 46.25 242.92 3,303.16 3,239.76 -1,174.78 326.15 5,998,720.74 565,844.22 4.94 -326.97 2_Gyro-NS-CT_Drill pipe (1) 3,750.00 46.46 243.46 3,310.06 3,246.66 -1,178.04 319.69 5,998,717.42 565,837.79 4.44 -320.51 2_Gyro-NS-CT_Drlll pipe (1) 3,760.00 46.67 244.04 3,316.94 3,253.54 -1,181.25 313.18 5,998,714.15 565,831.30 4.71 -314.00 2_Gyro-NS-CT_Drill pipe (1) 3,770.00 47.13 244.42 3,323.77 3,260.37 -1,184.43 306.60 5,998,710.92 565,824.76 5.37 -307.43 2_Gyro-NS-CT_Drill pipe (1) 3,780.00 47.31 244.83 3,330.56 3,267.16 -1,187.57 299.97 5,998,707.72 565,818.15 3.51 -300.80 2_Gyro-NSCT_Drill pipe (1) 9/162019 12:14:44PM Page 11 COMPASS 5000.15 Build 91 Survey Halliburton Definitive Survey Report Map Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU S-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU S-203PB1 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB1 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing Easting DLS Section (usft) (') (`) (usft) (usft) (usft) (usft) (ft) (ft) (-1100-) (ft) Survey Tool Name 3,790.00 47.37 245.30 3,337.34 3,273.94 -1,190.67 293.30 5,998,704.56 565,811.51 3.51 -294.13 2_Gyro-NS-CT_Drill pipe (1) 3,800.00 48.01 245.61 3,344.07 3,280.67 -1,193.74 286.57 5,998,701.43 565,804.81 6.80 -287.41 2_Gyro-NS-CT_Dnll pipe (1) 3,810.00 48.30 245.96 3,350.74 3,287.34 -1,196.80 279.78 5,998,698.32 555,798.05 3.90 -280.61 2_Gyro-NS-CT_Drill pipe (1) 3,820.00 48.54 246.25 3,357.38 3,293.98 -1,199.83 272.94 5,998,695.23 565,791.24 3.24 -273.78 2_Gym-NS-CT_Drill pipe (1) 3,830.00 49.09 246.55 3,363.96 3,300.56 -1,202.84 266.04 5,998,692.15 565,784.37 5.95 -266.88 2_Gyro-NS-CT_Drill pipe (1) 3,840.00 49.18 246.91 3,370.51 3,307.11 -1,205.83 259.10 5,998,689.10 565,777.45 2.87 -259.94 2_Gyro-NS-CT_Drill pipe (1) 3,850.00 49.18 247.24 3,377.04 3,313.64 -1,208.78 252.13 5,998,686.10 565,770.50 2.50 -252.97 2_Gyro-NS-CT_Drill pipe (1) 3,860.00 49.48 247.48 3,383.56 3,320.16 -1,211.70 245.13 5,998,683.12 565,763.53 3.51 -245.97 2_Gyro-NS-CT_DnIl pipe (1) 3,870.00 49.74 247.88 3,390.04 3,326.64 -1,214.59 238.08 5,998,680.16 565,756.51 4.01 -238.93 2 Gyro-NS-CT_Drill pipe (1) 3,880.00 49.90 248.30 3,396.49 3,333.09 -1,217.44 230.99 5,998,677.25 565,749.45 3.59 -231.84 2_Gyro-NS-CT_Drill pipe (1) 3,890.00 50.30 248.66 3,402.91 3,339.51 -1,220.25 223.85 5,998,674.37 565,742.34 4.86 -224.71 2_Gyro-NS-CT_Dnll pipe (1) 3,900.00 50.73 249.01 3,409.26 3,345.86 -1,223.04 216.66 5,998,671.52 565,735.16 5.08 -217.51 2_Gyro-NS-CT_Ddll pipe (1) 3,910.00 50.86 249.41 3,415.59 3,352.19 -1,225.79 209.41 5,998,668.71 565,727.95 3.36 -210.27 2_Gym-NS-CT_Drill pipe (1) 3,920.00 51.08 249.76 3,421.88. 3,358.48 -1,228.50 202.13 5,998,665.94 565,720.69 3.50 -202.99 2_Gyro-NS-CT_Drill pipe (1) 3,930.00 51.66 250.02 3,428.13 3,364.73 -1,231.19 194.80 5,998,663.19 565,713.38 6.15 -195.66 2_Gyro-NS-CT_Drill pipe (1) 3,940.00 51.87 250.47 3,434.31 3,370.91 -1,233.84 187.40 5,998,660.47 565,706.01 4.11 -188.27 2_Gyro-NS-CT_Dnll pipe (1) 3,950.00 52.01 250.95 3,440.48 3,377.08 -1,236.44 179.97 5,998,657.80 565,698.60 4.03 -180.84 2_Gyro-NS-CT_Ddil pipe (1) 3,960.00 52.85 251.26 3,446.58 3,383.18 -1,239.01 172.47 5,998,655.17 565,691.13 8.75 -173.34 2_Gyro-NS-CT_Drill pipe (1) 3,970.00 52.75 251.66 3,452.62 3,389.22 -1,241.54 164.92 5,998,652.57 565,683.60 3.34 -165.79 2_Gyro-NS-CT_Drill pipe (1) 3,980.00 52.79 252.08 3,458.67 3,395.27 -1,244.02 157.36 5,998,650.03 565,676.05 3.37 -158.22 2_Gyro-NS-CT_Dnll pipe (1) 3,990.00 53.33 252.44 3,464.68 3,401.28 -1,246.45 149.74 5,998,647.53 565,668.46 6.12 -150.61 2_Gyro-NS-CT_D6ll pipe (1) 4,000.00 53.58 252.89 3,470.64 3,407.24 -1,248.85 14207 5,998,645.06 565,660.82 4.40 -142.95 2_Gyro-NS-CT_Dnll pipe (1) 4,010.00 53.69 253.25 3,476.57 3,413.17 -1,251.19 134.37 5,998,642.65 565,653.14 3.10 -135.24 2_Gyro-NS-CT_Drill pipe (1) 4,020.00 54.17 253.65 3,482.45 3,419.05 -1,253.50 126.62 5,998,640.28 565,645.41 5.79 -127.50 2_Gyro-NS-CT_Drill pipe (1) 4,030.00 54.47 254.15 3,488.29 3,424.89 -1,255.75 118.82 5,998,637.96 565,637.63 5.05 -119.69 2_Gyro-NS-CT Drill pipe (1) 4,040.00 54.55 254.48 3,494.09 3,430.69 -1,257.95 110.98 5,998,635.69 565,629.81 2.80 -111.86 2 Gyro -NS -CT Drill pipe (1) 4,050.00 54.92 254.71 3,499.87 3,436.47 -1,260.12 103.11 5,998,633.45 565,621.96 4.15 -103.99 2_Gyro-NS-CT_Drill pipe (1) 4,060.00 55.35 254.95 3,505.58 3,442.18 -1,262.26 95.19 5,998,631.24 565,614.06 4.73 -96.07 2_Gyro-NS-CT_Drill pipe (1) 4,070.00 55.35 255.22 3,511.27 3,447.87 -1,264.38 87.24 5,998,629.05 565,606.13 2.22 -88.12 2_Gyro-NS-CT_Will pipe (1) 4,080.00 55.44 255.54 3,516.95 3,453.55 -1,266.46 79.27 5,998,626.90 565,598.18 2.78 -80.16 2 Gyro-NS-CT_Drill pipe (1) 4,090.00 56.11 255.83 3,522.57 3,459.17 -1,268.50 71.26 5,998,624.79 565,590.19 7.12 -72.15 2_Gyro-NS-CT_Drill pipe (1) 4,100.00 56.09 256.08 3,528.15 3,464.75 -1,270.52 63.21 5,998,622.71 565,582.16 2.08 -64.10 2_Gyro-NS-CT_Drill pipe (1) 4,110.00 56.08 256.30 3,533.73 3,470.33 -1.272.50 55.15 5,998,620.65 565,574.12 1.83 -56.04 2_Gyro-NS-CT_Dnll pipe (1) 4,120.00 56.69 256.47 3,539.26 3,475.86 -1,274.46 47.06 5,998,618.62 565,566.04 6.26 -47.95 2_Gyro-NS-CT_DnII pipe (1) 4,130.00 56.88 256.78 3,544.74 3,481.34 -1,276.39 38.92 5,998,616.62 565,557.92 3.22 -39.81 2_Gyro-NS-CT_Drill pipe (1) 4,140.00 56.94 257.07 3,550.20 3,486.80 -1,278.29 30.76 5,998,614.65 565,549.78 2.50 -31.65 2_Gyro-NS-CT_Dnll pipe (1) 4,150.00 57.83 257.24 3,555.59 3,492.19 -1,280.16 22.55 5,998,612.71 565,541.58 9.01 -23.44 2_Gyro-NS-CT_Dnll pipe (1) 4,160.00 58.26 257.47 3,560.88 3,497.48 -1,282.02 14.27 5,998,610.78 565,533.32 4.72 -15.16 2_Gyro-NS-CT_Dnll pipe (1) 4,170.00 58.14 257.72 3,566.15 3,502.75 -1,283.85 5.97 5,998,608.88 565,525.04 2.44 -6.86 2_Gyro-NS-CT_Drill pipe (1) 4,180.00 58.60 257.87 3,571.40 3,508.00 -1,285.65 -2.36 5,998,607.01 565,516.73 4.77 1.46 2_Gyro-NS-CT_Dnll pipe (1) 91162019 12:14:44PM Page 12 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU S-203PB1 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) C) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,190.00 59.09 257.99 3,576.57 3,513.17 -1,287.44 -10.72 5,998,605.14 565,508.38 5.01 9.82 2_Gyro-NS-CT_Drill pipe (1) 4,200.00 59.24 258.18 3,581.70 3,518.30 -1,289.21 -19.13 5,998,603.30 565,499.99 2.22 18.23 2_Gyro-NS-CT_Drill pipe (1) 4,210.00 59.82 258.38 3,586.77 3,523.37 -1,290.96 -27.56 5,998,601.47 565,491.57 6.05 26.66 2_Gyro-NS-CT_Drill pipe (1) 4,220.00 60.42 258.62 3,591.75 3,528.35 -1,292.69 -36.06 5,998,599.67 565,483.09 6.35 35.16 2_Gym-NS-CT_0rll pipe (1) 4,230.00 60.58 258.79 3,596.67 3,533.27 -1,294.39 -44.60 5,998,597.89 565,474.57 2.18 43.69 2_Gyro-NS-CT_Drill pipe (1) 4,240.00 60.95 258.95 3,601.56 3,538.16 -1,296.08 -53.16 5,998,596.13 565,466.03 3.95 52.25 2_Gyro-NS-CT_DnIl pipe (1) 4,250.00 61.43 259.11 3,606.38 3,542.98 -1,297.74 -61.76 5,998,594.39 565,457.44 5.00 60.85 2_Gyro-NS-CT_Dnll pipe (1) 4,260.00 61.46 259.32 3,611.16 3,547.76 -1,299.39 -70.39 5,998,592.67 565,448.83 1.87 69.48 2_Gyro-NS-CT_Drill pipe (1) 4,270.00 61.37 259.50 3,615.94 3,552.54 -1,301.00 -79.02 5,998,590.98 565,440.21 1.82 78.11 2_Gyro-NS-CT_Drill pipe (1) 4,280.00 61.83 259.59 3,620.70 3,557.30 -1,302.60 -87.67 5,998,589.31 565,431.58 4.67 86.76 2_Gyro-NS-CT_Dnll pipe (1) 4,290.00 61.81 259.76 3,625.42 3,562.02 -1,304.18 -96.34 5,998,567.65 565,422.92 1.69 95.43 2_Gyro-NS-CT_Dnll pipe (1) 4,300.00 61.69 259.97 3,630.15 3,566.75 -1,305.72 -105.01 5,998,586.03 565,414.26 2.06 104.10 2_Gyro-NS-CT_Drill pipe (1) 4,310.00 62.45 260.09 3,634.84 3,571.44 -1,307.25 -113.72 5,998,584.42 565,405.57 7.67 112.80 2_Gyro-NS-CT_Drill pipe (1) 4,320.00 62.67 260.26 3,639.45 3,576.05 -1,308.77 -122.46 5,998,582.83 565,396.84 2.67 121.55 2_Gyro-NS-CT_Drill pipe (1) 4,330.00 62.50 260.40 3,644.05 3,580.65 -1,310.26 -131.21 5,998,581.26 565,388.11 2.11 130.30 2_Gyro-NS-CT_Drill pipe (1) 4,340.00 63.22 260.42 3,648.61 3,585.21 -1,311.74 -139.99 5,998,579.71 565,379.35 7.20 139.07 2_Gyr0-NS-CT_Dnll pipe (1) 4,350.00 63.37 260.51 3,653.11 3,589.71 -1,313.22 -148.80 5,998,578.15 565,370.55 1.70 147.88 2_Gyro-NS-CT_Dnll pipe (1) 4,360.00 63.26 260.61 3,657.60 3,594.20 -1,314.69 -157.61 5,998,576.61 565,361.75 1.42 156.69 2_Gyro-NS-CT_Drill pipe (1) 4,370.00 63.73 260.68 3,662.06 3,598.66 -1,316.14 -166.44 5,998,575.07 565,352.94 4.74 165.52 2 Gyro-NS-CT_Drill pipe (1) 4,380.00 64.19 260.78 3,666.45 3,603.05 -1,317.59 -175.31 5,998,573.55 565,344.08 4.69 174.39 2_Gyro-NS-CT_Dn1l pipe (1) 4,390.00 64.40 260.89 3,670.79 3,607.39 -1,319.02 -184.20 5,998,572.04 565,335.20 2.32 183.28 2_Gyro-NS-CT_DnII pipe (1) 4,400.00 65.07 260.96 3,675.06 3,611.66 -1,320.45 -193.13 5,998,570.53 565,326.26 6.73 192.21 2_Gyro-NS-CT_Drill pipe (1) 4,410.00 65.67 260.99 3,679.22 3,615.82 -1,321.88 -202.11 5,998,569.03 565,317.32 6.01 201.19 2_Gyro-NS-CT_Drill Pipe (1) 4,420.00 65.82 261.06 3,683.33 3,619.93 -1,323.30 -211.12 5,998,567.53 565,308.33 1.63 210.19 2_Gyro-NS-CT_Drill pipe (1) 4,430.00 66.04 261.17 3,687.41 3,624.01 -1,324.71 -220.14 5,998,566.04 565,299.32 2.42 219.21 2_Gyro-NS-CT_Drill pipe (1) 4,440.00 67.11 261.22 3,691.38 3,627.98 -1,326.11 -229.20 5,998,564.55 565,290.27 10.71 228.28 2_Gyra-NS-CT_Dnll pipe (1) 4,450.00 67.55 261.43 3,695.24 3,631.84 -1,327.51 -238.33 5,998,563.08 565,281.16 4.81 237.40 2_Gyro-NS-CT_Drill pipe (1) 4,460.00 67.62 261.66 3,699.05 3,635.65 -1,328.86 -247.47 5,998,561.64 565,272.03 2.24 246.54 2_Gyro-NS-CT_Drill pipe (1) 4,470.00 68.65 261.74 3,702.78 3,639.38 -1,330.20 -256.65 5,998,560.22 565,262.86 10.33 255.72 2_Gyro-NS-CT_Drill pipe (1) 4,480.00 68.68 261.84 3,706.41 3,643.01 -1,331.53 -265.87 5,998,558.81 565,253.65 0.98 264.94 2 Gyro-NS-CT_Ddll pipe (1) 4,490.00 68.53 261.91 3,710.06 3,646.66 -1,332.85 -275.09 5,998,557.42 565,244.45 1.64 274.16 2_Gyro-NS-CT_Drill pipe (1) 4,500.00 69.42 261.91 3,713.65 3,650.25 -1,334.16 -284.33 5,998,556.02 565,235.22 8.90 283.40 2_Gyro-NS-CT Drill pipe (1) 4,510.00 69.72 262.00 3,717.14 3,653.74 -1,335.48 -293.61 5,998,554.63 565,225.95 3.12 292.68 2_Gyro-NS-CT_Drill pipe (1) 4,520.00 69.70 262.14 3,720.61 3,657.21 -1,336.77 -302.90 5,998,553.25 565,216.67 1.33 301.97 2_Gyro-NS-CT_Drill pipe (1) 4,530.00 70.23 262.20 3,724.03 3,660.63 -1,338.05 -312.21 5,998,551.89 565,207.38 5.33 311.27 2_Gyro-1,18-CT_Drill pipe (1) 4,540.00 70.50 262.30 3,727.39 3,663.99 -1,339.32 -321.54 5,998,550.54 565,198.06 2.86 320.60 2 Gyro-NS-CT_Ddll pipe (1) 4,550.00 70.51 262.39 3,730.73 3,667.33 -1,340.58 -330.88 5,998,549.20 565,188.73 0.85 329.95 2_Gyro-NS-CT_Drill pipe (1) 4,560.00 70.90 262.52 3,734.04 3,670.64 -1,341.81 -340.24 5,998,547.88 565,179.38 4.09 339.30 2_Gyro-NS-CT Drill pipe (1) 4,570.00 71.59 262.71 3,737.25 3,673.85 -1,343.03 -349.63 5,998,546.58 565,170.01 7.13 346.69 2_Gyro-NS-CT_Drill pipe (1) 4,580.00 71.62 262.98 3,740.41 3,677.01 -1,344.21 -359.04 5,998,545.32 565,160.60 2.58 358.11 2_Gyro-NS-CT_DrII pipe (1) 91162019 12:14:44PM Page 13 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU 5-203PB1 Design: MPU 5-203PB1 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing (usft) (') (1) (usft) (usft) (usft) (usft) (ft) 4,590.00 72.01 263.18 3,743.53 3,680.13 -1,345.36 -368.48 5,998,544.09 4,600.00 72.84 263.28 3,746.55 3,683.15 -1,346.48 -377.94 5,998,542.88 4,610.00 72.99 263.42 3,749.49 3,686.09 -1,347.59 -387.44 5,998,541.69 4,620.00 73.11 263.53 3,752.40 3,689.00 -1,348.68 -396.94 5,998,540.52 4,630.00 74.32 263.61 3,755.20 3,691.80 -1,349.75 -406.48 5,998,539.36 4,640.00 74.88 263.79 3,757.86 3,694.46 -1,350.81 -416.06 5,998,538.22 4,650.00 75.60 263.89 3,760.41 3,697.01 -1,351.85 -425.68 5,998,537.10 4,660.00 76.70 263.95 3,762.80 3,699.40 -1,352.87 -435.33 5,998,535.99 4,670.00 77.11 264.07 3,765.07 3,701.67 -1,353.89 -445.02 5,998,534.89 4,680.00 76.93 264.18 3,767.31 3,703.91 -1,354.89 -454.71 5,998,533.80 4,690.00 77.48 264.19 3,769.53 3,706.13 -1,355.88 -464.41 5,998,532.73 4,700.00 77.73 264.26 3,771.67 3,708.27 -1,356.86 -474.13 5,998,531.66 4,710.00 77.86 264.33 3,773.79 3,710.39 -1,357.83 483.85 5,998,530.61 4,720.00 78.48 264.36 3,775.84 3,712.44 -1,358.80 -493.59 5,998,529.56 4,730.00 78.81 264.36 3,777.81 3,714.41 -1,359.76 -503.35 5,998,528.51 4,740.00 78.95 264.33 3,779.74 3,716.34 -1,360.73 -513.12 5,998,527.46 4,750.00 79.20 264.29 3,781.63 3,718.23 -1,361.70 -522.89 5,998,526.40 4,760.00 79.39 264.28 3,783.49 3,720.09 -1,362.68 -532.66 5,998,525.33 4,770.00 79.33 264.31 3,785.34 3,721.94 -1,363.65 -542.44 5,998,524.27 4,780.00 79.36 264.33 3,787.18 3,723.78 -1,364.63 -552.22 5,998,523.21 4,790.00 79.87 264.30 3,788.99 3,725.59 -1,365.60 -562.01 5,998,522.15 4,800.00 8001 264.44 3,790.73 3,727.33 -1,366.57 -571.81 5,998,521.10 4,810.00 80.31 264.65 3,792.44 3,729.04 -1,367.50 -581.62 5,998,520.08 4,820.00 81.50 264.81 3,794.02 3,730.62 -1,368.41 -591.45 5,998,519.08 4,830.00 82.17 265.01 3,795.44 3,732.04 -1,369.29 -601.31 5,998,518.12 4,840.00 82.82 265.28 3,796.75 3,733.35 -1,370.13 -611.19 5,998,517.19 4,846.77 83.36 265.31 3,797.56 3,734.16 -1,370.68 817.89 5,998,516.58 4,904.94 84.70 268.40 3,803.62 3,740.22 -1,373.85 -675.64 5,998,512.91 4,968.52 83.38 269.42 3,810.22 3,746.82 -1,375.05 -738.87 5,998,511.15 5,032.31 83.39 270.41 3,817.57 3,754.17 -1,375.15 -802.23 5,998,510.50 5,096.62 84.01 271.22 3,824.62 3,761.22 -1,374.24 -866.15 5,998,510.85 5,159.75 86.43 272.63 3,829.88 3,766.48 -1,372.13 -929.01 5,998,512.41 5,223.17 87.16 272.57 3,833.43 3,770.03 -1,369.25 -992.27 5,998,514.73 5,286.77 88.78 272.34 3,835.68 3,772.28 -1,366.53 -1,055.77 5,998,516.89 5,309.42 89.58 272.45 3,836.01 3,772.61 -1,365.58 -1,078.40 5,998,517.64 5,405.95 90.42 275.41 3,83601 3,772.61 -1,358.97 -1,174.69 5,998,523.41 5,469.78 90.73 275.77 3,835.37 3,771.97 -1,352.75 -1,238.21 5,998,529.07 5,532.85 92.70 276.11 3,833.48 3,770.08 -1,346.23 -1,300.91 5,998,535.04 5,597.02 94.56 277.08 3,829.42 3,766.02 -1,338.87 -1,364.53 5,998,541.84 5,660.62 94.80 276.89 3,824.23 3,760.83 -1,331.17 -1,427.44 5,998,548.99 Well MPU 5-203 MPU 5-203 Actual RKB @ 63.40usft MPU 5-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Map Easting DLS (ft) (°1100') 565,151.18 4.34 565,141.73 8.35 565,132.24 2.01 565,122.75 565,113.22 565,103.65 565,094.05 565,084.40 565,074.73 565,065.04 565,055.35 565,045.64 565,035.93 565,026.20 565,016.45 565,006.70 564,996.94 564,987.17 564,977.40 564,967.63 564,957.85 564,948.06 564,938.26 564,928.44 564,918.59 564,908.72 564,902.03 564,844.30 564,781.10 564,717.75 564,653.83 564,590.95 564,527.68 564,464.17 564,441.53 564,345.20 564,281.63 564,218.88 564,155.21 564,092.23 1.60 12.12 5.86 7.26 11.02 4.26 2.09 5.50 2.59 1.47 6.21 3.30 1.43 2.53 1.90 O.67 0.36 5.11 1.96 3.64 12.00 6.99 7.03 7.99 5.76 2.62 1.54 1.58 4.43 1.15 2.57 3.57 3.19 0.74 3.17 3.27 0.48 Vertical Section (ft) Survey Tool Name 367.54 2_Gyro-NS-CT_Dnl1 pipe (1) 377.00 2_Gyro-NS-CT_Drill pipe (1) 386.50 2_Gyro-NS-CT_Drill pipe (1) 396.00 2_Gyro-NS-CT_Dnll pipe (1) 405.54 2_Gyro-NS-CT_D611 pipe (1) 415.12 2_Gyre-NS-CT_Drill pipe (1) 424.73 2_Gym-NS-CT_Dnll pipe (1) 434.39 2 Gyro-NS-CT_DO pipe (1) 444.07 2_Gym-NS-CT_Drill pipe (1) 453.76 2_Gyr NS-CT_Dnll pipe (1) 463.47 2_Gyro-NS-CT_Dnll pipe (1) 473.18 2 Gyro-NS-CT_Drill pipe (1) 482.91 2_Gyre-NS-CT_Drill pipe (1) 492.65 2_Gyro-NS-CT_Dnll pipe (1) 502.40 2_Gyro-NS-CT_Dnll pipe (1) 512.17 2_Gyro-NS-CT_Drill pipe (1) 521.94 2_Gyro-NS-CT_Dnll pipe (1) 531.71 2_Gyro-NS-CT Drill pipe (1) 541.49 2_Gyro-NS-CT_Drill pipe (1) 551.27 2_Gyno-NS-CT_Dnll pipe (1) 561.06 2_Gyro-NS-CT_Drill pipe (1) 570.85 2_Gyro-NS-CT_Dnll pipe (1) 580.66 2_Gyro-NS-CT_Drill pipe (1) 590.49 2_Gyro-NS-CT_Drill pipe (1) 600.35 2_Gyro-NS-CT_Drill pipe (1) 610.23 2_Gyro-NS-CT_Drill pipe (1) 616.93 2_Gyro-NS-CT Drill pipe (1) 674.69 2 MWD+IFR2+MS+Sag(2) 737.91 2 MWD+IFR2+MS+Sa9 (2) 801.27 2 MWD+IFR2+MS+Sag (2) 865.19 2 MWD+IFR2+MS+Sag(2) 928.06 2_MWD+IFR2+MS+Sag(2) 991.31 2 MWD+IFR2+MS+Sag (2) 1,054.82 2_MWD+IFR2+MS+Sag(2) 1,077.44 2 MWD+IFR2+MS+Sag(2) 1,173.74 2_MWD+IFR2+MS+Sag(3) 1,237.27 2_MWD+IFR2+MS+Sag(3) 1,299.97 2_MWD+IFR2+MS+Sag(3) 1,363.59 2_MWD+IFR2+MS+Sag (3) 1,426.51 2_MWD+IFR2+MS+Sag (3) 9/162019 12:14.:44PM Page 14 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU S-203PB1 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB1 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD NDSS +NIS +PJ -W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 5,724.27 94.62 274.95 3,819.00 3,755.60 -1,324.62 -1,490.54 5,998,554.98 564,029.09 3.05 1,489.61 2_MWD+1FR2+MS+Sag(3) 5,787.86 93.94 273.43 3,814.25 3,750.85 -1,319.99 -1,553.78 5,998,559.06 563,965.82 2.61 1,552.86 2_MWD+IFR2+MS+Sag (3) 5,851.07 93.81 272.21 3,809.98 3,746.58 -1,316.89 -1,616.77 5,998,561.61 563,902.81 1.94 1,615.85 2_MWD+IFR2+MS+Sag (3) 5,914.97 93.81 270.41 3,805.74 3,742.34 -1,315.43 -1,680.51 5,998,562.51 563,839.07 2.81 1,679.59 2_MWD+IFR2+MS+Sag(3) 5,978.65 93.38 270.07 3,801.74 3,738.34 -1,315.16 -1,744.06 5,998,562.22 563,775.52 0.86 1,743.14 2_MWD+IFR2+MS+Sag (3) 6,041.96 93.94 269.52 3,797.70 3,734.30 -1,315.39 -1,807.24 5,998,561.44 563,712.35 1.24 1,806.32 2_MWD+IFR2+MS+Sag(3) 6,105.55 93.75 268.65 3,793.44 3,730.04 -1,316.40 -1,870.68 5,998,559.87 563,648.93 1.40 1,869.76 2_MWD+IFR2+MS+Sag(3) 6,169.10 93.01 267.26 3,789.69 3,726.29 -1,318.67 -1,934.07 5,998,557.05 563,585.56 2.47 1,933.15 2_MWD+IFR2+MS+Sag(3) 6,232.57 93.08 266.24 3,786.32 3,722.92 -1,322.26 -1,997.35 5,998,552.90 563,522.32 1.61 1,996.43 2_MWD+IFR2+MS+Sag (3) 6,296.24 93.26 267.74 3,782.80 3,719.40 -1,325.60 -2,060.83 5,998,549.01 563,458.88 2.37 2,059.91 2_MWD+IFR2+MS+Sag(3) 6,360.35 93.94 270.05 3,778.77 3,715.37 -1,326.83 -2,124.80 5,998,547.21 563,394.93 3.75 2,123.87 2_MWD+IFR2+MS+Sag (3) 6,423.88 93.75 271.25 3,774.51 3,711.11 -1,326.11 -2,188.18 5,998,547.37 563,331.55 1.91 2,187.26 2_MWD+IFR2+MS+Sag(3) 6,487.23 93.88 270.93 3,770.30 3,706.90 -1,324.91 -2,251.38 5,998,548.02 563,268.35 0.54 2,250.46 2_MWD+IFR2+MS+Sag (3) 6,550.90 92.39 269.39 3,766.81 3,703.41 -1,324.73 -2,314.95 5,998,547.64 563,204.79 3.36 2,314.03 2_MWD+IFR2+MS+Sag(3) 6,614.58 92.52 268.20 3,764.09 3,700.69 -1,326.07 -2,378.56 5,998,545.75 563,141.20 1.88 2,377.63 2_MWD+IFR2+MS+Sag(3) 6,677.91 92.70 268.05 3,761.20 3,697.80 -1,328.14 -2,441.79 5,998,543.12 563,078.00 0.37 2,440.86 2_MWD+IFR2+MS+Sag (3) 6,741.22 92.52 268.15 3,758.32 3,694.92 -1,330.24 -2,505.00 5,998,540.47 563,014.81 0.33 2,504.07 2_MWD+IFR2+MS+Sag(3) 6,805.38 92.46 268.97 3,755.53 3,692.13 -1,331.85 -2,569.08 5,998,538.30 562,950.76 1.28 2,568.15 2_MWD+IFR2+MS+Sag(3) 6,869.91 93.26 270.58 3,752.31 3,688.91 -1,332.10 -2,633.52 5,998,537.48 562,886.32 2.78 2,632.59 2_MWD+IFR2+MS+Sag(3) 6,932.41 93.51 271.12 3,748.62 3,685.22 -1,331.18 -2,695.91 5,998,537.86 562,823.94 0.95 2,694.98 2_MWD+IFR2+MS+Sag (3) 6,996.29 93.38 271.12 3,744.78 3,681.38 -1,329.93 -2,759.66 5,998,538.54 562,760.18 0.20 2,758.73 2_MWD+IFR2+MS+Sag(3) 7,060.39 93.57 273.98 3,740.90 3,677.50 -1,327.08 -2,823.57 5,998,540.83 562,696.25 4.46 2,822.64 2_MWD+IFR2+MS+Sag(3) 7,124.04 93.20 272.09 3,737.14 3,673.74 -1,323.72 -2,887.02 5,998,543.64 562,632.79 3.02 2,886.09 2_MWD+IFR2+MS+Sag(3) 7,187.73 92.58 271.81 3,733.93 3,670.53 -1,321.56 -2,950.59 5,998,545.24 562,569.20 1.07 2,949.67 2_MWD+IFR2+MS+Sag(3) 7,251.10 92.40 270.68 3,731.17 3,667.77 -1,320.18 -3,013.88 5,998,546.06 562,505.91 1.80 3,012.96 2_MWD+IFR2+MS+Sag (3) 7,314.34 92.45 271.04 3,728.50 3,665.10 -1,319.23 -3,077.06 5,998,546.46 562,442.73 0.57 3,076.14 2 MWD+IFR2+MS+Sag (3) 7,377.83 93.01 270.51 3,725.47 3,662.07 -1,318.38 -3,140.47 5,998,546.76 562,379.32 1.21 3,139.55 2_MWD+IFR2+MS+Sag (3) 7,441.46 92.46 269.24 3,722.44 3,659.04 -1,318.51 -3,204.03 5,998,546.06 562,315.77 2.17 3,203.11 2_MWD+IFR2+MS+Sag(3) 7,505.37 92.58 268.01 3,719.63 3,656.23 -1,320.05 -3,267.86 5,998,543.97 562,251.97 1.93 3,266.93 2_MWD+IFR2+MS+Sag (3) 7,568.58 91.96 268.52 3,717.12 3,653.72 -1,321.96 -3,330.99 5,998,541.51 562,188.86 1.27 3,330.06 2_MWD+IFR2+MS+Sag (3) 7,632.65 91.78 268.81 3,715.03 3,651.63 -1,323.45 -3,395.01 5,998,539.45 562,124.86 0.53 3,394.08 2_MWD+IFR2+MS+Sag(3) 7,695.33 92.70 268.58 3,712.58 3,649.18 -1,324.88 -3,457.62 5,998,537.48 562,062.27 1.51 3,456.70 2_MWD+IFR2+MS+Sag (3) 7,760.12 94.00 269.27 3,708.80 3,645.40 -1,326.09 -3,522.29 5,998,535.70 561,997.62 2.27 3,521.36 2_MWD+IFR2+MS+Sag (3) 7,823.60 93.44 269.94 3,704.68 3,641.28 -1,326.53 -3,585.63 5,998,534.70 561,934.29 1.37 3,584.70 2_MWD+IFR2+MS+Sag (3) 7,887.44 93.14 270.49 3,701.01 3,637.61 -1,326.29 -3,649.37 5,998,534.38 561,870.56 0.98 3,648.44 2_MWD+IFR2+MS+Sag(3) 7,950.58 93.57 270.79 3,697.32 3,633.92 -1,325.58 -3,712.39 5,998,534.54 561,807.54 0.83 3,711.47 2_MWD+IFR2+MS+Sag (3) 8,014.58 94.00 269.86 3,693.09 3,629.69 -1,325.22 -3,776.25 5,998,534.34 561,743.69 1.60 3,775.33 2_MWD+IFR2+MS+Sag (3) 8,078.17 94.25 270.34 3,688.52 3,625.12 -1,325.11 -3,839.68 5,998,533.89 561,680.27 0.85 3,838.75 2_MWD+IFR2+MS+Sag(3) 8,140.55 93.69 270.08 3,684.20 3,620.80 -1,324.88 -3,901.91 5,998,533.57 561,618.04 0.99 3,900.98 2_MWD+IFR2+MS+Sag (3) 8,205.08 93.69 268.75 3,680.05 3,616.65 -1,325.54 -3,966.30 5,998,532.35 561,553.67 2.06 3,965.37 2_MWD+IFR2+MS+Sag(3) 9/162019 12:14:44PM Page 15 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Coordinate Reference: Well MPU S-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU S-203PB1 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB1 _ Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W Northing Easting DLS Section (usft) (`) (1) (usft) (usft) (usft) (usft) (ft) (ft) ("1100') (ft) Survey Tool Name 8,268.93 93.57 268.60 3,676.01 3,612.61 -1,327.01 -4,030.00 5,998,530.32 561,489.98 0.30 4,029.07 2_MWD+IFR2+MS+Sag(3) 8,332.90 92.15 268.19 3,672.81 3,609.41 .1,328.80 4,093.87 5,998,527.97 561,426.14 2.31 4,092.94 2_MWD+IFR2+MS+Sag (3) 8,395.98 90.36 268.35 3,671.43 3,608.03 -1,330.71 4,156.90 5,998,525.51 561,363.14 2.85 4,155.97 2_MWD+IFR2+MS+Sag(3) 8,459.73 89.86 268.96 3,671.31 3,607.91 -1,332.20 4,220.63 5,998,523.46 561,299.43 1.24 4,219.70 2_MWD+IFR2+MS+Sag(3) 8,523.73 89.62 269.72 3,671.60 3,608.20 .1,332.94 -4,284.63 5,998,522.16 561,235.45 1.25 4,283.69 2_MWD+IFR2+M8+Sag(3) 8,587.49 89.99 270.11 3,671.82 3,608.42 -1,333.03 4,348.39 5,998,521.51 561,171.70 0.84 4,347.45 2_MWD+IFR2+MS+Sag (3) 8,650.90 90.17 270.64 3,671.73 3,608.33 -1,332.62 -4,411.79 5,998,521.37 561,108.29 0.88 4,410.86 2_MWD+IFR2+MS+Sag(3) 8,714.46 89.43 271.46 3,671.95 3,608.55 -1,331.46 -4,475.34 5,998,521.97 561,044.74 1.74 4,474.41 2_MWD+IFR2+MS+Sag(3) 8,778.25 90.11 272.29 3,672.21 3,608.81 -1,329.37 -4,539.10 5,998,523.50 560,980.98 1.68 4,538.17 2_MWD+IFR2+MS+Sag (3) 8,841.66 92.02 273.45 3,671.03 3,607.63 .1,326.19 -4,602.41 5,998,526.12 560,917.64 3.52 4,601.48 2_MWD+IFR2+MS+Sag (3) 8,904.99 93.50 272.55 3,667.98 3,604.58 -1,322.88 -4,665.58 5,998,528.88 560,854.46 2.73 4,664.65 2_MWD+IFR2+MS+Sag (3) 8,968.35 94.62 272.51 3,663.49 3,600.09 -1,320.09 4,728.72 5,998,531.11 560,791.30 1.77 4,727.79 2_MWD+IFR2+MS+Sag(3) 9,032.09 95.73 270.90 3,657.74 3,594.34 -1,318.20 -4,792.17 5,998,532.44 560,727.84 3.06 4,791.24 2_MWD+IFR2+MS+Sag (3) 9,095.77 94.63 270.36 3,651.99 3,588.59 -1,317.51 -4,855.58 5,998,532.59 560,664.43 1.92 4,854.66 2_MWD+IFR2+MS+Sag (3) 9,159.25 93.26 270.07 3,647.63 3,584.23 -1,317.27 -4,918.91 5,998,532.27 560,601.11 2.21 4,917.99 2_MWD+IFR2+MS+Sag(3) 9,223.13 91.84 269.55 3,644.78 3,581.38 -1,317.48 -4,982.72 5,998,531.50 560,537.31 2.37 4,981.80 2_MWD+IFR2+MS+Sag(3) 9,285.46 90.54 268.26 3,643.49 3,580.09 -1,318.67 -5,045.03 5,998,529.76 560,475.02 2.94 5,044.10 2_MWD+IFR2+MS+Sag(3) 9,350.25 90.23 268.52 3,643.06 3,579.66 -1,320.49 -5,109.79 5,998,527.37 560,410.29 0.62 5,108.87 2_MWD+IFR2+MS+Sag (3) 9,413.78 89.74 268.09 3,643.07 3,579.67 -1,322.37 -5,173.29 5,998,524.93 560,346.81 1.03 5,172.37 2_MWD+IFR2+MS+Sag(3) 9,477.28 91.10 270.06 3,642.61 3,579.21 -1,323.40 -5,236.78 5,998,523.35 560,283.34 3.77 5,235.85 2_MWD+IFR2+MS+Sag(3) 9,540.61 90.42 269.73 3,641.77 3,578.37 -1,323.51 -5,300.10 5,998,522.68 560,220.03 1.19 5,299.17 2_MWD+IFR2+MS+Sag(3) 9,604.53 88.87 269.91 3,642.16 3,578.76 -1,323.71 -5,364.02 5,998,521.92 560,156.12 2.44 5,363.09 2_MWD+IFR2+MS+Sag(3) 9,666.71 88.44 269.43 3,643.62 3,580.22 -1,324.07 -5,426.18 5,998,521.02 560,093.97 1.04 5,425.25 2_MWD+IFR2+MS+Sag (3) 9,730.44 88.50 269.83 3,645.32 3,581.92 -1,324.48 -5,489.88 5,998,520.05 560,030.28 0.63 5,488.96 2_MWD+IFR2+MS+Sag(3) 9,787.00 88.50 269.83 3,646.80 3,583.40 -1,324.65 5,546.42 5,998,519.38 559,973.74 0.00 5,545.50 PROJECTED to TD Checked By: Chelsea Wright 'W"�'- - Approved By: Benjamin Hand EE - - Date: 09-16-2019 9/1612019 12:14:44PM Page 16 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU S-203PB2 500292364471 Sperry Drilling Definitive Survey Report 16 September, 2019 HALLIBURTON Sporry Drilling Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU 5-203PB2 Design: MPU 5-203PB2 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU 5-203 MPU S-203 Actual RKB @ 63.40usft MPU 5-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU 5-203 Well Position +NI -S +E/ -W Position Uncertainty Wellbore Magnetics MPU 5-203PB2 Model Name 0.00 usft Northing: 5,999,892.50 usfl 0.00 usft Easting: 565,507.81 usfl 0.00 usft Wellhead Elevation: usft Sample Date Declination (°) BGGM2018 9/5/2019 16.52 Latitude: 70" 24'36.560 N Longitude: 149° 27'59,733 W Ground Level: 36.70 usft Dip Angle Field Strength (°) (nT) 80.92 57 413.70041413 Design MPU S-203PB2 Audit Notes: wet sands encountered after fault at 10525'MD. P&A'd section Version: 1.0 Phase: ACTUAL Tie On Depth: 8,014.58 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (°) 26.70 0.00 0.00 270.04 Survey Program Date 9/13/2019 From (usft) To (usft) Survey (Wellbore) Tool Name Description Survey Date 88.88 4,846.77 MPU 5-203PB1 SDI Gyro (MPU 5-203PI 2_Gyro-NS-CT_Drill pipe H037Ga: Continuous on wireline in drill pipe 09/02/2019 MPU S-203PB1 MWD+IFR2+MS+Sag (12_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 08/26/2019 4,904.94 5,405.95 5,309.42 8,014.58 MPU 5-203PB1 MWD+IFR2+MS+Sag 1<2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa 09/03/2019 MPU 5-203PB2 MWD+MS+Sag (3) (MP12_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 09/05/2019 8,073.00 11,319.17 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +EI -W Northing Easting DLS Section (usft) (1 (') (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 26.70 0.00 0.00 26.70 -36.70 0.00 0.00 5,999,892.50 565,507.81 0.00 0.00 UNDEFINED 88.88 0.55 81.39 88.88 25.48 0.04 0.30 5,999,892.55 565,508.10 0.88 -0.30 2_Gyro-NS-CT_Drill pipe (1) 96.58 0.49 80.28 96.58 33.18 0.06 0.36 5,999,892.56 565,508.17 0.79 -0.36 2_Gyro-NS-CT_Drill pipe (1) 100.00 0.48 79.04 100.00 36.60 0.06 0.39 5,999,892.56 565,508.20 0.42 -0.39 2 Gyro-NS-CT_Drill pipe (1) 110.00 0.44 74.05 110.00 46.60 0.08 0.47 5,999,892.58 565,508.28 0.57 -0.47 2_Gyro-NS-CT_Drill pipe (1) 120.00 0.45 70.91 120.00 56.60 0.10 0.54 5,999,892.61 565,508.35 0.26 -0.54 2_Gyro-NS-CT_Drill pipe (1) 130.00 0.46 75.26 130.00 66.60 0.13 0.62 5,999,892.63 565,508.43 0.36 -0.62 2_Gyro-NS-CT_Drill pipe (1) 140.00 0.47 78.77 140.00 76.60 0.14 0.70 5,999,892.65 565,508.51 0.30 -0.70 2_Gyr -NS-CT-Drill pipe (1) 150.00 0.48 76.25 150.00 86.60 0.16 0.78 5,999,892.67 565,508.59 0.23 -0.78 2_Gyro-NS-CT Drill pipe (1) 160.00 0.47 81.08 160.00 96.60 0.18 0.86 5,999,892.69 565,508.67 0.41 -0.86 2_Gyro-NS-CT_Drill pipe (1) 170.00 0.51 86.04 170.00 106.60 0.19 0.95 5,999,892.70 565,508.75 0.58 -0.95 2_Gyro-NSCT_Dnll pipe (1) 9/16/2019 12:24:39PM Page 2 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU 5-203PB2 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB2 Database: NORTHUS+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (-1100-) (ft) Survey Tool Name 180.00 0.56 86.69 180.00 116.60 0.19 1.04 5,999,892.70 565,508.85 0.50 -1.04 2_Gyro-NS-CT_Drill pipe (1) 190.00 0.57 89.34 190.00 126.60 0.20 1.14 5,999,892.71 565,508.95 0.28 -1.14 2 Gyro-NS-CT_Drill pipe (1) 200.00 0.57 92.35 199.99 136.59 0.20 1.24 5,999,892.71 565,509.05 0.30 -1.24 2_Gyro-NB-CT_Dnll pipe (1) 210.00 0.62 95.61 209.99 146.59 0.19 1.34 5,999,892.70 565,509.15 0.60 -1.34 2_Gyro-NS-CT_Drill pipe (1) 220.00 0.68 94.50 219.99 156.59 0.18 1.45 5,999,892.69 565,509.26 0.61 -1.45 2_Gyro-NS-CT Drill pipe (1) 230.00 0.78 93.98 229.99 166.59 0.17 1.58 5,999,892.68 565,509.39 1.00 -1.58 2_Gyro-NS-CT_Dnll pipe ll) 240.00 0.86 94.26 239.99 176.59 0.16 1.72 5,999,892.67 565,509.53 0.80 -1.72 2_Gyro-NS-CT_Drili pipe (1) 250.00 0.94 97.58 249.99 186.59 0.14 1.88 5,999,892.66 565,509.69 0.95 -1.88 2_Gyro-NS-CT_Drill pipe (1) 260.00 1.02 98.39 259.99 196.59 0.12 2.05 5,999,892.64 565,509.86 0.81 -2.05 2_Gyro-NS-CT_Drill pipe (1) 270.00 1.09 95.90 269.99 206.59 0.10 2.23 5,999,892.62 565,510.04 0.84 -2.23 2_Gyro-NS-CT_Drill pipe (1) 280.00 1.17 96.05 279.99 216.59 0.08 2.43 5,999,892.60 565,510.24 0.80 -2.43 2_Gyro-NS-CT_Drill pipe (1) 290.00 1.26 98.12 289.98 226.58 0.05 2.64 5,999,892.57 565,510.45 1.00 -2.64 2_Gyro-NS-CT_Drill pipe (1) 300.00 1.29 97.86 299.98 236.58 0.02 2.86 5,999,892.54 565,510.67 0.31 -2.86 2_Gyro-NS-CT_Drill pipe (1) 310.00 1.39 98.65 309.98 246.58 -0.02 3.09 5,999,892.51 565,510.90 1.02 -3.09 2_Gyro-NS-CT_Drill pipe (1) 320.00 1.62 102.87 319.97 256.57 -0.07 3.35 5,999,892.46 565,511.16 2.55 -3.35 2_Gyro-NS-CT_Drill pipe (1) 330.00 1.80 105.15 329.97 266.57 -0.14 3.64 5,999,892.39 565,511.45 1.92 -3.64 2_Gyro-NS-CT_Drill pipe (1) 340.00 1.92 105.56 339.96 276.56 -0.22 3.95 5,999,892.31 565,511.76 1.21 -3.95 2_Gyro-NSCT Drill pipe (1) 350.00 2.06 107.17 349.96 286.56 -0.32 4.28 5,999,892.22 565,512.10 1.51 .4.28 2_Gyro-NS-CT_Drill pipe (1) 360.00 2.26 108.85 359.95 296.55 -0.44 4.64 5,999,892.10 565,512.46 2.10 4.64 2_Gyro-NS-CT_Dn1l pipe (1) 370.00 2.50 110.77 369.94 306.54 -0.58 5.03 5,999,891.96 565,512.85 2.53 -5.03 2_Gyro-NS-CT Drill pipe (1) 380.00 2.69 114.01 379.93 316.53 -0.75 5.45 5,999,891.80 565,513.27 2.40 -5.45 2_Gyro-NS-CT_Drill pipe (1) 390.00 2.78 115.60 389.92 326.52 -0.95 5.88 5,999,891.60 565,513.70 1.18 -5.88 2_Gyro-NS-CT_Drill pipe (1) 400.00 3.00 113.75 399.91 336.51 -1.16 6.34 5,999,891.39 565,514.16 2.39 -6.34 2_Gyro-NS-CT_Ddil pipe (1) 410.00 3.66 113.11 409.89 346.49 -1.39 6.88 5,999,891.17 565,514.70 6.61 -6.88 2_Gyro-NS-CT_Drill pipe (1) 420.00 4.33 113.73 419.87 356.47 -1.67 7.51 5,999,890.90 565,515.34 6.71 -7.52 2_Gyro-NS-CT_Dnll pipe (1) 430.00 4.80 114.18 429.84 366.44 -1.99 8.24 5,999,890.58 565,516.07 4.71 -8.24 2_Gyro-NS-CT_Drill pipe (1) 440.00 5.28 114.21 439.80 376.40 -2.35 9.04 5,999,890.23 565,516.87 4.80 -9.04 2_Gyro-NS-CT_Drill pipe (1) 450.00 5.72 114.19 449.75 386.35 -2.75 9.92 5,999,889.84 565,517.75 4.40 -9.92 2_Gym-NS-CT_Drill pipe (1) 460.00 6.04 114.72 459.70 396.30 -3.17 10.85 5,999,889.42 565,518.69 3.25 -10.85 2_Gyro-NS-CT_0611 pipe (1) 470.00 6.36 115.34 469.64 406.24 -3.63 11.83 5,999,888.98 565,519.67 3.27 -11.83 2_Gyro-NS-CT Drill pipe (1) 480.00 6.68 115.56 479.58 416.18 -4.12 12.85 5,999,888.50 565,520.70 3.21 -12.86 2 Gyro-NS-CT_Dnll pipe (1) 490.00 6.98 115.86 489.50 426.10 -4.63 13.92 5,999,887.99 565,521.77 3.02 -13.93 2_Gyro-NS-CT_Drill pipe (1) 500.00 7.32 116.19 499.43 436.03 -5.18 15A4 5,999,887.45 565,522.90 3.42 -15.05 2_Gyro-NS-CT_Drill pipe (1) 510.00 7.65 116.71 509.34 445.94 -5.76 16.21 5,999,886.88 565,524.07 3.37 -16.21 2_Gyra-NS-CT_Drill pipe (1) 520.00 8.00 117.37 519.25 455.85 -6.38 17.42 5,999,886.28 565,525.29 3.61 -17.43 2_Gyro-NS-CT_Ddil pipe (1) 530.00 8.41 117.90 529.15 465.75 -7.04 18.69 5,999,885.62 565,526.56 4.17 -18.69 2_Gyro-NS-CT_Drill pipe (1) 540.00 8.77 118.82 539.03 475.63 -7.75 20.00 5,999,884.93 565,527.88 3.85 -20.01 2_Gyro-NS-CT_Drill pipe (1) 550.00 9.18 119.74 548.91 485.51 -8.51 21.36 5,999,884.18 565,529.24 4.34 -21.37 2_Gyro-NS-CT_Drill pipe (1) 560.00 9.68 120.46 558.78 495.38 -9.33 22.78 5,999,883.37 565,530.67 5.14 -22.79 2_Gyro-NS-CT Dnll pipe (1) 570.00 10.15 121.60 568.63 505.23 -10.22 24.25 5,999,882.49 565,532.15 5.09 -24.26 2_Gyro-NS-CT_Drill pipe (1) 9/16/2019 12:24:39PM Page 3 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU S-203PB2 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 580.00 10.65 122.60 578.46 515.06 -11.18 25.78 5,999,881.55 565,533.69 5.32 -25.79 2_Gyro-NS-CT_Drill pipe (1) 590.00 11.12 123.30 588.28 524.88 -12.21 27.37 5,999,880.53 565,535.28 4.88 -27.38 2_Gyro-NS-CT_Drlll pipe (1) 600.00 11.52 124.58 598.09 534.69 -13.31 29.00 5,999,879.45 565,536.92 4.72 -29.00 2 Gyro-NS-CT_Drill pipe (1) 610.00 11.87 125.87 607.88 544.48 -14.48 30.65 5,999,878.30 565,538.58 4.37 -30.66 2_Gyro-NS-CT_Dnll pipe (1) 620.00 12.18 126.20 617.66 554.26 -15.70 32.34 5,999,877.08 565,540.28 3.18 -32.35 2_Gyro-NS-CT_Ddll pipe (1) 630.00 12.70 126.83 627.43 564.03 -16.98 34.07 5,999,875.82 565,542.02 5.37 -34.08 2_Gyro-NS-CT_Drill pipe (1) 640.00 13.15 128.25 637.17 573.77 -18.35 35.84 5,999,874.47 565,543.81 5.51 -35.85 2_Gyro-NS-CT_Drill pipe (1) 650.00 13.49 129.75 646.90 583.50 -19.80 37.63 5,999,873.04 565,545.61 4.85 -37.64 2 Gyro-NS-CT_Drill pipe (1) 660.00 13.91 130.61 656.62 593.22 -21.32 39.44 5,999,871.52 565,547.43 4.67 -39.45 2_Gyro-NS-CT Drill pipe (1) 670.00 14.57 131.42 666.31 602.91 -22.94 41.29 5,999,869.93 565,549.30 6.89 -41.31 2_Gyro-NS-CT_Ddll pipe (1) 680.00 15.03 132.23 675.98 612.58 -24.64 43.20 5,999,868.24 565,551.22 5.04 -43.22 2_Gyro-NS-CT_Drill pipe (1) 690.00 15.39 133.26 685.63 622.23 -26.42 45.12 5,999,866.48 565,553.16 4.50 -45.14 2_Gyro-NS-CT_Drill pipe (1) 700.00 15.77 134.23 695.26 631.86 -28.28 47.06 5,999,864.64 565,555.12 4.61 -47.08 2_Gyro-NS-CT_Dnll pipe (1) 710.00 16.15 135.23 704.88 641.48 -30.22 49.02 5,999,862.72 565,557.09 4.69 49.04 2_Gyro-NS-CT_Dnll pipe (1) 720.00 16.57 136.24 714.47 651.07 -32.23 50.98 5,999,860.72 565,559.07 5.07 -51.01 2_Gyro-NS-CT_Drill pipe (1) 730.00 17.06 137.39 724.04 660.64 -34.34 52.96 5,999,858.63 565,561.07 5.92 52.99 2_Gyro-NS-CT_Drill pipe (1) 740.00 17.49 138.39 733.59 670.19 -36.55 54.95 5,999,856.44 565,563.08 5.23 -54.98 2_Gyro-NS-CT_Drill pipe (1) 750.00 17.89 138.86 743.12 679.72 -38.83 56.96 5,999,854.18 565,565.11 4.25 -56.99 2_Gyro-NS-CT_Drill pipe (1) 760.00 18.16 139.60 752.63 689.23 41.17 58.98 5,999,851.85 565,567.15 3.54 -59.01 2 Gyra-NS-CT_Dnll pipe (1) 770.00 18.33 140.36 762.13 698.73 43.57 61.00 5,999,849.47 565,569.18 2.92 -61.03 2_Gyro-NS-CT_Drll pipe (1) 780.00 18.58 140.87 771.61 708.21 46.01 63.00 5,999,847.05 565,571.21 2.98 -63.04 2_Gyro-NS-CT_Drill pipe (1) 790.00 18.81 141.12 781.08 717.68 -48.50 65.02 5,999,844.57 565,573.25 2.44 -65.06 2_Gyro-NS-CT_Drill pipe (1) 800.00 18.97 141.91 790.55 727.15 -51.04 67.04 5,999,842.06 565,575.29 3.02 -67.07 2_Gyro-NS-CT_Dnll pipe (1) 810.00 19.16 142.45 800.00 736.60 -53.62 69.04 5,999,839.49 565,577.31 2.59 -69.08 2_Gyro-NS-CT_Drill pipe (1) 820.00 19.25 143.29 809.44 746.04 -56.24 71.02 5,999,836.89 565,579.32 2.91 -71.06 2_Gyro-NS-CT_Drill pipe (1) 830.00 19.37 144.51 818.88 755.48 -58.91 72.97 5,999,834.23 565,581.29 4.21 -73.01 2_Gyro-NS-CT_Drill pipe (1) 840.00 19.55 145.25 828.31 764.91 -61.64 74.89 5,999,831.53 565,583.23 3.05 -74.93 2 Gyro-NS-CT_Drill pipe (1) 850.00 19.64 145.87 837.73 774.33 54.40 76.79 5,999,828.78 565,585.15 2.27 -76.83 2_Gyro-NS-CT Drill pipe (1) 860.00 19.75 146.67 847.14 783.74 -67.21 78.66 5,999,825.99 565,587.05 2.91 -78.70 2_Gyro-NS-CT_Drill pipe (1) 870.00 19.88 147.23 856.55 793.15 -70.05 80.51 5,999,823.17 565,588.92 2.30 -80.55 2_Gyro-NS-CT_Drill pipe (1) 880.00 19.99 147.59 865.95 802.55 -72.92 82.34 5,999,820.31 565,590.78 1.65 -82.39 2 Gyro-NS-CT_Drill pipe (1) 890.00 20.03 147.98 875.35 811.95 -75.82 84.17 5,999,817.43 565,592.63 1.39 -84.22 2_Gyro-NS-CT_Dnll pipe (1) 900.00 20.18 148.24 884.74 821.34 -78.73 85.98 5,999,814.53 565,594.47 1.75 -86.04 2_Gyro-NS-CT_Dnll pipe (1) 910.00 20.40 148.41 894.12 830.72 -81.69 87.80 5,999,811.60 565,596.32 2.28 -87.86 2_Gyn NS-CT_DnII pipe (1) 920.00 20.56 148.68 903.49 840.09 -84.67 89.63 5,999,808.63 565,598.17 1.86 -89.69 2_Gyro-NS-CT_Drill pipe (1) 930.00 20.78 148.93 912.84 849.44 -87.69 91.46 5,999,805.62 565,600.02 2.37 -91.52 2_Gyro-NS-CT_Drill pipe (1) 940.00 21.07 149.05 922.18 858.78 -90.75 93.30 5,999,802.58 565,601.89 2.93 -93.36 2_Gyro-NS-CT Drill pipe (1) 950.00 21.27 149.29 931.51 868.11 -93.85 95.15 5,999,799.49 565,603.77 2.18 -95.21 2_Gyro-NS-CT_Drill pipe (1) 960.00 21.51 149.50 940.82 877.42 -96.99 97.00 5,999,796.37 565,605.65 2.52 -97.07 2_Gyro-NS-CT_Drill pipe (1) 970.00 21.94 149.39 950.11 886.71 -100.17 98.88 5,999,793.21 565,607.56 3.32 -98.95 2_Gyro-NS-CT_Dnll pipe (1) 9/162019 12:24:39PM Page 4 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU 5-203 MPU 5-203PB2 MPU S-203PB2 Local Co-ordinate Reference: Well MPU 5-203 TVD Reference: MPU 5-203 Actual IRKS @ 63.40usft MD Reference: MPU 5-203 Actual RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVOSS +NIS +EI -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 980.00 22.12 149.13 959.39 895.99 -103.39 100.80 5,999,790.01 565,609.50 2.96 -100.87 2_Gym-NS-CT_Drill pipe (1) 990.00 22.49 148.91 968.64 905.24 -106.64 102.75 5,999,786.77 565,611.48 3.79 -102.82 2_Gyro-NS-CT_Dnll pipe (1) 1,000.00 22.92 148.63 977.86 914.46 -109.94 104.75 5,999,783.49 565,613.51 4.43 -104.83 2_Gyro-NS-CT_Drill pipe (1) 1,010.00 23.14 148.27 987.07 923.67 -113.28 106.80 5,999,780.17 565,615.59 2.61 -106.88 2_Gyro-NS-CT_Dnll pipe (1) 1,020.00 23.32 147.93 996.25 932.85 -116.63 108.88 5,999,776.85 565,617.70 2.24 -108.96 2_Gyro-NS-CT_Drill pipe (1) 1,030.00 23.74 147.56 1,005.42 942.02 -120.00 111.01 5,999,773.49 565,619.86 4.45 -111.10 2_Gyro-NSCT_Drill pipe (1) 1,040.00 24.08 147.08 1,014.57 951.17 -123.41 113.20 5,999,770.10 565,622.08 3.92 -113.29 2 Gyro -NS -CT Dnll pipe (1) 1,050.00 24.39 146.49 1,023.68 960.28 -126.85 115.45 5,999,766.68 565,624.36 3.93 -115.54 2_Gyro-NS-CT_DrIl pipe (1) 1,060.00 24.93 145.96 1,032.77 969.37 -130.31 117.77 5,999,763.24 565,626.71 5.84 -117.86 2_Gym-NS-CT_Drill pipe (1) 1,070.00 25.36 145.50 1,041.82 978.42 -133.83 120.16 5,999,759.75 565,629.13 4.72 -120.26 2_Gyro-NS-CT_Drill pipe (1) 1,080.00 25.66 144.90 1,050.85 987.45 -137.36 122.62 5,999,756.23 565,631.62 3.96 -122.72 2_Gyro-NS-CT Drill pipe (1) 1,090.00 26.06 144.33 1,059.85 996.45 -140.92 125.15 5,999,752.70 565,634.18 4.71 -125.24 2_Gyro-NS-CT_Dnll pipe (1) 1,100.00 26.42 143.92 1,068.82 1,005.42 -144.50 127.74 5,999,749.14 565,636.80 4.03 -127.84 2_Gyro-NS-CT_Drill pipe (1) 1,110.00 26.65 143.51 1,077.76 1,014.36 -148.10 130.38 5,999,745.56 565,639.47 2.94 -130.48 2_Gyro-NS-CT_Ddll pipe (1) 1,120.00 26.95 143.03 1,086.69 1,023.29 -151.72 133.08 5,999,741.97 565,642.20 3.70 -133.18 2_Gyro-NS-CT_Drill pipe (1) 1,130.00 27.22 142.64 1,095.59 1,032.19 -155.34 135.83 5,999,738.37 565,644.98 3.23 -135.94 2_Gyro-NS-CT_Dnll pipe (1) 1,140.00 27.33 142.23 1,104.48 1,041.08 -158.98 138.62 5,999,734.76 565,647.81 2.18 -138.73 2_Gyro-NS-CT_Dnll pipe (1) 1,150.00 27.53 141.67 1,113.36 1,049.96 -162.60 141.46 5,999,731.16 565,650.68 3.26 -141.57 2_Gyro-NS-CT Drill pipe (1) 1,160.00 27.88 141.20 1,122.21 1,058.81 -166.24 144.36 5,999,727.55 565,653.61 4.13 -144.48 2_Gyro-NS-CT_Drill pipe (1) 1,170.00 28.03 140.66 1,131.04 1,067.64 -169.88 147.31 5,999,723.94 565,656.59 2.94 -147.43 2_Gyro-NSCT_Drill pipe (1) 1,180.00 28.16 140.08 1,139.87 1,076.47 -173.51 150.32 5,999,720.34 565,659.63 3.02 -150.44 2_Gyr NS -CT -Drill pipe (1) 1,190.00 28.41 139.63 1,148.67 1,085.27 -177.13 153.37 5,999,716.74 565,662.72 3.29 -153.50 2_Gyro-NS-CT_Dnll pipe (1) 1,200.00 28.48 139.31 1,157.46 1,094.06 -180.75 156.47 5,999,713.15 565,665.84 1.68 -156.59 2_Gyro-NS-CT_Drill pipe (1) 1,210.00 28.46 138.97 1,166.25 1,102.85 -184.35 159.59 5,999,709.57 565,668.99 1.63 -159.72 2_Gyro-NS-CT_Drlli pipe (1) 1,220.00 28.82 138.65 1,175.03 1,111.63 -187.96 162.74 5,999,705.99 565,672.18 3.91 -162.87 2_Gyro-NS-CT_Drill pipe (1) 1,230.00 28.92 138.46 1,183.79 1,120.39 -191.58 165.94 5,999,702.40 565,675.41 1.36 -166.07 2_Gyro-NS-CT_Dnll pipe (1) 1,240.00 29.01 138.33 1,192.54 1,129.14 -195.20 169.15 5,999,698.81 565,678.65 1.10 -169.29 2_Gym-NS-CT_Dril1 pipe (1) 1,250.00 29.18 138.21 1,201.28 1,137.88 -198.83 172.39 5,999,695.21 565,681.92 1.80 -172.53 2 Gyro-NS-CT_Drill pipe (1) 1,260.00 29.38 138.03 1,210.00 1,146.60 -202.47 175.66 5,999,691.60 565,685.22 2.19 -175.80 2_Gyro-NS-CT_Drill pipe (1) 1,270.00 29.57 137.79 1,218.70 1,155.30 -206.12 178.95 5,999,687.98 565,688.55 2.24 -179.10 2_Gyro-NS-CT_Drill pipe (1) 1,280.00 29.90 137.60 1,227.39 1,163.99 -209.79 182.29 5,999,684.34 565,691.92 3.43 -182.44 2 Gyro -NS -CT Dnll pipe (1) 1,290.00 30.29 137.43 1,236.04 1,172.64 -213.49 185.68 5,999,680.67 565,695.34 3.99 -185.83 2_Gyro-NS-CT_Drill pipe (1) 1,300.00 30.62 137.20 1,244.66 1,181.26 -217.21 189.12 5,999,676.97 565,698.81 3.50 -189.27 2_Gyro-NS-CT_Drill pipe (1) 1,310.00 31.07 136.99 1,253.24 1,189.84 -220.97 192.61 5,999,673.25 565,702.33 4.63 -192.76 2 Gyro -NS -CT Dnll pipe (1) 1,320.00 31.49 136.75 1,261.79 1,198.39 -224.76 196.16 5,999,669.49 565,705.91 4.38 -196.31 2_Gyro-NS-CT_Dnll pipe (1) 1,330.00 31.82 136.48 1,270.30 1,206.90 -228.57 199.76 5,999,665.71 565,709.55 3.59 -199.92 2_Gyro-NS-CT_Dnll pipe (1) 1,340.00 32.17 136.24 1,278.78 1,215.38 -232.41 203.42 5,999,661.91 565,713.24 3.72 -203.58 2 Gyro-NS-CT_Drlll pipe (1) 1,350.00 32.55 135.93 1,287.23 1,223.83 -236.26 207.13 5,999,658.09 565,716.98 4.15 -207.30 2_Gyro-NS-CT_Drill pipe (1) 1,360.00 32.81 135.74 1,295.65 1,232.25 -240.14 210.89 5,999,654.25 565,720.78 2.80 -211.06 2_Gyro-NS-CT_Dnll pipe (1) 1,370.00 32.99 135.64 1,304.04 1,240.64 -244.02 214.69 5,999,650.39 565,724.61 1.88 -214.86 2_Gyro-NS-CT_Dnll pipe (1) 9/162019 12:24:39PM Page 5 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU 5-203P62 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI -S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) ("1100-) (ft) Survey Tool Name 1,380.00 33.25 135.46 1,312.42 1,249.02 -247.92 218.51 5,999,646.53 565,728.47 2.78 -218.69 2_Gyro-NS-CT_Drill pipe (1) 1,390.00 33.42 135.36 1,320.77 1,257.37 -251.84 222.37 5,999,642.65 565,732.36 1.79 -222.55 2_Gyro-NS-CT_Drill pipe (1) 1,400.00 33.43 135.40 1,329.12 1,265.72 -255.76 226.24 5,999,638.76 565,736.26 0.24 -226.42 2_Gyro-NS-CT_Drill pipe (1) 1,410.00 33.61 135.30 1,337.46 1,274.06 -259.69 230.12 5,999,634.87 565,740.18 1.88 -230.30 2_Gyro-NS-CT_Drill pipe (1) 1,420.00 33.71 135.22 1,345.78 1,282.38 -263.62 234.02 5,999,630.96 565,744.11 1.09 -234.21 2_Gyro-NS-CT_Drill pipe (1) 1,430.00 33.61 135.09 1,354.10 1,290.70 -267.55 237.93 5,999,627.07 565,748.06 1.23 -238.12 2_Gyro-NS-CT_Drill pipe (1) 1,440.00 33.74 134.87 1,362.43 1,299.03 -271.47 241.85 5,999,623.19 565,752.01 1.78 -242.04 2_Gyro-NS-CT_Drill pipe (1) 1,450.00 33.89 134.67 1,370.73 1,307.33 -275.39 245.80 5,999,619.30 565,756.00 1.87 -246.00 2_Gyro-NS-CT_Drill pipe (1) 1,460.00 33.78 134.42 1,379.04 1,315.64 -279.30 249.77 5,999,615.43 565,760.00 1.77 -249.97 2_Gym-NS-CT_Drill pipe (1) 1,470.00 33.77 134.15 1,387.35 1,323.95 -283.18 253.75 5,999,611.58 565,764.01 1.50 -253.95 2_Gyro-NS-CT_Drili pipe (1) 1,480.00 33.82 133.91 1,395.66 1,332.26 -287.04 257.75 5,999,607.75 565,768.04 1.43 -257.95 2_Gyro-NS-CT_Drill pipe (1) 1,490.00 33.75 133.71 1,403.98 1,340.58 -290.89 261.76 5,999,603.94 565,772.09 1.31 -261.97 2_Gym-NS-CT_Drill pipe (1) 1,500.00 33.71 133.66 1,412.29 1,348.89 -294.73 265.78 5,999,600.14 565,776.14 0.49 -265.99 2_Gyro-NS-CT_Drill pipe (1) 1,510.00 33.89 133.52 1,420.60 1,357.20 -298.57 269.81 5,999,596.34 565,780.20 1.96 -270.02 2_Gyro-NS-CT_Drill pipe (1) 1,520.00 33.73 133.45 1,428.91 1,365.51 -302.39 273.85 5,999,592.55 565,784.27 1.65 -274.06 2_Gyro-NS-CT_Drill pipe (i) 1,530.00 33.40 133.50 1,437.24 1,373.84 -306.20 277.86 5,999,588.78 565,788.32 3.31 -278.07 2 Gym-NS-CT_Drill pipe (1) 1,540.00 33.41 133.44 1,445.59 1,382.19 -309.99 281.85 5,999,585.03 565,792.34 0.35 -282.07 2_Gyro-NS-CT_Drill pipe (1) 1,550.00 33.22 133.45 1,453.95 1,390.55 -313.76 285.84 5,999,581.29 565,796.36 1.90 -286.06 2_Gyro-NS-CT_Drill pipe (1) 1,560.00 32.83 133.62 1,462.33 1,398.93 -317.52 289.79 5,999,577.57 565,800.35 4.01 -290.01 2_Gyro-NS-CT_Drill pipe (1) 1,570.00 32.79 133.64 1,470.74 1,407.34 -321.26 293.71 5,999,573.86 565,804.30 0.41 -293.94 2_Gym-NS-CT_Drill pipe (1) 1,580.00 32.70 133.65 1,479.15 1,415.75 -324.99 297.63 5,999,570.16 565,808.25 0.90 -297.86 2_Gym-NS-CT Drlll pipe (1) 1,590.00 32.53 133.70 1,487.57 1,424.17 -328.71 301.53 5,999,566.48 565,812.18 1.72 -301.76 2_Gyro-NS-CT_DO pipe (1) 1,600.00 32.58 133.74 1,496.00 1,432.60 -332.43 305.42 5,999,562.79 565,816.10 0.54 -305.65 2_Gyro-NS-CT_Ddll pipe (1) 1,610.00 32.58 133.83 1,504.43 1,441.03 -336.16 309.30 5,999,559.10 565,820.02 0.48 -309.54 2_Gyro-NS-CT_Drill pipe (1) 1,620.00 32.43 133.86 1,512.86 1,449.46 -339.88 313.18 5,999,555.41 565,823.93 1.51 -313.42 2_Gyro-NS-CT Drill pipe (1) 1,630.00 32.43 133.88 1,521.30 1,457.90 -343.59 317.05 5,999,551.73 565,827.83 0.11 -317.28 2_Gyro-NS-CT_Drili pipe (1) 1,640.00 32.51 134.05 1,529.74 1,466.34 -347.32 320.91 5,999,548.04 565,831.72 1.21 -321.15 2_Gyro-NS-CT_Drill pipe (1) 1,650.00 32.33 134.19 1,538.18 1,474.78 -351.05 324.76 5,999,544.34 565,835.60 1.95 -325.00 2_Gym-NS-CT_Drill pipe (1) 1,660.00 32.18 134.37 1,546.63 1,483.23 -354.78 328.58 5,999,540.65 565,839.46 1.78 -328.83 2_Gym-NS-CT_Drill pipe (1) 1,670.00 32.16 134.48 1,555.10 1,491.70 -358.51 332.38 5,999,536.96 565,843.29 0.62 -332.63 2_Gyro-NS-CT_Ddll pipe (1) 1,680.00 31.91 134.59 1,563.58 1,500.18 362.23 336.16 5,999,533.27 565,847.10 2.57 -336.42 2_Gym-NS-CT_Drill pipe (1) 1,690.00 31.63 134.77 1,572.08 1,508.68 -365.93 339.91 5,999,529.60 565,850.88 2.96 -340.16 2_Gym-NS-CT_Drill pipe (1) 1,700.00 31.57 134.81 1,580.60 1,517.20 -369.62 343.62 5,999,525.94 565,854.63 0.64 -343.88 2_Gyro-NS-CT_Drill pipe (1) 1,710.00 31.34 134.88 1,589.13 1,525.73 -373.30 347.32 5,999,522.30 565,858.36 2.33 -347.59 2_Gyro-NS-CT_Dill pipe (i) 1,720.00 31.06 135.01 1,597.68 1,534.28 -376.96 350.99 5,999,518.67 565,862.06 2.88 -351.25 2 -Gym -NS -CT -Drill pipe (1) 1,730.00 31.08 134.92 1,606.25 1,542.85 -380.61 354.64 5,999,515.05 565,865.74 0.51 -354.91 2_Gym-NS-CT_Drill pipe (1) 1,740.00 30.98 134.80 1,614.81 1,551.41 -384.24 358.30 5,999,511.45 565,869.43 1.18 358.56 2_Gym-NS-CT_Drill pipe (1) 1,750.00 30.79 134.60 1,623.40 1,560.00 -387.85 361.95 5,999,507.87 565,873.11 2.16 -362.22 2_Gym-NS-CT Dnll pipe (1) 1,760.00 30.84 134.34 1,631.98 1,568.58 -391.44 365.60 5,999,504.32 565,876.79 1.42 -365.87 2_Gym-NS-CT_Drill pipe (1) 1,770.00 30.93 134.19 1,640.57 1,577.17 -395.03 369.28 5,999,500.77 565,880.50 1.18 -369.55 2_Gyro-NS-CT_Drill pipe (1) 9/1612019 12:24:39PM Page 6 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU S-203 MPU S-203PB2 MPU S-203PB2 Local Co-ordinate Reference: Well MPU S-203 TVD Reference: MPU S-203 Actual RKB @ 63.40usft MD Reference: MPU S-203 Actual RKB @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (usft) (usft) (ft) (ft) (111001 (ft) Survey Tool Name 1,780.00 30.91 133.91 1,649.15 1,585.75 -398.60 372.97 5,999,497.23 565,884.23 1.45 -373.25 2_Gyro-NS-CT_Drill pipe (1) 1,790.00 31.12 133.50 1,657.72 1,594.32 -402.16 376.69 5,999,493.70 565,887.98 2.98 -376.98 2_Gyro-NS-CT_Drill pipe (1) 1,800.00 31.34 133.21 1,666.27 1,602.87 -405.72 380.46 5,999,490.17 565,891.78 2.66 -380.75 2_Gyro-NS-CT_Drill pipe (1) 1,810.00 31.50 132.78 1,674.80 1,611.40 -409.27 384.28 5,999,486.65 565,895.63 2.75 -384.56 2_Gyro-NS-CT_Drill pipe (1) 1,820.00 31.82 132.16 1,683.31 1,619.91 -412.82 388.15 5,999,483.14 565,899.53 4.56 -388.44 2 Gyro-NS-CT_Drill pipe (1) 1,830.00 32.25 131.63 1,691.79 1,628.39 -416.36 392.10 5,999,479.64 565,903.51 5.14 -392.39 2_Gyro-NS-CT_0nll pipe (1) 1,840.00 32.55 131.08 1,700.23 1,636.83 -419.90 396.12 5,999,476.13 565,907.56 4.21 -396.41 2_Gyro-NS-CT_Dhll pipe (1) 1,850.00 32.95 130.46 1,708.64 1,645.24 -423.43 400.22 5,999,472.64 565,911.69 5.22 -400.51 2_Gyro-NS-CT_Drill pipe (1) 1,860.00 33.47 129.95 1,717.01 1,653.61 426.97 404.40 5,999,469.14 565,915.90 5.90 -404.70 2_Gyro-NS-CT_Drill pipe (1) 1,870.00 33.83 129.50 1,725.33 1,661.93 -430.51 408.66 5,999,465.63 565,920.19 4.38 408.96 2_Gyro-NS-CT_Drill pipe (1) 1,880.00 34.15 129.06 1,733.63 1,670.23 -434.05 412.99 5,999,462.13 565,924.55 4.04 -413.29 2_Gyro-NS-CT_Drill pipe (1) 1,890.00 34.55 128.76 1,741.88 1,678.48 -437.59 417.38 6,999,458.63 565,928.97 4.34 -417.69 2_Gyro-NS-CT_Drill pipe (1) 1,900.00 34.80 128.67 1,750.11 1,686.71 .441.15 421.82 5,999,455.11 565,933.44 2.55 -422.13 2_Gyro-NS-CT Dnll pipe (1) 1,910.00 34.86 128.65 1,758.31 1,694.91 -444.72 426.28 5,999,451.58 565,937.93 0.61 -426.59 2Gyro-NS-CT_Dnll pipe (1) 1,920.00 35.01 128.66 1,766.51 1,703.11 -448.29 430.75 5,999,448.04 565,942.43 1.50 -431.06 2_Gyro-NS-CT_Ddil pipe (1) 1,930.00 35.06 128.74 1,774.70 1,711.30 -451.88 435.23 5,999,444.49 565,946.95 0.68 -435.55 2_Gyro-NS-CT_Drill pipe (1) 1,940.00 34.99 128.77 1,782.89 1,719.49 455.48 439.71 5,999,440.94 565,951.45 0.72 -440.02 2 Gyro-NS-CT_Drill pipe (1) 1,950.00 35.11 128.79 1,791.08 1,727.68 -459.07 444.18 5,999,437.38 565,955.96 1.21 -444.50 2_Gyro-NS-CT_Dnl1 pipe (1) 1,960.00 35.16 128.84 1,799.25 1,735.85 -462.68 448.67 5,999,433.82 565,960.48 0.58 -448.99 2_Gyro-NS-CT_Drill pipe (1) 1,970.00 34.99 128.92 1,807.44 1,744.04 -466.29 453.14 5,999,430.25 565,964.98 1.76 -453.47 2_Gyro-NS-CT_Drill pipe (1) 1,980.00 34.95 129.00 1,815.63 1,752.23 369.89 457.60 5,999,426.68 565,969.47 0.61 -457.93 2_Gyro-NS-CT_Drill pipe (1) 1,990.00 34.97 129.15 1,823.83 1,760.43 373.50 462.05 5,999,423.11 565,973.95 0.88 362.38 2_Gyro-NS-CT_Drill pipe (1) 2,000.00 34.78 129.31 1,832.03 1,768.63 -477.12 466.48 5,999,419.54 565,978.41 2.11 366.81 2_Gyro-NS-CT_Drill pipe (1) 2,010.00 34.61 129.42 1,840.25 1,776.85 -480.73 470.88 5,999,415.96 565,982.84 1.81 371.21 2_Gyro-NS-CT_Drill pipe (1) 2,020.00 34.61 129.41 1,848.48 1,785.08 384.34 475.26 5,999,412.40 565,987.26 0.06 375.60 2_Gym-NS-CT_Drill pipe (1) 2,030.00 34.40 129.53 1,856.72 1,793.32 387.94 479.64 5,999,408.83 565,991.66 2.21 379.98 2_Gyro-NS-CT_Dhll pipe (1) 2,040.00 34.19 129.59 1,864.99 1,801.59 391.53 483.98 5,999,405.28 565,996.04 2.13 384.32 2_Gyro-NS-CT_Drill pipe (1) 2,050.00 34.37 129.58 1,873.25 1,809.85 395.11 488.32 5,999,401.73 566,000.41 1.80 388.67 2_Gyro-NS-CT_Drill pipe (1) 2,060.00 34.33 129.69 1,881.50 1,818.10 398.71 492.67 5,999,398.17 566,004.79 0.74 393.02 2_Gyro-NS-CT_Dnll pipe (1) 2,070.00 34.22 129.70 1,889.77 1,826.37 -502.31 497.00 5,999,394.62 566,009.15 1.10 -497.35 2 Gyro-NS-CT_Drill pipe (1) 2,080.00 34.37 129.70 1,898.03 1,834.63 -505.91 501.34 5,999,391.05 566,013.52 1.50 -501.69 2_Gyro-NS-CT_Drill pipe (1) 2,090.00 34.30 129.88 1,906.29 1,842.89 -509.52 505.67 5,999,387.48 566,017.88 1.23 -506.03 2_Gyro-NS-CT Drill pipe (1) 2,100.00 34.01 130.07 1,914.56 1,851.16 -513.13 509.97 5,999,383.91 566,022.21 3.09 510.33 2_Gyro-NS-CT_Dnll pipe (1) 2,110.00 34.09 130.16 1,922.85 1,859.45 -516.73 514.25 5,999,380.34 566,026.53 0.95 -514.61 2_Gyro-NS-CT_Drill pipe (1) 2,120.00 33.99 130.48 1,931.13 1,867.73 -520.36 518.52 5,999,376.76 566,030.83 2.05 -518.89 2_Gyro-NS-CT_Drill pipe (1) 2,130.00 33.56 130.94 1,939.45 1,876.05 523.98 522.74 5,999,373.17 566,035.07 5.00 -523.10 2 Gyro-NS-CT_Drill pipe (1) 2,140.00 33.39 131.43 1,947.79 1,884.39 -527.61 526.89 5,999,369.58 566,039.25 3.19 -527.26 2_Gyro-NS-CT_Drill pipe (1) 2,150.00 33.23 132.05 1,956.15 1,892.75 -531.27 530.99 5,999,365.96 566,043.38 3.76 531.36 2_Gyro-NS-CT_Drill pipe (1) 2,160.00 32.90 132.83 1,964.53 1,901.13 -534.95 535.01 5,999,362.31 566,047.44 5.39 -535.38 2 Gyro-NS-CT_Dnll pipe (1) 2,170.00 32.62 133.75 1,972.94 1,909.54 -538.66 538.95 5,999,358.64 566,051.41 5.71 -539.33 2_Gyro-N8-CT_Dnll pipe (1) 9/162019 12:24:39PM Page 7 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual IRKS @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU S-203PB2 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB2 Database: NORTH US+CANADA Survey Map MD Inc Azi TVD TVDSS +NI -S +E/ -W Northing (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) 2,180.00 32.60 134.35 1,981.36 1,917.96 -542.41 542.82 5,999,354.92 2,190.00 32.44 134.98 1,989.79 1,926.39 -546.19 546.65 5,999,351.18 2,200.00 32.15 135.60 1,998.24 1,934.84 -549.98 550.41 5,999,347.42 2,210.00 32.20 136.03 2,006.71 1,943.31 -553.80 554.12 5,999,343.63 2,220.00 31.94 136.74 2,015.18 1,951.78 -557.65 557.78 5,999,339.82 2,230.00 31.62 137.67 2,023.68 1,960.28 -561.51 561.36 5,999,335.99 2,240.00 31.60 138.15 2,032.20 1,968.80 -565.40 564.87 5,999,332.13 2,250.00 31.41 138.70 2,040.73 1,977.33 -569.31 568.34 5,999,328.25 2,260.00 31.11 139.27 2,049.27 1,985.87 -573.23 571.74 5,999,324.37 2,270.00 31.12 139.71 2,057.84 1,994.44 -577.15 575.10 5,999,320.47 2,280.00 30.90 140.38 2,066.41 2,003.01 -581.10 578.41 5,999,316.55 2,290.00 30.51 141.20 2,075.00 2,011.60 -585.06 581.64 5,999,312.62 2,300.00 30.39 141.85 2,083.62 2,020.22 -589.03 584.79 5,999,308.68 2,310.00 30.25 142.45 2,092.26 2,028.86 -593.01 587.89 5,999,304.72 2,320.00 29.94 143.03 2,100.91 2,037.51 -597.00 590.92 5,999,300.76 2,330.00 29.77 143.61 2,109.58 2,046.18 -601.00 593.90 5,999,296.79 2,340.00 29.75 144.22 2,118.26 2,054.86 -605.01 596.82 5,999,292.81 2,350.00 29.39 145.14 2,126.96 2,063.56 -609.03 599.67 5,999,288.81 2,360.00 29.06 146.19 2,135.69 2,072.29 -613.07 602.43 5,999,284.80 2,370.00 29.10 146.74 2,144.43 2,081.03 -617.12 605.11 5,999,280.77 2,380.00 28.97 147.19 2,153.17 2,089.77 -621.19 607.76 5,999,276.73 2,390.00 28.78 147.64 2,161.93 2,098.53 -625.25 610.36 5,999,272.68 2,400.00 28.93 148.17 2,170.69 2,107.29 -629.34 612.92 5,999,268.62 2,410.00 28.65 149.02 2,179.45 2,116.05 -633.45 615.43 5,999,264.53 2,420.00 28.32 150.18 2,188.24 2,124.84 -637.57 617.85 5,999,260.44 2,430.00 28.38 150.97 2,197.04 2,133.64 -641.70 620.18 5,999,256.32 2,440.00 28.25 151.62 2,205.84 2,142.44 -645.86 622.46 5,999,252.18 2,450.00 27.98 152.27 2,214.66 2,151.26 -650.02 624.68 5,999,248.04 2,460.00 28.16 152.81 2,223.49 2,160.09 -654.20 626.84 5,999,243.89 2,470.00 28.26 153.75 2,232.30 2,168.90 -658.42 628.97 5,999,239.69 2,480.00 27.86 154.92 2,241.12 2,177.72 -662.66 631.01 5,999,235.46 2,490.00 27.72 155.78 2,249.97 2,186.57 666.90 632.95 5,999,231.24 2,500.00 27.69 156.55 2,258.82 2,195.42 -671.15 634.83 5,999,227.01 2,510.00 27.57 157.31 2,267.68 2,204.28 -675.41 636.65 5,999,222.76 2,520.00 27.41 158.08 2,276.55 2,213.15 -679.68 638.40 5,999,218.50 2,530.00 27.35 158.75 2,285.43 2,222.03 -683.96 640.09 5,999,214.24 2,540.00 27.05 159.64 2,294.33 2,230.93 -688.23 641.72 5,999,209.99 2,550.00 26.66 160.80 2,303.25 2,239.85 -692.48 643.24 5,999,205.75 2,560.00 26.62 161.51 2,312.19 2,248.79 -696.73 644.69 5,999,201.52 2,570.00 26.37 162.17 2,321.14 2,257.74 -700.97 646.08 5,999,197.29 Map Easting DLS (ft) (°/100') 566,055.32 3.24 566,059.17 3.75 566,062.97 4.40 566,066.71 2.34 566,070.41 4.58 566,074.02 5.85 566,077.56 2.52 566,081.07 3.45 566,084.51 4.21 566,087.90 566,091.24 566,094.50 566,097.69 566,100.82 566,103.89 566,106.90 566,109.86 566,112.75 566,115.53 566,118.26 566,120.94 566,123.57 566,126.17 566,128.72 566,131.17 566,133.54 566,135.85 566,138.10 566,140.31 566,142.47 566,144.54 566,146.53 566,148.44 566,150.30 566,152.09 566,153.81 566,155.48 566,157.04 566,158.53 566,159.95 2,28 4.09 5.72 3.51 3.34 4.25 3.35 3.03 5.79 6.10 2.70 2.54 2.89 2.97 4.96 6.44 3.80 3.35 4.08 3.11 4.55 6.80 4.25 3.59 3.72 3.90 3.14 5.05 6.53 3.21 3.86 Vertical Section (ft) Survey Tool Name -543.20 2_Gyro-NS-CT_D611 pipe (1) 547.03 2_Gyro-NS-CT_Dn1l pipe (1) -550.79 2_Gym-NS-CT_Drill pipe (1) -554.50 2_Gyro-NS-CT_Drill pipe (1) -558.17 2_Gym-NS-CT_Dnli pipe (1) -561.75 2_Gyro-NS-CT_Drill pipe (1) -565.27 2_Gyro-NS-CT_Drill pipe (1) -568.74 2 Gyro-NS-CT_Drill pipe (1) -572.14 2_Gyro-NS-CT_Drill pipe (1) -575.50 2_Gyro-NS-CT_Drill pipe (1) -578.82 2_Gym-NS-CT_Drill pipe (1) -582.05 2_Gym-NS-CT_Drill pipe (1) -585.20 2_Gyro-NS-CT_Dnll pipe (1) -588.30 2_Gyro-NS-CT_Drill pipe (1) -591.34 2_Gyro-NS-CT_Drill pipe (1) -594.32 2_Gym-NS-CT_Drill pipe (1) -597.24 2_Gyro-NS-CT_Dnll pipe (1) -600.10 2_Gyro-NS-CT_Drill pipe (1) -602.86 2 Gyro-N&G-F Drill pipe (1) -605.54 2_Gyro-NS-CT_Drill pipe (1) -608.19 2_Gyro-NS-CT_Drill pipe (1) -610.80 2 Gyro-NS-CT_Dnll pipe (1) -613.36 2_Gyro-NS-CT_Drill pipe (1) -615.88 2_Gyro-NS-CT_Drlll pipe (1) -618.29 2_Gyro-NS-CT_Dril pipe (1) -620.63 2_Gyro NS-GT_Drill pipe (1) -622.91 2_Gym-NS-CT Drill pipe (1) -625.13 2_Gyro-NS-CT_Dnll pipe (1) 627.30 2 Gyro-NS-CT_D611 pipe (1) -629.43 2_Gyr NS-GT_Drill pipe (1) -631.47 2 Gyro -NS -CT Drill pipe (1) -633.42 2_Gyro-NS-CT_Dnll pipe (1) 635.30 2_Gyro-NS-CT_Ddll pipe (1) -637.12 2_Gym-NS-CT_Drill pipe (1) -638.87 2_Gyro-NS-CT_Drill pipe (1) 640.57 2_Gyro-NS-CT_Ddll pipe (1) -642.20 2_Gyro-NS-CT_Drill pipe (1) -643.73 2_Gyro-NS-CT_Drill pipe (1) -645.18 2_Gyro-NS-CT_Drill pipe (1) 646.57 2_Gyre-NS-CT_Drill pipe (1) 9/162019 12:24:39PM Page 8 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU 5-203PB2 Design: MPU 5-203PB2 Survey MD Inc (usft) (1) 2,580.00 26.06 2,590.00 26.17 2,600.00 26.11 2,610.00 25.97 2,620.00 26.11 2,630.00 26.10 2,640.00 26.09 2,650.00 26.26 2,660.00 26.42 2,670.00 26.42 2,680.00 26.52 2,690.00 26.69 2,700.00 26.68 2,710.00 26.69 2,720.00 26.80 2,730.00 26.62 2,740.00 26.32 2,750.00 26.29 2,760.00 26.20 2,770.00 26.01 2,780.00 26.04 2,790.00 25.88 2,800.00 25.56 2,810.00 25.51 2,820.00 25.42 2,830.00 25.32 2,840.00 25.37 2,850.00 25.51 2,860.00 25.47 2,870.00 25.59 2,880.00 25.78 2,890.00 25.88 2,900.00 26.01 2,910.00 26.28 2,920.00 26.63 2,930.00 26.66 2,940.00 27.02 2,950.00 27.24 2,960.00 27.45 2,970.00 28.05 Azi 162.86 163.39 164.21 165.30 166.05 166.81 167.73 168.50 169.43 170.58 171.63 172.31 173.08 173.77 174.27 175.55 177.37 178.22 178.79 179.59 180.40 181.21 182.19 183.40 184.54 185.76 186.84 187.79 189.57 190.97 191.93 192.79 193.57 194.29 195.53 197.21 198.31 199.17 199.97 200.71 TVD (usft) 2,330.11 2,339.09 2,348.07 2,357.05 2,366.04 2,375.02 2,384.00 2,392.97 2,401.93 2,410.89 2,419.84 2,428.78 2,437.72 2,446.65 2,455.58 2,464.51 2,473.47 2,482.43 2,491.40 2,500.38 2,509.37 2,518.36 2,527.37 2,536.39 2,545.42 2,554.45 2,563.49 2,572.52 2,581.55 2,590.57 2,599.58 2,608.58 2,617.58 2,626.55 2,635.51 2,644.44 2,653.37 2,662.27 2,671.15 2,680.00 TVDSS (usft) 2,266.71 2,275.69 2,284.67 2,293.65 2,302.64 2,311.62 2,320.60 2,329.57 2,338.53 2,347.49 2,356.44 2,365.38 2,374.32 2,383.25 2,392.18 2,401.11 2,410.07 2,419.03 2,428.00 2,436.98 2,445.97 2,454.96 2,463.97 2,472.99 2,482.02 2,491.05 2,500.09 2,509.12 2,518.15 2,527.17 2,536.18 2,545.18 2,554.18 2,563.15 2,572.11 2,581.04 2,589.97 2,598.87 2,607.75 2,616.60 Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +N/ -S +E/ -W Northing (usft) (usft) (ft) -705.18 647.41 5,999,193.09 -709.39 648.69 5,999,188.89 -713.62 649.92 5,999,184.67 -717.86 651.07 5,999,180.45 -722.11 652.16 5,999,176.20 -726.39 653.19 5,999,171.94 -730.68 654.16 5,999,167.66 -735.00 655.07 5,999,163.35 -739.35 655.92 5,999,159.00 -743.73 656.69 5,999,154.63 -748.14 657.38 5,999,150.23 -752.57 658.00 5,999,145.80 -757.02 658.58 5,999,141.35 -761.49 659.09 5,999,136.90 -765.96 659.56 5,999,132.43 -770.44 659.96 5,999,127.95 -774.89 660.23 5,999,123.51 -779.31 660.40 5,999,119.08 -783.73 660.52 5,999,114.66 -788.13 660.58 5,999,110.26 -792.52 660.58 5,999,105.88 -796.90 660.52 5,999,101.50 -801.24 660.39 5,999,097.16 -805.54 660.18 5,999,092.86 -809.83 659.88 5,999,088.56 -814.10 659.50 5,999,084.29 -818.35 659.03 5,999,080.04 -822.61 658.48 5,999,075.77 -826.87 657.83 5,999,071.51 -831.11 657.06 5,999,067.27 -835.36 656.20 5,999,063.01 -839.61 655.27 5,999,058.75 -843.87 654.27 5,999,054.48 -848.15 653.21 5,999,050.19 -852.45 652.07 5,999,045.88 -856.76 650.80 5,999,041.57 -861.05 649.43 5,999,037.26 -865.37 647.96 5,999,032.93 -869.70 646.42 5,999,028.58 -874.07 644.80 5,999,024.21 Well MPU 5-203 MPU 5-203 Actual RKB @ 63.40usft MPU 5-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Map Easting DLS (ft) (°1100') 566,161.32 4.35 566,162.63 2.58 566,163.90 3.66 566,165.09 4.99 566,166.21 3.58 566,167.28 3.35 566,168.29 4.05 566,169.24 3.80 566,170.12 4.43 566,170.93 566,171.66 566,172.33 566,172.94 566,173.49 566,174.00 566,174.44 566,174.75 566,174.96 566,175.11 566,175.21 566,175.25 566,175.23 566,175.14 566,174.97 566,174.71 566,174.36 566,173.93 566,173.42 566,172.81 566,172.08 566,171.25 566,170.36 566,169.40 566,168.37 566,167.27 566,166.04 566,164.70 566,163.27 566,161.77 566,160.19 5.12 4.79 3.49 3.46 3.10 2.50 6.03 8.65 3.78 2.68 4.00 3.57 3.89 5.32 5.24 4.98 5.32 4.65 4.31 7.67 6.15 4.57 3.88 3.65 4.17 6.54 7.54 6.13 4.50 4.23 6.92 vertical Section (ft) Survey Tool Name -647.90 2_Gyro-NS-CT_Drill pipe (1) -649.18 2_Gyro-NS-CT_Drill pipe (1) -650.42 2_Gym-NS-CT_Drill pipe (1) -651.57 2_Gym-NS-CT_Dnll pipe (1) -652.66 2_Gyro-NS-CT_0011 pipe (1) -653.70 2_Gyro-NS-CT_Drill pipe (1) -654.67 2_Gym-NS-CT_Drill pipe (1) -655.58 2_Gym-NS-CT_Dnll pipe (1) -656.43 2_Gyro-NS-CT_Drill pipe (1) -657.21 2_Gyro-NS-CT_Drill pipe (1) -657.90 2_Gyro-NS-CT_Drill pipe (1) -658.53 2_Gym-NS-CT_Dnll pipe (1) -659.10 2_Gyro-NS-CT_Drill pipe (1) -659.62 2_Gym-NS-CT_Drill pipe (1) -660.09 2_Gym-NS-CT_Drill pipe (1) -660.49 2_Gyro-NS-CT_Drill pipe (1) -660.77 2_Gyro-NS-CT_Drill pipe (1) -660.95 2_Gyra-NS-CT_Drill pipe (1) -661.07 2_Gym-NS-CT_Drill pipe (1) -661.13 2_Gyro-NS-CT_Drill pipe (1) -661.13 2_Gyro-NS-CT_Ddll pipe (1) -661.08 2_Gym-NS-CT_Drill pipe (1) -660.95 2_Gyro-NS-CT_Drill pipe (1) -660.74 2 -GYM -NS -CT Drill pipe (1) -660.45 2_Gyro-NS-CT_Drill pipe (1) -660.07 2_Gyro-NS-CT_Drill pipe (1) -659.60 2_Gyro-NS-CT_Dnll pipe (1) -659.06 2_Gyro-NS-CT_Drill pipe (1) -658.41 2_Gyro-NS-CT_Drill pipe (1) -657.64 2_Gyro-NS-CT_Drill pipe (1) -656.79 2_Gyro-NS-CT_Dnll pipe (1) -655.86 2_Gyro-NS-CT_Dhll pipe (1) -654.86 2_Gyro-NS-CT_Drill pipe (1) -653.80 2_Gyro-NS-CT_Drill pipe (1) -652.66 2_Gyro-NS-CT_Dnll pipe (1) -651.40 2_Gyro-NS-CT_Drill pipe (1) -650.03 2_Gyro-NS-CT_Drill pipe (1) -648.56 2_Gym-NS-CT_Dnll pipe (1) -647.03 2_Gyro-NS-CT_Dnll pipe (1) -645.41 2_Gyro-NS-CT_Drill pipe (1) 9/16/2019 12:24:39PM Page 9 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU S-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU S-203PB2 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (") (°) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 2,980.00 28.21 201.61 2,688.82 2,625.42 -878.46 643.10 5,999,019.79 566,158.53 4.53 -643.71 2_Gyro-NS-CT_Dnll pipe (1) 2,990.00 28.34 202.84 2,697.63 2,634.23 -882.85 641.31 5,999,015.39 566,156.78 5.97 -641.92 2_Gyro-NS-CT_Dnll pipe (1) 3,000.00 28.68 203.79 2,706.41 2,643.01 -887.23 639.42 5,999,011.00 566,154.93 5.67 -640.04 2_Gyro-NS-CT_Drill pipe (1) 3,010.00 28.97 204.44 2,715.17 2.651.77 -891.63 637.45 5,999,006.58 566,152.99 4.27 -638.07 2_Gyro-NS-CT_Drill pipe (1) 3,020.00 29.05 205.04 2,723.92 2,660.52 -896.04 635.42 5,999,002.16 566,151.00 3.02 -636.05 2 -Gyro -NS -CT -Drill pipe (1) 3,030.00 29.37 205.65 2,732.65 2,669.25 -900.45 633.33 5,998,997.73 566,148.95 4.37 -633.96 2_Gyro-NS-CT_Drill pipe (1) 3,040.00 29.47 206.37 2,741.36 2,677.96 -904.86 631.18 5,998,993.30 566,146.84 3.68 -631.81 2_Gyro-NS-CT_Drili pipe (1) 3,050.00 29.42 207.36 2,750.07 2,686.67 -909.25 628.96 5,998,988.89 566,144.66 4.89 -629.59 2_Gyro-NS-CT_DdIl pipe (1) 3,060.00 29.48 208.52 2,758.77 2,695.37 -913.59 626.65 5,998,984.53 566,142.39 5.73 -627.29 2_Gyro-NS-CT_Drill pipe (1) 3,070.00 29.76 209.37 2,767.47 2,704.07 -917.91 624.26 5,998,980.18 566,140.04 5.05 -624.90 2 -Gyro -NS -13T Drill pipe (1) 3,080.00 29.75 210.08 2,776.15 2,712.75 -922.22 621.80 5,998,975.85 566,137.61 3.53 -622.44 2_Gyro-NS-CT_Drill pipe (1) 3,090.00 29.79 210.84 2,784.83 2,721.43 -926.50 619.28 5,998,971.55 566,135.13 3.79 -619.93 2_Gyro-NS-CT_Dnll pipe (1) 3,100.00 30.04 211.58 2,793.50 2,730.10 -930.77 616.70 5,998,967.26 566,132.59 4.46 -617.35 2_Gyro-NS-CT_Ddll pipe (1) 3,110.00 30.13 212.58 2,802.15 2,738.75 -935.02 614.04 5,998,962.99 566,129.96 5.09 -614.69 2_Gyro-NS-CT_Drill pipe (1) 3,120.00 30.04 213.74 2,810.80 2,747.40 -939.21 611.29 5,998,958.77 566,127.26 5.88 -611.95 2_Gyro-NS-CT_Drill pipe (1) 3,130.00 30.47 214.55 2,819.44 2,756.04 -943.30 608.47 5,998,954.58 566,124.47 5.93 -609.12 2_Gyro-NS-CT_Drill pipe (1) 3,140.00 30.39 215.36 2,828.06 2,764.66 -947.53 605.56 5,998,950.40 566,121.60 4.16 -606.23 2 Gyro-NS-CT_Dnli pipe (1) 3,150.00 30.35 216.16 2,836.69 2,773.29 -951.64 602.61 5,998,946.28 566,118.68 4.06 -603.27 2_Gyro-NS-CT_0611 pipe (1) 3,160.00 30.52 216.86 2,845.31 2,781.91 -955.71 599.60 5,998,942.18 566,115.71 3.93 -600.26 2_Gyro-NS-CT_Drill pipe (1) 3,171 30.68 217.62 2,853.92 2,790.52 -959.76 596.51 5,998,938.10 566,112.66 4.19 -597.18 2_Gyro-NS-CT_Drill pipe (1) 3,180.00 30.72 218.50 2,862.52 2,799.12 -963.78 593.37 5,998,934.05 566,109.55 4.51 -594.04 2_Gyro-NS-CT_Dnll pipe (1) 3,190.00 30.94 219.32 2,871.11 2,807.71 -967.77 590.15 5,998,930.04 566,106.37 4.74 -590.82 2_Gyro-NS-CT_Drill pipe (1) 3,200.00 31.20 220.07 2,879.67 2.816.27 -971.74 586.85 5,998,926.04 566,103.11 4.66 -587.53 2_Gyro-NS-CT_Ddll pipe (1) 3,210.00 31.28 220.59 2,888.22 2,824.82 -975.69 583.50 5,998,922.06 566,099.78 2.81 -584.18 2_Gyro-NS-CT_Drill pipe (1) 3,220.00 31.50 221.13 2,896.76 2,833.36 -979.63 580.09 5,998,918.09 566,096.41 3.57 -580.77 2_Gyro-NS-CT_Drill pipe (1) 3,230.00 31.88 221.60 2,905.27 2,841.87 -983.57 576.62 5,998,914.11 566,092.98 4.53 -577.30 2_Gyro-NS-CT_Dnll pipe (1) 3,240.00 32.09 222.20 2,913.75 2,850.35 -987.52 573.08 5,998,910.14 566,089.47 3.81 -573.77 2_Gyro-NS-CT_Drill pipe (1) 3,250.00 32.21 222.90 2,922.22 2,858.82 -991.44 569.48 5,998,906.19 566,085.91 3.91 -570.17 2_Gyro-NS-CT_Drill pipe (1) 3,260.00 32.73 223.46 2,930.65 2,867.25 -995.35 565.81 5,998,902.24 566,082.27 6.01 -566.50 2_Gyro-NS-CT_Drill pipe (1) 3,270.00 32.99 223.99 2,939.05 2,875.65 -999.27 562.06 5,998,898.29 566,078.56 3.88 -562.75 2_Gyro-NS-CT Dnll pipe (1) 3,280.00 33.05 224.45 2,947.44 2,884.04 -1,003.18 558.26 5,998,894.35 566,074.79 2.58 -558.96 2_Gyro-NS-CT_Drill pipe (1) 3,290.00 33.37 224.70 2,955.80 2,892.40 -1,007.08 554.41 5,998,890.42 566,070.98 3.48 -555.11 2_Gyro-NS-CT_Drill pipe (1) 3,300.00 33.58 225.03 2,964.15 2,900.75 -1,010.99 550.52 5,998,886.48 566,067.12 2.78 -551.23 2_Gyro-NS-CT_Drill pipe (1) 3,310.00 33.58 225.45 2,972.48 2,909.08 -1,014.88 546.59 5,998,882.55 566,063.23 2.32 -547.30 2_Gyro-NS-CT_Drill pipe (1) 3,320.00 33.82 225.78 2,980.80 2,917.40 -1,018.76 542.63 5,998,878.63 566,059.30 3.02 -543.34 2_Gyro-NS-CT_Dhll pipe (1) 3,330.00 33.98 226.10 2,989.10 2,925.70 -1,022.64 538.62 5,998,874.72 566,055.33 2.40 -539.33 2_Gyro-NS-CT_Drili pipe(1) 3,340.00 33.96 226.24 2,997.39 2,933.99 -1,026.51 534.59 5,998,870.81 566,051.33 0.81 -535.31 2_Gyro-NS-CT_Drill pipe (1) 3,350.00 34.16 226.32 3,005.67 2,942.27 -1,030.38 530.54 5,998,866.91 566,047.32 2.05 531.26 2_Gyro-NS-CT_Drill pipe (1) 3,360.00 34.40 226.53 3,013.94 2,950.54 -1,034.26 526.46 5,998,862.99 566,043.27 2.68 -527.18 2 Gym-NS-CT_Dnll pipe (1) 3,370.00 34.52 226.76 3,022.18 2,958.78 -1,038.15 522.35 5,998,859.07 566,039.19 1.77 523.07 2_Gyro-NS-CT_Drill pipe (1) 91162019 12:24:39PM Page 10 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU 5-203PB2 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB2 Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-1100') (ft) Survey Tool Name 3,380.00 34.77 227.05 3,030.41 2,967.01 -1,042.03 518.20 5,998,855.15 566,035.08 2.99 -518.92 2_Gyro-NS-CT_Drill pipe (1) 3,390.00 35.11 227.39 3,038.61 2,975.21 -1,045.92 513.99 5,998,851.22 566,030.91 3.92 -514.72 2 -Gym -NS -CT -Drill pipe (1) 3,400.00 35.35 227.95 3,046.77 2,983.37 -1,049.81 509.73 5,998,847.30 566,026.68 4.02 -510.46 2_Gyro-NS-CT_Drill pipe (1) 3,410.00 35.67 228.52 3,054.92 2,991.52 -1,053.68 505.40 5,998,843.40 566,022.38 4.60 -506.13 2_Gyro-NS-CT_Dnll pipe (1) 3,420.00 36.12 229.27 3,063.02 2,999.62 -1,057.53 500.98 5,998,839.50 566,017.99 6.29 -501.72 2_Gyro-NS-CT_Ddll pipe (1) 3,430.00 36.47 229.99 3,071.08 3,007.68 -1,061.36 496.47 5,998,835.63 566,013.52 5.51 -497.21 2_Gym-NS-CT_Drill pipe (1) 3,440.00 36.78 230.71 3,079.10 3,015.70 -1,065.17 491.87 5,998,831.79 566,008.96 5.30 -492.62 2 Gyro-NS-CT_Drill pipe (1) 3,450.00 37.34 231.18 3,087.08 3,023.68 -1,068.97 487.19 5,998,827.95 566,004.31 6.28 -487.94 2_Gym-NS-CT Drill pipe (1) 3,460.00 37.66 231.71 3,095.01 3,031.61 -1,072.76 482.43 5,998,824.11 565,999.59 4.54 -483.18 2_Gyro-NS-CT Drill pipe (1) 3,470.00 37.84 232.17 3,102.92 3,039.52 -1,076.54 477.61 5,998,820.30 565,994.80 3.34 -478.36 2_Gyro-NS-CT_Drill pipe (1) 3,480.00 38.26 232.44 3,110.80 3,047.40 -1,080.30 472.74 5,998,816.49 565,989.96 4.52 473.49 2_Gyro-NS-CT_Drill pipe (1) 3,490.00 38.65 232.71 3,118.63 3,055.23 -1,084.08 467.80 5,998,812.66 565,985.05 4.25 468.55 2_Gyro-NS-CT_Drill pipe (1) 3,500.00 38.87 233.05 3,126.43 3,063.03 -1,087.86 462.81 5,998,808.84 565,980.09 3.06 -463.56 2_Gyro-NS-CT_DnII pipe (1) 3,510.00 39.35 233.30 3,134.18 3,070.78 -1,091.64 457.76 5,998,805.02 565,975.08 5.05 458.52 2_Gyro-NS-CT_Drill pipe (1) 3,520.00 39.66 233.55 3,141.90 3,078.50 -1,095.43 452.65 5,998,801.18 565,970.00 3.48 -453.41 2_Gyro-NS-CT_Drill pipe (1) 3,530.00 39.92 233.79 3,149.58 3,086.18 -1,099.23 447.49 5,998,797.35 565,964.88 3.02 -448.26 2_Gyro-NS-CT_Dri1l pipe (1) 3,540.00 40.35 234.10 3,157.23 3,093.83 -1,103.02 442.28 5,998,793.51 565,959.70 4.74 -443.05 2_Gyro-NS-CT_Dn1l pipe (1) 3,550.00 40.77 234.51 3,164.83 3,101.43 -1,106.81 437.00 5,998,789.67 565,954.46 4.97 -437.77 2_Gyro-NS-CT_Drill pipe (1) 3,560.00 40.97 234.89 3,172.39 3,108.99 -1,110.59 431.66 5,998,785.84 565,949.15 3.19 432.43 2_Gyro-NS-CT_Drill pipe (1) 3,570.00 41.24 235.27 3,179.92 3,116.52 -1,114.36 426.27 5,998,782.03 565,943.79 3.68 -427.05 2_Gyro-NS-CT_Drili pipe (1) 3,580.00 41.72 235.60 3,187.42 3,124.02 -1,118.11 420.81 5,998,778.23 565,938.37 5.27 -421.59 2_Gyro-NS-CT_Drill pipe (1) 3,590.00 41.97 235.97 3,194.87 3,131.47 -1,121.87 415.30 5,998,774.43 565,932.89 3.51 -416.08 2_Gym-NS-CT_Drill pipe (1) 3,600.00 42.07 236.35 3,202.29 3,138.89 -1,125.59 409.74 5,998,770.65 565,927.36 2.73 -410.52 2_Gyro-NS-CT_Drill pipe (1) 3,610.00 42.47 236.63 3,209.69 3,146.29 -1,129.31 404.13 5,998,766.89 565,921.79 4.42 404.92 2_Gyro-NS-CT_Drill pipe (1) 3,620.00 42.58 237.07 3,217.06 3,153.66 -1,133.00 398.47 5,998,763.14 565,916.16 3.17 -399.26 2_Gyro-NS-CT_Drill pipe (1) 3,630.00 42.72 237.67 3,224.42 3,161.02 -1,136.66 392.76 5,998,759.44 565,910.49 4.30 -393.56 2_Gyro-NS-CT_Dnll pipe (1) 3,640.00 42.99 238.05 3,231.75 3,168.35 -1,140.27 387.00 5,998,755.77 565,904.76 3.74 -387.80 2 -Gyro -NS -CT Drill pipe (1) 3,650.00 43.18 238.45 3,239.05 3,175.65 -1,143.87 381.20 5,998,752.13 565,898.99 3.33 -381.99 2 Gym-NS-CT_Drill pipe (1) 3,660.00 43.17 238.88 3,246.35 3,182.95 -1,147.43 375.35 5,998,748.52 565,893.17 2.94 -376.15 2_Gyro-NS-CT Drill pipe (1) 3,670.00 43.59 239.23 3,253.61 3,190.21 -1,150.96 369.46 5,998,744.94 565,887.32 4.84 -370.26 2_Gyro-NS-CT_Drill pipe (1) 3,680.00 44.05 239.79 3,260.83 3,197.43 -1,154.47 363.49 5,998,741.37 565,881.38 6.02 364.30 2 Gyro-NS-CT_Drill pipe (1) 3,690.00 44.29 240.42 3,268.00 3,204.60 -1,157.94 357.45 5,998,737.84 565,875.37 5.00 -358.26 2_Gyro-NS-CT_Drill pipe (1) 3,700.00 44.75 240.99 3,275.13 3,211.73 -1,161.38 351.34 5,998,734.36 565,869.29 6.09 -352.15 2_Gyro-NS-CT_Drill pipe (1) 3,710.00 45.21 241.49 3,282.21 3,218.81 -1,164.78 345.14 5,998,730.91 565,863.12 5.80 -345.96 2_Gyro-NS-CT_Drill pipe (1) 3,720.00 45.49 242.00 3,289.23 3,225.83 -1,168.14 338.88 5,998,727.48 565,856.89 4.58 -339.69 2_Gyro-NS-CT_Dn1l pipe (1) 3,730.00 45.86 242.50 3,296.22 3,232.82 -1,171.47 332.54 5,998,724.10 565,850.58 5.15 -333.36 2_Gyro-NS-CT_Drill pipe (1) 3,740.00 46.25 242.92 3,303.16 3,239.76 -1,174.78 326.15 5,998,720.74 565,844.22 4.94 -326.97 2_Gyro-NS-CT_Drill pipe (1) 3,750.00 46.46 243.46 3,310.06 3,246.66 -1,178.04 319.69 5,998,717.42 565,837.79 4.44 -320.51 2_Gyro-NS-CT Dnll pipe (1) 3,760.00 46.67 244.04 3,316.94 3,253.54 -1,181.25 313.18 5,998,714.15 565,831.30 4.71 -314.00 2_Gyro-NS-CT_Dri1l pipe (1) 3,770.00 47.13 244.42 3,323.77 3,260.37 -1,184.43 306.60 5,998,710.92 565,824.76 5.37 -307.43 2_Gyro-NS-CT_Drill pipe (1) 9/152019 12:24:39PM Page 11 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt S Pad MPU S-203 MPU S-203PB2 MPU S-203PB2 Local Co-ordinate Reference: Well MPU S-203 TVD Reference: MPU S-203 Actual RKB @ 63.40usft MD Reference: MPU S-203 Actual IRKS @ 63.40usft North Reference: True Survey Calculation Method: Minimum Curvature Database: NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1S +EI -W Northing Easting DLS Section (usft) V) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,780.00 47.31 244.83 3,330.56 3,267.16 -1,187.57 299.97 5,998,707.72 565,818.15 3.51 -300.80 2_Gyro-NS-CT_Drill pipe (1) 3,790.00 47.37 245.30 3,337.34 3,273.94 -1,190.67 293.30 5,998,704.56 565,811.51 3.51 -294.13 2_Gym-NS-CT_Dnll pipe (1) 3,800.00 48.01 245.61 3,344.07 3,280.67 -1,193.74 286.57 5,998,701.43 565,804.81 6.80 -287.41 2_Gyro-NS-CT_Dnll pipe (1) 3,810.00 48.30 245.96 3,350.74 3,287.34 -1,196.80 279.78 5,998,698.32 565,798.05 3.90 -280.61 2_Gyro-NSCT_Dn1l pipe (1) 3,820.00 48.54 246.25 3,357.38 3,293.98 -1,199.83 272.94 5,998,695.23 565,791.24 3.24 -273.78 2 Gyro-NS-CT_Dnll pipe (1) 3,830.00 49.09 246.55 3,363.96 3,300.56 -1,202.84 266.04 5,998,692.15 565,784.37 5.95 -266.88 2_Gyro-NS-CT_Drill pipe (1) 3,840.00 49.18 246.91 3,370.51 3,307.11 -1,205.83 259.10 5,998,689.10 565,777.45 2.87 -259.94 2_Gyro-NS-CT_Drill pipe (1) 3,850.00 49.18 247.24 3,377.04 3,313.64 -1,208.78 252.13 5,998,686.10 565,770.50 2.50 -252.97 2_Gyro-NS-CT_Drill pipe (1) 3,860.00 49.48 247.48 3,383.56 3,320.16 -1,211.70 245.13 5,998,683.12 565,763.53 3.51 -245.97 2_Gyro-NS-CT_Dnll pipe (1) 3,870.00 49.74 247.88 3,390.04 3,326.64 -1,214.59 238.08 5,998,680.16 565,756.51 4.01 -238.93 2_Gyro-NSCT_Drill pipe (1) 3,880.00 49.90 248.30 3,396.49 3,333.09 -1,217.44 230.99 5,998,677.25 565,749.45 3.59 -231.84 2_Gyro-NS-CT_Dnll pipe (1) 3,890.00 50.30 248.66 3,402.91 3,339.51 -1,220.25 223.85 5,998,674.37 565,742.34 4.86 -224.71 2_Gyro-NS-CT_Drill pipe (1) 3,900.00 50.73 249.01 3,409.26 3,345.86 -1,223.04 216.66 5,998,671.52 565,735.16 5.08 -217.51 2_Gyro-NS-CT_Drill pipe (1) 3,910.00 50.86 249.41 3,415.59 3,352.19 -1,225.79 209.41 5,998,668.71 565,727.95 3.36 -210.27 2 Gyro-NS-CT_Drill pipe (1) 3,920.00 51.08 249.76 3,421.88 3,358.48 -1,228.50 202.13 5,998,665.94 565,720.69 3.50 -202.99 2_Gyro-NS-CT_Drill pipe (1) 3,930.00 51.66 250.02 3,428.13 3,364.73 -1,231.19 194.80 5,998,663.19 565,713.38 6.15 -195.66 2_Gyro-NS-CT_Dnll pipe (1) 3,940.00 51.87 250.47 3,434.31 3,370.91 -1,233.84 187.40 5,998,660.47 565,706.01 4.11 -188.27 2 Gyro -NS -CT Drill pipe (1) 3,950.00 52.01 250.95 3,440.48 3,377.08 -1,236.44 179.97 5,998,657.80 565,698.60 4.03 -180.84 2_Gyro-NS-CT_DnIl pipe (1) 3,960.00 52.85 251.26 3,446.58 3,383.18 -1,239.01 172.47 5,998,655.17 565,691.13 8.75 -173.34 2_Gyro-NS-CT_Drill pipe (1) 3,970.00 52.75 251.66 3,452.62 3,389.22 -1,241.54 164.92 5,998,652.57 565,683.60 3.34 -165.79 2_Gyro-NS-CT_Drill pipe (1) 3,980.00 52.79 252.08 3,458.67 3,395.27 -1,244.02 157.36 5,998,650.03 565,676.05 3.37 -158.22 2_Gyro-NS-CT_Drill pipe (1) 3,990.00 53.33 252.44 3,464.68 3,401.28 -1,246.45 149.74 5,998,647.53 565,668.46 6.12 -150.61 2_Gyro-NS-CT_Drill pipe (1) 4,000.00 53.58 252.89 3,470.64 3,407.24 -1,248.85 142.07 5,998,645.06 565,660.82 4.40 -142.95 2_Gyro-NS-CT_Drill pipe (1) 4,010.00 53.69 253.25 3,476.57 3,413.17 -1,251.19 134.37 5,998,642.65 565,653.14 3.10 -135.24 2_Gyro-NS-CT_Ddil pipe (1) 4,020.00 54.17 253.65 3,482.45 3,419.05 -1,253.50 126.62 5,998,640.28 565,645.41 5.79 -127.50 2_Gyro-NS-CT_Drill pipe (1) 4,030.00 54.47 254.15 3,488.29 3,424.89 -1,255.75 118.82 5,998,637.96 565,637.63 5.05 -119.69 2 -Gyro -NS -CT Drill pipe (1) 4,040.00 54.55 254.48 3,494.09 3,430.69 -1,257.95 110.98 5,998,635.69 565,629.81 2.80 A11.86 2_Gym-NS-CT_Drill pipe (1) 4,050.00 54.92 254.71 3,499.87 3,436.47 -1,260.12 103.11 5,998,633.45 565,621.96 4.15 -103.99 2_Gyro-NS-CT_Drill pipe (1) 4,060.00 55.35 254.95 3,505.58 3,442.18 -1,262.26 95.19 5,998,631.24 565,614.06 4.73 -96.07 2_Gyro-NS-CT_Drill pipe (1) 4,070.00 55.35 255.22 3,511.27 3,447.87 -1,264.38 87.24 5,998,629.05 565,606.13 2.22 -88.12 2_Gyro-NS-CT_Drill pipe (1) 4,080.00 55.44 255.54 3,516.95 3,453.55 -1,266.46 79.27 5,998,626.90 565,598.18 2.78 -80.16 2_Gyro-NS-CT_Drill pipe (1) 4,090.00 56.11 255.83 3,522.57 3,459.17 -1,268.50 71.26 5,998,624.79 565,590.19 7.12 -72.15 2_Gyro-NS-CT_Drill pipe (1) 4,100.00 56.09 256.08 3,528.15 3,464.75 -1,270.52 63.21 5,998,622.71 565,582.16 2.08 -64.10 2_Gyro-NS-CT_Drill pipe (1) 4,110.00 56.08 256.30 3,533.73 3,470.33 -1,272.50 55.15 5,998,620.65 565,574.12 1.83 -56.04 2_Gyro-NS-CT_Dnll pipe (1) 4,120.00 56.69 256.47 3,539.26 3,475.86 -1,274.46 47.06 5,998,618.62 565,566.04 6.26 -47.95 2_Gyro-NS-CT_Drill pipe (1) 4,130.00 56.88 256.78 3,544.74 3,481.34 -1,276.39 38.92 5,998,616.62 565,557.92 3.22 -39.81 2_Gyro-NS-CT_Drill pipe (1) 4,140.00 56.94 257.07 3,550.20 3,486.80 -1,278.29 30.76 5,998,614.65 565,549.78 2.50 -31.65 2_Gyro-NS-CT_Drill pipe (1) 4,150.00 57.83 257.24 3,555.59 3,492.19 -1,280.16 22.55 5,998,612.71 585,541.58 9.01 -23.44 2_Gyro-NS-CT_Dn11 pipe (1) 4,160.00 58.26 257.47 3,560.88 3,497.48 -1,282.02 14.27 5,998,610.78 565,533.32 4.72 -15.16 2_Gyro-NS-CT_Drill pipe (1) 4,170.00 58.14 257.72 3,566.15 3,502.75 -1,283.85 5.97 5,998,608.88 565,525.04 2.44 -6.86 2_Gyro-NS-CT_Ddil pipe (1) 9116/1019 12:24:39PM Page 12 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilwrp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU 5-203PB2 Survey Calculation Method: Minimum Curvature Design: MPU 5-203PB2 Database: NORTH US + CANADA Survey Map MD Inc Azi ND TVDSS +NI -S +W -W Northing (usft) (1) (`) (usft) (usft) (usft) (usft) (ft) 4,180.00 58.60 257.87 3,571.40 3,508.00 -1,285.65 -2.36 5,998,607.01 4,190.00 59.09 257.99 3,576.57 3,513.17 -1,287.44 -10.72 5,998,605.14 4,200.00 59.24 258.18 3,581.70 3,518.30 -1,289.21 -19.13 5,998,603.30 4,210.00 59.82 258.38 3,586.77 3,523.37 -1,290.96 -27.56 5,998,601.47 4,220.00 60.42 258.62 3,591.75 3,528.35 -1,292.69 -36.06 5,998,599.67 4,230.00 60.58 258.79 3,596.67 3,533.27 -1,294.39 -44.60 5,998,597.89 4,240.00 60.95 258.95 3,601.56 3,538.16 -1,296.08 -53.16 5,998,596.13 4,250.00 61.43 259.11 3,606.38 3,542.98 -1,297.74 -61.76 5,998,594.39 4,260.00 61.46 259.32 3,611.16 3,547.76 -1,299.39 -70.39 5,998,592.67 4,270.00 61.37 259.50 3,615.94 3,552.54 -1,301.00 -79.02 5,998,590.98 4,280.00 61.83 259.59 3,620.70 3,557.30 -1,302.60 -87.67 5,998,589.31 4,290.00 61.81 259.78 3,625.42 3,562.02 -1,304.18 -96.34 5,998,587.65 4,30000 61.69 259.97 3,630.15 3,566.75 -1,305.72 -105.01 5,998,586.03 4,310.00 62.45 260.09 3,634.84 3,571.44 -1,307.25 -113.72 5,998,584.42 4,320.00 62.67 260.26 3,639.45 3,576.05 -1,308.77 -122.46 5,998,582.83 4,330.00 62.50 260.40 3,644.05 3,580.65 -1,310.26 -131.21 5,998,581.26 4,340.00 63.22 260.42 3,648.61 3,585.21 -1,311.74 -139.99 5,998,579.71 4,350.00 63.37 260.51 3,653.11 3,589.71 -1,313.22 -148.80 5,998,578.15 4,360.00 63.26 260.61 3,657.60 3,594.20 -1,314.69 -157.61 5,998,576.61 4,370.00 63.73 260.68 3,662.06 3,598.66 -1,316.14 -166.44 5,998,575.07 4,380.00 64.19 260.78 3,666.45 3,603.05 -1,317.59 -175.31 5,998,573.55 4,390.00 64.40 260.89 3,670.79 3,607.39 -1,319.02 -184.20 5,998,572.04 4,400.00 65.07 260.96 3,675.06 3,611.66 -1,320.45 -193.13 5,998,570.53 4,410.00 65.67 260.99 3,679.22 3,615.82 -1,321.88 -202.11 5,998,569.03 4,420.00 65.82 261.06 3,683.33 3,619.93 -1,323.30 -211.12 5,998,567.53 4,430.00 66.04 261.17 3,687.41 3,624.01 -1,324.71 -220.14 5,998,566.04 4,440.00 67.11 261.22 3,691.38 3,627.98 -1,326.11 -229.20 5,998,564.55 4,450.00 67.55 261.43 3,695.24 3,631.84 -1,327.51 -238.33 5,998,563.08 4,460.00 67.62 261.66 3,699.05 3,635.65 -1,328.86 -247.47 5,998,561.64 4,470.00 68.65 261.74 3,702.78 3,639.38 -1,330.20 -256.65 5,998,560.22 4,480.00 68.68 261.84 3,706.41 3,643.01 -1,331.53 -265.87 5,998,558.81 4,490.00 68.53 261.91 3,710.06 3,646.66 -1,332.85 -275.09 5,998,557.42 4,500.00 69.42 261.91 3,713.65 3,650.25 -1,334.16 -284.33 5,998,556.02 4,510.00 69.72 262.00 3,717.14 3,653.74 -1,335.48 -293.61 5,998,554.63 4,620.00 69.70 262.14 3,720.61 3,657.21 -1,336.77 -302.90 5,998,553.25 4,530.00 70.23 262.20 3,724.03 3,660.63 -1,338.05 -312.21 5,998,551.89 4,540.00 70.50 262.30 3,727.39 3,663.99 -1,339.32 -321.54 5,998,550.54 4,550.00 70.51 262.39 3,730.73 3,667.33 -1,340.58 -330.88 5,998,549.20 4,560.00 70.90 262.52 3,734.04 3,670.64 -1,341.81 -340.24 5,998,547.88 4,570.00 71.59 262.71 3,737.25 3,673.85 -1,343.03 -349.63 5,998,546.58 Map Easting DLS (ft) ('1100') 565,516.73 4.77 565,508.38 5.01 565,499.99 2.22 565,491.57 6.05 565,483.09 565,474.57 565,466.03 565,457.44 565,448.83 565,440.21 565,431.58 565,422.92 565,414.26 565,405.57 565,396.84 565,388.11 565,379.35 565,370.55 565,361.75 565,352.94 565,344.08 565,335.20 565,326.28 565,317.32 565,308.33 565,299.32 565,290.27 565,281.16 565,272.03 565,262.86 565,253.65 565,244.45 565,235.22 565,225.95 565,216.67 565,207.38 565,198.06 565,188.73 565,179.38 565,170.01 6.35 2.18 3.95 5.00 1.87 1.82 4.67 1.69 2.06 7.67 2.67 2.11 7.20 1.70 1.42 4.74 4.69 2.32 6.73 6.01 1.63 2.42 10.71 4.81 2.24 10.33 0.98 1.64 8.90 3.12 1.33 5.33 2.86 0.85 4.09 7.13 Vertical Section (ft) Survey Tool Name 1.46 2_Gyro-NS-CT_Ddll pipe (1) 9.82 2_Gyro-NS-CT_Drill pipe (1) 1823 2_Gyrc-NS-CT_Drill pipe (1) 26.66 2_Gym-NS-CT_Dnll pipe (1) 35.16 2_Gyro-NS-CT_Dnll pipe (1) 43.69 2 -Gyro -NS -CT Dnll pipe (1) 52.25 2 Gyro-NS-CT_Drill pipe (1) 60.85 2_Gyro-NS-CT_Dnll pipe (1) 69.48 2_Gym-NS-CT_Dnll pipe (1) 78.11 2_Gyro-NS-CT_Drill pipe (1) 86.76 2_Gyro-NS-CT_Dnll pipe (1) 95.43 2_Gyro-NS-CT_Dnll pipe (1) 104.10 2_Gym-NS-CT_Drill pipe (1) 112.80 2_Gyro-NS-CT_Drill pipe (1) 121.55 2_Gyro-NS-CT_Dnll pipe (1) 130.30 2_Gym-NS-CT_Dnll pipe (1) 139.07 2_Gym-NS-CT_Dnll pipe (1) 147.88 2_Gyro-NS-CT_D611 pipe (1) 156.69 2_Gym-NS-CT_Drill pipe (1) 165.52 2_Gyro-NS-CT_Drill pipe (1) 174.39 2_Gyro-NS-CT_Drill pipe (1) 183.28 2_Gyro-NS-CT_Drill pipe (1) 192.21 2_Gym-NS-CT_Drill pipe (1) 201.19 2 -Gym -NS -CT Dfill pipe (1) 210.19 2_Gyro-NS-CT_Drill pipe (1) 219.21 2_Gyro-NS-CT_Drill pipe (1) 228.28 2_Gym-NS-CT_Drill pipe (1) 237.40 2 Gyro-NS-CT_Drill pipe (1) 246.54 2_Gyro-NS-CT_DnIl pipe (1) 255.72 2 Gyro-NS-CT_Drill pipe (1) 264.94 2_Gyro-NS-CT_Drill pipe (1) 274.16 2_Gyro-NS-CT_Drill pipe (1) 283.40 2_Gyro-NS-CT_Drill pipe (1) 292.68 2 -Gym -NS -CT -Drill pipe (1) 301.97 2_Gyro-NS-CT_Drill pipe (1) 311.27 2_Gyro-NS-CT_Drill pipe (1) 320.60 2_Gym-NS-CT_Dnll pipe (1) 329.95 2_Gym-NS-CT_Drl1 pipe (1) 339.30 2_Gyro-NS-CT_Drill pipe (1) 348.69 2_Gyro-NS-CT_Ddll pipe (1) 9/16/2019 12:24:39PM Page 13 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU 5-203PB2 Design: MPU 5-203PB2 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +NIS +El -W Northing (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) 4,580.00 71.62 262.98 3,740.41 3,677.01 -1,344.21 -359.04 5,998,545.32 4,590.00 72.01 263.18 3,743.53 3,680.13 -1,345.36 -368.48 5,998,544.09 4,600.00 72.84 263.28 3,746.55 3,683.15 -1,346.48 -377.94 5,998,542.88 4,610.00 72.99 263.42 3,749.49 3,686.09 -1,347.59 -387.44 5,998,541.69 4,620.00 73.11 263.53 3,752.40 3,689.00 -1,348.68 -396.94 5,998,540.52 4,630.00 74.32 263.61 3,755.20 301.80 -1,349.75 -406.48 5,998,539.36 4,640.00 74.88 263.79 3,757.86 3,694.46 -1,350.81 -416.06 5,998,538.22 4,650.00 75.60 263.89 3,760.41 3,697.01 -1,351.85 -425.68 5,998,537.10 4,660.00 76.70 263.95 3,762.80 3,699.40 -1,352.87 -435.33 5,998,535.99 4,670.00 77.11 264.07 3,765.07 3,701.67 -1,353.89 -445.02 5,998,534.89 4,680.00 76.93 264.18 3,767.31 3,703.91 -1,354.89 454.71 5,998,533.80 4,690.00 77.48 264.19 3,769.53 3,706.13 -1,355.88 464.41 5,998,532.73 4,700.00 77.73 264.26 3,771.67 3,708.27 -1,356.86 -474.13 5,998,531.66 4,710.00 77.86 264.33 3,773.79 3,710.39 -1,357.83 483.85 5,998,530.61 4,720.00 78.48 264.36 3,775.84 3,712.44 -1,358.80 493.59 5,998,529.56 4,730.00 78.81 264.36 3,777.81 3,714.41 -1,359.76 503.35 5,998,528.51 4,740.00 78.95 264.33 3,779.74 3,716.34 -1,360.73 -513.12 5,998527.46 4,750.00 79.20 264.29 3,781.63 3,718.23 -1,361.70 -522.89 5,998,526.40 4,760.00 79.39 264.28 3,783.49 3,720.09 -1,362.68 -532.66 5,998,525.33 4,770.00 79.33 264.31 3,785.34 3,721.94 -1,363.65 -542.44 5,998,524.27 4,780.00 79.36 264.33 3,787.18 3,723.78 -1,364.63 -552.22 5,998,523.21 4,790.00 79.87 264.30 3,788.99 3,725.59 -1,365.60 -562.01 5,998,522.15 4,800.00 80.01 264.44 3,790.73 3,727.33 -1,366.57 -571.81 5,998,521.10 4,810.00 80.31 264.65 3,792.44 3,729.04 -1,367.50 -581.62 5,998,520.08 4,820.00 81.50 264.81 3,794.02 3,730.62 -1,368.41 -591.45 5,998,519.08 4,830.00 82.17 265.01 3,795.44 3,732.04 -1,369.29 501.31 5,998,518.12 4,840.00 82.82 265.28 3,796.75 3,733.35 -1,370.13 -611.19 5,998,517.19 4,846.77 83.36 265.31 3,797.56 3,734.16 -1,370.68 -617.89 5,998,516.58 4,904.94 84.70 268.40 3,803.62 3,740.22 -1,373.85 -675.64 5,998,512.91 4,968.52 83.38 269.42 3,810.22 3,746.82 -1,375.05 -738.87 5,998,511.15 5,032.31 83.39 270.41 3,817.57 3,754.17 -1,375.15 -802.23 5,998,510.50 5,096.62 84.01 271.22 3,824.62 3,761.22 -1,374.24 -866.15 5,998,510.85 5,159.75 86.43 272.63 3,829.88 3,766.48 -1,372.13 -929.01 5,998,512.41 5,223.17 87.16 272.57 3,833.43 3,770.03 -1,369.25 -992.27 5,998,514.73 5,286.77 88.78 272.34 3,835.68 3,772.28 -1,366.53 -1,055.77 5,998,516.89 5,309.42 89.58 272.45 3,836.01 3,772.61 -1,365.58 -1,078.40 5,998,517.64 5,405.95 90.42 275.41 3,836.01 3,772.61 -1,358.97 -1,174.69 5,998,523.41 5,469.78 90.73 275.77 3,835.37 3,771.97 -1,352.75 -1,238.21 5,998,529.07 5,532.85 92.70 276.11 3,833.48 3,770.08 -1,346.23 -1,300.91 5,998,535.04 5,597.02 94.56 277.08 3,829.42 3,766.02 -1,338.87 -1,364.53 5,998,541.84 Well MPU S-203 MPU 5-203 Actual RKB @ 63.40usft MPU S-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Map Easting DLS (ft) ('1100') 565,160.60 2.58 565,151.18 4.34 565,141.73 8.35 565,132.24 2.01 565,122.75 565,113.22 565,103.65 565,094.05 565,084.40 565,074.73 565,065.04 565,055.35 565,045.64 565,035.93 565,026.20 565,016.45 565,006.70 564,996.94 564,987.17 564,977.40 564,967.63 564,957.85 564,948.06 564,938.26 564,928.44 564,918.59 564,908.72 564,902.03 564,844.30 564,781.10 564,717.75 564,653.83 564,590.95 564,527.68 564,464.17 564,441.53 564,345.20 564,281.63 564,218.88 564,155.21 1.60 12.12 5.86 7.26 11.02 4.26 2.09 5.50 2.59 1.47 6.21 3.30 1.43 2.53 1.90 0.67 0.36 5.11 1.96 3.64 12.00 6.99 7.03 7.99 5.76 2.62 1.54 1.58 4.43 1.15 2.57 3.57 3.19 0.74 3.17 3.27 Vertical Section (ft) Survey Tool Name 358.11 2_Gyro-NS-CT_Drill pipe (1) 367.54 2_Gyro-NS-CT_Drill pipe (1) 377.00 2_Gyro-NS-CT_Drill pipe (1) 386.50 2_Gym-NS-CT_Dnll pipe (1) 396.00 2_Gyro-NS-CT Drill pipe (1) 405.54 2_Gyro-NS-CT_Ddll pipe (1) 415.12 2_Gyro-NS-CT_Drill pipe (1) 424.73 2_Gyro-NS-CT_Dnll pipe (1) 434.39 2_Gyro-NS-CT_Dnll pipe (1) 444.07 2 Gyro-NS-CT_DO pipe (1) 453.76 2_Gyro-NS-CT_Ddll pipe (1) 463.47 2_Gyro-NS-CT_Dnll pipe (1) 473.18 2_Gym-NS-CT_Dnll pipe (1) 482.91 2_Gyro-NS-CT_Dnll pipe (1) 492.65 2_Gyro-NS-CT_Drill pipe (1) 502.40 2_Gyro-NS-GT_Drill pipe (1) 512.17 2 -GYM -NS -CT -Drill pipe (1) 521.94 2_Gyro-NS-CT_Drill pipe (1) 531.71 2_Gyro-NS-CT_Dnll pipe (1) 541.49 2_Gym-NS-CT_Drill pipe (1) 551.27 2_Gyro-NS-CT_Drill pipe (1) 561.06 2_Gyro-NS-CT_Drill pipe (1) 570.85 2_Gyro-NS-CT_Drill pipe (1) 580.66 2 -Gym -NS -CT -Drill pipe (1) 590.49 2_Gyro-NS-CT_Drill pipe (1) 600.35 2 -Gyro -NS -CT Drill pipe (1) 610.23 2_Gyro-NS-CT_Drill pipe (1) 616.93 2_Gyro-NS-CT_Dnll pipe (1) 674.69 2 MWD+IFR2+MS+Sag (2) 737.91 2 MWD+IFR2+MS+Sag (2) 801.27 2 MWD+IFR2+MS+Sag (2) 865.19 2_MWD+IFR2+MS+Sag (2) 928.06 2_MWD+IFR2+MS+Sag (2) 991.31 2_MWD+IFR2+MS+Sag (2) 1,054.82 2_MWD+IFR2+MS+Sag (2) 1,077.44 2_MWD+IFR2+MS+Sag (2) 1,173.74 2_MWD+IFR2+MS+Sag (3) 1,237.27 2_MWD+IFR2+MS+Sag(3) 1,299.97 2_MWD+IFR2+MS+Sag(3) 1,363.59 2_MWD+IFR2+MS+Sag (3) 9/162019 12:24:39PM Page 14 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU 5-203 Project: Milne Point TVD Reference: MPU 5-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU 5-203 Actual RKB @ 63.40usft Well: MPU 5-203 North Reference: True Wellbore: MPU 5-203PB2 Survey Calculation Method: Minimum Curvature Design: MPU 5-203PB2 - Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 5,660.62 94.80 276.89 3,824.23 3,760.83 -1,331.17 -1,427.44 5,998,548.99 564,092.23 0.48 1,426.51 2_MWD+IFR2+MS+Sag (3) 5,724.27 94.62 274.95 3,819.00 3,755.60 -1,324.62 -1,490.54 5,998,554.98 564,029.09 3.05 1,489.61 2_MWD+IFR2+MS+Sag (3) 5,787.86 93.94 273.43 3,814.25 3,750.85 -1,319.99 -1,553.78 5,998,559.06 563,965.82 2.61 1,552.86 2_MWD+IFR2+MS+Sag(3) 5,851.07 93.81 272.21 3,809.98 3,746.58 -1,316.89 -1,616.77 5,998,561.61 563,902.81 1.94 1,615.85 2_MWD+IFR2+MS+Sag (3) 5,914.97 93.81 270.41 3,805.74 3,742.34 -1,315.43 -1,680.51 5,998,562.51 563,839.07 2.81 1,679.59 2_MWD+IFR2+MS+Sag (3) 5,978.65 93.38 270.07 3,801.74 3,738.34 -1,315.16 -1,744.06 5,998,562.22 563,775.52 0.86 1,743.14 2_MWD+IFR2+MS+Sag (3) 6,041.96 93.94 269.52 3,797.70 3,734.30 -1,315.39 -1,807.24 5,998,561.44 563,712.35 1.24 1,806.32 2_MWD+IFR2+MS+Sag(3) 6,105.55 93.75 268.65 3,793.44 3,730.04 -1,316.40 -1,870.68 5,998,559.87 563,648.93 1.40 1,869.76 2_MWD+IFR2+MS+Sag(3) 6,169.10 93.01 267.26 3,789.69 3,726.29 -1,318.67 -1,934.07 5,998,557.05 563,585.56 2.47 1,933.15 2_MWD+IFR2+MS+Sag (3) 6,232.57 93.08 266.24 3,786.32 3,722.92 -1,322.26 -1,997.35 5,998,552.90 563.522.32 1.61 1,996.43 2_MWD+IFR2+MS+Sag (3) 6,296.24 93.26 267.74 3,782.80 3,719.40 -1,325.60 -2,060.83 5,998,549.01 563,458.88 2.37 2,059.91 2_MWD+IFR2+MS+Sag (3) 6,360.35 93.94 270.05 3,778.77 3,715.37 -1,326.83 -2,124.80 5,998,547.21 563,394.93 3.75 2,123.87 2_MWD+IFR2+MS+Sag(3) 6,423.88 93.75 271.25 3,774.51 3,711.11 -1,326.11 -2,188.18 5,998,547.37 563,331.55 1.91 2,187.26 2_MWD+IFR2+MS+Sag(3) 6,487.23 93.88 270.93 3,770.30 3,706.90 -1,324.91 -2,251.38 5,998,548.02 563,268.35 0.54 2,250.46 2_MWD+IFR2+MS+Sag (3) 6,550.90 92.39 269.39 3,766.81 3,703.41 -1,324.73 -2,314.95 5,998,547.64 563,204.79 3.36 2,314.03 2_MWD+IFR2+MS+Sag (3) 6,614.58 92.52 268.20 3,764.09 3,700.69 -1,326.07 -2,378.56 5,998,545.75 563,141.20 1.88 2,377.63 2 MWD+IFR2+MS+Sag(3) 6,677.91 92.70 268.05 3,761.20 3,697.80 -1,328.14 -2,441.79 5,998,543.12 563,078.00 0.37 2,440.86 2_MWD+IFR2+MS+Sag(3) 6,741.22 92.52 268.15 3,758.32 3,694.92 -1,330.24 -2,505.00 5,998,540.47 563,014.81 0.33 2,504.07 2_MWD+IFR2+MS+Sag (3) 6,805.38 92.46 268.97 3,755.53 3,692.13 -1,331.85 -2,569.08 5,998,538.30 562,950.76 1.28 2,568.15 2_MWD+IFR2+MS+Sag (3) 6,869.91 93.26 270.58 3,752.31 3,688.91 -1,332.10 -2,633.52 5,998,537.48 562,886.32 2.78 2,632.59 2_MWD+IFR2+MS+Sag (3) 6,932.41 93.51 271.12 3,748.62 3,685.22 -1,331.18 -2,695.91 5,998,537.86 562,823.94 0.95 2,694.98 2_MWD+IFR2+MS+Sag(3) 6,996.29 93.38 271.12 3,744.78 3,681.38 -1,329.93 -2,759.66 5,998,538.54 562,760.18 0.20 2,758.73 2_MWD+IFR2+MS+Sag(3) 7,060.39 93.57 273.98 3,740.90 3,677.50 -1,327.08 -2,823.57 5,998,540.83 562,696.25 4.46 2,822.64 2_MWD+IFR2+MS+Sag (3) 7,124.04 93.20 272.09 3,737.14 3,673.74 -1,323.72 -2,887.02 5,998,543.64 562,632.79 3.02 2,886.09 2_MWD+IFR2+MS+Sag (3) 7,187.73 92.58 271.81 3,733.93 3,670.53 -1,321.56 -2,950.59 5,998,545.24 562,569.20 1.07 2,949.67 2_MWD+IFR2+MS+Sag(3) 7,251.10 92.40 270.68 3,731.17 3,667.77 -1,320.18 -3,013.88 5,998,546.06 562,505.91 1.80 3,012.96 2 MWD+IFR2+MS+Sag(3) 7,314.34 92.45 271.04 3,728.50 3,665.10 -1,319.23 -3,077.06 5,998,546.46 562,442.73 0.57 3,076.14 2_MWD+IFR2+MS+Sag (3) 7,377.83 93.01 270.51 3,725.47 3,662.07 -1,318.38 -3,140.47 5,998,546.76 562,379.32 1.21 3,139.55 2_MWD+IFR2+MS+Sag (3) 7,441.46 92.46 269.24 3,722.44 3,659.04 -1,318.51 -3,204.03 5,998,546.06 562,315.77 2.17 3,203.11 2_MWD+IFR2+MS+Sag(3) 7,505.37 92.58 268.01 3,719.63 3,656.23 -1,320.05 -3,267.86 5,998,543.97 562,251.97 1.93 3,266.93 2_MWD+IFR2+MS+Sag(3) 7,568.58 91.96 268.52 3,717.12 3,653.72 -1,321.96 -3,330.99 5,998,541.51 562,188.86 1.27 3,330.06 2_MWD+IFR2+MS+Sag (3) 7,632.65 91.78 268.81 3,715.03 3,651.63 -1,323.45 -3,395.01 5,998,539.45 562,124.86 0.53 3,394.08 2_MWD+IFR2+MS+Sag (3) 7,695.33 92.70 268.58 3,712.58 3,649.18 -1,324.88 -3,457.62 5,998,537.48 562,062.27 1.51 3,456.70 2_MWD+IFR2+MS+Sag (3) 7,760.12 94.00 269.27 3,708.80 3,645.40 -1,326.09 -3,522.29 5,998,535.70 561,997.62 2.27 3,521.36 2_MWD+IFR2+MS+Sag (3) 7,823.60 93.44 269.94 3,704.68 3,641.28 -1,326.53 -3,585.63 5,998,534.70 561,934.29 1.37 3,584.70 2_MWD+IFR2+MS+Sag (3) 7,887.44 93.14 270.49 3,701.01 3,637.61 -1,326.29 -3,649.37 5,998,534.38 561,870.56 0.98 3,648.44 2_MWD+IFR2+MS+Sag (3) 7,950.58 93.57 270.79 3,697.32 3,633.92 -1,325.58 -3,712.39 5,998,534.54 561,807.54 0.83 3,711.47 2_MWD+IFR2+MS+Sag (3) 8,014.58 94.00 269.86 3,693.09 3,629.69 -1,325.22 3,776.25 5,998,534.34 561,743.69 1.60 3,775.33 2_MWD+IFR2+MS+Sag(3) 8,073.00 94.23 270.30 3,688.90 3,625.50 -1,325.14 -3,834.52 5,998,533.91 561,685.42 0.85 3,833.59 2_MWD+IFR2+MS+Sag(4) 8,140.98 92.08 272.05 3,685.16 3,621.76 A,323.75 -3,902.38 5,998,534.71 561,617.56 4.08 3,901.45 2_MWD+IFR2+MS+Sag (4) 9/1612019 12:24:39PM Page 15 COMPASS 5000.15 Build 91 Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: MPU 5-203 Wellbore: MPU 5-203PB2 Design: MPU 5-203PB2 Survey Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +N1 -S +EI -W Northing (usft) V) (1) (usft) (usft) (usft) (usft) (ft) 8,204.54 92.27 273.98 3,682.75 3,619.35 -1,320.41 -3,965.80 5,998,537.49 8,268.53 93.20 275.79 3,679.69 3,616.29 -1,314.96 4,029.48 5,998,542.37 8,332.06 93.44 276.35 3,676.02 3,612.62 -1,308.26 -4,092.55 5,998,548.53 8,395.77 93.81 276.91 3,671.99 3,608.59 -1,300.92 -4,155.71 5,998,555.31 8,459.73 93.69 277.15 3,667.80 3,604.40 -1,293.11 -4,219.05 5,998,562.57 8,522.96 93.26 276.24 3,663.97 3,600.57 -1,285.75 4,281.73 5,998,569.37 8,587.06 93.69 275.58 3,660.09 3,596.69 -1,279.16 -4,345.37 5,998,575.40 8,650.60 92.64 273.20 3,656.58 3,593.18 -1,274.30 -4,408.62 5,998,579.70 8,716.22 92.03 270.09 3,653.90 3,590.50 -1,272.42 4,474.16 5,998,581.01 8,777.46 91.22 267.89 3,652.17 3,588.77 -1,273.50 -4,535.36 5,998,579.39 8,840.80 90.79 266.86 3,651.06 3,587.66 -1,276.40 -4,598.62 5,998,575.94 8,905.12 91.03 266.82 3,650.03 3,586.63 -1,279.95 -4,662.83 5,998,571.83 8,968.69 92.46 266.48 3,648.10 3,564.70 -1,283.66 -4,726.26 5,998,567.56 9,029.24 93.88 266.99 3,644.75 3,581.35 -1,287.10 -4,786.62 5,998,563.59 9,095.71 94.18 266.40 3,640.08 3,576.68 -1,290.93 -4,852.82 5,998,559.19 9,159.15 94.19 265.74 3,635.45 3,572.05 -1,295.26 -4,915.94 5,998,554.30 9,222.87 93.82 265.98 3,631.00 3,567.60 -1,299.85 -4,979.34 5,998,549.15 9,286.41 93.94 266.17 3,626.70 3,563.30 -1,304.19 -5,042.58 5,998,544.26 9,350.18 92.70 267.52 3,623.01 3,559.61 -1,307.69 -5,106.15 5,998,540.20 9,411.51 90.48 267.95 3,621.30 3,557.90 -1,310.12 -5,167.40 5,998,537.24 9,476.85 89.55 268.02 3,621.29 3,557.89 -1,312.41 -5,232.70 5,998,534.37 9,540.48 89.43 268.63 3,621.85 3,558.45 -1,314.27 -5,296.30 5,998,531.95 9,602.77 90.05 269.83 3,622.14 3,558.74 -1,315.11 -5,358.58 5,998,530.57 9,667.21 90.91 271.30 3,621.60 3,558.20 -1,314.48 -5,423.01 5,998,530.64 9,730.79 90.42 270.96 3,620.86 3,557.46 -1,313.22 -5,486.58 5,998,531.34 9,793.83 91.41 270.97 3,619.85 3,556.45 -1,312.16 -5,549.60 6,998,531.84 9,856.87 90.67 270.52 3,618.71 3,555.31 -1,311.34 -5,612.62 5,998,532.11 9,919.87 91.34 269.47 3,617.60 3,554.20 -1,311.35 5,675.61 5,998,531.55 9,983.46 92.40 266.97 3,615.53 3,552.13 -1,313.32 -5,739.13 5,998,529.02 10,047.00 93.51 266.77 3,612.25 3,548.85 -1,316.78 -5,802.49 5,998,525.00 10,111.58 92.58 266.47 3,608.82 3,545.42 -1,320.59 -5,866.87 5,998,520.64 10,174.71 91.53 265.40 3,606.56 3,543.16 -1,325.06 -5,929.80 5,998,515.61 10,238.44 90.67 266.57 3,605.33 3,541.93 -1,329.52 -5,993.36 5,998,510.59 10,301.81 90.66 268.44 3,604.60 3,541.20 -1,332.28 -6,056.66 5,998,507.28 10,365.68 91.53 270.15 3,603.38 3,539.98 -1,333.06 -6,120.51 5,998,505.94 10,428.19 92.52 272.70 3,601.17 3,537.77 -1,331.51 -6,182.95 5,998,506.94 10,493.04 92.33 271.24 3,598.42 3,535.02 -1,329.28 -6,247.71 5,998,508.60 10,557.74 92.33 270.20 3,595.79 3,532.39 -1,328.47 -6,312.35 5,998,508.85 10,621.17 91.10 270.36 3,593.90 3,530.50 -1,328.16 -6,375.75 5,998,508.60 10,685.13 88.99 269.92 3,593.85 3,530.45 -1,328.01 -6,439.70 5,998,508.19 Well MPU 5-203 MPU S-203 Actual RKB @ 63.40usft MPU 5-203 Actual RKB @ 63.40usft True Minimum Curvature NORTH US + CANADA Map Vertical Easting DLS Section (ft) (=/100•) (ft) Survey Tool Name 561,554.12 3.05 3,964.88 2_MWD+IFR2+MS+Sag (4) 561,490.40 3.18 4,028.56 2_MWD+IFR2+MS+Sag(4) 561,427.28 0.96 4,091.63 2_MWD+IFR2+MS+Sag(4) 561,364.07 1.05 4,154.80 2_MWD+IFR2+MS+Sag (4) 561,300.66 0.42 4,218.15 2_MWD+IFR2+MS+Sag (4) 561,237.93 1.59 4,280.83 2_MWD+IFR2+MS+Sag (4) 561,174.24 1.23 4,344.48 2_MWD+IFR2+MS+Sag(4) 561,110.95 4.09 4,407.73 2_MWD+IFR2+MS+Sag(4) 561,045.41 4.83 4,473.27 2_MWD+IFR2+MS+Sag(4) 560,984.23 3.83 4,534.47 2_MWD+IFR2+MS+Sag (4) 560,921.00 1.76 4,597.73 2 MWD+IFR2+MS+Sag (4) 560,856.82 0.38 4,661.94 2_MWD+IFR2+MS+Sag (4) 560,793.44 2.31 4,725.37 2_MWD+IFR2+MS+Sag (4) 560,733.12 2.49 4,785.72 2_MWD+IFR2+MS+Sag(4) 560,666.96 0.99 4,851.91 2_MWD+IFR2+MS+Sag(4) 560,603.89 1.04 4,915.03 2_MWD+IFR2+MS+Sag(4) 560,540.54 0.69 4,978.43 2_MWD+IFR2+MS+Sag(4) 560,477.34 0.35 5,041.67 2_MWD+IFR2+MS+Sag (4) 560,413.82 2.87 5,105.23 2_MWD+IFR2+MS+Sag (4) 560,352.59 3.69 5,166.48 2_MWD+IFR2+MS+Sag (4) 560,287.32 1.43 5,231.78 2_MWD+IFR2+MS+Sag (4) 560,223.74 0.98 5,295.38 2_MWD+IFR2+MS+Sag(4) 560,161.48 2.17 5,357.66 2_MWD+IFR2+MS+Sag(4) 560,097.05 2.64 5,422.09 2_MWD+IFR2+MS+Sag(4) 560,033.48 0.94 5,485.66 2_MWD+IFR2+MS+Sag(4) 559,970.46 1.57 5,548.68 2_MWD+IFR2+MS+Sag (4) 559,907.44 1.37 5,611.71 2_MWD+IFR2+MS+Sag (4) 559,844.46 1.98 5,674.69 2_MWD+IFR2+MS+Sag (4) 559,780.96 4.27 5,738.21 2_MWD+IFR2+MS+Sag (4) 559,717.64 1.77 5,801.57 2_MWD+IFR2+MS+Sag (4) 559,653.31 1.51 5,865.94 2_MWD+IFR2+MS+Sag(4) 559,590.43 2.37 5,928.87 2_MWD+IFR2+MS+Sag (4) 559,526.91 2.28 5,992.43 2_MWD+IFR2+MS+Sag (4) 559,463.64 2.95 6,055.73 2_MWD+IFR2+MS+Sag (4) 559,399.81 3.00 6,119.58 2_MWD+IFR2+MS+Sag(4) 559,337.36 4.37 6,182.02 2_MWD+IFR2+MS+Sag(4) 559,272.60 2.27 6,246.78 2_MWD+IFR2+MS+Sag(4) 559,207.96 1.61 6,311.42 2_MWD+IFR2+MS+Sag (4) 559,144.56 1.96 6,374.82 2_MWD+IFR2+MS+Sag (4) 559,080.61 3.37 6,438.77 2_MWD+IFR2+MS+Sag (4) 9/162019 12:24:39PM Page 16 COMPASS 5000.15 Build 91 Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU S-203 Project: Milne Point TVD Reference: MPU S-203 Actual RKB @ 63.40usft Site: M Pt S Pad MD Reference: MPU S-203 Actual RKB @ 63.40usft Well: MPU S-203 North Reference: True Wellbore: MPU S-203PB2 Survey Calculation Method: Minimum Curvature Design: MPU S-203PB2 Database: NORTH US+CANADA Survey 9/162019 12:24:39PM Page 17 COMPASS 5000.15 Build 91 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (=If00•) (ft) Survey Tool Name 10,748.55 86.59 270.02 3,596.29 3,532.89 -1,328.04 -6,503.07 5,998,507.61 559,017.25 3.79 6,502.14 2_MWD+IFR2+MS+Sag(4) 10,812.23 83.80 268.66 3,601.62 3,538.22 -1,328.77 -6,566.52 5,998,506.32 558,953.83 4.87 6,565.59 2_MWD+IFR2+MS+Sag (4) 10,875.67 81.05 267.81 3,609.99 3,546.59 -1,330.70 -6,629.37 5,998,503.83 558,891.00 4.53 6,628.43 2_MWD+IFR2+MS+Sag (4) 10,939.52 77.97 267.41 3,621.61 3,558.21 -1,333.32 -6,692.09 5,998,500.67 558,828.31 4.86 6,691.15 2_MWD+IFR2+MS+Sag(4) 11,002.79 74.94 267.83 3,636.43 3,573.03 -1,335.88 -6,753.54 5,998,497.57 558,766.89 4.83 6,752.60 2_MWD+IFR2+MS+Sag (4)M 11,066.76 72.22 267.35 3,654.51 3,591.11 -1,338.45 -6,814.84 5,998,494.46 558,705.62 4.31 6,813.90 2_WD+IFR2+MS+Sag (4) 11,130.13 69.07 267.19 3,675.51 3,612.11 -1,341.30 -6,874.55 5,998,491.09 558,645.94 4.98 6,873.61 2_MWD+IFR2+MS+Sag(4) 11,193.80 66.47 267.79 3,699.59 3,636.19 -1,343.88 -6,933.43 5,998,487.99 558,587.10 4.18 6,932.49 2_MWD+IFR2+MS+Sag(4) 11,257.81 63.54 268.63 3,726.64 3,663.24 -1,345.70 -6,991.40 5,998,485.66 558,529.14 4.73 6,990.46 2_MWD+IFR2+MS+Sag (4) 11,319.17 60.88 269.07 3,755.24 3,691.84 -1,346.79 -7,045.67 5,998,484.10 558,474.89 4.38 7,044.73 2_MWD+IFR2+MS+Sag(4) 11,377.00 60.88 269.07 3,783.39 3,719.99 -1,347.61 -7,096.19 5,998,482.83 558,424.39 0.00 7,095.24 PROJECTED to TD Checked By: Chelsea Wright Approved By: Benjamin Hand ?� '" Date: 09-16-2019 9/162019 12:24:39PM Page 17 COMPASS 5000.15 Build 91 Hilcorp Energy Company CASING & CEMENTING REPORT Lease 8 Well No. MP S-203 County North Slope Borough State Alaska Sup, CASING RECORD DQTrI Su a e t Dale Run 29 -Aug -19 J Lott/ O. Amend Csg WL On Hook: 240 Type Float Collar: Battle Adapter no. Mrs m Mon: Csg Wt. On Slips: 150,1310 Type of Shoe: Conventional Casing Crew: Weatherford Rotate Csg X Yes _ No Recip Csg X Yes _ No 6_5 Ft. Min. 9.45 PPG Fluid Description: Spud Liner hanger Info (Make/Model): Liner hanger test pressure: Centralizer Placement: CEMENTING REPORT Liner top Packer?: -Yes -No Floats Held X Yes No Shoe@ 5355 FC@ 5,275.00 Casing (Or Liner) Detail Top of Liner Setting Depths its. Component Sae Wt. Grace THD Make Length Bottom Top 1 Shoe 95/8 TXP BTC DHS 1.60 5,355.00 5,353.40 2 Casing 95/8 40.0 L-80 TXP BTC Mixing / Pumping Rate (bpm): 76.63 5,353.40 5,276.77 1 Float Collar 95/8 w TXP BTC DHS 1.30 5,276.77 5,275.47 1 Casing 95/8 40.0 L-80 TXP BTC m r 39.40 5,275.47 5,236.07 1 Baffle Adapter 95/8 Type; Density (ppg) TXP BTC Halliburton 1.58 5,236.07 5,234.49 79 Casing 95/8 40.0 L-80 TXP BTC 9.45 Rate(bpm): 3,129.91 5,234.49 2,104.58 1 Pup 95/8 40.0 L-80 TXP BTC Yes -No 9.17 2,104.58 2,095.41 1 ESC 95/8 40.0 L-80 TXP BTC Cement In Place At: 5:15 2.85 2,095.41 2,092.56 I Pup 95/8 40.0 L -BO TXP BTC 27.77 2,092.56 2,064.79 65 Casing 95/8 40A L-80 T%P BTC 2,064.79 2,064.79 Surface Csg WL On Hook: 240 Type Float Collar: Battle Adapter no. Mrs m Mon: Csg Wt. On Slips: 150,1310 Type of Shoe: Conventional Casing Crew: Weatherford Rotate Csg X Yes _ No Recip Csg X Yes _ No 6_5 Ft. Min. 9.45 PPG Fluid Description: Spud Liner hanger Info (Make/Model): Liner hanger test pressure: Centralizer Placement: CEMENTING REPORT Liner top Packer?: -Yes -No Floats Held X Yes No Post lob Calculations: Calculated Cant Vol @ 0% excess 30 Total Volume cmt Pumped: 551.2 Cmt returned to surface: 18 Calculated cement left in wellbore: 321.62 OH volume Calculated: 321.62 OH volume actual: 369.92 Actual % Washout: 13 F- www.weliez.net WellEz Information Management LLC ver 04818br Shoe@ 5355 FC@ 5,275.00 Top of Liner PreOush (Spacer) Type: Tuned Spacer/ Red Dye/ Ppl E Flake Density (ppg) 10 Volume pumped (BBLs) 60 Lead Slurry Type: Extend E Cem Sacks: 392 Yield: 2.35 Density (ppg) 12 Volume pumped (BBLs) 132 Mixing / Pumping Rate (bpm): 4.3 Tail Slurry w Type: Swill Cem Sacks: 396 Yield: 1.16 Density (ppg) 15.8 Volume pumped (BBLs) 82 Mixing / Pumping Rate (bpm): 4.3 m r Post Flush (Spacer) rc Type; Density (ppg) Rate (bpm): Volume: a Displacement: Type: Spud Mud Density(ppg) 9.45 Rate(bpm): 6 Volume (actual /calculated): 399.95/397.1 FCP(psi): 650 Pump used for disp: MP#1 Bump Plug? X Yes _No Bump press 1150 Casing Rotated? X Yes _No Recipmwted? X Yes -No % Returns during job 100 Cement returns to surface? X Yes _No Spacerretums? X Yes _No Vol to Surf: 18 Cement In Place At: 5:15 Date: 8/30/2019 Estimaletl TOC: 1,769 Method Used To Determine TOC: Calc Stage Collar@ 2092 Type ES Cementer Closure OK Y PreBush (Spacer) Type: Tuned Spacer/ Red Dye/ Pot E Flake Density (ppg) 10 Volume pumped (BBLs) 57 Lead Slurry Type: Arctic Cem Sacks: 604 Yield: 2.94 Density (ppg) 10.7 Volume pumped (BBLs) 281 Mixing / Pumping Rate (bpm): 5 Tail Slurry Type: Swift Cem Sacks: 270 Yield: 5.08 m Density (ppg) 15.8 Volume pumped (BBLs) 56.2 Mixing / Pumping Rate (bpm): 5 0 z Post Flush (Spacer) 0. Type: Density (ppg) Rate (bpm): Volume: w a Displacement: Type: Spud Mud Density(ppg) 9.5 Rate(bpm): 6.5 Volume (actual /calculated): 139.8/158.7 FCP(psi): 510 Pump used for disp: MP#1 Bump Plug? X Yes _No Bump press 1500 Casing Rotated? X No Reciprocated? _Yes X No %R etums during job 100 _Yes Cement returns to surface? X Yes _ No Spacer returns? X Yes -No Vol to Surf: 160 Cement In Place At: 1600 Date: 8/30/2019 Estimated TOC: 0 Method Used To Determine TOC: ReNmed Post lob Calculations: Calculated Cant Vol @ 0% excess 30 Total Volume cmt Pumped: 551.2 Cmt returned to surface: 18 Calculated cement left in wellbore: 321.62 OH volume Calculated: 321.62 OH volume actual: 369.92 Actual % Washout: 13 F- www.weliez.net WellEz Information Management LLC ver 04818br MEMORANDUM TO: Jim Regg P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission ' eef"t i�(otlj DATE: FROM: Matt Herrera SUBJECT: Petroleum Inspector 8/31/2019 Diverter Vent Line Hilcorp Innovation MPU S-203 Hilcorp PTD 2191090 8/30/2019: 1 traveled to the Hilcorp Innovation rig drilling surface hole at MPU S-203 to inspect the diverter vent line. This was a follow-up to AOGCC approval to remove a section of diverter pipe to allow large truck/trailer access to the pipe shed side of the rig (there is only very limited access around backside of pad with pickup trucks)., AOGCC approval was conditioned as follows: - Keep the trucks a minimum of 75 feet away from the end of the diverter line at except when they must drive by the diverter line to access the pipe shed. Ensure there is always constant communication by radio from the rig floor to the men working on the diverter line during this operation. The full diverter vent line was intact during my visit with proper signage restricted access. All potential ignition sources were at least 75 feet from the vent line outlet. Attachments: Photos (3) 2019-083 0_Diverter_Hilcorp_Innovation_MPU_S-203 _mh. docx Page 1 of 3 Diverter Vent Line — Hilcorp Innovation (MPU 5-203) Photos by AOGCC Inspector M. Herrera (PT6 2-lg1Oqn) 8/30/2019 2019-0830_Diverter_Hilcorp_Innovation_MPU_5-203_mh. docx Page 2 of 3 2019-0830_Diverter_Hilcorp_Innovation_MPU_S-203_mh.docx Page 3 of 3 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Ugnu Undefined Pool, MPU S-203 Hilcorp Alaska, LLC Permit to Drill Number: 219-109 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Surface Location: 3228' FSL, 503' FEL, SEC. 12, TI 2N, RI OE, UM, AK Bottomhole Location: 1900' FSL, 609' FWL, SEC. 11, RI OE, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this _�y of August, 2019. a' a REE 0 0 4 �.5 E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MUG Q 1 2019 PERMIT TO DRILL 20 AA(' 25 nn5 a 1� 1 a. Type of Work: 11b. Proposed Well Class: Exploratory - Gas Service - WAG M Service - Disp ❑ 1 c. Specify if well is proposed for: Drill 9 Lateral ❑ Stratigraphic Test ❑ Development - Oil Q Service - Winj ❑ Single Zone ❑� Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory -Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 MPU S-203 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 13,669' TVD: 3,626' Milne Point Field Ugnu Undefined 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3228' FSL, 503' FEL, Sec 12, TI 2N, R10E, UM, AK ADL380109, ADL380110 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1901' FSL, 1295' FEL, Sec 12, T12N, R10E, UM, AK LONS 01-001 8/26/2019 Total Depth: 9. Acres in Property: nt wiq rrl 14. Distance to Nearest Property: 1900' FSL, 609' FWL, Sec 11, T12N, R10E, UM, AK 4997 =, 6 1900' to nearest unit boundary 41b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): r28'r 15. Distance to Nearest Well Open Surface: x-565507 y- 5999892 Zone -4 GL / BF Elevation above MSL (ft): 37.4 to Same Pool: 2170' MPU S-41 16. Deviated wells: Kickoff depth: 330 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94.75 degrees Downhole: 1680 Surface: 1297 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling I Length MD TVD MD TVD (including stage data) 42" 20" 215# X-42 Weld 80' Surface Surface 107' 107' ±270 ft3 Stg 1 L - 648 ft3 / T- 458 ft3 12-1/4" 9-5/8" 40# L-80 TXP SR 5,092' Surface Surface 5,092' 3,815' Stg 2 L - 1937 ft3 / T- 314 ft3 Tieback 7-5/8" 29.7# L-80 Hyd 521 4,942' Surface Surface 4,942' 3,802' Tieback Assy 8-1/2" 4-1/2" 13.5# L-80 Hyd 625 8,727' 4,942' 3,802' 13,669' 3,626' 150p Screens Liner w/ Swell Pkrs 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 21 20. Attachments: Property Plat O BOP Sketch Drilling Program Time v. Depth Plot v Shallow Hazard Analysis Diverter Sketch B Seabed Report e Drilling Fluid Program e 20 AAC 25.050 requirements B 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: 'en el hfloor .COm Authorized Title: Drilling Manager Contact Phone: 777-8395 Authorized Signature: �' _ _ Q Date: p I + Commission Use Only Permit to Drill Number: Permit Approval Q See cover letter for other Number: 150-02.11— Data. 1 1101 requirements. Conditions of approval q: 1Ifbox is checked, well may not be used to explore for, test, or produce coalbed m thane, as hydrates, or gas contained in shales: O 30noE E 1 EST 1 s t Other: 1�„\,,,tC� k,{1�\ �Op-` Samples mq'd: Yes ❑ Noff Mud log req'd: Yes El poF/ 1 w U lJrO 2 SC7� S \ J 7AIV 0.Y' P H2S measures: Yes ElNo L7 Directional svy req'd: Yes No ❑ [3 Spacing exception req'd: Yes ❑ Nol9' Inclination -only svy req'd: Yes ❑ No p' Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BYLit Date: J Approved COMMISSIONER THE COMMISSION ' Submit Form and Form 10-401 Revised ,o13j,-/� This perm[t is valid r005(g)Attachments in Duplicate nn4R7AbIGIfG..�'J`tZY7N i�iCDB S/l9l ��V//�lL_V aa„ !ll�� /_lY Hilcorp Alaska, LLC Milne Point Unit (MPU) S-203 Drilling Program Version 1 7/29/2019 Table of Contents 1.0 2.0 3.0 4.0 5.0 6.0 7.0 8.0 9.0 10.0 11.0 WellSummary.................................................................................................................................2 Management of Change Information............................................................................................3 TubularProgram: ........................................................................................................................... 4 DrillPipe Information: ................................................................................................................... 4 Internal Reporting Requirements..................................................................................................5 PlannedWellbore Schematic..........................................................................................................6 Drilling / Completion Summary.....................................................................................................7 Mandatory Regulatory Compliance /Notifications .....................................................................8 R/U and Preparatory Work NX 13-5/8115M Diverter Configuration Drill 12-1/4" Hole Section 10 11 13 12.0 Run 9-5/8" Surface Casing...........................................................................................................16 13.0 Cement 9-5/8" Surface Casing.....................................................................................................21 14.0 BOP NIU and Test.........................................................................................................................26 15.0 Drill 8-1/2" Hole Section...............................................................................................................27 16.0 Run 4-1/2" Production Screen Liner...........................................................................................32 17.0 Run 7-5/8" Tieback.......................................................................................................................37 18.0 Run Jet Pump Assembly...............................................................................................................40 19.0 RDMO............................................................................................................................................41 20.0 Innovation Rig Diverter Schematic.............................................................................................42 21.0 Innovation Rig BOP Schematic...................................................................................................43 22.0 Wellhead Schematic......................................................................................................................44 23.0 Days Vs Depth...............................................................................................................................45 24.0 Formation Tops & Information...................................................................................................46 25.0 Anticipated Drilling Hazards.......................................................................................................47 26.0 Innovation Rig Layout..................................................................................................................50 27.0 FIT Procedure...............................................................................................................................51 28.0 Innovation Rig Choke Manifold Schematic................................................................................52 29.0 Casing Design................................................................................................................................53 30.0 8-1/2" Hole Section MASP............................................................................................................54 31.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................55 32.0 Surface Plat (As Built) (NAD 27).................................................................................................56 1.0 Well Summary Milne Point Unit S-203 Ugnu Producer Drilling Procedure Well MPU S-203 Pad Milne Point "S" Pad Planned Completion Type Jet Pump on 3-1/2" Production Tubing Target Reservoir(s) U nu MB Planned Well TD, MD / TVD 13,668' MD / 3,815' TVD PBTD, MD / TVD 13,658' MD / 3,815' TVD Surface Location (Governmental) 2052' FNL, 503' FEL, Sec 12, T12N, R10E, UM, AK Surface Location (NAD 27) X= 565,507.93, Y= 5,999,892.45 Top of Productive Horizon (Governmental) 1901' FSL, 1295' FEL, Sec 12, T12N, R10E, UM, AK TPH Location (NAD 27) X= 564,727.68, Y= 5,998,558.35 BHL (Governmental) 1900' FSL, 609' FWL, Sec 11, T12N, R10E, UM, AK BHL AD 27) X= 556,073.73, Y=5,998,487.94 AFE Number 1914120 AFE Drilling Days 19 days AFE Completion Das 4 days AFE Drilling Amount $4,115,581 AFE Completion Amount $2,410,812 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1297 psig Maximum Anticipated Pressure Downhole/Reservoir) 1680 psig Work String 5" 19.5# S-135 DS -50 & NC 50 KB Elevation above MSL: 26.5 ft + 37.4 ft = 63.9 ft GL Elevation above MSL: 37.4 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 Milne Point Unit 5-203 Ugnu Producer ff Drilling Procedure �, 2.0 Management of Change Information 11 Hilcorp Alaska, LLC Iijlcorp r rcigy C orp Changes to Approved Permit to Drill Date: 8112019 Subject: Changes to Approved Permit to Drill for MPU S-203 File #: MPU S-203 Drilling and Completion Program Any modifications to MPU S-203 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be approved in advance to the AOGCC. Approval: Drilling Manager Date Prepared: Drilling Engineer Page 3 Milne Point Unit S-203 Ugnu Producer HilcoI Drilling Procedure E'o Czx 3.0 Tubular Program: Hole Section OD (in) ID in Drift in Conn OD in(#/ft) Wt Grade Conn Burst Collapse (psi) Tension (k -lbs) Cond 20" 19.25" - - - X-52 Weld 19.5 5-135 DS50 36,100 43,1007560k1b 7NC50 Production 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 Tieback 7-5/8" 6.875" 6.75" 7.947 29.7 L-80 Hydril521 6,890 4,790 683 8-1/2" 4-1/2 Screens 3.920 3.795 4.714 13.5 L-80 Hydril625 9020 8540 279 4.0 Drill Pipe Information: All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 OD ID (` ., etion in in in #/ft Surface & 5" 4.276" 3.25" 6.625" 19.5 5-135 DS50 36,100 43,1007560k1b 7NC50 Production __5'_'_t_4,2_76- 3.25" 6.625" 19.5 5-135 31,032 34,136 All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 n Hilcorp ��ar c�p.oy 5.0 Internal Reporting Requirements Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 5.1 Fill out daily drilling report and cost report on Wel1Ez. • 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 pmazzolinigbilcorp.com, mmyerskhilcorp, jengel .hilcorp.com and edinger@hilcoip.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 mmyersin, hilcoM,com 'enpel@hilcorp.com and cdinger@hiIcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mmyers@hilcorp.com iengel@hilcorp.com and cdineer(&hilcoW.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 jengel@hilcorp.com Completion Engineer Taylor Wellman 907.777.8449 907.907.9533 twellman@hilcorp.com Geologist Seth Nolan 907.777.8308 907.519.8225 snolan 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 Beming@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 cdinger@hilcorp.com Page 5 6.0 Planned Wellbore Schematic Proposed SCHEMATIC TD=1ssm' MDI fro=S,EXr'jT'C{ P9m=13,4A' Mq /Psm=S,®T 1T1ai Page 6 TREE & WELLHEAD nee enmeran ave• shy 71-117QrMCGenV Milne Point Unit S-203 Ugnu Producer Drilling Procedure fvlllne P: ti ii �': v en:NIP I_.20• Last C: PTD. T_. OPEN HOLE / CEMENT DETAIL Cund.cW' .2ick3 WVGrKkIC Sib I - Lead 151"Qbw10e C=I Tail -3954a ft Com i 12114' S:b 2 -lend- 324 hr. f6RiJTai1-16,0a,,G BPF 190pNyeum edT trL �reen inerin B-12'M1Ge k CASING DETAIL Sale Type WVGrKkIC ID TOP IM BPF 2tl' Wndu 4jAJIi-52/Wdd WA Sudace wr WA 9519' Sudse 401 L -MI TM5R 9935 Sudace Sp9Y 1)07W7W Tleead 29.JJL90JU Ml 691: Sudace 494Y1:10459 4 Ifr I Gen. 150 Sr".' J)3jL-W/Hvd.1tE2S 1 3920 1 4942 131969' .0149 TOBRIG OCTAL 3.412" 1 7.bin 9.3JLdOJ000-9b 1 2.992 1 Suduce 1 c49E. tlO=eJ WELL INCLINATION DETAIL sOP 33D Mux Dot0.nyle=9475 4-1/2" SOLID LINER DETAIL TOP (MO) I TOP IND! 9L0 (MO) I _ I (TVD) T6 4-1/2" Screens LINER DETAIL �n TOP (MO) I TOP ITVD) IMDI Btm rrvDJ Teo GENERAL WELLINFO API: TAO Com letimiQ e: rutum 7.0 Drilling / Completion Summary MPU S-203 is a grassroots iet pump producer planned to be drilled in the Ugnu MB sand. S-203 is part of an five well program targeting the Ugnu sand on S -Pad. The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Ugnu MB sand. An 8.5" lateral section will then be drilled. A 4-1/2" 150µ screen liner will be run in the open hole section and the well produced with an jet pump assembly. J The Innovation Rig will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately August 17, 2019, pending rig schedule. Surface casing will be run to 5,092' MD / 3,815' 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" screen production liner. 6. Run 7-5/8" tieback. 7. Run production tubing. 8. N/D BOP, N/U Tree, RDMO. Reservoir Evaluation Plan: Surface hole: Mud Logging. On Site geologist. LWD: GR+ Res Production Hole: Mud Logging & Sample Catching. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 Milne Point Unit 5-203 Ugnu Producer Hilcorp Ennyy Campmy Drilling Procedure 7.0 Drilling / Completion Summary MPU S-203 is a grassroots iet pump producer planned to be drilled in the Ugnu MB sand. S-203 is part of an five well program targeting the Ugnu sand on S -Pad. The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Ugnu MB sand. An 8.5" lateral section will then be drilled. A 4-1/2" 150µ screen liner will be run in the open hole section and the well produced with an jet pump assembly. J The Innovation Rig will be used to drill and complete the wellbore. Drilling operations are expected to commence approximately August 17, 2019, pending rig schedule. Surface casing will be run to 5,092' MD / 3,815' 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" screen production liner. 6. Run 7-5/8" tieback. 7. Run production tubing. 8. N/D BOP, N/U Tree, RDMO. Reservoir Evaluation Plan: Surface hole: Mud Logging. On Site geologist. LWD: GR+ Res Production Hole: Mud Logging & Sample Catching. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 Milne Point Unit 5-203 Ugnu Producer Horp Drilling Procedure e .� comv�r 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 S-203. Ensure to provide AOGCC 24 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". o Ensure the diverter vent line is at least 75' away from potential ignition sources • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: None requested Page 8 n Hilcorp Fungy Company Summary of BOP Equipment and Test Requirements Milne Point Unit S-203 Ugnu Producer 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 • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/3000 o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" • 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-I/8" x 5M Kill line 250/3000 • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Required AOGCC Notifications: • Well control event (BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPS. • 24 hours notice prior to casing running & cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: jim.regggalaska.eov 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@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: hiip://doa.alaska.gov/ogc/forms/TestWitnessNotifhtmi Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 H Hilcorp Eue�gy Company 9.0 R/U and Preparatory Work Milne Point Unit S-203 Ugnu Producer Drilling Procedure 9.1 S-203 will utilize a newly set 20" conductor on S Pad. 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 be used on in the production lateral only. 9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<800F). 9.10 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 Grapy Compmy 10.0 N/U 13-5/8" 5M Diverter Configuration Milne Point Unit S-203 Ugnu Producer 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. Page 11 Milne Point Unit S-203 Ugnu Producer Ho Drilling Procedure 10.4 Rig & Diverter Orientation: 75' Radius Clear of Ignition Sources — Diverter Line MPU S Pad Page 12 t� I ` 43 14S1 37 ■ ' 35 N 34 N 33 ■ 32 t 001 I *Drawing Not To Scate 11.0 Drill 12-1/4" Hole Section Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 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# 5-135. • 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 Ugnu MB 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. Keep DLS < 6 deg / 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. • Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. • Gas hydrates may be present on S -Pad. S -15i encountered hydrates in 2002, no other well have seen hydrates. If seen, they are typically around 2100-2400' TVD (oust below permafrost). Be prepared for hydrates: Page 13 I/ H Hilcorp eo�By c�veny Milne Point Unit S-203 Ugnu Producer Drilling Procedure • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD • Monitor returns for hydrates, checking pressurized & non -pressurized scales • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. • Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. 11.5 12-1/4" hole mud program summary • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg, Depth Interval MW ( ) Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.2+ (Higher MW for hydrates if seen/needed) MW can be cut once —500' below hydrate zone • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with the cementers to see what YP value they have targeted). Page 14 H Hilcorp E -W CamP+^Y System Type: 8.8 - 9.8 ppg Pre -Hydrated Aquagel/freshwater spud mud Properties: Milne Point Unit S-203 Ugnu Producer Drilling Procedure Section Density Viscosity Plastic Viscosity Yield Point AN FL pH Tem Surface 8.8-9.8 75-175 20-40 25-45 <10 8.5-9.0 if required for <I0 FL 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 <I0 FL ALDACIDE G 0.1 ppb 11.6 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 11.7 RIH t/ bottom, proceed to BROOH t/ HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5 - 10 ft / minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.8 TOOH and LD BHA 11.9 No open hole logging program planned. Page 15 H Hilcorp ez�y comp.ay 12.0 12.1 Run 9-5/8" Surface Casing 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. Milne Point Unit S-203 Ugnu Producer Drilling Procedure • 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" TXP, 2 Centralizers 10' from each end w/ stop rings 1 joint — 9-5/8" TXP, 1 Centralizer mid joint w/ stop ring 9-5/8" Float Collar w/ Stage Cementer Bypass Baffle 'Top Hat' 1 joint — 9-5/8" TXP, 1 Centralizer mid joint with stop ring 9-5/8" HES Baffle Adaptor • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 16 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No, Closing Sleeve No. Shear Pins Opening Sleeve No. Shear Pins ES Cementer Depth AFTBaffle Adapter (if used) ID Depth Bypass or Shul-o8 Baffle to Depth Float Collar Depth Float Shoe Depth Hole TD "Reference Casing Sales Manual Section 5 Page 17 «A Overall Length B Mas. 1➢ Altar ➢nlbul C Maa. Tool OD D Open" Seat ID E Closing Seat ID Plug Set Part No. Opening Plug Oc OD Shut -oft Plug OD Bypass Plug (if used) OD Milne Point Unit S-203 Ugnu Producer Drilling Procedure RBcarp ENI Running Order ENI Cementer A slsu[ OR Phq Baffle lbapter, V By-0us Plug a.1�. By Pass Baffle Float Collar Float stroe H Hilcorp M-� Milne Point Unit S-203 Ugnu Producer Drilling Procedure 12.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: • 1 centralizer every Joint t/ -- 1000' MD from shoe • 1 centralizer every 2 joints to -2,000' above shoe (Top of Ugnu) • Verify depth of lowest UQnu 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). • Install centralizers over couplings on 5 joints below and 10 joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. 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 Page 18 H Hilcorp � O-2 TXPV BTC Milne Point Unit S-203 Ugnu Producer Drilling Procedure Outside Diameter 9.625 in. Min. Wall 87,5% Con ,, OD Make-up Loss Thickness Couplmg Length Threads per ir. (�) Grade L80 Ccnnecdon ID Ccnnedien OD Option 8823 in. REGULAR Type 1 Well Thickness D395 in. Oonne,,ion OD REGULAR COUPLING - Option Eody. Red Grade LBOType 1- Drift API Standard 1st Earl -Broom 2" Barxl: - Type Casing 3rdBard - PIPE BODY DATA GEOMETRY Piominal OD 8625 in. Nominal Weight 40 hos+E Onit ticminal ID 8.935 in. 64'aPThioness 0395 in. Plein End I-WgM OD Testa'. API Page 19 ---1110872018 saw PIPE BODY 1st8alyd Red 2re Bard: Brown 3rd Band: - 4th Band: - 9,679 ie 3897111stt PERFORMANCE Sod, Yet stteegth 916.1000 Ms Freers l Yr 5750 pial st1Ys 80050 pial Course 3090 psi GEOMETRY Con ,, OD Make-up Loss 10.625 in. 4.891 in. Couplmg Length Threads per ir. 10825 or 5 Ccnnecdon ID Ccnnedien OD Option 8823 in. REGULAR PERFORMANCE TaPsion £8kienoy 100.0: smt Yed 4rength 916 000 x1000 Interval Pressure Capacity I'1 5750000 psi Ihs C.presion Effniency 100% Comprime' n svecgN 916.000 x1000 Mai. Albwable Bending 3B 2100 E lbs Emiral prassure Capacity 3060.000 ps, MAKE-UPTORQUES M:r,.anum 18860&bs Optimum 20960 Edbs Mailmum 23460E -lips OPERATION LIMIT TORQUES Openrs Tgae 35600E-bs Yield Torque 43400 Noe Notes This connection is fully interchangeable with: TXP& BTC - 9.625 in - 36143.5147153.5158.4 Ibslft [1) Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C3 I 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 Tenarts technical sales representative. n Hilcorp �C-Pay Milne Point Unit 5-203 Ugnu Producer 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 I 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 Milne Point Unit S-203 Ugnu Producer Drilling Procedure 13.1 Hold a pre -job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the 151 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 151 Stage Total Cement Volume: Page 21 I Section Calculation Vol (bbl) Vol (ft3) � 12-1/4" OH x 9-5/8" (4,092'- 2500') x .0558 bpf x 1.3 = 115.5 648.4 J Casing Total Lead 115.5 648.4 12-1/4" OH x 9-5/8" (5,092' - 4,092') 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 I Milne Point Unit S-203 Ugnu Producer Drilling Procedure Cement Slurry Design (V Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 4,972' x .0758 bpf= 376.8 bbls 80 bbl of tuned spacer to be left behind sta eg tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, f4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 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 Page 22 Lead Slurry Tall Slurry System ExtendaCEM'° System SwiftCEM TM System Density 11.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed Water 21.13 gal/sk 5.04 gal/sk 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: 4,972' x .0758 bpf= 376.8 bbls 80 bbl of tuned spacer to be left behind sta eg tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, f4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 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 Page 22 H Hilo Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 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. 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 Milne Point Unit 5-203 Ugnu Producer Horp Drilling Procedure Eoegy Cmvpmy Second Stage Surface Cement Job: 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Hold pre -job safety meeting. 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) SwiftCEM .M System (Hal Cem) 20" Conductor x 9-5/8" Casing (110') x.26 bpf x 1= 28.6 161 J 12-1/4" OH x 9-5/8" Casing (2000'- 110') x.0558 bpf x 3 = 316.4 1776.3 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): Paee 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 Paee 24 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2500' x .0758 bpf = 190 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1000 — 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8" final joint. L/D cut joint. Make final cut on 9-5/8". Dress off stump. Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As -Run" casing tally & casing and cement report to iengel(a hilcorp.com and cdinger 2hilcorp. com This will be included with the EOW documentation that goes to the AOGCC. Page 25 Milne Point Unit 5-203 Ugnu Producer Hilco•y Energy Compmy Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: 2500' x .0758 bpf = 190 bbls mud 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. 13.29 Land closing plug on stage collar and pressure up to 1000 — 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8" final joint. L/D cut joint. Make final cut on 9-5/8". Dress off stump. Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As -Run" casing tally & casing and cement report to iengel(a hilcorp.com and cdinger 2hilcorp. com This will be included with the EOW documentation that goes to the AOGCC. Page 25 H Hilcorp �•� �vmr 14.0 14.1 14.2 Milne Point Unit S-203 Ugnu Producer Drilling Procedure BOP N/U and Test N/D the diverter T, 16" knife gate, 16" diverter line & N/U 11" x 13-5/8" 5M casing spool. N/U 13-5/8" x 5M CTI BOP as follows: • BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / 13- 5/8" x 5M mud cross / 13-5/8" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5.5" VBRs in top cavity, blind ram in bottom cavity. • Single ram should be dressed with 2-7/8" x 5.5" VBRs or 5" Solid Body Rams • N/U bell nipple, install flowline. • Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to mud cross). • Install (1) manual valve & HCR valve on choke side of mud cross. (manual valve closest to mud cross) 14.3 Run 5" BOP test plug (if not installed previously). • Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Confirm test pressures with PTD • Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug • Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 14.4 R/D BOP test equipment 14.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.6 Mix 8.9 ppg Baradrill-N fluid for production hole. 14.7 Set wearbushing in wellhead. 14.8 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 14.9 Ensure 5" liners in mud pumps. Page 26 n Hilco T coAN rp � 15.0 Drill 8-1/2" Hole Section 15.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.220 PDM) Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 15.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool or ESIPC. 15.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.4 R/U and test casing to 2500 psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC reg is 50% of burst = 6870 / 2 = —3500 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 15.5 Drill out shoe track and 20' of new formation. 15.6 CBU and condition mud for FIT. 15.7 Conduct FIT to 12 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. Cass +e, 1= tY�t4i�`AL'6ATA 15.8 POOH & LD Cleanout BHA, 6 GGA 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 5-203 Ugnu Producer 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 viscosifter concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter) for sufficient hole cleaning • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9 — 9.5 ppg Baradrill-N drilling fluid Properties: J Section j Density Plastic Viscosity Yield Point Total Solids MBT HPHT Production 1 8.9-9.5 15-25 20-25 <10% <7 <11.0 J( 0- 3- I•o PPy •.bevv Os+- Pmnupr (3L jSis- ✓D_ System Formulation: Baradrill-N Product Concentration Water 0.955 bbl KCL 1I 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 -GIDE 207 0.015 ppb Page 28 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid 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. • Limit maximum instantaneous ROP to < 250 fph. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. • Target ROP is as fast as we can clean the hole without having to backream connections • Schrader Bluff NB Concretions: Historically 4-6% of lateral • MPD will be used to monitor for abnormal pressure on connections 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 openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary Page 29 Milne Point Unit 5-203 Ugnu Producer Hilco Drilling Procedure 15.11 TIH with 8-1/2" directional assembly to bottom 15.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid 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. • Limit maximum instantaneous ROP to < 250 fph. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. • Target ROP is as fast as we can clean the hole without having to backream connections • Schrader Bluff NB Concretions: Historically 4-6% of lateral • MPD will be used to monitor for abnormal pressure on connections 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 openhole sidetrack is achieved. 15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary Page 29 n Hite C!AT. Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 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 Mix and pump 40 bbl 10 ppb SAPP pill. Lineup to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well 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. 15.18 Displace 1.5 OH + Liner volume with viscosified brine. Proposed brine blend (aiming for an 8 on the 6rpm reading) - KCl: 7.1bbp for 2% NaCl: 60.9ppg for 9.4ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42ppb Flo -Vis Plus: 1.25ppb Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if fiu•ther discussion needed prior to BROOH. 15.19 Perform production screen test (PST). Reduce flow rate and RPM as per PST Test Procedure. The mud has been properly conditioned when the mud will pass the production screen test (3 330m1 samples passing through the screen in the same amount of time which will indicate no plugging of the screen). Reference PST Test Procedure • Ugnu MB sand screen completion require passing PST with 150µ coupons • Circulate and condition fluid as much as needed to pass the production screen test 15.20 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (385 gpm min). • Rotate at maximum rpm that can be sustained. Limit pulling speed to 5 — 10 min/std (slip to slip time, not including connections). If backreaming operations are commenced, continue backreaming to the shoe 15.21 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while BROOH 15.22 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. Page 30 H Hilcorp F—W Compmy Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 15.23 Monitor well for flow. Increase fluid weight if necessary. If abnormal pressure has been seen, displace to higher MW (determined on closed connections) from surface shoe to surface. Wellbore breathing has been seen on MPU SB wells, may be possible for Ugnu. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise 15.24 POOH and LD BHA. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. 15.25 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 31 H Hilcorp Erorp Compevy 16.0 Run 4-1/2" Production Screen Liner Milne Point Unit S-203 Ugnu Producer Drilling Procedure 16.1. Well control preparedness: In the event of an influx of formation fluids while running the 4- 1/2" production screens, the following well control response procedure will be followed: • 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" screen. • 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. 16.2. Well control preparedness: In the event of an influx of formation fluids while running the 2- 3/8" inner string inside the 4-1/2" production screens: • P/U & M/U the 5" safety joint (with 4-1/2" x 2-3/8" triple connect crossover installed on bottom, TIW valve in open position on top, 2-3/8" handling joint above TIW). NIX 2-3/8'' and then 4-1/2" to triple connect. • This joint shall be fully M/U with crossovers prior to running the first joint of wash pipe. • 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. 16.3. R/U 4-1/2" screen running equipment. • Ensure 4-1/2" x DS -50 crossover is on rig floor and M/U to FOSV. • Ensure all casing 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. 16.4. Run 4-1/2" screen production liner — Reference screen handling and running procedure. • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. Thread compound will plug the screens. • Use Hydril 625 stabbing guide on screen joints • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Run packoff and float shoe on bottom. • 4-1/2" Screens should auto —fill, top off with completion brine if needed • Swell packers will not be required on this completion unless the well is drilled out of zone Page 32 Milne Point Unit S-203 Ugnu Producer Hilcorp Drilling Procedure Hilm 4-%2" Lower Completion Running Order • 4-'/2" Float Shoe, BTC box (Bakerlok all 4-%z" shoe track connections below the last semi- premium/premium connection) • 4-%2" WIV (wellbore isolation valve), BTC box x pin • 4-%2" spacer joint, —30 - 40', IBT-M box x BTC pin • 4-'/2" Drillable Pac Off Sub, IBT-M box x pin • 5' 4.5" 13.59 Hydril 625 Box X 4.5" 12.6# IBT Pin crossover • 1 joint 4-%2" 13.5#/ft L-80 Hydril 625 Liner (optional) • 4-'/2" 13.5#/ft L-80 Hydril 625 Screens • Joints of 4-'/2" 13.5#/ft Hydril 625 L-80 Liner (liner lap) as needed • 4'4.5" 13.5# Hydril 625 Box X Pin pup joint (safety joint) • 7" 26# HYD 563 Box x 4.5" 13.5# Hydril 625 Pin crossover • Baker SLZXP Liner Hanger/Liner Top Packer w/ 7" 26# Hydril 563 pin 1 rp12 a"7 _Rn Uv,.]Al 62G Tnrnne OD Minimum Maximum O eratin Tor ue 4.5" 8,000 ft -lbs 12,800 ft -lbs 12,800 ft -lbs Page 33 Hilcorp a =re Covenr Milne Point Unit 5-203 Ugnu Producer Drilling Procedure Wall 87.5% Wedge 6250 1013112017 Outside DiameterMin. 4.500 in. Wall 87.5% GEOMETRY Thickness I9 Grade LBO Nm mai 00 4.500 in. Npm rof Weight 13.50 krsft Type 1 3-795 in. Wall Thickness 0.290 in. Connection OD REGULAR COUPLING PIPE BODY ODTclerm. API Option PERFORMANCE Body Red 1st Band: Red Grade L80 Type V Drift API Standard tst Band. Brown 2nd Band: CNlapse 8540 psi fid Band: - Brown c,,r11 eTiciuDATA 3rd Band: - 3rd Band - GEOMETRY Type Casing 4th Bond :- -._ � b __SLY DAT:, GEOMETRY Nm mai 00 4.500 in. Npm rof Weight 13.50 krsft Drift 3-795 in. Nominal ID 3920m. VW Thitlm 01901n. PUm End Wight 13.051�.R ODTclerm. API PERFORMANCE Body Yeid St gde 357 x1000 tlbs awemal Yield 9020 Psi 9MY5 90000 Psi CNlapse 8540 psi c,,r11 eTiciuDATA GEOMETRY coneaction OD 4.714 in. Conneet. ID 3.849 in. Maknap Loss 4.830 in Threads Per in 3.59 Canneeton OD Opo REGULAR PERFORMANCE Tension EiSoienc 9t.0 % Joint YJ.m Strength 279.370 x1DW Interna! Pressure Capaeey 9020.000 psi lbs Cmnpression Elhaenry 50.5% Compressicr. amn2th 290.115x1000 Max. Allowable Bending 73.7-AODft lbs External Pressure Capacity 8540.000 psi MAKE-UP TORQUES Minimum 8000 a -lbs Op4mum 9000 ft-Ibs mmirnum 12800 bibs OPERATION LIMIT TORQUES Opraurg To . 12800RJhs Yield Tolpue 15000 ft4bs Page 34 Milne Point Unit 5-203 Ugnu Producer Drilling Procedure Note: Blank Pipe and Swell Packers may be ran if any out of zone excursion occur during lateral drilling 16.6. Pick up enough liner to provide for approximately 150' overlap inside 9-5/8" casing. • AOGCC regulations require a minimum 100' overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8" connection. 16.7. R/U false rotary and run 2-3/8" 6.4 # Inner String • Drift 2-3/8" inner string with minimum 1.5" drift (WIV closing ball 1.25") 16.8. Before picking up Baker SLZXP liner hanger / packer assembly, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.9. M/U liner hanger/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 PUW, SOW, ROT and torque. 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 screens and inner string will prevent the DP from auto filling. Fill DP with PST passed fluid 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. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 rpm 16.15. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.16. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.17. Rig up to pump down the work string with the rig pumps. 16.18. 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. Page 35 H Hilcorp EueW'Compvny Milne Point Unit S-203 Ugnu Producer Drilling Procedure 16.19. Continue pressuring up to 2700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the SLZXP to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up to 4500 psi to activate the hydraulic pusher tool to set the SLZXP packer. This will also release the HRDE running tool. 16.20. Bleed DP pressure to zero, Pick up to expose Rotating Dog Sub and set down 50k# without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k# again, 16.21. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.22. 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. 16.23. P/U above liner top packer and displace well to completion fluid. 16.24. 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. 16.25. Once liner is on bottom, swap to completion AFE Page 36 H Hilcorp GefgyCompavy 17.0 Run 7-5/8" Tieback Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 17.1 RIH with mule shoe on 5" DP to Liner Top and circulation Liner Top and SBE clean. POOH. 17.2 WU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie -back space out calculation. Install and test 7-5/8" (250/3000 psi) solid body casing rams. 17.2 R/U 7-5/8" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. Rig up computer torque monitoring service. String should stay full while running, r/u fill up line and check as appropriate. 17.3 P/U tieback seal assembly and set in rotary table. Ensure 7-5/8" seal assembly has x4A" holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7-5/8" annulus. 17.4 M/U first joint of 7-5/8" to seal assy. 17.5 Run 7-5/8" 29.7# H521 tieback to position seal assembly two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. Page 37 Milne Point Unit S-203 Ugnu Producer Drilling Procedure Wedge 5210 r....,., 11:�'br2013 OutsoOc Qlanlp-0tt 7�62S P1. Min. Wall 9735 GEOMETRY Thiobwss J'iGrrdo LM gow- Dtl0 s53m Npmmai ID GflTS m. wiil7n"n., Typo 1 Odin EOJ W'N : wzll Thlcaness 5.315n. Connection OD REGULAR PERFORMANCE owi. COUPLING MPEEZ01 flr]e \':cPo 5vena0i se] Sv`0.1D: onwrau'F,a10 fi890:c1 :rE 00000 Gsr aS." Nstl I::l D,nG Rc6 G+atic LWTYPo t Onit Apt Standard Tzt p;wt;L, grown 2nd 11x10. GEOMETRY 2nctl] rc • Orewe Trpa cosine iI j Cana _ro B. , ThtcaJr �l nl 3.18 CnnntUgn CO G,+,.+'. REGULAR 411, E"I'd. Page 38 GEOMETRY Vp[nkia:iG 7.6T3 m. Plaminal'Ha:OM 29.7151eo11 Dtl0 s53m Npmmai ID GflTS m. wiil7n"n., 0.175'n. Odin EOJ W'N : 09Ai IGs 11 _G Tc4eu'Cv APtl PERFORMANCE flr]e \':cPo 5vena0i se] Sv`0.1D: onwrau'F,a10 fi890:c1 :rE 00000 Gsr Cntg:cc 4790.1 iFa :EC iPJa; C,c.T GEOMETRY s. i[4J.p 0] co ?'9I7 { nn t 6830r. 114 fLu.: 3]001' ThtcaJr �l nl 3.18 CnnntUgn CO G,+,.+'. REGULAR PERFORMANCE l v. .qn Ellelpn!r 7r3':, lunl y0d 5lmlyin 413 e1 kJCma1 PR;:urc {aprr.[y 6s90.01ID0 lbs Gnm4lcvq� Ero::crrza 073'•. 307-Q5000Y M. Rlswabk P...9rq 34.5':105 h 1b, Eslcnml Prn.u.nc CdcN.dy 4790& D MAKE-UP TORQUES . ... 04C0h.M: CO.", 90900 t'U Maumnm 447015 f1 lbc OPERATION LIMIT TORQUES C" .. 39000 h -MI, VIM Tn . 53 9lbz Notes This Connection is fWly interchangeable with: Wedge 521 - 7.625 in. - 26.4133.7139 lbs/i? Connections with Ibpelc-as6 Technology are fully compatible Aith life same connection in its Standard version Page 38 17.6 M/U 7-5/8" to DP crossover. 17.7 M/U stand of DP to string, and M/U top drive. 17.8 Break circulation at 1 bpm and begin lowering string. 17.9 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 17.10 Continue lowering string and land out on no-go. Set down 5 — l0k lbs. Mark the pipe at this depth as "NO-GO DEPTH". 17.11 P/U string & remove unnecessary 7-5/8" joints. 17.12 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead. 17.13 Ensure circulation is possible through 7-5/8" string. 17.14 RU and circulation corrosion inhibited brine in the 9-5/8" x 7-5/8" annulus. 17.15 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7-5/8" x 9- 5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent casing collapse of 7-5/8", verify collapse pressure of 7-5/8" tie back. 17.16 Slack off and land hanger. 17.17 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 17.18 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min. 17.19 R/D casing running tools. 17.20 Test 7-5/8" x 9-5/8" production annulus to 1000 psi / 30 min. 17.3 Set test plug and change top rams from 7-5/8" to 2-7/8" x 5-1/2" VBR. Test annular and lower rams to 2-7/8" test joint, 250 low / 3000 psi high. Page 39 Milne Point Unit 5-203 Ugnu Producer Hiloo Drilling Procedure 17.6 M/U 7-5/8" to DP crossover. 17.7 M/U stand of DP to string, and M/U top drive. 17.8 Break circulation at 1 bpm and begin lowering string. 17.9 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 17.10 Continue lowering string and land out on no-go. Set down 5 — l0k lbs. Mark the pipe at this depth as "NO-GO DEPTH". 17.11 P/U string & remove unnecessary 7-5/8" joints. 17.12 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead. 17.13 Ensure circulation is possible through 7-5/8" string. 17.14 RU and circulation corrosion inhibited brine in the 9-5/8" x 7-5/8" annulus. 17.15 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7-5/8" x 9- 5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent casing collapse of 7-5/8", verify collapse pressure of 7-5/8" tie back. 17.16 Slack off and land hanger. 17.17 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 17.18 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min. 17.19 R/D casing running tools. 17.20 Test 7-5/8" x 9-5/8" production annulus to 1000 psi / 30 min. 17.3 Set test plug and change top rams from 7-5/8" to 2-7/8" x 5-1/2" VBR. Test annular and lower rams to 2-7/8" test joint, 250 low / 3000 psi high. Page 39 H Hilcorp E.'W Cwvpwy 18.0 18.1 18.2 Milne Point Unit S-203 Ugnu Producer Drilling Procedure Run Jet Pump Assembly Change upper pipe rams back to 2-7/8" x 5" VBR. Test same. Verify the Jet pump components. Run the 3-1/2" Jet Pump Completion (reverse circulating) as per the following: 3-1/2" Multi -drop Gauge Mandrel 5' pup joint 3-1/2" Sliding Sleeve 5' pup joint 4-1/2" Gauge Mandrel 4' pup joint 10' pup joint 3-1/2" X Nipple (ID=3.813") 10' pup joint 10'pupjoint 7-5/8110-1/2" Retrievable Packer 10' pup joint 10'pup joint 3-1/2" XN Nipple (ID=3.75") — set shallower than 70deg deviation. Preload RHC plug body. 10' pup joint 4-1/2" fulljoints (# joints to be determined by on deviation survey) 4-1/2" WLEG Confirm depths with OE post drilling and final directional survey (reference updated schematic). 18.3 M/U Jet Pump assembly and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 18.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 18.5 MU tubing hanger and landing joint. Terminate control lines. 18.6 Land tubing hanger. 18.7 Freeze protect well. 18.8 Drop ball and rod, pressure up to 1,700 psi to start setting of FHL packer. 18.9 Continue to pressure up to 3,000 psi to set packer. 18.10 Pressure up to 3,500 psi to test tubing for 30 minutes and chart. 18.11 Bleed tubing to 2,000 psi. 18.12 Pressure up annulus to 3,500 psi to test casing/packer for 30 minutes and chart. 18.13 Bleed tubing and IA down to 0 psi. 18.14 RILDS and test hanger. LD landing joint. 18.15 Install BPV. N/D BOP. Page 40 H HUilc molp Milne Point Unit S-203 Ugnu Producer Drilling Procedure 18.16 NIU tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 18.17 Set BPV plug. Test tree to 250 psi low / 5000 psi high. Pull BPV plug and BPV 18.18 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 18.19 Notify AOGCC of SVS testing. Test SVS on horizontal run of tree within 5 days of the start of production. Set low pressure trip below 275 psi Moose Pad header & separator pressure. 18.20 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 19.0 RDMO 19.1 RDMO Innovation Rig Page 41 H HilcoN 20.0 Innovation Rig Diverter Schematic 3.18' 13 Technol Page 42 Milne Point Unit S-203 Ugnu Producer Drilling Procedure ontrol Technology 3-5'B' 5M Control ethnology Double Ram -1?8' Choke Line X16' DNerter Line 0 Hilcorp �Tc�w 21.0 Innovation Rig BOP Schematic 63/f:➢17tf 9-518" DBL D Casing 13-5/8" NOM 9-5/8' BTC Btm x 10.5"-4 SA Pin Top Wl Primary Seal Page 43 0 [e Milne Point Unit S-203 Ugnu Producer Drilling Procedure x-13-518" 5M Control Technology Annular BOP 13-5/8" 5M Control Technology Double Ram _�-3-118" Choke Line ��-13-50 5M Control Technology Single Ram 518" x 5M 1"x 5M /16"x 5M 13-5/8" x 5M \— 2-1/16" x 5M 20" Casing -5/8" Casing ff HHCORU� 22.0 Wellhead Schematic d Page 44 Milne Point Unit S-203 Ugnu Producer Drilling Procedure I—' ] r r LI - 1 � I H Hilco2 E -a CnmpenY 23.0 Days Vs Depth 0 m Milne Point Unit S-203 Ugnu Producer Drilling Procedure MPU 5-203 Days vs Depth v Page 45 12000 14000 .It 01 0 5 10 15 20 25 Days 24.0 Formation Tops & Information MPU S-203 Formations (wp06) MD (ft) Milne Point Unit TVD (ft) Formation Pressure (psi) EMW (ppg) 5-203 Ugnu Producer 2029 Hil,m E.,no Company Drilling Procedure 24.0 Formation Tops & Information MPU S-203 Formations (wp06) MD (ft) TVDss (ft) TVD (ft) Formation Pressure (psi) EMW (ppg) Base Permafrost 2029 1813 1877 825.88 8.46 LA3 4175 3514 3578 1574.32 8.46 Ugnu MB 5108 3753 3817 1679.48 8.46 GENERALIZED GEOLOGICAL INFORMATION N° FORMATION LITH GEOL. DESCRIPTION COMMENTS ss ouw. o. o Predominantly heavy, pebbly gravel conglomerate from surface to 1800 ft. n Permafrost DIRECTIONAL PROBLEMS: HeGH DEGREE DOGLEGS AT t"? IN S -2n Ccan" Wye w2 S 34- S:detretked at 1,000' e ° e p . ° bridge at 2826 11 201 Ndl. 1]73' SV5 .•°.e. e-100' a °o Predominantly conglomerate gravel with increasing conce ITalions of GAS HYDRATES MAY BE clay down to 2500. PRESENT AT S -PAD. 1622' +I. food SV4a ° ° S -15i (2002) encountered hydrates in 1750 ° ° Base of Permafrost+!- 1750 ss- and below the permafrost Norte of p the other 2002 and 2003 S -Pad wells 0 drilled reported any shallow hydrate 2,000' 0 ° ° 2100' SV31T5 ° o ° SV3: Fine grained and well sorted sand, coarsening upward, deposited in SURFACE CASING AT 2500 WOSS IS +1.100' ° a shallow marine shelf environment Overlain by a 65 ft marine shale and REQUIRED ONALL NEW S PAD WELLS 2183' e1-100' SV2/Y4 NNING WRH&1-FRESS9 IN .2002oM BEG IUE silt shale bed which acts as a major confining layer isolates Y 1 g y'e TO POTENTIAL OVER -PRESSURE FROM Sag vanirktok injection into the lower Sagavanirtok sands, SV3 may contain gas IROECrORS. hydrates under S -Pad. SURFACE CASING RUNNING! SV2: Fine grained and well sorted marine sandstone, coarsening upward, CEMEN I ING PROBLEMS: 2600' Top SV17T3 with shale In lower section. SV2 may contain gas hydrates under S-Padybd>Aeinndnlz sot sucJ,. ca ea, N-100' 5h Nor, arc had to so casng on slips SVI: Shallow marine sandstone with shale in lower section SVi may S 34 hit bndEe.'i°,, -t", ane had tc contain aseas hydrates under S -Pad. do atop cerc�a cA Cr>xr mnc+!, a=r S9Oin<idmt SSO {set 3,000' fbeda Of Nude, CIay6 and e1NatOMe WID1 O[°ielerlal shows of oat shows of coal from 2300b3000. STUCK PIPE! 5-181, 58551J24AI 3384'- UG41K15 had to sidetrack around BKA 0sb. ''. 3456'A UGNU' CAUSE', LACK OF HOLE CLEANINGI'11 (A Gas Cut Mud a1 31001vd: B 13 Thick hydrocarbon column —200 to 300 ft thick in some S,30i and 20i fbnth odnuq. Areas. The Ugnu mcgon(interbedded fluvial sandstone and shale) C represents the initial progradation of theUgnu deltaic system over D i Ne underlying shallow marine er Fluvial nature determine top n baseluff can W dual TIGHTHOLE INMO03and S. of individual Bottomeiundinglt Bottom bounding surface of the entire Ugnu package is picked at the 5 urfaceoftentiangnupacfindividualedat 603 and ,a n M 79 CIRC LAT THOROUGHLY regional unconhumity M705 (see the M -sands below). 525 CIRCULATE ATEINCRDUGIIL'! C M'SanCIS: Fluvial. deltaic channel sandstones prograded over °Rk TUSEPG 360TTOR UP Ofthe MORE :iR MORE USE PWOlE[D's€DR Of ntlsmnesofthe $chrsder BluMa. The MONITGWWA HOLE CLEANING. shallow mnto J B threne ere subdivided into three units (Ma. M -Sands am M. 3670, from difficlnto comic Mc from tap to bottom) that can be difficult to their due to their fluvial nurture, The M70vale marks the A the DIFFE AL STICKING! A 4120' sand. lfi intervals are typically g up andbaspa ka es o coarsening Ding upward packages of S-fOA. 08 sand. Treated wiN sized CaG 0 sand tedim H thicknesses, SO'll varying ShiCknea6ee, rangloB from 5060'Itsth. All xonee ate Nighty 'a unconsolidated sandstones with porosities range in the 3030% and C B permeabilifies reaching upwards of 2000.5000 md. Each M ;and Idr,S nets as a hydra ebcnlly repeats reservoir hated on eneem G r under-Iana'ur. 38901. Page 46 n Hilcorp Erc�yy Compuy 25.0 Anticipated Drilling Hazards Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates Gas hydrates have been seen on E Pad. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized mud scale. The non - pressurized scale will reflect the actual mud cut weight. Add 1.0 — 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti -Collison: There are a number of wells in close proximity. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Discuss offset wellbores with production foreman and consider shutting in adjacent wells if necessary. Monitor drilling parameters for signs of collision with another well. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for 1-12S. No 112S events have been documented on drill wells on this pad. Page 47 H Hilcorp E -W Gmpmy Milne Point Unit 5-203 Ugnu Producer 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 48 n Hilcorp e .By como.oy Milne Point Unit 5-203 Ugnu Producer 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. 1. The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 112S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: Abnormal pressure has been seen on E -Pad. Utilize MPD to mitigate any abnormal pressure seen. Anti -Collision 5-22 is <1.0 clearance factor, it is an abandoned ugnu producer that has a fully cemented lateral. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Page 49 H Hilcorp F—W c®ver 26.0 Innovation Rig Layout Milne Point Unit S-203 Ugnu Producer Drilling Procedure Page 50 Milne Point Unit 5-203 Ugnu Producer Hilcorp Drilling Procedure .1. mom, 27.0 FIT Procedure Formation Intelzrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: 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. PIU 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 perfonned 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 51 28.0 Innovation Rig Choke Manifold Schematic Page 52 Milne Point Unit 5-203 Ugnu Producer Hilco� a.w � Drilling Procedure 28.0 Innovation Rig Choke Manifold Schematic Page 52 29.0 Casing Design Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 11 Calculation & Casing Design Factors Hilcorp DATE: 811/2019 WELL: MPU S-203 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: 1297 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1297 psi (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 53 Cas ng Section Calculation/S ecocation 1 2 3 4 Casing OD 9-5/8"- 4-1/2" Top (MD) 0 4,942 Top (!VD) 0 3,810 Bottom (MD) 5,092 13,668 Bottom (TVD) 3,815 3,626 Length 5,092 8,726 Weight (ppf) 40 13.5 Grade L-80 L-0 Connection TV H625 Weight w/o Bouyancy Factor (lbs) 203,660 117,801 Tension at Top of Section (lbs) 203,680 117,801 Min strength Tension (1000 lbs) 916 279 Worst Case Safety Factor (tension) 4.50 •• 2.37 ' Collapse Pressure at bottom (Psi) 1,885 1,791 Collapse Resistance w/o tension (Psi) 3,090 8,540 Worst Case Safety Factor (Collapse) 1.64 -- 4.77 - MASP (psi) 1,297 1,297 Minimum Yield (psi) 5,750 9,020 Worst case safety factor (Burst) 4.43 6.95 Page 53 H Hilcorp P np'Coi^P+^Y Milne Point Unit 5-203 Ugnu Producer Drilling Procedure 30.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 11 8-1/2" Hole Section Hilcorp MPU S-203 Milne Point Unit MD TVD Planned Top: 5092 3815 Planned TD: 13668 3626 4nticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Ugnu MB 3,815 ✓ 1679 Oil 8.46 0.440 Offset Well Mud Densities Well MW range Top (TVD) Bottom (TVD) Date MPU S-22 9.0-9.5 2412 3733 2003 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2" hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 3,815 (ft) x 0.78(psi/ft)= 2975 2975(psi) - [0.1(psi/ft)*3815(ft)]= 2594 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 3815 (ft) x 0.44(psi/ft)= 1678 psi 1678(psi) - 0.1(psi/ft)*3815(ft) 1297 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 54 Milne Point Unit 5-203 Ugnu Producer Hilcorp Drilling Procedure en.w cm 31.0 Spider Plot (NAD 27) (Governmental Sections) Page 55 Milne Point Unit MPS -203 Well wpO6 1.300 2.600 D Feet ADL028018 s•u Se- 33 `,♦ ADL026906 •'Sec 3a U013NO10E ++ s -•sal Sec. $6 { ` ` 's IN, ' Sec. 35 e._: � 1 , ill' i ♦ 539 � l i 1 1 `1 \\ ��. i. ♦•♦ wcee • t + Sec.6 See. -s 1 :::.- Sec'2ce, , \\6ec.1 ,-.aeu i3r T} �., xsl: s2ks'SJJ \\ ifiS55.li 1 •�S 11 1\♦ \\ Lib 1 11 .' .6JI IE POINT -U IT I \♦ \\ \\ ' hyl�ly _ �� , DL3801 0 ' - .ADL- X-0�4' •Pv 4.]]P11cB3 1 I`+ HC]p61 s'-3 s.'. I \IPs-LC. L'e1 aHL 110121,0'11 0E IMPS L{iCU= BHL] ••--__---_ ? U012N01;-+, RIPS LC,\C TPNN'1 1E pec.Jj '.• • scru KUPARUK RIVER UNIT +F v wrH _______________________-_ '----------------------------------------------------------- _-________�__---_-_____ _____ Legend • MPS-UGN03_S HL U t3 Sec. 18 Sa: Ii ( f5&3i ADL023636 MPS-UGNU #3_TPH AOL 5637 ADL047446 MPS-UGNU k3 BHL PRUDHOE SAY UNIT • Other Bottum i tB6Li ♦ - - - Other Well Paths ♦♦ Q Oil and Gas Unit 6ounda-y ♦ ,Pad Pca+ydn; . .. Sec. 22 ♦♦ Se:: 23 Se_ 24 SISB611n Page 55 Milne Point Unit MPS -203 Well wpO6 1.300 2.600 D Feet ff Hilcorp eoena �mP.er Milne Point Unit S-203 Ugnu Producer Drilling Procedure 32.0 Surface Plat (As Built) (NAD 27) Below is the as -staked location. Once the asbuilt is received it will be sent out. ■o 5-203 30 ■n Y PIVD 1590'00• � �ro 3 ^I • ift,,.� L J L _1 U I II ct =� I I 1 — — — — — — — — — — — — — — — i GRAPHIC SCALE 0 W In 320 IN FEET ) t lnN - 160 ll. E -PN) 3) 26 25 .N] C -PAD -PAD 35 36 I 31 n2N I I 2 I 1 6 1 5 I W THIS - Ii I 12 5 -PC i \ VICINITY MAP W.TS LEGEND AS-STAFam C0Np1Clm ■ EKISTMG CONWC 4E I. DAR W SAWr.. AIME P. 2015 2 ApQ4:NCE EEID BOdf: NV D -DI PG. 30-31 1 N]PIZMTK 01" R .WSKA PAT: "L WfIE .. ACV. A. MOWDC P09TONS ARE NA927. S PAO MEAN SC FAC10R R' 0AID90192 G XOPUWAL ANI) 1 V CAI. COWiNOE IS PASSU ON WP S Pb "ANXt YCNDM5115 S-E6s1. S -MD, AND S-1Esf. 7. EIEYATCWS ARE WUf PWI WEAN %A IEVEL I OCATFO WITHIN PROTRACTED SEC. 12. T. 12 N.. R. 10 E.. UMIAT MERIDIAN. AK. WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL SECTION N0. COORDINATES COORDINATES POSMON(DMS) POSInoN(D.DD) PAD ELEV. OFFSETS 5-203 Y=5.999,892.46 N=2,236.94 70'24'36.560" 70.4101556- 37.4' 3,228'FSL ,• _ 16y Xo 565,507.93' E= 6.370.01' 14927'59.729" 1149.4665975' S03'FEL Page 56 Hilcorp Alaska 6 , a Nil�., °i MPU S PAD 96t- AE2 AS -STAKED CONDUCTOR � � ,• _ 16y WELL 5-203 t a 1 Page 56 Hilcorp Alaska, LLC Milne Point M Pt S Pad Proposal Plan: MPU S-203 S-203 - UGNU#3 Plan: MPU S-203 wp06 Standard Proposal Report 25 July, 2019 HALLIBURTON Sperry Drilling Services HALLI B U RTO N SECTION DETAILS -- -- Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect aperrV Orill-, 1 26.50 0.00 0.00 26.50 0.00 0.00 0.00 0.00 0.00 2 330.00 0.00 0.00 330.00 0.00 0.00 0.00 0.00 0.00 3 1000,00 20.10 152.00 986.34 -102.71 54.61 3.00 152.00 -54.68 4 1480.48 36.61 130.33 1408.76 -269.90 204.01 4.00 -42.00 -204.19 5 2079.12 36.61 130.33 1689.27 -500.95 476.19 0.00 0.00 -476.54 6 4892.51 85.00 270.04 3798.13 -1327.42 -685.45 4.00 135.78 684.53 7 5042.51 85.00 270.04 3811.20 -1327.32 -834.88 0.00 0.00 833.96 8 5092.51 85.00 270.04 3815.56 -1327.28 -884.69 0.00 0.00 883.77 9 5314.08 91.65 270.04 3822.04 -1327.13 -1106.04 3.00 -0.03 1105.12 Project: Milne Point 10 6716.10 91.65 270.04 3781.74 -1326.25 -2507.48 0.00 0.00 2506.56 i 11 6783.20 93.66 270.04 3778.63 -1326.21 -2574.50 3.00 0.11 2573.58 Site: M Pt S Pad 12 6810.39 92.84 270.03 3777.09 -1326.19 -2601.66 3.00 -179.51 2600.73 Well: Plan: MPU S-203 13 7491.05 92.84 270.03 3743.31 -1325.80 -3281.48 0.00 0.00 3280.55 S-203 - UGNUl3 14 7554.58 94.75 270.04 3739.11 -1325.76 -3344.87 3.00 0.21 3343.94 Wellbore: 15 8304.58 94.75 270.04 3677.00 -1325.24 -4092.29 0.00 0.00 4091.36 Design: MPU S-203 wp06 16 8497,15 88.01 270.04 3672.36 -1325.11 4284.69 3.50 -179.98 4283.76 17 8719.81 88.01 270.04 3680.10 -1324.96 -4507.22 0.00 0.00 4506.29 18 8804.73 90.77 270.04 3681.00 -1324,90 -4592.12 3.25 0,05 4591.20 19 8850.63 92.15 269.99 3679.83 -1324.89 -4638.01 3.00 -1.95 4637.09 20 10522.94 92.15 269.99 3617.20 -1325.09 -6309.15 0.00 0.00 6308.22 Hilcorp Alaska, LLC 21 10727.82 86.00 270.00 3620.51 -1325.10 -6513.90 3,00 179.94 6512,97 22 10777.82 86.00 270,00 3624.00 -1325.10 -6563.78 0.00 0.00 6562.85 ;alculation Method: Minimum Curvature 23 10819.75 84.75 269,91 3627.38 -1325.13 -6605.57 3.00 -176.10 6604.64 Error System: ISCWSA 24 11799.44 84.75 269.91 3717.11 -1326.60 -7581.14 0.00 0.00 7580.21 Scan Method: Closest Approach 3D 25 11908.35 88.00 270.20 3724.00 -1326.49 -7689.82 3.00 5.02 7688.89 Error Surface: Pedal Curve 26 12138.25 92.60 270.36 3722.81 -1325.36 -7919.65 2,00 2.03 7918.73 Warning Method: Error Ratio 27 12582.98 92.60 270.36 3702.67 -1322.55 -8363.92 0.00 6.00 8362.99 26 12643.20 93.75 270.02 3699.34 -1322.35 -8424.04 2.00 -16.49 8423.12 29 13168.20 93.75 270.02 3665.00 -1322.16 -8947.92 0.00 8947.00 30 13192.74 94.49 270.04 3663.24 -1322.15 -8972.39 3.00 1.31 8971.47 31 13668.85 94.49 270.04 3626.00 -1321.85 -9447.04 0.00 0.00 9446.12 750 O 0 1500 300C H ASlart Dir3-1100':330'MD,330TVD StartDir 4°1100' : 1000' MD, 986.34T/D 500 End Dir : 1480.48' MD, 1408.76'TVD 000 - - ° Target Annotation SURVEY PROGRAM Start Dir 3°/100' : 330' MD, 330'TVD Date: 2019.O6-07TOD:OD:GO Validated: Yes Version: Start Dir 4-/100' : 1000' MD, 986.34'TVD Depth From Dept, To aumay/Plan Tool 26.50 1250.00 MPUS203,o06IS203-UGNUX3) 2_Gy NS C_Dnll pipe 1250.00 6092.51 MPUS203"W(S-203-UGNM) 2_MWD+IFR2+MS+Sag 626.00 Start Dir 3-/100': 6716.1' MD, 3781.74'TVD M *M + 750 O 0 1500 300C H ASlart Dir3-1100':330'MD,330TVD StartDir 4°1100' : 1000' MD, 986.34T/D 500 End Dir : 1480.48' MD, 1408.76'TVD 000 - - ° Target Annotation Start Dir 3°/100' : 330' MD, 330'TVD Start Dir 4-/100' : 1000' MD, 986.34'TVD TVD End Dir : 1480.48' MD, 1408.76' TVD MD Start Dir 4°/100' : 2079.12' MD, 1889.27'TVD Name End Dir : 4892.51' MD, 3798.13' TVD MPS -203 wp03 Heel 3751.66 5092.51 Start Dir 3-1100' : 5092.51' MD, 3815.56'TVD 9 5/8" x 12 1/4" End Dir : 5314.08' MD, 3822.04' TVD 626.00 Start Dir 3-/100': 6716.1' MD, 3781.74'TVD MPS -203 wpD4 CP1 6-518 6 5/8" x 8 112" End Dir : 6810.39' MD, 3777.09' TVD Start Dir 3-1100' : 7491.05' MD, 3743.31'TVD \ End Dir : 7554.58' MD, 3739.11' TVD MPS -203 wp04 CP2 Start Dir 3.5°/100' : 8304.58' MD, 3677'TVD End Dir : 8497.15' MD, 3672.36' TVD Start Dir 3.25.1100' : 8719.81' MD, 3680.1'TVD MPS -203 wp04 CP3 Start Dir 3°1100' : 8804.73' MD, 3681'TVD End Dir : 8850.63' MD, 3679.83' TVD Start Dir 3.1100' :10522.94' MD, 3617.2'TVD MPS-ZOJ xy05 Tce End Dir : 10727.82' MD, 3620.51' TVD MPS -203 wp04 CP4 Start Dir 3°1100' : 10777.82' MD, 3624'TVD MPS203 woos CP2 Endo!, 1D819.75' MD, 3627.38' TVD MPS205 wp03 Toe-axl Start Dir 3°/100' : 11799.44' MD, 3717.117VD MPS -203 wp04 CPS Start Dir 2-1100' : 11908.35' MD, 3724'TVD 3000 End Dir : 12138.25' MD, 3722.81' TVD 9000 9750 10500 11250 Start Dir 2e/100' : 12582.98' MD, 3702.67'TVD End Dir : 12643.2' MD, 3699.34' TVD MPS -203 wpO5 Toe Start Dir 3-/100': 13168.2' MD, 3666TVD Vertical Section at 270.04' (1500 usfUin) End Dir : 13192.74' MD, 3663.24' TVD MPS -205 wp03 Toe - ext Total Depth : 13668.85' MD, 3626' TVD REFERENCE INFORMATION CASING DETAILS Co-ordinate (NIE) Reference: Well Proposal Plan: MPU S-203, Tme North TVD TVDSS MD Size Name Vertical (TVD) Reference: MPU S-203 As -staked RKB @ 6:3 ft 815.56 3751.66 5092.51 9-5/8 9 5/8" x 12 1/4" Measured Depth Reference: MPU S-203 As -staked RKB @ 63.90usfl 626.00 3562.10 13668.85 6-518 6 5/8" x 8 112" Calculation Method: Minimum Curvature u, o \ 9518"z 121/4" FORMATION TOP DETAILS No formation data is available WELL DETAILS: Proposal Plan: MPU S-203 37.40 +N/ -S +E/ -W Northing Easting Latiflude Longitude 0.00 0.00 5999892,46 665507.93 70' 24'36.560 N 149° 27' 59.729 /1101 o�noa o^0 w�°��`°�� ^,�`,° poo o'°' `y°" ��w ��4O"o`4' -^o. F°' y`4 �° �°- o^ tea° boa yo ° F ^.� F°- IV `r° so r0 0 0 2500 ti ,p^• e°' �.°- �o" Fo- o,�^ y ,�A doe o� oyn7 ry0 0� �°' vio 4dI a m ^ o' o4, ` - 3000 Rig CO Q� , c0 Q O �� O a° 9 y9J 4'R i i d c� O O ' O SCD ^�' O 4ica Q , W , 5N mz y9 mz , O , >° 4, 9t, c5, 3r Cu�O ,' y r ' 4 h, , y �^, WS ,' 65/8'x81/2. 12000 h N ' o U , $\ MPU 5-203 wp06 u, o \ 9518"z 121/4" MPS-ZOJ xy05 Tce MPS -203 w,03 Heel MPS -203 Wg04 CP1 MPS203 woos CP2 MPS -203 WP04 CP3 MPS -203 wPD4 LPC MPS203 Wy04 CPS MPS205 wp03 Toe-axl -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 Vertical Section at 270.04' (1500 usfUin) 12000 WELL DETAILS: Proposal Plan: MPU S-203 Project: Milne PointNALLIBURTON 37.40 _ Site: M Pt S Pad +N/ -S 10-W Northing Easing Laitmde longitude Well: Proposal Plan: MPU S-2 1 Sperry Drilling O.OD. 0.00 5999892.46 565507.93 70°24'36.560N 149"2T 59.729W Wellbore: S-203-UGNU#3 Plan: MPU S-203 wp06 CASING DETAILS REFERENCE INFORMATION TVD TVDSS MD Size Namepo-ortlinata(NIE) Refereme: Well Proposal Plan: MPU S-203. True North 3815.56 3751.66 5092.51 9.5/6 9 51W x 12 1/4" Venioal (TVD) Reference: MPU 5203 As -slaked RKS @ 63.90usa 3000 3626.00 3562.10 13668.85 6-5/8 65/8'%81/2' Measured Depen Reference: MPU S2a3As-staked RKB@63.9QasD Calculation Maned: Minimum Curvatura 2000- 1000— San 0001000Stan Dir 3"/I00' : 330 MD, 330 -TVD Surt Dir4°/100' : IOOD' MD, 9R6.34TVD 3 p End Dir: 1480.48'MD, 1408J6'TVD C ` Stan Dir 4"/101201 1689.27'TVD MPS -205 wp(13 Toe -n + i MPS -203 wy04 CP MI'5-203 wP113 Hcc 1' p r MPS -203 wpO4 C MPS -203 wl>D4 CP MI'5.203 wp04 C 1 11 2500 y-1000 6 5B" x 8 12'` 4 MPS -2W wpf15 To r r MPS -203 wp(W C 9 518" x 12 1/4" �1 2210 £ MPU 5-203 wplM'—�s. x� , Jj. a ' $ •+gyp �a d. ov :3° r a. F -2000 0� t `Faa L'3° d': s Q'ON O,. 2� co'.,' 3� 1D.. i� Or f ` F. Jr . s� �6oa � `� dG. aa0 �. � -,P � `� F21 0 �'Oq, '13 • �'�3 W.22 �q2, 2�3e /�� DDS �: '�cJ J2J Oso 9oc N " 0,�3 4� " ° d4 . c9 °a 3iT �3 �Dl icg 20 ifs �.r. 83s4z. �O3 cJ�c °e' �Oc• ?'i, �a Jr, �. � az �d 3 DJ J' 'tid M d °o,. i �s, 0, s3 . J D. �. bs'2i '/id 203 cyD3 y8;y 3�3J 11' s� 20 3c3p 03c1 3cJD &8$ °a.& 'lid &3$ 9sB, syla yd 2yd3d .sem 4'�� O -3000 •3c cc3 mss? JL O3J `diT J9T � • 3c c$ `ri, �� 3T 3, iD c � a, O 21 JJ Jdi 41. Jc, $. Ld O o2 Gd � O 23 �Ld Ted Ld Ld 20 '��. \36 2/d 3130 R3j a9. 'J9 TL d,3 J� TLO � a�G BTL "3cB '2jd3 TGd'3cJ '�iT 933 �d PGd d eis O �O 11000 -10000 -9000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 3000 West( -)Bast(+) (1500 usf /in) HALLIBURTON Database: NORTH US + CANADA Company: Hiloorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Proposal Plan: MPU S-203 Wellbore: S-203-UGNU#3 Design: MPU S-203 wp06 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Proposal Plan: MPU S-203 TVD Reference: MPU S-203 As -staked RKB @ 63.90usft MD Reference: MPU S-203 As -staked RKB @ 63.90usft 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 S Pad PLAN Tie On Depth: 26.50 Site Position: +N/ -S Northing: From: Map (usft) Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Proposal Plan: MPU S-203 Well Position +NI -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 5,999,978.00usft Latitude: 566,345.00usft Longitude: 0" Grid Convergence: 5,999,892.46 usfl 565,507.93 usfl usfl S-203 - UGNU#3 Model Name Sample Date Declination (% BGGM2018 7/27/2019 16.58 MPU S-203 wp06 Latitude: Longitude: Ground Level: Dip Angle (1) 70' 24'37.329 N 149° 27'35.171 W n c. 70° 24'36.560 N 149'27'59.729 W 37.40 usft Field Strength (nT) 57,417.85702582 Phase: PLAN Tie On Depth: 26.50 Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 26.50 0.00 0.00 270.04 7/252019 1:24:14PM Page 2 COMPASS 5000.15 Build 91 Plan Sections Measured Halliburton H A LL I B U R TO N TVD Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Proposal Plan: MPU S-203 Company: Hilcorp Alaska, LLC TVD Reference: MPU S-203 As -staked RKB @ 63.90usft Project: Milne Point MD Reference: MPU S-203 As -staked RKB @ 63.90usft Site: M Pt S Pad North Reference: True Well: Proposal Plan: MPU S-203 Survey Calculation Method: Minimum Curvature Wellbore: S-203-UGNU#3 (°) (1) Design: MPU S-203 wp06 usft (usft) Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (°) (1) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 26.50 0.00 0.00 26.50 -37.40 0.00 0.00 0.00 0.00 0.00 0.00 330.00 0.00 0.00 330.00 266.10 .0+00 0.00 0.00 0.00 0.00 0.00 1,000.00 20.10 152.00 986.34 92244 -102.71 54.61 3.00 3.00 0.00 152.00 1,480.48 36.61 130.33 1,408.76 1,344.86 -269.90 204.01 4.00 3.44 -4.51 -42.00 2,079.12 36.61 130.33 1,889.27 1,825.37 -500.95 476.19 0.00 0.00 0.00 0.00 4,892.51 85.00 270.04 3,798.13 3,734.23 -1,327.42 -685.45 4.00 1.72 4.97 135.78 5,042.51 85.00 270.04 3,811.20 3,747.30 -1,327.32 -834.88 0.00 0.00 0.00 0.00 5,092.51 85.00 270.04 3,815.56 3,751.66 -1,327.28 -884.69 0.00 0.00 0.00 0.00 5,314.08 91.65 270.04 3,822.04 3,758.14 -1,327.13 -1,106.04 3.00 3.00 0.00 -0.03 6,716.10 91.65 270.04 3,781.74 3,717.84 -1,326.25 -2,507.48 0.00 0.00 0.00 0.00 6,783.20 93.66 270.04 3,778.63 3,714.73 -1,326.21 -2,574.50 3.00 3.00 0.01 0.11 6,810.39 92.84 270.03 3,777.09 3,713.19 -1,326.19 -2,601.66 3.00 -3.00 -0.03 -179.51 7,491.05 92.84 270.03 3,743.31 3,679.41 -1,325.80 -3,281.48 0.00 0.00 0.00 0.00 7,554.58 94.75 270.04 3,739.11 3,675.21 -1,325.76 -3,344.87 3.00 3.00 0.01 0.21 8,304.58 94.75 270.04 3,677.00 3,613.10 -1,325.24 -4,092.29 0.00 0.00 0.00 0.00 8,497.15 88.01 270.04 3,672.36 3,608.46 -1,325.11 -4,284.69 3.50 -3.50 0.00 -179.98 8,719.81 88.01 270.04 3,680.10 3,616.20 -1,324.96 -4,507.22 0.00 0.00 0.00 0.00 8,804.73 90.77 270.04 3,681.00 3,617.10 -1,324.90 -4,592.12 3.25 3.25 0.00 0.05 8,850.63 92.15 269.99 3,679.83 3,615.93 -1,324.89 -4,638.01 3.00 3.00 -0.10 -1.95 10,522.94 92.15 269.99 3,617.20 3,553.30 -1,325.09 -6,309.15 0.00 0.00 0.00 0.00 10,727.82 86.00 270.00 3,620.51 3,556.61 -1,325.10 -6,513.90 3.00 -3.00 0.00 179.94 10,777.82 86.00 270.00 3,624.00 3,560.10 -1,325.10 -6,563.78 0.00 0.00 0.00 0.00 10,819.75 84.75 269.91 3,627.38 3,563.48 -1,325.13 -6,605.57 3.00 -2.99 -0.20 -176.10 11,799.44 84.75 269.91 3,717.11 3,653.21 -1,326.60 -7,581.14 0.00 0.00 0.00 0.00 11,908.35 88.00 270.20 3,724.00 3,660.10 -1,326.49 -7,689.82 3.00 2.99 0.26 5.02 12,138.25 92.60 270.36 3,722.81 3,658.91 -1,325.36 -7,919.65 2.00 2.00 0.07 2.03 12,582.98 92.60 270.36 3,702.67 3,638.77 -1,322.55 -8,363.92 0.00 0.00 0.00 0.00 12,643.20 93.75 270.02 3,699.34 3,635.44 -1,322.35 -8,424.04 2.00 1.92 -0.57 -16.49 13,168.20 93.75 270.02 3,665.00 3,601.10 -1,322.16 -8,947.92 0.00 0.00 0.00 0.00 13,192.74 94.49 270.04 3,663.24 3,599.34 -1,322.15 -8,972.39 3.00 3.00 0.07 1.31 13,668.85 94.49 270.04 3,626.00 3,562.10 -1,321.85 -9,447.04 0.00 0.00 0.00 0.00 725/2019 1:24:14PM Page 3 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Proposal Plan: MPU S-203 Wellbore: S-203 - UGNU#3 Design: MPU S-203 wp06 Planned Survey Measured 2.10 152.00 Vertical 336.08 Depth Inclination Azimuth Depth TVDss (usft) V) (0) (usft) usft 26.50 0.00 0.00 26.50 -37.40 100.00 0.00 0.00 100.00 36.10 200.00 0.00 0.00 200.00 136.10 300.00 0.00 0.00 300.00 236.10 330.00 0.00 0.00 330.00 266.10 Start Dir 3°/100' : 330' MD, 330'TVD 400.00 2.10 152.00 399.98 336.08 500.00 5.10 152.00 499.78 435.88 600.00 8.10 152.00 599.10 535.20 700.00 11.10 152.00 697.69 633.79 800.00 14.10 152.00 795.27 731.37 900.00 17.10 152.00 891.58 827.68 1,000.00 20.10 152.00 986.34 922.44 Start Dir 401100': 1000' MD, 986.34'TVD 0.00 1,100.00 23.22 145.20 1,079.28 1,015.38 1,200.00 26.57 139.98 1,169.99 1,106.09 1,300.00 30.06 135.88 1,258.02 1,194.12 1,400.00 33.66 132.57 1,342.94 1,279.04 1,480.48 36.61 130.33 1,408.75 1,344.85 End Dir : 1480.48' MD, 1408.76' TVD -31.55 1,500.00 36.61 130.33 1,424.42 1,360.52 1,600.00 36.61 130.33 1,504.69 1,440.79 1,700.00 36.61 130.33 1,584.96 1,521.06 1,800.00 36.61 130.33 1,665.23 1,601.33 1,900.00 36.61 130.33 1,745.50 1,681.60 2,000.00 36.61 130.33 1,825.76 1,761.86 2,079.12 36.61 130.33 1,889.27 1,825.37 Start Dir 4°/100' : 2079.12' MD, 1889.27'TVD 2,100.00 36.02 131.32 1,906.10 1,842.20 2,200.00 33.30 136.47 1,988.36 1,924.46 2,300.00 30.82 142.40 2,073.13 2,009.23 2,400.00 28.65 149.18 2,159.99 2,096.09 2,500.00 26.87 156.88 2,248.50 2,184.60 2,600.00 25.55 165.44 2,338.26 2,274.36 2,700.00 24.77 174.68 2,428.80 2,364.90 2,800.00 24.59 184.26 2,519.70 2,455.80 2,900.00 25.01 193.75 2,610.52 2,546.62 3,000.00 26.01 202.75 2,700.80 2,636.90 3,100.00 27.53 210.98 2,790.11 2,726.21 3,200.00 29.47 218.31 2,878.01 2,814.11 3,300.00 31.77 224.74 2,964.08 2,900.18 3,400.00 34.36 230.34 3,047.90 2,984.00 3,500.00 37.16 235.22 3,129.05 3,065.15 3,600.00 40.15 239.49 3,207.15 3,143.25 3,700.00 43.27 243.26 3,281.81 3,217.91 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Proposal Plan: MPU S-203 MPU S-203 As -staked RKB @ 63.90usft MPU S-203 As -staked RKB @ 63.90usft True Minimum Curvature -509.03 485.55 Map Map 4.00 -485.91 +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) -37.40 -561.51 0.00 0.00 5,999,892.46 565,507.93 0.00 0.00 0.00 0.00 5,999,892.46 565,507.93 0.00 0.00 0.00 0.00 5,999,892.46 565,507.93 0.00 0.00 0.00 0.00 5,999,892.46 565,507.93 0.00 0.00 0.00 0.00 5,999,892.46 565,507.93 0.00 0.00 -1.13 0.60 5,999,891.33 565,508.54 3.00 -0.60 -6.68 3.55 5,999,885.82 565,511.54 3.00 -3.55 -16.82 8.95 5,999,875.72 565,517.02 3.00 -8.96 -31.55 16.77 5,999,861.07 565,524.98 3.00 -16.80 -50.80 27.01 5,999,841.90 565,535.39 3.00 -27.05 -74.55 39.64 5,999,818.27 565,548.22 3.00 -39.69 -102.71 54.61 5,999,790.25 565,563.43 3.00 -54.68 -134.08 73.93 5,999,759.05 565,583.03 4.00 -74.03 -167.41 99.58 5,999,725.95 565,608.96 4.00 -99.69 -202.53 131.41 5,999,691.11 565,641.09 4.00 -131.55 -239.27 169.27 5,999,654.71 565,679.28 4.00 -169.44 -269.90 204.00 5,999,624.39 565,714.27 4.00 -204.19 -277.43 212.88 5,999,616.93 565,723.21 0.00 -213.07 -316.03 258.35 5,999,578.74 565,769.02 0.00 -258.57 -354.62 303.82 5,999,540.55 565,814.82 0.00 -304.06 -393.22 349.28 5,999,502.36 565,860.62 0.00 -349.56 -431.82 394.75 5,999,464.16 565,906.42 0.00 -395.05 -470.41 440.22 5,999,425.97 565,952.22 0.00 -440.55 -500.95 476.19 5,999,395.75 565,988.45 0.00 -476.54 -509.03 485.55 5,999,387.75 565,997.88 4.00 -485.91 -548.36 526.55 5,999,348.79 566,039.22 4.00 -526.94 -588.57 561.10 5,999,308.88 566,074.12 4.00 -561.51 -629.47 589.02 5,999,268.24 566,102.40 4.00 -589.46 -670.85 610.19 5,999,227.05 566,123.92 4.00 -610.65 -712.52 624.49 5,999,185.51 566,138.58 4.00 -624.98 -754.27 631.85 5,999,143.83 566,146.32 4.00 -632.38 -795.90 632.25 5,999,102.21 566,147.08 4.00 -632.81 -837.20 625.68 5,999,060.86 566,140.87 4.00 -626.27 -877.98 612.17 5,999,019.97 566,127.72 4.00 -612.79 -918.03 591.79 5,998,979.74 566,107.69 4.00 -592.43 -957.16 564.64 5,998,940.38 566,080.89 4.00 -565.30 -995.19 530.84 5,998,902.06 566,047.43 4.00 -531.54 -1,031.91 490.57 5,998,864.99 566,007.48 4.00 -491.29 -1,067.16 444.02 5,998,829.33 565,961.25 4.00 -444.76 -1,100.77 391.41 5,998,795.27 565,908.94 4.00 -392.18 -1,132.57 333.01 5,998,762.96 565,850.83 4.00 -333.80 7252019 1:24:14PM Page 4 COMPASS 5000.15 Build 91 Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Proposal Plan: MPU S-203 Wellbore: S-203-UGNU#3 Design: MPU 8-203 wp06 Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Proposal Plan: MPU S-203 MPU 5-203 As -staked RKB @ 63.90usft MPU 5-203 As -staked RKB @ 63.90usft True Minimum Curvature Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (0) (1) (usft) usft (usft) (usft) (usft) (usft) 3,288.77 3,800.00 46.50 246.61 3,352.67 3,288.77 -1,162.40 269.09 5,998,732.58 565,787.18 4.00 -269.90 3,900.00 49.81 249.61 3,419.38 3,355.48 -1,190.12 199.98 5,998,704.25 565,718.32 4.00 -200.81 4,000.00 53.20 252.33 3,481.62 3,417.72 -1,215.60 125.99 5,998,678.13 565,644.57 4.00 -126.84 4,100.00 56.65 254.81 3,539.08 3,475.18 -1,238.70 47.51 5,998,654.34 565,566.30 4.00 -48.38 4,200.00 60.14 257.11 3,591.49 3,527.59 -1,259.33 -35.10 5,998,632.99 565,483.88 4.00 34.22 4,300.00 63.66 259.25 3,638.59 3,574.69 -1,277.37 -121.42 5,998,614.19 565,397.73 4.00 120.53 4,400.00 67.22 261.26 3,680.15 3,616.25 -1,292.75 -211.04 5,998,598.04 565,308.25 4.00 210.14 4,500.00 70.80 263.17 3,715.97 3,652.07 -1,305.37 -303.53 5,998,584.60 565,215.89 4.00 302.62 4,600.00 74.40 265.00 3,745.87 3,681.97 -1,315.19 -398.43 5,998,573.95 565,121.09 4.00 397.51 4,700.00 78.01 266.76 3,769.71 3,705.81 -1,322.16 -495.27 5,998,566.13 565,024.32 4.00 494.35 4,800.00 81.64 268.48 3,787.37 3,723.47 -1,326.24 -593.60 5,998,561.19 564,926.04 4.00 592.67 4,892.51 85.00 270.04 3,798.13 3,734.23 -1,327.42 -685.45 5,998,559.21 564,834.21 4.00 684.53 End Dir : 4892.51' MD, 3798.13' TVD 4,900.00 85.00 270.04 3,798.78 3,734.88 -1,327.41 -692.92 5,998,559.15 564,826.75 0.00 691.99 5,000.00 85.00 270.04 3,807.50 3,743.60 -1,327.34 -792.54 5,998,558.34 564,727.14 0.00 791.61 5,042.51 85.00 270.04 3,811.20 3,747.30 -1,327.32 -834.88 5,998,558.00 564,684.80 0.00 833.96 5,092.51 85.00 270.04 3,815.56 3,751.66 -1,327.28 -884.69 5,998,557.60 564,634.99 0.00 883.77 Start Dir 30/100' : 5092.51' MD, 3815.56'TVD - 9 5/8" x 12 1/4" 5,100.00 85.22 270.04 3,816.20 3,752.30 -1,327.28 -892.16 5,998,557.54 564,627.53 3.00 891.23 5,200.00 88.22 270.04 3,821.91 3,758.01 -1,327.21 -991.98 5,998,556.73 564,527.72 3.00 991.05 5,300.00 91.22 270.04 3,822.39 3,758.49 -1,327.14 -1,091.97 5,998,555.92 564,427.75 3.00 1,091.04 5,314.08 91.65 270.04 3,822.04 3,758.14 -1,327.13 -1,106.04 5,998,555.80 564,413.67 3.00 1,105.12 End Dir : 5314.08' MD, 3822.04' TVD 5,400.00 91.65 270.04 3,819.57 3,755.67 -1,327.08 -1,191.93 5,998,555.10 564,327.80 0.00 1,191.00 5,500.00 91.65 270.04 3,816.69 3,752.79 -1,327.02 -1,291.89 5,998,554.29 564,227.85 0.00 1,290.96 5,600.00 91.65 270.04 3,813.82 3,749.92 -1,326.95 -1,391.85 5,998,553.48 564,127.91 0.00 1,390.92 5,700.00 91.65 270.04 3,810.94 3,747.04 -1,326.89 -1,491.81 5,998,552.66 564,027.96 0.00 1,490.88 5,800.00 91.65 270.04 3,808.07 3,744.17 -1,326.83 -1,591.76 5,998,551.85 563,928.02 0.00 1,590.84 5,900.00 91.65 270.04 3,805.19 3,741.29 -1,326.77 -1,691.72 5,998,551.04 563,828.07 0.00 1,690.80 6,000.00 91.65 270.04 3,802.32 3,738.42 -1,326.70 -1,791.68 5,998,550.22 563,728.12 0.00 1,790.75 6,100.00 91.65 270.04 3,799.45 3,735.55 -1,326.64 -1,891.64 5,998,549.41 563,628.18 0.00 1,890.71 6,200.00 91.65 270.04 3,796.57 3,732.67 -1,326.58 -1,991.60 5,998,548.59 563,528.23 0.00 1,990.67 6,300.00 91.65 270.04 3,793.70 3,729.80 -1,326.51 -2,091.56 5,998,547.78 563,428.29 0.00 2,090.63 6,400.00 91.65 270.04 3,790.82 3,726.92 -1,326.45 -2,191.52 5,998,546.97 563,328.34 0.00 2,190.59 6,500.00 91.65 270.04 3,787.95 3,724.05 -1,326.39 -2,291.47 5,998,546.15 563,228.39 0.00 2,290.55 6,600.00 91.65 270.04 3,785.07 3,721.17 -1,326.33 -2,391.43 5,998,545.34 563,128.45 0.00 2,390.51 6,700.00 91.65 270.04 3,782.20 3,718.30 -1,326.26 -2,491.39 5,998,544.52 563,028.50 0.00 2,490.47 6,716.10 91.65 270.04 3,781.74 3,717.84 -1,326.25 -2,507.49 5,998,544.39 563,012.41 0.00 2,506.56 Start Dir 30/100': 6716.1' MD, 3781.74'TVD 6,783.20 93.66 270.04 3,778.63 3,714.73 -1,326.21 -2,574.50 5,998,543.85 562,945.40 3.00 2,573.58 6,800.00 93.16 270.04 3,777.63 3,713.73 -1,326.20 -2,591.28 5,998,543.71 562,928.63 3.00 2,590.35 6,810.39 92.84 270.03 3,777.09 3,713.19 A,326.19 -2,601.66 5,998,543.63 562,918.25 3.00 2,600.73 End Dir : 6810.39' MD, 3777.09' TVD 6,900.00 92.84 270.03 3,772.64 3,708.74 -1,326.14 -2,691.16 5,998,542.90 562,828.76 0.00 2,690.23 7,000.00 92.84 270.03 3,767.68 3,703.78 -1,326.08 -2,791.03 5,998,542.08 562,728.90 0.00 2,790.11 7252019 1:24.14PM Page 5 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US +CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Proposal Plan: MPU S-203 Wellbore: S-203 - UGNU#3 Design: MPU S-203 wp06 Planned Survey Measured Map Vertical Depth Inclination Azimuth Depth TVDss (usft) (^) (1) (usft) usft 7,100.00 92.84 270.03 3,762.72 3,698.82 7,200.00 92.84 270.03 3,757.75 3,693.85 7,300.00 92.84 270.03 3,752.79 3,688.89 7,400.00 92.84 270.03 3,747.83 3,683.93 7,491.05 92.84 270.03 3,743.31 3,679.41 Start Dir 301100': 7491.05' MD, 3743.317VD 7,500.00 93.11 270.03 3,742.85 3,678.95 7,554.58 94.75 270.04 3,739.11 3,675.21 End Dir : 7554.58' MD, 3739.11' TVD 5,998,537.54 7,600.00 94.75 270.04 3,735.35 3,671.45 7,700.00 94.75 270.04 3,727.06 3,663.16 7,800.00 94.75 270.04 3,718.78 3,654.88 7,900.00 94.75 270.04 3,710.50 3,646.60 8,000.00 94.75 270.04 3,702.22 3,638.32 8,100.00 94.75 270.04 3,693.94 3,630.04 8,200.00 94.75 270.04 3,685.66 3,621.76 8,304.58 94.75 270.04 3,677.00 3,613.10 Start Dir 3.50/100' : 8304.58' MD, 3677'TVD 561,532.02 8,400.00 91.41 270.04 3,671.87 33607.97 8,497.15 88.01 270.04 3,672.36 3,608.46 End Dir : 8497.15' MD, 3672.36' TVD 3.50 8,500.00 88.01 270.04 3,672.46 3,608.56 8,600.00 88.01 270.04 3,675.94 3,612.04 8,700.00 88.01 270.04 3,679.41 3,615.51 8,719.81 88.01 270.04 3,680.10 3,616.20 Start Dir 3.2501100': 8719.81' MD, 3680.1TVD 8,804.73 90.77 270.04 3,681.00 3,617.10 Start Dir 30/100' : 8804.73' MD, 3681'TVD 0.00 8,850.63 92.15 269.99 3,679.83 3,615.93 End Dir : 8850.63' MD, 3679.83' TVD 4,638.01 8,900.00 92.15 269.99 3,677.98 3,614.08 9,000.00 92.15 269.99 3,674.24 3,610.34 9,100.00 92.15 269.99 3,670.49 3,606.59 9,200.00 92.15 269.99 3,666.75 3,602.85 9,300.00 92.15 269.99 3,663.00 3,599.10 9,400.00 92.15 269.99 3,659.26 3,595.36 9,500.00 92.15 269.99 3,655.51 3,591.61 9,600.00 92.15 269.99 3,651.77 3,587.87 9,700.00 92.15 269.99 3,648.02 3,584.12 9,800.00 92.15 269.99 3,644.28 3,580.38 9,900.00 92.15 269.99 3,640.53 3,576.63 10,000.00 92.15 269.99 3,636.79 3,572.89 10,100.00 92.15 269.99 3,633.04 3,569.14 10,200.00 92.15 269.99 3,629.29 3,565.39 10,300.00 92.15 269.99 3,625.55 3,561.65 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Proposal Plan: MPU S-203 MPU S-203 As -staked RKB @ 63.90usft MPU S-203 As -staked RKB @ 63.90usft True Minimum Curvature 7252019 1:24:14PM Page 6 COMPASS 5000.15 Build 91 Map Map +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 3,698.82 -1,326.02 -2,890.91 5,998,541.26 562,629.04 0.00 2,889.98 -1,325.97 -2,990.79 5,998,540.44 562,529.17 0.00 2,989.86 -1,325.91 -3,090.66 5,998,539.62 562,429.31 0.00 3,089.74 -1,325.85 -3,190.54 5,998,538.80 562,329.44 0.00 3,189.61 -1,325.80 -3,281.48 5,998,538.06 562,238.52 0.00 3,280.55 -1,325.79 -3,290.41 5,998,537.99 562,229.58 3.00 3,289.49 -1,325.76 -3,344.86 5,998,537.54 562,175.14 3.00 3,343.94 -1,325.73 -3,390.13 5,998,537.18 562,129.88 0.00 3,389.20 -1,325.66 -3,489.79 5,998,536.37 562,030.24 0.00 3,488.86 -1,325.59 -3,589.44 5,998,535.57 561,930.59 0.00 3,588.52 -1,325.52 -3,689.10 5,998,534.76 561,830.95 0.00 3,688.17 -1,325.45 -3,788.75 5,998,533.96 561,731.31 0.00 3,787.83 -1,325.38 -3,888.41 5,998,533.16 561,631.66 0.00 3,887.49 -1,325.31 -3,988.07 5,998,532.35 561,532.02 0.00 3,987.14 -1,325.24 -4,092.29 5,998,531.51 561,427.81 0.00 4,091.36 -1,325.17 -4,187.56 5,998,530.74 561,332.55 3.50 4,186.63 -1,325.11 -4,284.69 5,998,529.95 561,235.43 3.50 4,283.77 -1,325.11 4,287.54 5,998,529.93 561,232.58 0.00 4,286.61 -1,325.04 4,387.48 5,998,529.12 561,132.66 0.00 4,386.55 -1,324.97 -4,487.42 5,998,528.31 561,032.73 0.00 4,486.49 -1,324.96 -4,507.22 5,998,528.15 561,012.93 0.00 4,506.29 -1,324.90 4,592.12 5,998,527.46 560,928.04 3.25 4,591.20 -1,324.89 4,638.01 5,998,527.07 560,882.16 3.00 4,637.08 -1,324.90 -4,687.34 5,998,526.63 560,832.83 0.00 4,686.42 -1,324.91 -4,787.27 5,998,525.74 560,732.92 0.00 4,786.35 -1,324.92 -4,887.20 5,998,524.86 560,633.00 0.00 4,886.28 -1,324.93 -4,987.13 5,998,523.97 560,533.08 0.00 4,986.21 -1,324.94 -5,087.06 5,998,523.08 560,433.17 0.00 5,086.14 -1,324.96 -5,186.99 5,998,522.19 560,333.25 0.00 5,186.07 -1,324.97 -5,286.92 5,998,521.30 560,233.33 0.00 5,286.00 -1,324.98 -5,386.85 5,998,520.41 560,133.42 0.00 5,385.93 -1,324.99 -5,486.78 5,998,519.53 560,033.50 0.00 5,485.86 -1,325.00 -5,586.71 5,998,518.64 559,933.58 0.00 5,585.79 -1,325.02 -5,686.64 5,998,517.75 559,833.67 0.00 5,685.72 -1,325.03 -5,786.57 5,998,516.86 559,733.75 0.00 5,785.65 -1,325.04 -5,886.50 5,998,515.97 559,633.84 0.00 5,885.58 -1,325.05 -5,986.43 5,998,515.08 559,533.92 0.00 5,985.51 -1,325.06 -6,086.36 5,998,514.20 559,434.00 0.00 6,085.43 7252019 1:24:14PM Page 6 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US+CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt S Pad Well: Proposal Plan: MPU S-203 Wellbore: S-203-UGNU#3 Design: MPU S-203 wp06 Planned Survey Measured -8,480.72 Map Map Vertical 8,479.80 Depth Inclination Azimuth Easting Depth TVDss (usft) (1) (1) (usft) (usft) usft 10,400.00 92.15 269.99 559,334.09 3,621.80 3,557.90 10,500.00 92.15 269.99 559,234.17 3,618.06 3,554.16 10,522.94 92.15 269.99 559,211.25 3,617.20 3,553.30 Start Dir 30/100': 10522.94' MD, 3617.2'TVD 10,600.00 89.83 270.00 -1,325.10 3,615.87 3,551.97 10,700.00 86.83 270.00 -1,325.10 3,618.77 3,554.87 10,727.82 86.00 270.00 -1,325.10 3,620.51 3,556.61 End Dir : 10727.82' MD, 3620.51' TVD -6,585.89 10,777.82 86.00 270.00 6,584.97 3,624.00 3,560.10 Start Dir 30/100' : 10777.82' MD, 3624'TVD 6,604.64 10,800.00 85.34 269.95 558,834.96 3,625.68 3,561.78 10,819.75 84.75 269.91 558,735.40 3,627.38 3,563.48 End Dir :10819.75' MD, 3627.38' TVD 0.00 10,900.00 84.75 269.91 5,998,505.68 3,634.73 3,570.83 11,000.00 84.75 269.91 5,998,504.66 3,643.89 3,579.99 11,100.00 84.75 269.91 5,998,503.64 3,653.05 3,589.15 11,200.00 84.75 269.91 5,998,502.62 3,662.21 3,598.31 11,300.00 84.75 269.91 5,998,501.59 3,671.37 3,607.47 11,400.00 84.75 269.91 5,998,500.57 3,680.53 3,616.63 11,500.00 84.75 269.91 5,998,499.55 3,689.69 3,625.79 11,600.00 84.75 269.91 5,998,498.71 3,698.84 3,634.94 11,700.00 84.75 269.91 5,998,498.28 3,708.00 3,644.10 11,799.44 84.75 269.91 5,998,497.92 3,717.11 3,653.21 Start Dir 30/100': 11799.44' MD, 3717.11 TVD 11,908.35 88.00 270.20 2.00 3,724.00 3,660.10 Start Dir 20/100': 11908.35' MD, 3724'TVD 557,539.28 12,000.00 89.83 270.26 -8,081.23 3,725.73 3,661.83 12,100.00 91.83 270.34 -8,181.13 3,724.28 3,660.38 12,138.25 92.60 270.36 -8,281.02 3,722.81 3,658.91 End Dir : 12138.25' MD, 3722.81' TVD 5,998,496.74 12,200.00 92.60 270.36 -1,322.45 3,720.01 3,656.11 12,300.00 92.60 270.36 -1,322.35 3,715.48 3,651.58 12,400.00 92.60 270.36 3,710.95 3,647.05 12,500.00 92.60 270.36 3,706.43 3,642.53 12,582.98 92.60 270.36 3,702.67 3,638.77 Start Dir 2-/100': 12582.98' MD, 3702.67'TVD 12,600.00 92.92 270.27 3,701.85 3,637.95 12,643.20 93.75 270.02 3,699.34 3,635.44 End Dir : 12643.2' MD, 3699.34' ND 12,700.00 93.75 270.02 3,695.62 3,631.72 12,800.00 93.75 270.02 3,689.08 3,625.18 12,900.00 93.75 270.02 3,682.54 3,618.64 13,000.00 93.75 270.02 3,676.00 3,612.10 13,100.00 93.75 270.02 3,669.46 3,605.56 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Proposal Plan: MPU 8-203 TVD Reference: MPU S-203 As -staked RKB @ 63.90usft MD Reference: MPU S-203 As -staked RKB @ 63.90usft North Reference: True Survey Calculation Method: Minimum Curvature -1,322.33 -8,480.72 Map Map 0.00 8,479.80 +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (usft) (usft) (usft) 3,557.90 8,679.37 -1,325.08 -6,186.29 5,998,513.31 559,334.09 0.00 6,185.36 -1,325.09 -6,286.22 5,998,512.42 559,234.17 0.00 6,285.29 -1,325.09 -6,309.15 5,998,512.22 559,211.25 0.00 6,308.22 -1,325.10 -6,386.19 5,998,511.53 559,134.22 3.00 6,385.26 -1,325.10 -6,486.13 5,998,510.65 559,034.28 3.00 6,485.21 -1,325.10 -6,513.90 5,998,510.41 559,006.52 3.00 6,512.97 -1,325.10 -6,563.78 5,998,509.97 558,956.65 0.00 6,562.85 -1,325.11 -6,585.89 5,998,509.77 558,934.54 3.00 6,584.97 -1,325.13 -6,605.57 5,998,509.57 558,914.86 3.00 6,604.64 -1,325.25 -6,685.48 5,998,508.75 558,834.96 0.00 6,684.56 -1,325.40 -6,785.06 5,998,507.73 558,735.40 0.00 6,784.14 -1,325.55 -6,884.64 5,998,506.71 558,635.83 0.00 6,883.72 -1,325.70 -6,984.22 5,998,505.68 558,536.27 0.00 6,983.29 -1,325.85 -7,083.80 5,998,504.66 558,436.70 0.00 7,082.87 -1,326.00 -7,183.38 5,998,503.64 558,337.14 0.00 7,182.45 -1,326.15 -7,282.96 5,998,502.62 558,237.57 0.00 7,282.03 -1,326.30 -7,382.54 5,998,501.59 558,138.01 0.00 7,381.61 -1,326.45 -7,482.12 5,998,500.57 558,038.44 0.00 7,481.19 -1,326.60 -7,581.14 5,998,499.55 557,939.44 0.00 7,580.21 -1,326.49 -7,689.82 5,998,498.71 557,830.77 3.00 7,688.89 -1,326.12 -7,781.45 5,998,498.28 557,739.15 2.00 7,780.52 -1,325.59 -7,881.43 5,998,497.92 557,639.18 2.00 7,880.50 -1,325.36 -7,919.65 - 5,998,497.82 557,600.96 2.00 7,918.72 -1,324.97 -7,981.34 5,998,497.67 557,539.28 0.00 7,980.41 -1,324.34 -8,081.23 5,998,497.43 557,439.39 0.00 8,080.31 -1,323.70 -8,181.13 5,998,497.18 557,339.50 0.00 8,180.20 -1,323.07 -8,281.02 5,998,496.94 557,239.62 0.00 8,280.10 -1,322.55 -8,363.92 5,998,496.74 557,156.73 0.00 8,362.99 -1,322.45 -8,380.92 5,998,496.68 557,139.73 2.00 8,379.99 -1,322.35 -8,424.04 5,998,496.41 557,096.61 2.00 8,423.12 -1,322.33 -8,480.72 5,998,495.93 557,039.94 0.00 8,479.80 -1,322.29 -8,580.51 5,998,495.09 556,940.17 0.00 8,579.58 -1,322.26 -8,680.29 5,998,494.25 556,840.39 0.00 8,679.37 -1,322.22 -8,780.08 5,998,493.41 556,740.62 0.00 8,779.15 -1,322.19 -8,879.86 5,998,492.57 556,640.85 0.00 8,878.94 7/25/2019 1:24.' 14PM Page 7 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US+CANADA TVD Local Cc -ordinate Reference: Well Proposal Plan: MPU S-203 +E/ -W Company: Hiloorp Alaska, LLC (") (0) TVD Reference: MPU S-203 As -staked RKB @ 63.90usft Project: Milne Point 0.00 0.00 MD Reference: MPU S-203 As -staked RKB @ 63.90usft Site: M Pt S Pad 0.00 0.00 North Reference: True 5,998,558.00 564,684.80 0.00 Well: Proposal Plan: MPU S-203 -6,563.78 Survey Calculation Method: Minimum Curvature 0.00 0.00 Wellbore: S-203-UGNU#3 -9,447.04 5,998,487.94 556,073.74 0.00 0.00 3,681.00 -1,324.90 -4,592.12 Design: MPU S-203 wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI -S +E/ -W Northing Easting DLS Vert Section (usft) (^) (1) (usft) usft (usft) (usft) (usft) (usft) 3,601.10 13,168.20 93.75 270.02 3,665.00 3,601.10 -1,322.16 -8,947.92 5,998,492.00 556,572.80 0.00 8,946.99 Start Dir 301100': 13168.2' MD, 3665'TVD 13,192.74 94.49 270.04 3,663.24 3,599.34 -1,322.15 -8,972.39 5,998,491.80 556,548.33 3.00 8,971.47 End Dir : 13192.74' MD, 3663.24' TVD 13,200.00 94.49 270.04 3,662.67 3,598.77 -1,322.15 -8,979.63 5,998,491.74 556,541.09 0.00 8,978.71 13,300.00 94.49 270.04 3,654.85 3,590.95 -1,322.08 -9,079.33 5,998,490.93 556,441.41 0.00 9,078.40 13,400.00 94.49 270.04 3,647.03 3,583.13 -1,322.02 -9,179.02 5,998,490.12 556,341.73 0.00 9,178.09 13,500.00 94.49 270.04 3,639.21 3,575.31 -1,321.95 -9,278.71 5,998,489.31 556,242.05 0.00 9,277.79 13,600.00 94.49 270.04 3,631.38 3,567.48 -1,321.89 -9,378.41 5,998,488.50 556,142.37 0.00 9,377.48 13,668.85 94.49 270.04 3,626.00 3,562.10 -1,321.85 -9,447.04 5,998,487.94 556,073.74 0.00 9,446.12 Total Depth : 13668.85' MD, 3626' TVD Targets Target Name - hit/miss target -Shape MPS -203 wp04 CP6 - plan hits target center - Point MPS -203 wp03 Heel - plan hits target center - Point MPS -203 wp04 CP4 - plan hits target center - Point MPS -205 wp03 Toe - ext - plan hits target center - Point MPS -203 wp04 CP3 - plan hits target center - Point MPS -203 wp04 CP1 - plan hits target center - Point MPS -203 wp04 CP2 - plan hits target center - Point MPS -203 wp05 Toe - plan hits target center - Point Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting (") (0) (usft) (usft) (usft) (usft) (usft) 0.00 0.00 3,724.00 -1,326.49 -7,689.82 5,998,498.71 557,830.77 0.00 0.00 3,811.20 -1,327.32 -834.88 5,998,558.00 564,684.80 0.00 0.00 3,624.00 -1,325.10 -6,563.78 5,998,509.97 558,956.65 0.00 0.00 3,626.00 -1,321.85 -9,447.04 5,998,487.94 556,073.74 0.00 0.00 3,681.00 -1,324.90 -4,592.12 5,998,527.46 560,928.04 0.00 Wim WE 0.00 3,778.63 -1,326.21 -2,574.50 5,998,543.85 562,945.40 0.00 3,677.00 -1,325.24 0.00 3,665.00 -1,322.16 4,092.29 5,998,531.51 -8,947.92 5,998,492.00 561,427.81 556,572.80 7/25/2019 1:24: 14PM Page 8 COMPASS 5000.15 Build 91 HALLIBURTON Database: NORTH US + CANADA Local Co-ordinate Reference: Company: Hilcorp Alaska, LLC TVD Reference: Project: Milne Point MD Reference: Site: M Pts Pad North Reference: Well: Proposal Plan: MPU S-203 Survey Calculation Method; Wellbore: S-203-UGNU#3 Name (") Design: MPU S-203 wp06 3,626.00 6 5/8" x 8 Halliburton Standard Proposal Report Well Proposal Plan: MPU S-203 MPU S-203 As -staked RKB @ 63.90usft MPU S-203 As -staked RKB @ 63.90usfl True Minimum Curvature Casing Points Measured Vertical Casing Depth Depth Diameter (usft) (usft) Name (") 13,668.85 3,626.00 6 5/8" x 8 1/2" 6-5/8 5,092.51 3,815.56 9 5/8" x 12 114" 9-5/8 Plan Annotations--� - - -- - -- Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 330.00 330.00 0.00 0.00 Start Dir 30/100': 330' MD, 330'TVD 1,000.00 986.34 -102.71 54.61 Start Dir 4°/100' : 1000' MD, 986.34'TVD 1,480.48 1,408.75 -269.90 204.00 End Dir : 1480.48' MD, 1408.76' TVD 2,079.12 1,889.27 -500.95 476.19 Start Dir 40/100' : 2079.12' MD, 1889.27'TVD 4,892.51 3,798.13 -1,327.42 -685.45 End Dir : 4892.51' MD, 3798.13' TVD 5,092.51 3,815.56 -1,327.28 -884.69 Start Dir 30/100' : 5092.51' MD, 3815.56'TVD 5,314.08 3,822.04 -1,327.13 -1,106.04 End Dir : 5314.08' MD, 3822.04' TVD 6,716.10 3,781.74 -1,326.25 -2,507.49 Start Dir 301100': 6716.1' MD, 3781.74'TVD 6,810.39 3,777.09 -1,326.19 -2,601.66 End Dir : 6810.39' MD, 3777.09' TVD 7,491.05 3,743.31 -1,325.80 -3,281.48 Start Dir 30/100': 7491.05' MD, 3743.3l'TVD 7,554.58 3,739.11 -1,325.76 -3,344.86 End Dir : 7554.58' MD, 3739.11' TVD 8,304.58 3,677.00 -1,325.24 -4,092.29 Start Dir 3.50/100': 8304.58' MD, 3677'TVD 8,497.15 3,672.36 -1,325.11 -4,284.69 End Dir : 8497.15' MD, 3672.36' TVD 8,719.81 3,680.10 -1,324.96 -4,507.22 Start Dir 3.250/100' : 8719.81' MD, 3680.1'TVD 8,804.73 3,681.00 -1,324.90 -4,592.12 Start Dir 30/100' : 8804.73' MD, 3681'TVD 8,850.63 3,679.83 -1,324.89 -4,638.01 End Dir : 8850.63' MD, 3679.83' TVD 10,522.94 3,617.20 -1,325.09 -6,309.15 Start Dir 30/100': 10522.94' MD, 3617.2'TVD 10,727.82 3,620.51 -1,325.10 -6,513.90 End Dir : 10727.82' MD, 3620.51' TVD 10,777.82 3,624.00 -1,325.10 -6,563.78 Start Dir 30/100': 10777.82' MD, 3624'TVD 10,819.75 3,627.38 -1,325.13 -6,605.57 End Dir : 10819.75' MD, 3627.38' TVD 11,799.44 3,717.11 -1,326.60 -7,581.14 Start Dir 30/100': 11799.44' MD, 3717.1l'TVD 11,908.35 3,724.00 -1,326.49 -7,689.82 Start Dir 20/100': 11908.35' MD, 3724'TVD 12,138.25 3,722.81 -1,325.36 -7,919.65 End Dir : 12138.25' MD, 3722.81' TVD 12,582.98 3,702.67 -1,322.55 -8,363.92 Start Dir 2-/100': 12582.98' MD, 3702.67'TVD 12,643.20 3,699.34 -1,322.35 -8,424.04 End Dir : 12643.2' MD, 3699.34' TVD 13,168.20 3,665.00 -1,322.16 -8,947.92 Start Dir 30/100' : 13168.2' MD, 3665'TVD 13,192.74 3,663.24 -1,322.15 -8,972.39 End Dir : 13192.74' MD, 3663.24' TVD 13,668.85 3,626.00 -1,321.85 -9,447.04 Total Depth : 13668.85' MD, 3626' TVD Hole Diameter 8-1/2 12-1/4 7/2512019 1:24:14PM Page 9 COMPASS 5000.15 Build 91 Hilcorp Alaska, LLC Milne Point M Pt S Pad Proposal Plan: MPU S-203 S-203 - UGNU#3 MPU S-203 wp06 Sperry Drilling Services Clearance Summary Anticollision Report 25 July, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 wp06 Well Coordinates: 5,999,892.46 N, 565,507.93 E (70° 24'36.56" N, 149° 27'59.73" W) Datum Height: MPU S-203 As -staked RKB @ 63.90usft Scan Range: 26.50 to 5,092.51 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services Hilcorp Alaska, LLC H ALL I B U RTO N Milne Point Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 wp06 Scan Range: 26.50 to 5,092.51 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 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) (usft) (usft) (usft) usft M Pt H Pad M Pt S Pad MPS -06 - MPS -06 - MPS -06 4,521.15 240.87 4,521.15 200.28 4,219.19 5.935 Centre Distance Pass - MPS -06 - MPS -06 - MPS -06 4,601.50 248.14 4,601.50 195.95 4,269.15 4.755 Ellipse Separation Pass - MPS -06 - MPS -06 - MPS -06 4,726.50 288.01 4,726.50 218.66 4,340.18 4.153 Clearance Factor Pass - MPS -08 - MPS -08 - MPS -08 3,984.14 173.06 3,984.14 134.89 3,991.79 4.533 Centre Distance Pass - MPS -08 - MPS -08 - MPS -08 4,001.50 173.93 4,001.50 134.77 3,993.81 4.442 Ellipse Separation Pass - MPS -08 - MPS -08 - MPS -08 4,026.50 178.14 4,026.50 137.32 3,996.27 4.364 Clearance Factor Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 3,984.14 173.06 3,984.14 134.89 3,991.79 4.533 Centre Distance Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 4,001.50 173.93 4,001.50 134.77 3,993.81 4.442 Ellipse Separation Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 4,026.50 178.14 4,026.50 137.32 3,996.27 4.364 Clearance Factor Pass - MPS -09 - MPS -09 - MPS -09 2,167.56 375.09 2,167.56 341.14 2,043.70 11.049 Centre Distance Pass - MPS -09 -MPS -09 -MPS -09 2,176.50 375.13 2,176.50 340.94 2,051.18 10.971 Ellipse Separation Pass - MPS -09 - MPS -09 - MPS -09 2,301.50 385.95 2,301.50 348.45 2,156.60 10.291 Clearance Factor Pass - MPS -11 - MPS -11 - MPS -11 2,294.63 339.20 2,294.63 302.25 2,220.43 9.180 Centre Distance Pass - MPS -11 - MPS -11 - MPS -11 2,351.50 340.25 2,351.50 301.34 2,277.18 8.744 Ellipse Separation Pass - MPS -11 - MPS -11 - MPS -11 2,551.50 363.00 2,551.50 317.99 2,463.83 8.064 Clearance Factor Pass - MPS -I3 -MPS -13 -MPS -13 1,625.33 216.80 1,625.33 203.13 1,623.52 15.857 Centre Distance Pass - MPS -13 - MPS -13 - MPS -13 4,451.50 227.04 4,451.50 172.01 4,094.08 4.125 Clearance Factor Pass - MPS -13 - MPS -13 - MPS -13 4,501.50 219.08 4,501.50 167.36 4,122.79 4.236 Ellipse Separation Pass - MPS -14 - MPS -14 - MPS -14 1,316.42 197.08 1,316.42 181.74 1,372.23 12.843 Centre Distance Pass - MPS -14 - MPS -14 - MPS -14 1,326.50 197.21 1,326.50 181.72 1,380.13 12.736 Ellipse Separation Pass - MPS -I4 -MPS -14 -MPS -14 1,376.50 201.60 1,376.50 185.40 1,417.61 12.447 Clearance Factor Pass - MPS -22 -MPS -22 -MPS -22 1,131.42 199.85 1,131.42 186.87 1,155.18 15.404 Ellipse Separation Pass - MPS -22 - MPS -22 - MPS -22 5,092.51 1,375.79 5,092.51 1,282.85 3,972.98 14.803 Clearance Factor Pass - MPS -23 - MPS -23 - MPS -23 837.63 251.55 837.63 244.06 837.23 33.585 Centre Distance Pass - MPS -23 - MPS -23 - MPS -23 876.50 251.74 876.50 243.92 875.19 32.214 Ellipse Separation Pass - MPS -23 - MPS -23 - MPS -23 5,092.51 715.78 5,092.51 648.43 6,669.84 10.628 Clearance Factor Pass - 25 July, 2019 - 13:27 Page 2 of 9 COMPASS HALLIBURTON Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 wp06 Scan Range: 26.50 to 5,092.51 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Hilcorp Alaska, LLC Milne Point 25 July, 2019 - 13:27 Page 3 of 9 COMPASS 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 MPS -23 - MPS -231-1 - MPS -231-1 637.63 251.55 837.63 244.06 837.23 33.585 Centre Distance Pass - MPS -23 - MPS -231-1 - MPS -231-1 876.50 251.74 876.50 243.92 875.19 32.214 Ellipse Separation Pass - MPS -23 - MPS -231-1 - MPS -231-1 5,092.51 667.34 5,092.51 604.16 6,768.08 10.562 Clearance Factor Pass - - MPS -24 - MPS -24 - MPS -24 833.20 230.08 833.20 220.50 842.01 24.014 Centre Distance Pass - MPS -24 - MPS -24 - MPS -24 851.50 230.15 851.50 220.45 860.06 23.740 Ellipse Separation Pass - MPS -24 - MPS -24 - MPS -24 5,092.51 1,395.24 5,092.51 1,312.25 5,378.78 16.813 Clearance Factor Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 833.20 230.08 833.20 220.50 842.01 24.014 Centre Distance Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 851.50 230.15 851.50 220.45 860.06 23.740 Ellipse Separation Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 5,092.51 1,423.86 5,092.51 1,311.68 5,033.00 12.692 Clearance Factor Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 833.20 230.06 833.20 220.50 842.01 24.014 Centre Distance Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 851.50 230.15 851.50 220.45 860.06 23.740 Ellipse Separation Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 5,092.51 1,395.24 5,092.51 1,312.10 5,378.78 16.782 Clearance Factor Pass - MPS -25 - MPS -25 - MPS -25 629.84 223.59 629.84 217.61 629.32 37.393 Centre Distance Pass - MPS -25 - MPS -25 - MPS -25 651.50 223.66 651.50 217.51 649.67 36.226 Ellipse Separation Pass - MPS -25 - MPS -25 - MPS -25 976.50 260.20 976.50 250.90 943.70 27.988 Clearance Factor Pass - MPS -25 - MPS -251-1 - MPS -251-1 629.84 223.59 629.84 217.10 629.32 34.424 Centre Distance Pass - MPS -25 - MPS -25L1 - MPS -251-1 651.50 223.68 651.50 216.99 649.67 33.435 Ellipse Separation Pass - MPS -25 - MPS -251-1 - MPS -251-1 951.50 254.01 951.50 244.43 923.32 26.512 Clearance Factor Pass - MPS -26 -MPS -26 -MPS -26 1,257.09 76.54 1,257.09 64.46 1,284.25 6.334 Ellipse Separation Pass- _ MPS -26 - MPS -26 - MPS -26 1,301.50 80.04 1,301.50 66.68 1,322.99 5.991 Clearance Factor Pass - MPS -27 - MPS -27 - MPS -27 810.19 193.16 810.19 185.56 817.28 25.457 Centre Distance Pass - MPS -27 - MPS -27 - MPS -27 826.50 193.24 826.50 185.50 833.14 24.959 Ellipse Separation Pass - MPS -27 -MPS -27 -MPS -27 1,026.50 216.44 1,026.50 206.62 1,008.76 22.053 Clearance Factor Pass - MPS -27 - MPS -271-1 - MPS -27L1 810.19 193.16 810.19 185.66 817.26 25.811 Centre Distance Pass - MPS -27 - MPS -271-1 - MPS -271-1 826.50 193.24 826.50 185.60 833.14 25.299 Ellipse Separation Pass - MPS -27 -MPS -271 -1 -MPS -27L1 1,026.50 216.44 1,026.50 206.73 1,008.76 22.289 Clearance Factor Pass - MPS -27 - MPS-27PB1 - MPS-27PB7 810.19 193.16 810.19 185.04 817.26 23.761 Centre Distance Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 826.50 193.24 826.50 184.96 833.14 23.327 Ellipse Separation Pass - MPS -27 - MPS-27PB1 - MPS-27PB1 1,001.50 210.54 1,001.50 200.45 989.10 20.875 Clearance Factor Pass - MPS -28 - MPS -28 - MPS -28 816.85 174.07 816.85 164.20 831.72 17.636 Centre Distance Pass - 25 July, 2019 - 13:27 Page 3 of 9 COMPASS HALLIBURTON Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 Closest Approach 31) Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 wp06 Scan Range: 26.50 to 5,092.51 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Hileorp Alaska, LLC Milne Point 25 July, 2019 - 13:27 Page 4 of 9 COMPASS 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 MPS -28 - MPS -28 - MPS -28 826.50 174.09 826.50 164.17 841.38 17.539 Ellipse Separation Pass - MPS -28 - MPS -28 - MPS -28 926.50 178.92 926.50 168.32 934.97 16.886 Clearance Factor Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 816.85 174.07 816.85 164.20 831.72 17.636 Centre Distance Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 826.50 174.09 826.50 164.17 841.38 17.539 Ellipse Separation Pass - MPS -28 - MPS-28PB1 - MPS-28PB1 926.50 178.92 926.50 168.32 934.97 16.886 Clearance Factor Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 816.85 174.07 816.85 164.20 831.72 17.636 Centre Distance Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 826.50 174.09 626.50 164.17 841.38 17.539 Ellipse Separation Pass - MPS -28 - MPS-28PB2 - MPS-28PB2 926.50 178.92 926.50 168.32 934.97 16.886 Clearance Factor Pass - MPS -29 - MPS -29 - MPS -29 598.54 161.33 598.54 155.79 603.04 29.159 Centre Distance Pass - MPS -29 - MPS -29 - MPS -29 626.50 161.53 626.50 155.72 629.83 27.831 Ellipse Separation Pass - MPS -29 - MPS -29 - MPS -29 826.50 182.93 826.50 175.12 809.85 23.418 Clearance Factor Pass - MPS -29 - MPS -291-1 - MPS -291-1 598.54 161.33 598.54 155.28 603.04 26.673 Centre Distance Pass - MPS -29 - MPS -291-1 - MPS -291-1 626.50 161.53 626.50 155.21 629.83 25.560 Ellipse Separation Pass - MPS -29 - MPS -291-1 - MPS -29L1 826.50 182.93 826.50 174.60 809.85 21.968 Clearance Factor Pass - MPS -30 - MPS -30 - MPS -30 753.29 142.14 753.29 131.39 762.38 13.219 Centre Distance Pass - MPS -30 - MPS -30 - MPS -30 776.50 142.31 776.50 131.34 784.67 12.967 Ellipse Separation Pass - MPS -30 - MPS -30 - MPS -30 851.50 145.49 851.50 133.97 856.98 12.630 Clearance Factor Pass - MPS -31 - MPS -31 - MPS -31 962.43 108.05 962.43 99.24 984.93 12.268 Centre Distance Pass - MPS -31 - MPS -31 - MPS -31 976.50 108.18 976.50 99.22 998.49 12.074 Ellipse Separation Pass - MPS -31 - MPS -31 - MPS -31 1,076.50 116.48 1,076.50 106.26 1,092.30 11.420 Clearance Factor Pass - MPS -32 - MPS -32 - MPS -32 585.47 121.05 585.47 112.93 594.23 14.905 Centre Distance Pass - MPS -32 - MPS -32 - MPS -32 601.50 121.12 601.50 112.78 609.69 14.518 Ellipse Separation Pass - MPS -32 - MPS -32 - MPS -32 726.50 129.20 726.50 119.53 726.30 13.360 Clearance Factor Pass - MPS -33 - MPS -33 - MPS -33 671.80 105.62 671.80 99.36 673.26 16.854 Centre Distance Pass - MPS -33 - MPS -33 - MPS -33 726.50 105.90 726.50 99.20 728.29 15.783 Ellipse Separation Pass - MPS -33 - MPS -33 - MPS -33 876.50 114.84 876.50 106.86 873.85 14.385 Clearance Factor Pass - MPS -33 - MPS -33A- MPS -33A 671.80 105.62 671.80 99.36 679.57 16.854 Centre Distance Pass - MPS -33 - MPS -33A- MPS -33A 726.50 105.90 726.50 99.20 734.60 15.783 Ellipse Separation Pass - MPS -33 - MPS -33A- MPS -33A 876.50 114.84 876.50 106.86 880.16 14.386 Clearance Factor Pass - MPS -34 - MPS -34 - MPS -34 601.64 82.22 601.64 76.10 614.15 13.451 Ellipse Separation Pass - 25 July, 2019 - 13:27 Page 4 of 9 COMPASS HALLIBURTON Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 wp06 Scan Range: 26.50 to 5,092.51 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Hilcorp Alaska, LLC Milne Point 25 July, 2019 - 13:27 Page 5 of 9 COMPASS 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 MPS -34 - MPS -34 - MPS -34 701.50 89.29 701.50 82.14 708.15 12.482 Clearance Factor Pass - MPS -34 - MPS -341-1 - MPS -341-1 601.64 82.22 601.64 76.10 614.15 13.451 Ellipse Separation Pass - MPS34-MPS-341-1-MPS-341-1 701.50 89.29 701.50 82.14 708.15 12.482 Clearance Factor Pass - MPS -34 - MPS341-2 - MPS -34L2 601.64 82.22 601.64 76.10 614.15 13.451 Ellipse Separation Pass - MPS -34 - MPS341-2 - MPS -341-2 701.50 89.29 701.50 62.14 708.15 12.482 Clearance Factor Pass - MPS -35 - MPS -35 - MPS -35 585.52 58.97 565.52 51.48 596.52 7.876 Ellipse Separation Pass - MPS -35 - MPS -35 - MPS -35 626.50 60.22 626.50 52.46 635.89 7.759 Clearance Factor Pass - MPS -35 - MP3-35PB1 - MPS-35PB1 565.52 58.97 585.52 51.48 596.52 7.876 Ellipse Separation Pass - MPS -35 - MPS-35PB1 - MPS-35PB1 626.50 60.22 626.50 52.46 635.89 7.759 Clearance Factor Pass - MPS -35 - MPS-35PB2 - MPS-35PB2 585.52 58.97 585.52 51.48 596.52 7.876 Ellipse Separation Pass - MPS -35 - MPS-35PB2 - MPS-35PB2 626.50 60.22 626.50 52.46 635.89 7.759 Clearance Factor Pass - MPS -37 - MPS -37 - MPS -37 265.88 44.03 265.88 39.97 273.88 10.846 Centre Distance Pass - MPS -37 - MPS -37 - MPS -37 576.50 46.59 576.50 38.20 582.04 5.557 Ellipse Separation Pass - MPS -37 - MPS -37 - MPS -37 2,801.50 134.56 2,801.50 90.38 2,790.49 3.046 Clearance Factor Pass - MPS -39 - MPS -39 - MPS -39 26.50 14.90 26.50 13.98 28.03 16.309 Centre Distance Pass - MPS -39 - MPS -39 - MPS -39 251.50 16.05 251.50 12.19 252.68 4.163 Ellipse Separation Pass - - MPS -39 -MPS -39 -MPS -39 1,176.50 42.15 1,176.50 24.69 1,166.15 2.414 Clearance Factor Pass - MPS -41 - MPS -41 - MPS -41 26.50 15.15 26.50 14.23 34.13 16.580 Centre Distance Pass - MPS -41 - MPS -41 - MPS -41 401.50 17.26 401.50 11.28 409.05 2.887 Ellipse Separation Pass - MPS -41 - MPS -41 - MPS -41 3,351.50 87.66 3,351.50 33.06 3,337.52 1.605 Clearance Factor Pass - MPS -41 - MPS -41A- MPS -41A 26.50 15.15 26.50 14.23 34.13 16.580 Centre Distance Pass - MPS41 - MPS -41A - MPS -41A 401.50 17.26 401.50 1128 409.05 2.867 Ellipse Separation Pass - MPS-4I-MPS-41A-MPS41A 3,351.50 87.66 3,351.50 33.06 3,337.52 1.606 Clearance Factor Pass - MPS -41 - MPS-41APB1 - MPS-41APB1 26.50 15.15 26.50 14.23 34.13 16.580 Centre Distance Pass - MPS41 - MPS-41APB1 - MPS-41APB1 401.50 17.26 401.50 11.28 409.05 2.867 Ellipse Separation Pass - MPS41 - MPS-41APB1 - MPS-41APB1 3,351.50 87.66 3,351.50 33.06 3,337.52 1.605 Clearance Factor Pass - MPS41 - MPS41APB2 - MPS41APB2 26.50 15.15 26.50 14.23 34.13 16.580 Centre Distance Pass - MPS41 - MPS-41APB2 - MPS-41APB2 401.50 17.26 401.50 11.28 409.05 2.687 Ellipse Separation Pass - MPS41 - MPS-41APB2 - MPS-41APB2 3,351.50 87.66 3,351.50 33.06 3,337.52 1.605 Clearance Factor Pass - MPS43 - MPS -43 - MPS -43 449.11 38.00 449.11 31.40 457.14 5.757 Centre Distance Pass - 25 July, 2019 - 13:27 Page 5 of 9 COMPASS HALLIBURTON Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 wp06 Scan Range: 26.50 to 5,092.51 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Hileorp Alaska, LLC Milne Point 25 July, 2019 - 13:27 Page 6 of 9 COMPASS 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 MPS -43 - MPS -43 - MPS -43 501.50 38.32 501.50 30.97 508.85 5.213 Ellipse Separation Pass - MPS -43 - MPS -43 - MPS -43 601.50 41.61 601.50 32.87 606.12 4.762 Clearance Factor Pass - Proposal Plan: MPU S-201 - S-201 - UGNU#2 - S-201 276.50 29.70 276.50 26.58 277.30 9.522 Centre Distance Pass - Proposal Plan: MPU S-201 - S-201 - UGNU#2 - S-201 326.50 29.90 326.50 26.35 327.04 8.423 Ellipse Separation Pass - Proposal Plan: MPU S-201 - S-201 - UGNU#2 - S-201 626.50 36.77 626.50 30.60 623.82 5.963 Clearance Factor Pass - Proposal Plan: MPU S-202 - S-202 - UGNU#4 - S-202 276.50 61.33 276.50 58.21 277.30 19.660 Centre Distance Pass - Proposal Plan: MPU S-202 - S-202 - UGNU#4 - S-202 326.50 61.53 326.50 57.98 326.77 17.335 Ellipse Separation Pass - Proposal Plan: MPU S-202 - S-202 - UGNU#4 - S-202 5,092.51 700.11 5,092.51 623.04 4,934.99 9.085 Clearance Factor Pass - Proposal Plan: MPU S-204 - S-204 - UGNU#5 - S-204 326.50 30.20 326.50 26.64 327.30 8.481 Centre Distance Pass - Proposal Plan: MPU S-204 - S-204 - UGNU#5 - S-204 401.50 30.54 401.50 26.32 402.28 7.233 Ellipse Separation Pass - Proposal Plan: MPU S -2D4 - S-204 - UGNU#5 - S-204 526.50 34.02 526.50 28.69 526.95 6.383 Clearance Factor Pass - Proposal Plan: MPU S-205 - S-205 - UGNU#1 - MPU ; 1,029.65 53.70 1,029.65 43.49 1,036.10 5.261 Centre Distance Pass - Proposal Plan: MPU S-205 - S-205 - UGNU#1 - MPU ; 1,051.50 53.84 1,051.50 43.38 1,057.88 5.147 Ellipse Separation Pass - Proposal Plan: MPU S-205 - S-205 - UGNU#1 - MPU t 1,126.50 56.41 1,126.50 45.07 1,132.36 4.973 Clearance Factor Pass - Proposal Plan: MPU S-206 - S-206 - UGNU#6 - S-206 548.35 70.85 548.35 64.98 553.36 12.079 Centre Distance Pass - Proposal Plan: MPU S-206 - S-206 - UGNU#6 - S-206 551.50 70.85 551.50 64.96 556.50 12.018 Ellipse Separation Pass - Proposal Plan: MPU S-206 - S-206 - UGNU#6 - S-206 651.50 74.99 651.50 68.14 654.94 10.945 Clearance Factor Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 475.88 88.34 475.88 83.17 480.98 17.084 Centre Distance Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 501.50 88.48 501.50 83.07 506.49 16.347 Ellipse Separation Pass - Proposal Plan: MPU S-207 - MPU S-207 - MPU S-207 626.50 96.26 626.50 89.66 627.64 14.586 Clearance Factor Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 422.04 104.97 422.04 100.31 425.90 22.543 Centre Distance Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 451.50 105.07 451.50 100.13 455.37 21.293 Ellipse Separation Pass - Proposal Plan: MPU S-208 - MPU S-208 - MPU S-208 651.50 119.54 651.50 112.72 647.81 17.527 Clearance Factor Pass - Proposal Plan: MPU S-209 - S-209 - MPU S-209 wp01 351.50 120.76 351.50 116.78 354.00 30.304 Centre Distance Pass - Proposal Plan: MPU S-209 - S-209 - MPU S-209 wp01 401.50 120.97 401.50 116.52 404.00 27.147 Ellipse Separation Pass - Proposal Plan: MPU S-209 - S-209 - MPU S-209 wp01 626.50 135.05 626.50 128.52 621.46 20.695 Clearance Factor Pass - Proposal Plan: S-210 - MPU S-210 - MPU S-210 wp01 326.50 136.03 326.50 132.29 328.70 36.294 Centre Distance Pass - Proposal Plan: S-210 - MPU S-210 - MPU S-210 wp01 376.50 136.18 376.50 131.96 378.55 32.279 Ellipse Separation Pass - Proposal Plan: S-210 - MPU S-210 - MPU S-210 wp01 701.50 160.89 701.50 153.63 689.87 22.164 Clearance Factor Pass - 25 July, 2019 - 13:27 Page 6 of 9 COMPASS HALLIBURTON Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 From (usft) 26.50 1,250.00 5,092.51 To (usft) 1,250.00 MPU S-203 wp06 5,092.51 MPU S-203 wp06 13,668.85 MPU S-203 wp06 Survey/Plan Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 2_Gyro-NS-GC_Drill pipe 2_MWD+IFR2+MS+Sag 2_MWD+IFR2+MS+Sag Hileorp Alaska, LLC Milne Point 25 July, 2019 - 13:27 Page 7 of 9 COMPASS HALLIBUgTON Project: Milne Point REFERENCE INFORMATION WELL DETAIISposel :PmPlan: MPU S-203 NAD 1927 (NADCONCONUS) Alaska Zone 04 Coa-tlinate(ME) Reference: wall Pro ul Ran: MNJ S-203, True North Site: M Pt S Pad VerXcal (TVD) Reference MPU 5-203oAs-staked RKe Q 83.Wusft 37.40 9nomy Or•Illing Well: Proposal Plan: MPU 5-20 3 Measured DepthReference: MPU S-203 Asslaketl RKB@G3.Wusft +N/-$ +pJ_W Nodhing Fasting latinude Longitude Wellbore: S-203 - UGNU#3 Calculation Method Minimum Curvature 0.00 0.00 5999892.4E 565507.93 70° 24' 363W 149° 27' 59.729 W Plan: MPU S-203 wp06 SURVEY PROGRAM GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Date: 2019 -D6 -07T00:00:00 Validated: Yes Version: LM 26.50 To 13668.85 Ladder/S.F. Plots SH(1 of 2) CASING DETAILS Depth From Depth To Survey/Plan Tool 26.50 1250.00 MPU S-203 wp06(S-203-UGNU#3)2_Gyro-NS.GC_Dnll pip 250.00 5092.51 MPU 5203 wpD6(S-203-UGNU#3)2_MWD+IFR2+MS+Sag TVD TVDSS MD Sim Name 3815.56 3751.66 5092.51 9-5/8 95/8"x121/4" 5092.51 13668.85 MPU 5-203 wp06(S-203-UGNU#3)2 MWD+IFR2+MS+Sag 3626.00 3562.10 13668.85 6-58 658"xR 1/2" _i __moi (' MPS -2 / ._. C MPS -35 . V' MPS -3t i l i - o MPU S- o MPS -3 (0120.00 109 wp01 MPS -3 — MPU m MPS- 0a 90,00— 0) MPU S 07 wp01 1 MPS- U -Hee S-202 m60.00— MPU S OS wp02 0 MPS -3 i MPS- ' c 0?00 8 S-204 W04 MPS -3 MPS -4 0.00 0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850 4125 4400 4675 4950 5225 Measured Depth (550 usft/in) 4.00 — I 1 v 3.00 N I LL — I C I o I I m 2.00 - Collision Risk Procedures Req. ap Collision Avoidance Req. 1.00 No -Go Zone - Stop Drilling j NOERRORS 0.00 0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3650 4125 4400 4675 4950 5225 Measured Depth (550 usft/in) Hilcorp Alaska, LLC Milne Point M Pt S Pad Proposal Plan: MPU S-203 S-203 - UGNU#3 MPU S-203 wp06 Sperry Drilling Services Clearance Summary Anticollision Report 25 July, 2019 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 wp06 Well Coordinates: 5,999,892.46 N, 565,507.93 E (70° 24'36.56" N, 149° 27' 59.73" W) Datum Height: MPU S-203 As -staked RKB @ 63.90usft Scan Range: 5,092.51 to 13,668.85 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 Wp06 Scan Range: 5,092.51 to 13,668.85 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft Site Name Comparison Well Name - Wellbore Name - Design M Pt H Pad MPH -07 - MPH -07A- MPH -07A MPH -07 - MPH -07A - MPH -07A MPH -07 - MPH -07A- MPH -07A M Pt S Pad Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum (usft) (usft) (usft) (usft) usft 12,992.51 1,227.88 12,992.51 916.94 12,998.00 3.949 Clearance Factor 13,367.51 1,117.18 13,367.51 859.46 12,998.00 4.335 Ellipse Separation 13,523.10 1,106.29 13,523.10 863.88 12,998.00 4.564 Centre Distance Mlcorp Alaska, LLC Milne Point Separation Warning Pass - Pass - Pass - MPS -06 - MPS -06 - MPS -06 5,092.51 529.69 5,092.51 441.79 4,511.60 6.026 Clearance Factor Pass - MPS -08 - MPS -08 - MPS -08 5,092.51 1,083.52 5,092.51 1,030.50 3,848.35 20.435 Clearance Factor Pass - MPS -08 - MPS-08PB1 - MPS-08PB1 5,092.51 1,083.52 5,092.51 1,030.50 3,846.35 20.435 Clearance Factor Pass - MPS -13 - MPS -13 - MPS -13 5,092.51 562.68 5,092.51 511.44 4,345.90 10.982 Clearance Factor Pass - MPS -14 - MPS -14 - MPS -14 7,064.77 1,487.08 7,064.77 1,282.06 5,208.25 7.253 Centre Distance Pass - MPS -I4 -MPS -14 -MPS -14 7,967.51 1,518.82 7,967.51 1,246.67 6,118.28 5.581 Ellipse Separation Pass - MPS -14- MPS -14 - MPS -14 8,392.51 1,562.09 8,392.51 1,270.15 6,431.81 5.351 Clearance Factor Pass - MPS -22 - MPS -22 - MPS -22 MPS -22 - MPS -22 - MPS -22 MPS -23 - MPS -23 - MPS -23 5,682.63 393.80 5,682.63 358.65 6,737.51 11.202 Centre Distance Pass - MPS -23 - MPS -23 - MPS -23 5,692.51 393.92 5,692.51 358.55 6,737.54 11.135 Ellipse Separation Pass - MPS -23 - MPS -23 - MPS -23 5,992.51 501.10 5,992.51 441.13 6,738.13 8.355 Clearance Factor Pass - — MPS -23 - MPS -231-1 - MPS -231-1 5,658.13 345.92 5,658.13 317.12 6,716.08 12.009 Centre Distance Pass - MPS -23 - MPS -231-1 - MPS -231-1 5,667.51 346.05 5,667.51 317.09 6,715.27 11.950 Ellipse Separation Pass - MPS -23 - MPS -231-1 - MPS -23L1 5,942.51 447.15 5,942.51 394.94 6,693.26 8.564 Clearance Factor Pass - MPS -24 -MPS -24 -MPS -24 6,742.51 231.51 6,742.51 178.36 6,381.25 4.356 Ellipse Separation Pass - MPS -24 - MPS -24 - MPS -24 6,850.05 216.23 6,850.05 185.35 6,446.00 7.002 Centre Distance Pass - MPS -24 - MPS -24 - MPS -24 7,192.51 340.89 7,192.51 235.67 6,675.74 3.240 Clearance Factor Pass - MPS-24-MPS-24PB1-MPS-24PB1 5,892.51 1,129.48 5,892.51 1,007.91 5,033.00 9.291 Clearance Factor Pass - MPS -24 - MPS-24PB1 - MPS-24PB1 5,942.51 1,127.65 5,942.51 1,006.50 5,033.00 9.308 Ellipse Separation Pass - MPS-24-MPS-24PB1-MPS-24PB1 5,958.68 1,127.54 5,958.68 1,006.56 5,033.00 9.320 Centre Distance Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 6,651.02 216.23 6,851.02 185.22 6,447.48 6.974 Centre Distance Pass - MPS -24 - MPS-24PB2 - MPS-24PB2 7,017.51 249.28 7,017.51 173.44 6,574.90 3.287 Ellipse Separation Pass - 25 July, 2019 - 13:28 Page 2 of 6 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 Closest Approach 3D Proximity Scan on Current Survey Data (North Reference) Reference Design: M Pt S Pad - Proposal Plan: MPU S-203 - S-203 - UGNU#3 - MPU S-203 wp06 Scan Range: 5,092.51 to 13,668.85 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 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) (usft) (usft) (usft) usft MPS -24 - MPS-24PB2 - MPS-24PB2 7,267.51 363.79 7,267.51 211.62 6,760.00 2.391 Clearance Factor Pass - MPS -25 - MPS -25 - MPS -25 7,888.11 410.30 7,888.11 346.52 8,975.52 6.433 Ellipse Separation Pass - MPS -25 - MPS -25 - MPS -25 8,192.51 510.86 8,192.51 417.42 8,970.43 5.467 Clearance Factor Pass - MPS -25 - MPS -25L1 - MPS -251-1 7,617.51 447.81 7,617.51 370.27 8,916.83 5.775 Clearance Factor Pass - MPS -25 - MPS -251-1 - MPS -25L1 7,867.51 369.11 7,867.51 316.70 8,911.82 7.043 Ellipse Separation Pass - MPS -25 - MPS -251-1 - MPS -25L1 7,871.14 369.10 7,871.14 316.76 8,911.74 7.053 Centre Distance Pass - MPS -26 - MPS -26 - MPS -26 6,116.28 343.08 6,116.28 240.92 4,805.13 3.358 Centre Distance Pass - MPS -26 - MPS -26 - MPS -26 6,217.51 350.96 6,217.51 230.70 4,874.74 2.918 Ellipse Separation Pass - MPS -26 - MPS -26 - MPS -26 6,317.51 373.38 6,317.51 239.93 4,941.68 2.798 Clearance Factor Pass - MPS -27 -MPS -271 -1 -MPS -271-1 11,191.78 1,521.01 11,191.78 1,122.09 11,255.00 3.813 Centre Distance Pass - MPS -27 -MPS -271 -1 -MPS -27L1 11,267.51 1,522.89 11,267.51 1,119.54 11,255.00 3.776 Ellipse Separation Pass - MPS -27 -MPS -271 -1 -MPS -271-1 11,392.51 1,534.20 11,392.51 1,125.39 11,255.00 3.753 Clearance Factor Pass - MPS -31 - MPS -31 - MPS -31 9,275.72 481.68 9,275.72 130.70 7,362.95 1.372 Clearance Factor Pass - MPS -33 -MPS -33A -MPS -33A 6,579.74 1,161.30 6,579.74 1,023.20 4,975.14 8.409 Centre Distance Pass - MPS -33 -MPS -33A -MPS -33A 6,592.51 1,161.37 6,592.51 1,023.20 4,975.14 8.405 Ellipse Separation Pass - MPS -33 -MPS -33A -MPS -33A 6,667.51 1,163.75 6,667.51 1,024.78 5,013.71 8.374 Clearance Factor Pass - Proposal Plan: MPU S-201 - S-201 - UGNU#2 - S-201 11,325.54 697.58 11,325.54 379.71 11,604.11 2.195 Centre Distance Pass - Proposal Plan: MPU S-201 - S-201 - UGNU#2 - S-201 13,668.85 703.14 13,668.85 275.18 13,938.74 1.643 Clearance Factor Pass - Proposal Plan: MPU S-202 - S-202 - UGNU#4 - S-202 5,434.77 699.98 5,434.77 620.11 5,277.68 8.765 Centre Distance Pass - Proposal Plan: MPU S-202 - S-202 - UGNU#4 - S-202 13,668.85 700.31 13,668.85 266.99 13,502.12 1.624 Clearance Factor Pass - Proposal Plan: MPU S-204 - 5-204 - UGNU#5 - S-204 12,640.40 1,400.01 12,640.40 1,018.35 12,377.36 3.668 Centre Distance Pass - Proposal Plan: MPU S-204 - S-204 - UGNU#5 - S-204 13,668.85 1,400.17 13,668.85 969.43 13,394.66 3.251 Clearance Factor Pass - Proposal Plan: MPU S-205 - S-205 - UGNU#1 - MPU! 11,217.09 1,397.97 11,217.09 1,058.34 11,962.86 4.116 Centre Distance Pass - Proposal Plan: MPU S-205 - S-205 - UGNU#1 - MPU t 13,668.85 1,402.15 13,668.85 944.75 14,410.29 3.065 Clearance Factor Pass - 25 July, 2019 - 13:28 Page 3 of 6 COMPASS HALLIBURTON Anticollision Report for Proposal Plan: MPU S-203 - MPU S-203 wp06 From (usft) 26.50 1,250.00 5,092.51 To (usft) 1,250.00 MPU S-203 wp06 5,092.51 MPU S-203 wp06 13,668.85 MPU S-203 wp06 Survey/Plan Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool 2_Gyro-NS-GCDrill pipe 2_MWD+IFR2+MS+Sag_ 2_MWD+IFR2+MS+Sag Hileorp Alaska, LLC Milne Point 25 July, 2019 - 13:28 Page 4 of 6 COMPASS REFERENCE INFORMATION WELL DETAILS:Propreal Plan: MPU S-203 NAD 1927(NADCON CONUS) Alaska 7nne 04 HALLIBURTON Project: Milne Point ( ndinate (F E) Refe nni Wel Proposal Plan: MPU 5-203. True Nodb 3740 Stir, Drilling Site: M Pt S Pad Vertical (TVD) Reference: MPU 5.203 As-staketl ftKB @ 83 W-" Well: Proposal Plan: MPU 5-20 Measarcalculation Dpfennei hill RKB@63,11., +NI0.00 +0.00 Ninhing Fasting Lotitmde Longitude tan:M Minimum Gurs-Olked 5999892.46 565507.93 70°24'76.560N 149°27'59.729W Wellbore: 5-203-U Plan: MPU S-203 wp06 SURVEY PROGRAM GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Date: 2019-06-07T00:00:00 Validated: Yes Version: 26.50 To 13668.85 Depth From Depth To Survey/Plan Tool CASING DETAILS Ladder/S.F. Plots Depth 1250.00 MPUS-203 wp06 (S-203-UGNUM3)2_GyroNS-GC_Dnll pipe ND TVDSS MD Sire Name PH(2of2) 250.00 5092.51 MPU S-203wp06(S-203-UGNU#3)2_MWD+IFR2+MS+Sag ;g15.56 3751.66 50')2.51 9-5/8 95/8"x121/4" 5092.51 13668.85 MPU S-203 wp06(S-203-UGNU#3)2_MWD+IFR2+MS+Sa9 3626.00 3562.10 13668.85 6-5/8 6 5/8" x 8 12" 180.00 �- --� I 150.00 o �I ' O O --- (00120.00 _- .__ _._ ._.-- j c m 1 _. 090.0 - -- -. ----- N 60.00---- 0.00 - 0) 0) MPS -22 30.00 - I I 0.00 5400 5850 6300 6750 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 12150 12600 13050 13500 Measured Depth (900 usfUin) I i i 4.00 O ' 1 U L � 3.00 o. Collision Risk Procedures Req. ! .00 2.00- _ Collision Avoidance Req. Collision No -Go Zone - Stop Drilling 1.00 - 1 NOERRORS ! 1 0.00- lill lilt 5400 5850 6300 6750 7200 7650 8100 8550 9000 9450 9900 10350 10800 11250 11700 12150 12600 13050 13500 Measured Depth (900 usft/in) 9 9 a [REEr ku mnn�J eon/Ipop em/toxo v.]m9]a eevtom diate 2 Casing/Liner Cement o.mYvan voopn.eaei p wrmw. aa. BIM �tn^I.. 4 nm I^a ^naaw4YprBM1 W\ um^aMBlnl W6 95W 101. lap N•amlmalxl 5p Mwmvmum.I00t/nl N9uIrM VeWm. I0el1 mnvamn leeu rmr[.wlrwwlmraseu • [Ba M/a 4mmrrp Ine vauOM/a w rwao rrxaxllnl aoYUUYhnI Ina.m.ww 4Yrrenllq 60 M1 glue Wumn4ryNlM1 0 0 romFmnlq 0 BAog fmnlxl 1 SWSB m.IBetl "'hQ. r n.0 ume laBy 0 twrp errlr.evawgeey®� real X.9wr.ava.maeazl o �n. YB .a mal r^uFmnVdumlBazl ll pwr.Yv^amleBll�ar Owmal o.mYvan voopn.eaei p wrmw. aa. BIM �tn^I.. 4 nm I^a ^naaw4YprBM1 W\ um^aMBlnl W6 95W 101. lap N•amlmalxl 5p Mwmvmum.I00t/nl N9uIrM VeWm. I0el1 mnvamn leeu rmr[.wlrwwlmraseu • [Ba M/a 4mmrrp Ine vauOM/a wamRam room umn.me ro I^Yr �W tlgmuaelrnl B.narpem 60 M1 glue Mammtl4n4r6atO 11^I [.}B6 w w.m.m em BAog fmnlxl 1 SWSB rnuemNrmY^aw u.ry BB lwl "'hQ. ..I —IML1 ].sn3E9 twrp errlr.evawgeey®� ^ 4nr%murn a%N r^uFmnVdumlBazl ll pwr.Yv^amleBll�ar Owmal ^YgOr ntl .IdF—I +a +^cerra< iengrA hrc.Meaal%1 o uamppn.l ^v IOBVnI .X/q mrlx nYnl+nonrxe 95W m.IBBI [rv/n BpWr.ewlum leBUn1 005o51s p.m^ .w Vebrrn leeLl NromFmnvannlBeu msz90z T—,: n.Roewvau^.leep nyq WA —12 am mar Totals w[IBBQ IL+ wa 1fA.4rle.y a ®.[. i.W\ ftr Spacer sww lry. unsmm Banipbn SW nahweinelOC MormWwXw04m.arB^ BA35 ma44a4Lgop ll^I }cn i^a YM IOIInI 6t>5 m^aMBlnl ]w.3rs 0.ram E.w l%I m.I00VM11 o0}9w M VNum. I00L1 50 .r yavwm.leets rm pueVelwn laetl B Production Liner • [Ba M/a 4mmrrp Ine vauOM/a wamRam room umn.me ro I^Yr �W tlgmuaelrnl Ilnl Mammtl4n4r6atO 11^I [.}B6 nxn 4n[u InI L.;15p 95m 93w fmnlxl 1 SWSB Vau 0.Bpulntivqum.IBBt1 OM1121 ana.vMum.lBetl ..I —IML1 ].sn3E9 twrp errlr.evawgeey®� _au ^ai Totals r^uFmnVdumlBazl ll pwr.Yv^amleBll�ar Owmal mm m aA.Y. .IdF—I +a van ownaw.e.p nm �p,.w.Y.. uamppn.l nWl 1 m4Nn[IB linlf 0316 mnNn[plM1l 169 13669 95W MdmFvnnlxl 50 BpWr.ewlum leBUn1 005o51s N9wr.awem leeu z s96s NromFmnvannlBeu msz90z lwlR.wlrwvmm.leazl®a.' ®aa wl mmrp. 1sAXw • [Ba M/a wmYmw eortp Xr.[..rM xw B4mmr err I r �4Ymooum 4w.mum 4e{%rlhl BO anntrxlknpn 0.rnmlar.al%I mrI00VM1l 001>Mz MIOt[meq{anntrxk WRp bmaVaurolBOtl 1 SWSB ana.vMum.lBetl twrp errlr.evawgeey®� _au ^ai Totals wgBeq n13e1 M _axa ]S.MWIBeL 1)el s9sl fi 3z9,H9 +x[a I mtxm¢IBIm'i .e4tecxlrylBlinl }m .R v.Atn �o 4^e.em4rlM mmemw.mmewan toewnammrinl pm abyener 4rqur Bveeallnl dE93 lerr6rn n^msMemameelEtl ^ <rmetlblernlvlmpn weeayel ........ . . Melfi Int a4n{Wpra[4 knpA 69 mrtpmpol ahlnphl • p4danmemmtap N+Meaxaleehl S}E.9 aln r�p.tm.rB [nz Bmlwpa4piwh/nl ■ u 1,4S1_ 3N 5-203 9 ■ 37 ■ 3s ■ M ■ 33 ■ 32 ■ail30 ■ ■ 29I ■ 2B EB ■ 2S ■ 2H ■Ia 22 ■ 211 ■ 20 ■ 191 ■ 16 ■17 ■1B ■ 151 ■14 ■ 1a ■12 11 1 7 PLANT 15'00'00" I I I I I I I I I I I I \_ I ■10 SE ■ 91 I \0`71 IN 71 3 _ _ — — _ — — i I 0 j' °SB -04■ I — L J LJ L I I _ I 1 I I 7 / GRAPHIC SCALE 0 80 160 320 ( IN FEET) NOTES: 1 Inch - 160 k. 27 1 26 25 30 G -PAD PAD T1 3N 35 PLANT GEODETIC 31 T1214I CELLAR SECTION NO. 2 1 COORDINATES N71 5 PAD ELEV. wo OFFSETS S-203 Y=5,999,892.50' N=2,237.01' 70'24'36.560" 70.4101557' THIS PROJECT 36.7' 3,228'FSL - E= 6,369.90' 149'27'59.733" 149.4665924' 503' FEL 12 6 I VICINITY MAP N.T.S. + ! AS -BUILT CONDUCTOR ■ EXISTING CONDUCTOR 1. DATE OF SURVEY: JULY 26, 2019 Z. REFERENCE FIOD BOOK: HC19-04 PGs 07-06. 3. HORIZONTAL DATUM 15 ALASKA STATE PLANE, ZONE 4, NAD27. 4. GEODETIC POSITIONS ARE NAD27. 5. PAD MEAN SCALE FACTOR IS: 0.99990492 6. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MP S PAD OPERATOR MONUMENTS S -EAST, S -MID, AND S -NEST. 7. ELEVATIONS ARE MILNE POINT MEAN SEA LEVEL. >r SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND UCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS -BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 26, 2019, LOCATED WITHIN PROTRACTED SEC. 12. T. 12 N., R. 10 E.. UMIAT MERIDIAN. AK. WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL CELLAR SECTION NO. COORDINATES I COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEV. BOX ELEV. OFFSETS S-203 Y=5,999,892.50' N=2,237.01' 70'24'36.560" 70.4101557' 36.7' 36.7' 3,228'FSL X= 565,507.81 E= 6,369.90' 149'27'59.733" 149.4665924' 503' FEL bell JACOBS Hilcorp Alaska Dx1E 7 9 19 FRB19 mps MPS 0 O1 G1£ MPU S PAD AEccs62 AS—BUILT CONDUCTOR Op 9 159ip FOt INFtltl1A11W q1p L �AWMAWC MA9(1 Olq]' 9 1 LF 1 xa pAa 9Cn9W 9T tlIN 190 n1-smr 1' = 160' WELL S-203 From: Cody Dinaer To: aover. David L (CED) Cc: Rixse. Melvin G ICED); Joe Enael Subject: RE: [EXTERNAL] MP 5-203 GL Change Date: Wednesday, August 7, 2019 10:14:17 AM Yes sir that is correct. New KB will be 63.2'. Thanks Dave! From: Boyer, David L (CED) [mailto:david.boyer2@alaska.gov] Sent: Wednesday, August 7, 2019 9:35 AM To: Cody Dinger <cdinger@hilcorp.com> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] MP 5-203 GL Change Hi Cody, Mel passed along the GL change for MP 5-203 well (37.4' to 36.7') from the recent As Built survey. In the proposed surveys that I loaded into GeoGraphix, the KB used was 63.9'. Since the RT to GL measurement will change by 0.7', will the new KB be 63.2' for planning purposes? I can make the change easily to our database. Thanks, Dave Boyer AOGCC The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e- mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. while all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. ' I I I PLANT 043 — Z� 115'00'00' 41 I GR/p L 27 25 25 30 G—PAD PAD TI 3N -IS-203 39 I GEODETIC I ■ 37 2 6 5 NO. COORDINATES COORDINATES POSITION(DMS) THIS PRTIOJECT_ & rc — BOX ELEV. OFFSETS 11 12 - _.- 7 I 8 N=2,237.01' 70'24'36.560" 70.4101557' 032 36.7' 3,228'FSL S-203 ■ 311 I 149'27'59.733" 149.4665924' . 503'FEL 0 281 E27m 25 0 24 023 0 22 I ■ 211 I 020 I 1 ■n I N 151 ■ u a1 I M12 ■ 16 ■ 91 Sf\12 7 j SECPON -7-4-56-- -------I �3 ' 0 I 0 °° 5a-04 ■ IID L I LJ _J U I ' I ' 1 GRAPHIC SCALE 0 BO 160 320 ( IN FEET) NOTES: 1 Inch — 160 fL 27 25 25 30 G—PAD PAD TI 3N 35 36 I 31 GEODETIC T1 2N I GRAVEL 2 6 5 NO. COORDINATES COORDINATES POSITION(DMS) THIS PRTIOJECT_ & rc — BOX ELEV. OFFSETS 11 12 - _.- 7 I 8 VICINITY MAP N.T.S LEGEND AS—BUILT CONDUCTOR ■ EASTING CONDUCTOR 1. DATE OF SURVEY: JULY 26, 2019 2. REFERENCE FIELD BOOK: HC19-04 PGS 07-08. 3. HORIZONTAL DATUM IS ALASKA STATE PLANE. ZONE 4, NAD27, 4. GEODETIC POSITIONS ARE NAD27. 5. PAD MEAN SCALE FACTOR IS 0.99990492 6. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MP S PAD OPERATOR MONUMENTS S -EAST, S -MID, AND S -WEST. 7. ELEVATIONS ARE MILNE POINT MEAN SEA LEVEL AA 10200 ti"*t3SItlNAL SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS—BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 26, 2019. COATED wn lnl PPnTPArTF'n sFr. 19_ L 17 W. R. 10 E.. UMIAT MERIDIAN, AK. WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEV. BOX ELEV. OFFSETS Y=5,999,892.50' N=2,237.01' 70'24'36.560" 70.4101557' 367' 36.7' 3,228'FSL S-203 X= 565,507.81' E= 6 369.90' 149'27'59.733" 149.4665924' . 503'FEL h pp DRAPER MR.A. ��I3ilcorp AlaskaAlaskaJAWEISME119 MPS 01 �„� MPU S PADscar: AEcc562 AS—BUILT CONDUCTORSMG 7 1• . 160' WELL S-203 un �... SnvvoD er cwc Transform Points Pu s-ao3 Source coordinate system Target coordinate system State Plane 1927 - Alaska Zone 4Albers al Area (-1511) Datum: NAD 1927 - North America Datum of 1927 (Mean) NAD 1927 - North America Datum of 1927 (Mean) ff e _val-ues i-nto -t-he s-rea-s- he -et- or copy -and paste ---c-olumn- s -of -data from a spreadsheet using the keyboard shortcuts Ctd+C to �opy and Ctd+V to paste. Then dick on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: I O "/Development Service —Exploratory Stratigraphic Test —Non -Conventional FIELD: M i ( L4 POOL: q h til, _ h d � A 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 rogram. 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)(2XB) and Regulation 20 AAC 25.071, composite curves for well logs ran 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, UGNU UNDEF WTRSP - 525120 PTD#:2191090 Company H_ilcorp Alaska LLC _ Initial Class/Type Well Name: MILNE PT UNIT S-203 Program DEV Well bore seg ❑ __DEV_L PEND GeoArea 890 Unit 11328 On/Off Shore On _ Annular Disposal ❑ Administration 1 Permit fee attached. _ NA 2 Lease number appropriate. _ _ _ _ _ _ _ _ _ _ Yes 3 Unique well. name and number _ _ _ _ _ _ _ _ _ ...... _ . Yes 4 Well located in a. defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __No... - _ Ugnu Undefined Pool- statewide spacing requirements apply._ _ 5 Well located proper distance from drilling unit boundary _ _ ..... _ . Yes 6 .Well located proper distance from other wells _ _ _ _ _ _ .. Yes 7 Sufficient acreage available in.dinUing unit...... _ .. Yes 8 If deviated, is wellbore plat.included _ _ _ _ _ _ .. Yes _ _ .... 9 Operator only affected party ..... Yes. 10 Operator has. appropriate bond in force _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yes 11 Permit can be issued without conservation order _ .. Yes Appr Date 12 Permit can be issued without administrativeapproval.. _ _ _ _ _ Yes 13 Can permit be approved before 15-day wait. .. _ _ _ Yes DLB 8/5/2019 - 14 Well located within area and strata authorized by Injection Order # (put 10# in comments). (For NA_ _ 15 All wells.within 1/4.mile area of review identified (For service well only). - _ _ _ NA. . 16 Pre-produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven, gas conforms to AS31,05.030Q.1.A),Q.2.A-D) 18 Conductor stringprovided _ _ . ................ . . . . Yes _ _ - 20" conductor fully cemented, Engineering 19 Surface casingprotectsall known USOWs _ _ _ _ _ _ _ _ _ _ . . . ......... . . . Yes Surface casing fully cemented with shoe placed in the target reservoir 20 CMT, vol adequate to circulate on conductor & surf csg _ .......... . . . . Yes _ Surface casing fully cemented with shoe placed in the target reservoir. 21 C.MT. vol adequate to tie-in long string to surf csg......... ... . . . . . . . . . . NA_ _ Surface casing fully cemented with shoe placesd in. the target reservoir 22 CMT. will cover all known productive horizons. _ _______ _ _ _ _ _ _ _ _ _ NA_ Surface casing fully cemented with shoe placed in the target reservoir 23 Casing designs adequate for C, T, B 8-permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 24 Adequate tankage or reserve pit _ _ _ _ - Yes _ _ ... Innovation rig has adequate pits and good truck supp-ort... 25 If a re-drill, has -a 107403 for abandonment been approved NA _ - - .. New grassroots well 26 Adequate wellbore separation proposed _ _ _ _ _ _ _ Yes _ MPU S-22 offset well fails the scan but has no HSE risk... 27 If diverter required, does it meet regulations _ _ _ ........ _ _ _ Yes - _ 18" diverter Appr Date 28 Drilling fluid program schematic & equip list adequate _ _ Yes _ _ All fluids planned to be overbalanced to pore pressure MGR 8/7/2019 29 BOPEs..do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ 1 annular, 3 ram stack with 3-1/8" Kill and Choke lines 30 BQPE.press rating appropriate: test to (put psig in comments)_ .. _ _ _ _ _ Yes _ _ 13-5/8".51M tested to 3000. psi . . . . . . . ........ . . 31 Chokemanifold complies w/API. RP-53 (May 84). _ _ _ _ _ _ _ _ Yes _ _ 2-9/16" ball valves throughout choke manifold .. _ 32 Work will occur without operation shutdown.. _ _ _ _ _ _ _ _ Yes No Operational shut downs planned._ 33 Is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ No - MPU S Pad isnot considered in H2S.pad 34 .Mechaniral.000dition of wells w4hin AOR verified (Forservice well only) _ _ _ _ _ _ _ _ _ _ _ NA ..... This is a development(produoer) well, ... . 35 Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ .. ....... Yes _ _ .. _ . No H2S anticipated .... . . . . . . .. . Geology 36 Datapresentedon potential overpressure zones _ - _ _ _ _ _ _ _ ... _ _ _ _ _ Yes ........ . . . . . . . . . . . . . . . ...... . Appr Date 37 Seismic analysis of shallow gas zones . . . . . . . . . . . ............ . . NA DLB 8/5/2019 38 Seabed condition survey (if off.-shore) __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA 39 Contact name/phone for weekly_ progress reports_ [exploratory only] _ ...... NA Geologic Engineering Public Initial Ugnu test well.... 5 wells planned in pilot project. Date: Date Date Commissioner: Commissioner: Commissioner �� 8�`�%�