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217-077
Reviewed By: P.I. 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Cook 2024-0803_Suspend_MPU_C-47_photos_gc Page 2 of 4 2024-0803_Suspend_MPU_C-47_photos_gc Page 3 of 4 Tubing Pressure Tubing-Casing Annulus (IA) Pressure 2024-0803_Suspend_MPU_C-47_photos_gc Page 4 of 4 Casing-Casing Annulus (OA) Pressure 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,115 feet 6,520 & 6,846 feet true vertical 7,035 feet 6,873 feet Effective Depth measured 6,448 feet N/A feet true vertical 4,788 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 / TC-II 2,337' 1,970' Packers and SSSV (type, measured and true vertical depth)NA NA NA 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Same 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Wells Manager Contact Phone: 9-5/8" NA NA Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 N/A measured true vertical Packer MD 151' Size 151' 4,886' Length Liner Casing Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 000 0 00 0 TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 217-077 50-029-23577-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047433, ADL0047434 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT C-47 Plugs Junk measured measured Conductor 6,590'Surface Production Liner 16"151' 6,564'5,750psi Burst NA Collapse NA 3,090psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:47 am, Aug 20, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.08.19 21:22:15 - 08'00' Taylor Wellman (2143) DSR-8/21/24 RBDMS JSB 082824 WCB 10-2-2024 ___________________________________________________________________________________ Updated by CJD 8/8/18 SCHEMATIC Milne Point Unit Well: MPC-47 PTD: 217-077 API: 50-029-23577-70(71, 72)-00 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16” Conductor 164/A-106B/Weld N/A Surface 151’ N/A 9-5/8” Surface 40/L-80/DWC/C 8.75” Surface 6,590’ 0.0758 TUBING DETAIL 4-1/2” Tubing 12.6/L-80/TC-II 3.958” Surface 2,337’ 0.0152 16” JEWELRY DETAIL No. Item Top MD 1 Cmt Retainer 6,520’ 2 ECP 6,846’ PBTD = 6,448’ MD / ±4,789’ TVD TD = 10,115’ MD / 7,034’TVD KB Elev Above Sea Level: 42’ / GL Elev: 15.2’ GENERAL WELL INFO API: 50-029-23577-[70,71,72]-00 Drilled and Cased by Innovation – 7/20/18 OPEN HOLE / CEMENT DETAIL Conductor Driven 12-1/4” 1st stage 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4” 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg On top of ECP 50 bbls 15.8 ppg Class G 2nd Attempt on Top of ECP 61 bbls 15.7 ppg Class G Thru/Top of Cmt Retainer 44 bbls 15.8 ppg Class G,±6bbl left on top of Retainer 2nd Attempt on Top of Cmt Retainer Post Rig – Coil MIRU and pumped 5 bbls of 15.8ppg Class G. Tagged TOC @ 6,448’ MD. WELL INCLINATION DETAIL KOP @ 294’ Max Hole Angle =66° 8-1/2” hole 10,115’ MD / 7,034’ TVD 9-5/8” 6,590 MD 4,886’TVD Top of Fish 6,873’ MD 1 2 4-1/2” TOC tagged @ 6,448’ MD MPC-47 suspended well inspection pics Sign Front Right side Back MPC-47 suspended well inspection pics Left side Backside from wellhead Left side from wellhead Right side from wellhead MPC-47 suspended well inspection pics Front side from wellhead TBG gauge IA gauge OA gauge MPC-47 suspended well inspection pics Cellar STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations Li Fracture StimulatLi Pull Tubing Ll Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulat Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ :rforate New Pool ❑ Repair We❑ Re-enter Susp Well ❑ Other: Inspect Well ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development [A Stratigraphic❑ Exploratory ❑ Service ❑ 217-077 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23577-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL047434 / ADL047433 MPU C-47 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Milne Point / Kuparuk River Oil 11. Present Well Condition Summary: Total Depth measured 10,115 feet Plugs measured 6,448 & 6,846 feet true vertical 7,035 feet Junk measured 6,873 feet Effective Depth measured 6,448 feet Packer measured N/A feet true vertical 4,788 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 151' 16" 151' 151' N/A N/A Surface 6,564' 9-5/8" 6,590' 4,886' 5,750psi 3,090psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6 / L-80 / TC -II 2,337' 1,970' Packers and SSSV (type, measured and true vertical depth) N/A N/A NIA N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 20 100 Subsequent to operation: 0 0 0 20 100 14. Attachments (required per 20 AAC 25.m0, 25.o7r, s 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development 21 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil L Gas[—WDSPL Printed and Electronic Fracture Stimulation Data El ❑ WINJ E] WAG ❑ GINJ ❑ SUSP ({bV SPLUG E] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A �(wrwr W Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: wrlyard(U7hilcorp.com Authorized Signature: Date: 8/14/2019 Contact Phone: 777-8547 r� q z� ly �y(�yRBDMSl1�'° UG 1 11019 Form 10-404 Revised 4/2017 Submit Original Only n KB Elev Above Sea Level: 42'/GL Elev: 15.2' 16" 4-1/2"e TOC tagged (a) ti 6,448' MD =w7- 9-5/8"6590 MID 1.886'TVI) PBTD = 6,448' MD /+4,789' TVD TD = 10,115' MD / 7,034'TVD SCHEMATIC Milne Point Unit Well: MPC -47 PTD: 217-077 - A P I : 50-029-23577-70(71, 72)-00 WELL INCLINATION DETAIL KOP @ 294' Max Hole Angle =66° JEWELRY DETAIL No.Item Top MD CASING DETAIL 6,520' 2 ECP 6,846' Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16" Conductor 164/A-306B/Weld N/A Surface 151' N/A 9-5/8" Surface 40/L-80/DWC/C 8.75" Surface 6,590' 0.0758 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 1 3.958" Surface 2,337' 0.0152 WELL INCLINATION DETAIL KOP @ 294' Max Hole Angle =66° JEWELRY DETAIL No.Item Top MD 1 Cmt Retainer 6,520' 2 ECP 6,846' OPEN HOLE / CEMENT DETAIL Conductor Driven 12-1/4" 1st stage 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg On top of ECP 50 bbis 15.8 ppg Class 2nd Attempt on Top of ECP 61 bbls 15.7 ppg Class G Thru/Top of Cmt Retainer 44 bbls 15.8 ppg Class G,±6bbl left on top of Retainer 2nd Attempt on Top of Cmt Retainer Post Rig — Coil MIRU and pumped 5 bbls of 15.8ppg Class G. Tagged TOC @ 6,448' MD. 8-1/2" hole 10,115' MD / 7,034' TVD GENERAL WELL INFO API: 50-029-23577-[70,71,72]-00 Drilled and Cased by Innovation —7/20 Updated by GD 8/8/18 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: - im iC, Inspector: t5 Well Name: PIS C -1y PTD No.: / 7 — 4 7 Location Verified? If Verified, How? �qh�«,� il^'�h 14Pi SaU tr.7 MOP Suspension Dale: sand Well Pressures (psi): Tubing �N IA OA g (f M Of ng Surface -^"d f5C5 Up Actions J: ts]o4e Operator { L C p ARF— Oper. Rep: _ /kry lk b Oper. Phone: (�70 `2991,'�)74 Oper Email:[ Date AOGCC Notified T' fia Type of Inspection: $ CAVA vjkg, Wellbore Diagram Avail.? Photos Taken? S Supry BY: PLB 17J2014 Newest Copy of Suspended Well Inspection Porm - Copy SC by Conductor Annulus Fill Coat Corrosion Inhibitor (Cl) Applications Well Field API PTD Treatment Date CI Fill Volume (gal) Final Cl Top END 2-14 DIU 50029216390000 1861490 10/29/2018 12 sand from 6' to within 1', surface MPC-45 MPU 50029235790000 2170920 10/1/2018 2 surface MPC-46 MPU 50029235760000 2170520 10/1/2018 5 sand from 8'to within 1', surface MPC-47 MPU 50029235770000 2170770 10/1/2018 8 surface MPF-106 MPU 50029236000000 2180280 10/1/2018 2 surface MPF-107 MPU 50029235920000 2180010 10/1/2018 18 surface MPF-108 MPU 50029235980000 2180210 10/1/2018 3 sand from 4-1/2'to within 1', surface MPF-109 MPU 50029235960000 2180140 10/1/2018 15 surface MPF-110 MPU 50029235990000 2180220 10/1/2018 2 surface MPL-46 MPU 50029235510000 2151180 10/1/2018 10 surface MPL-47 MPU 50029235500001 2151170 10/1/2018 3 surface MPL-51 I MPU 50029235870000 2171510 10/1/2018 4 surface MPL-52 MPU 50029235900000 2171740 10/1/2018 4 surface MPL-54 MPU 50029236070000 2180660 10/1/2018 6 surface MPL-56 MPU 50029236040000 218050 10/1/2018 2 surface MPL-57 MPU 50029236090000 2180720 10/1/2018 1 surface Suspended Well Inspection Review Report InspectNo: susBDB190805064725 Date Inspected: 8/1/2019 Inspector: Brian Bixby Type of Inspection: Subsequent ' Well Name: MILNE PT UNIT C-47 Date AOGCC Notified: 7/31/2019 Permit Number: 2170770 Operator: Hilcorp Alaska LLC Suspension Approval: Sundry # 318-287 Operator Rep: Matt Linder Suspension Date: 7/6/2018 Wellbore Diagram Avail? ❑� Location Verified? ❑r Photos Taken? O If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: 100 Fluid in Cellar? ❑ IA: 0 - BPV Installed? ❑ OA: 20 VR Plug(s) Installed? ❑ Wellhead Condition Good, Nice and clean Condition of Cellar Good Surrounding Surface Condition Good Comments Location verified by Bell Survey As Built pad map. Supervisor Comments Photos(2)attached ' 'q 14IL� Wednesday, August 14, 2019 f DATA SUBMITTAL COMPLIANCE REPORT �v 10/26/2018 a0 Permit to Drill 2170770 Well Name/No. MILNE PT UNIT C-47 n Operator HILCORP ALASKA LLC API No. 50-029-23577-00-00 MD 10115 TVD 7034 Completion Date Completion Status SUSP Current Status SUSP UIC No REQUIRED INFORMATION / Mud Log No/ Samples No,/ Directional Survey Yes v DATA INFORMATION List of Logs Obtained: ROP, DGR, EWR, ALD, CTN, ABG, MD, TVD Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data ED C 28614 Digital Data Log C 28614 Log Header Scans ED C 29578 Digital Data (from Master Well Data/Logs) Interval OH/ Start Stop CH Received Comments 110 10293 9/21/2017 Electronic Data Set, Filename: MPU C- 47PB1_DGR_ABG_EW R_ADR.las 9/21/2017 Electronic File: MPU C- 47PB1_DGR_ABG_EWR_ADR MD Final.cgm 9/21/2017 Electronic File: MPU C- 47PB1_DGR _ABG_EWR_ADR TVD Final.cgm 9/21/2017 Electronic File: MPU C-47 PBI - Definitive Survey.pdf 9/21/2017 Electronic File: MPU C-47 PBt_GEO.txt 9/21/2017 Electronic File: MPU C-47 PBt_GIS.txt 9/21/2017 Electronic File: MPU C- 47PB1 DGR ABG EWR ADR MD Final.emf 9/21/2017 Electronic File: MPU C- 47PB1_DGR_ABG_EWR_ADR TVD Final.emf 9/21/2017 Electronic File: MPU C- 47PB1_DGR_ABG_EWR_ADR MD Final.pdf 9/21/2017 Electronic File: MPU C- 47PBI_DGR_ABG_EWR_ADR TVD Final.pdf 9/21/2017 Electronic File: MPU C- 47PB1_DGR_ABG_EWR_ADR MD Final.tif 9/21/2017 Electronic File: MPU C- 47PB1_DGR_ABG_EWR_ADR TVD Final.tif 0 0 2170770 MILNE PT UNIT C-47 PI31 LOG HEADERS 110 10492 8/8/2018 Electronic Data Set, Filename: MPU C- 47PB2_DGR_ABG_EWR_ALD_CTN.las AOGCC Page I of 4 Friday, October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2170770 Well Name/No. MILNE PT UNIT C-47 Operator HILCORP ALASKA LLC API No. 50-029-23577-00-00 MD 10115 TVD 7034 Completion Date Completion Status SUSP Current Status SUSP UIC No ED C 29578 Digital Data 8/8!2018 Electronic File: MPU C- 47PB2 DGR_ABG_EWR_ALD_CTN MD Final.cgm ED C 29578 Digital Data 8/8/2018 Electronic File: MPU C- 47PB2_OGR_ABG_EWR_ALD_CTN TVD Final.cgm ED C 29578 Digital Data 8/8/2018 Electronic File: C-47 PB2 Definitive Survey Report.pdf ED C 29578 Digital Data 8/8/2018 Electronic File: MPU C-47 PB2 - Definitive Survey.txt ED C 29578 Digital Data 8/8/2018 Electronic File: MPU C47 P132 - GIS.w ED C 29578 Digital Data 8/8/2018 Electronic File: MPU C- 47PI32_DGR_ABG_EWR_ALD_CTN MD Final.emf ED C 29578 Digital Data 8/812018 Electronic File: MPU C- - 47PB2_DGR_ABG_EWR_ALD_CTN TVD Final.emf ED C 29578 Digital Data 8/8/2018 Electronic File: MPU C- 47PB2_DGR_ABG_EWR_ALD_CTN MD Final.pdf ED C 29578 Digital Data 8/8/2018 Electronic File: MPU C- 47PB2—DGR _ABG _EWR_ALD _CTN TVD Final.pdf ED C 29578 Digital Data 8/8/2018 Electronic File: MPU C- 47PB2_DGR_ABG_EWR_ALD_CTN MD Final.tif ED C 29578 Digital Data 8/8/2018 Electronic File: MPU C- 47PB2 DGR_ABG_EWR_ALD _CTN TVD Final.tif Log C 29578 Log Header Scans 0 0 2170770 MILNE PT UNIT C47 LOG HEADERS Log C 29579 Log Header Scans 0 0 2170770 MILNE PT UNIT C-47 LOG HEADERS ED C 29579 Digital Data 110 10116 8/8/2018 Electronic Data Set, Filename: MPU C- 47PB3_DGR_E W R_ALD_CTN.las ED C 29579 Digital Data 8/8/2018 Electronic File: MPU C- 47PB3_DGR_EWR_ALD_CTN MD Final.cgm ED C 29579 Digital Data 8/8/2018 Electronic File: MPU C- 47PB3_DGR_EWR_ALD_CTN TVD Final.cgm AOGCC Page 2 of Friday, October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2018 Permit to Drill 2170770 Well Name/No. MILNE PT UNIT C-47 Operator HILCORP ALASKA LLC MD 10115 TVD 7034 ED C 29579 Digital Data ED C 29579 Digital Data ED C 29579 Digital Data ED C 29579 Digital Data ED C 29579 Digital Data ED C 29579 Digital Data ED C 29579 Digital Data ED C 29579 Digital Data ED C 29579 Digital Data Well Cores/Samples Information: Name INFORMATION RECEIVED Completion Report Y Production Test Information Y / NA Geologic Markers/Tops Y COMPLIANCE HISTORY Completion Date: Release Date: 6/1/2017 Description API No. 50-029-23577-00-00 Completion Date Completion Status SUSP Current Status SUSP UIC No 8/8/2018 Electronic File: C-47FW Definitive Survey Report - Signed.pdf 8/8/2018 Electronic File: MPU C-47 PB3 - Definitive Survey.td 8/8/2018 Electronic File: MPU C-47 PB3 - GIS.txt 8/8/2018 Electronic File: MPU C- 47PB3_DGR_EWR_ALD _CTN MD Final.emf 8/8/2018 Electronic File: MPU C- 47PB3_DGR_EWR_ALD_CTN TVD Final.emf 8/8/2018 Electronic File: MPU C- 47PB3_DGR_EWR_ALD_CTN MD Final.pdf 8/8/2018 Electronic File: MPU C- 47PB3_DGR _EWR_ALD_CTN TVD Final.pdf 8/8/2018 Electronic File: MPU C- 47PB3_DGR_EWR_ALD_CTN MD Final.tif 8/8/2018 Electronic File: MPU C- 47PB3_DGR_EWR_ALD_CTN TVD Final.tif Sample Interval Set Start Stop Sent Received Number Comments Directional / Inclination Data Y Mechanical Integrity Test Information Y / NA Daily Operations Summary Y Date Comments Mud Logs, Image Files, Digital Data Y / NA Core Chips Y / NA Composite Logs, Image, Data Files Y Core Photographs Y / NA Cuttings Samples Y / NA Laboratory Analyses Y / NA AOGCC Page 3 of 4 Friday, October 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 10/28/2018 Permit to Drill 2170770 Well Name/No. MILNE PT UNIT C-47 Operator HILCORP ALASKA LLC MD 10115 TVD 7034 Completion Date Completion Status SUSP Current Status SUSP Comments: Compliance Reviewed By: J API No. 50-029-23577-00-00 UIC No Date: AO<'< < Page 4 of 4 Friday, October 26; 2018 -b-4-7 vebra Oudean Hilcorp Alaska, Lia: GeoTech 3800 Centerpoint Drive, Suite 1400 r�}° Anchorage, AK 99503 S Tele: 907 777-8339 Ailn�rp ,u ... k., t.la: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 11/19/2018 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU C-47 PB2 + PB3 Digital Data Resubmit corrected API number and well number in the las data Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Date: I l b -(a 116 Guhl, Meredith D (DOA) From: Debra Oudean <doudean@hilcorp.com> Sent: Monday, November 19, 2018 11:48 AM To: Guhl, Meredith D (DOA) Subject: RE: MPU C-47 PB2, PTD 217-077, LAS file incorrect Attachments: MPU C-47 PB2_PB3 AOGCC 111982018.doc; MPU C-47PB2 _DGR_ABG_EWR_ALD CTN.las; MPU C-47PB3_DGR_EWR_ALD_CTN.las Meredith, Attached is the corrected data for MPU C-47 PB2 Debra A. Oudean AK_GeoTech From: Guhl, Meredith D (DOA)[mailto:meredith.guhl@alaska.gov] Sent: Friday, October 26, 2018 12:21 PM To: Debra Oudean <doudean@hilcorp.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: MPU C-47 P132, PTD 217-077, LAS file incorrect Debra, Please submit a corrected LAS file for MPU C-47 P62, as the API number and well name in the file are incorrectly labeled PB1 and 50-029-23577-70. Please provide the updated LAS file by November 14, 2018. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 mered ith.au h I @a laska.aov Direct: (907) 793-1235 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 a -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 Meredith GuhI at 907-793-1235 or meredith.zuhl@alaska.eov. MPU C-47 (PTD 217-077) Note to File Per the Well Completion Report received 8/8/2018, after drilling two sections of lost hole (Plugbacks "PB1" and "P62"), after drilling operations reached a TD of 10,115' MD / 7034' TVD, the drill string became stuck. Many attempts to free it were unsuccessful, and it was subsequently backed -off leaving the top of the fish at 6873' MD / 5080' TVD within the section of hole that the Operator currently terms "PB3." The well was suspended by placing a cement plug across the 9-5/8" casing shoe at 6,590' MD / 4887'TVD. S Davies 8/17/2018 2 asm. V`Y V L. LO STATE OF ALASKA AUG 0 8 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION _ WELL COMPLETION OR RECOMPLETION REPORT A ta, Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑� • 20A 025.105 20A 025.110 GINJ ❑ WINJ ❑ WAG[—] WDSPL ❑ No. of Completions: _ 0 ib. Well Class: Development Q Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Abend.: 7/6/2018 14. Permit to Drill Number / Sundry: •217-077, 318-196, 318-287 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: June 28, 2017 15. API Number: 50-029-23577-[70,71,72]-00 4a. Location of Well (Governmental Section): Surface: 722' FSL, 2304_' FEL, Sec 10, T13N, R10E, UM, AK Top of Productive Interval: N/A Total Depth: 225' FSL, 1722' FWL, Sec 2, T13N, R10E, UM, AK 8. Date TD Reached: June 20, 2018 16. Well Name and Number: 'MPU C-47 (PB1, PB2, PB3 9. Ref Elevations: KB: 42' • GL:15.2' BF:15.2' ' 17. Field / Pool(s): Milne Point Unit Kuparuk Oil Pool 10. Plug Back Depth MDfTVD: 6,448' MD / 4,789' TVD 18. Property Designation: ADL047434 / ADLO47433 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558156 - y- 6029004 - Zone- 4 TPI: x- N/A y- N/A Zone- Total Depth: x- 562139 y- 6033818 Zone- 4 11. Total Depth MD/TVD: • 10,115' MD / 7,034' TVD' 19. DNR Approval Number: LONS 84-123 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1,929' MD / 1,674' TVD 5. Directional or Inclination Survey: Yes : (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MDfFVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ROP DGR EWR ALD CTN ABG MD & TVD 21N/51N for [PB1 (sent previously), PB2, PB3] 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MHOLE SIZE CEMENTING RECORD D SETTING DEPTH TVD AMOUNT TOP BOTTOM TOP BOTTOM PULLED 16" 164# A -106B Surface 151' Surface 151' Conductor Driven 9-5/8" 40# Stg1 L-700 sx/T-295 sx 67 bbls L-80 Surface 6,590' Surface 4,887' 12-1/4" Stg 2 L - 335 sx / T - 175 sx 185 bbis 24. Open to production or injection? Yes ❑ No Q If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): S,ec- rAc 6 5L-Ye`''dLeA 1 I 11 eetVlPCETt0fVE — r].jT /r G JVtR1�FIE/D! =LJ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 2,337' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casing Press: I lCalculated 124 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/20'lBDMS_"UG 17 2010 CONTINUED ON PAGE 2 Y aK,� f( ��{�/3riA+Submit ORIGINIAL only. 28. CORE DATA Conventional Core(s): Yes ❑ No Sidewall Cores: Yes ❑ No ❑✓ ' If Yes, list formations and intervals cored (MDfTVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 1,929' 1,674' Attach separate pages to this farm, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. "'See attachment for details— Formation at total depth: 31. List of Attachments: Wellbore Schematic, Drilling Reports, Definitive Surveys (PB1, PB2, PB3), Csg and Cmt Report, Geologic Marker Details. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drillin Manager Contact Email: -Cdi0-qer@1JIcorp.com AuthorizedQ Contact Phone: 777-8389 Signature: Date. ( 7 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 41b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, Fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only MPU C-47 Formation Markers C-47 PB1 tops Top MD TVD Base Permafrost 1929 1674 Top Ugnu 3263 2605 Top Schraeder 5703 4284 Base Schraeder 6448 4788 Top HRZ 9287 6750 Base HRZ 9535 6896 Top Kup C 10217 7152 Base Kup C 10269 7167 Top Kup A 10437 7313 C-47 PB2 tops Top MD TVD Base Permafrost Top Ugnu Top Schraeder Base Schraeder Top HRZ 9808 6769 Base HRZ 9835 6792 Top Kup C 10249 7150 Base Kup C 10269 7167 Top Kup A 10437 7313 TD in Kup A C-47 PB3 tops Top MD TVD Base Permafrost Top Ugnu Top Schraeder Base Schraeder Top HRZ 9,799 6,769 Base HRZ 9,884 6,840 Top Kup C Base Kup C Top Kup A TD in Kup A I fol am, vim KOP above HRZ TD in KUP A KOP above HRZ TD below Base HRZ I Flilmra At—ke, LLC. KB Elev Above Sea Level: 42'/GL Elev: 15.2' VAFIA 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg IA90 N1 16"' Wt/Grade/Conn Drift ID Top Btm BPF .y Conductor 164/A-106B/Weld N/A Surface 151' N/A 4 Surface 4-1/2" V� TOC tagged (W. � Cwt Top of Fish 6,873' MD 6. Driven CASING DETAIL 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 9-5/8" 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg IA90 N1 Type Wt/Grade/Conn Drift ID Top Btm BPF 16" Conductor 164/A-106B/Weld N/A Surface SCHEMATIC Milne Point Unit Well: MPC -47 PTD: 217-077 API: 50-029-23577-70(71, 72)-00 tlM r/ 8-1/2" hole 111 10,115' MD / 7,034' TVD Q-� i I'll Ie GENERAL WELL INFO WELL INCLINATION DETAIL API: 50-029-23577-[70,71,721-00 KOP @ 294' Drilled and Cased by Innovation —7/20/18 Max Hole Angle =66' JEWELRY DETAIL No. Item Top MD 1 Cmt Retainer 6,520' 2 1 ECP 6,846' OPEN HOLE / CEMENT DETAIL Conductor Driven CASING DETAIL 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16" Conductor 164/A-106B/Weld N/A Surface 151' N/A 9-5/8" Surface 40/L-80/DWC/C 8.75" Surface 6,590' 0.0758 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 1 3.958" Surface 2,337' 0.0152 tlM r/ 8-1/2" hole 111 10,115' MD / 7,034' TVD Q-� i I'll Ie GENERAL WELL INFO WELL INCLINATION DETAIL API: 50-029-23577-[70,71,721-00 KOP @ 294' Drilled and Cased by Innovation —7/20/18 Max Hole Angle =66' JEWELRY DETAIL No. Item Top MD 1 Cmt Retainer 6,520' 2 1 ECP 6,846' OPEN HOLE / CEMENT DETAIL Conductor Driven 12-1/4" 1st stage 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg On top of ECP 50 bbls 15.8 ppg Class G 2nd Attempt on Top of ECP 61 bbls 15.7 ppg Class G Thru/Top of Cmt Retainer 44 bbis 15.8 ppg Class G, t6bbl left on top of Retainer 2nd Attempt on Top of Cmt Retainer Post Rig — Coil MIRU and pumped 5 bbls of 15.8ppg Class G. Tagged TOC @ 6,448' MD. [PBTD =6,448'MD/14,789'TVD D _ 10,115' MD / 7,034'TVD Updated by CID 8/8/18 n Well Name: MP C-47 Field: Milne Point County/State: , Alaska (LAT/LONG): ovation (RKB): API #: Hilcorp Energy Company Composite Report Spud Dale: 6/282017 Job Name: 1710174D MPC -47 (1) Drilling Contractor Innovation AFE #: AFF $ ActimityDatel ops ,summar. 6/25/2017 Continue R/D svc lines throughout rig. Secure stairways. Remove cuttings boxes and containment. Install cross beams in cellar for mob. Peak trucking on location @ 21:40 hrs.;Demob pipeshed, gen module, pits and catwalk. Stage on location. Demob sub off well C-46.;Walk sub in line with well row. Install wheels and tow bar. Install flowbox and take measurements for flowline modification. Build flowline. Mob down well row and spot sub.;Spin sub and walk over well 047. Verify sub is ctr over conductor. Notification sent via email for diverter test to AOGCC 05:51 his 626/17. 6/262017 Spot catwalk, Pipeshed, Pits, & Gen mod. Continue working on flow line & Flow box modifications. Release trucks at 12:00. Work on both centrifuges (found feed tubes in poor condition).;Shim sub with 1.125 strips. Hook up interconnects. Trouble shoot MP#1 Drive . Open up MP#1&2 and replace valves and seats as needed. Continue working on flow line & Flow box modifications.;Cont flowbox/flowline modifications. R/U pits. Service rig and ready handling equipment. C/O saver sub w/ new DS -50 thread. RKB / GL = 26.89', RKB/Wellhead = 25.96'.;Load, strap and tally 210 total its 5", DS -50. Work on pre -rig acceptance checklist. Troubleshoot TDS enable function. Electrician found loose connection on fiber optic com Iine,;Continue working on flowbox and flow ine modifications (1° drop F/ flowbox - T/ corner, 1.6° drop F/ comer - T/ shakers). Cont C/O saver sub. Cont load 5" DP.;Contmue working on rig acceptance checklist. Put steam throughout rig.;WU diverter stack. Install knife valve, NN diverter line. Plumb inlet lines and drains. Plumb in flowline innerconnect.;Hauled 520 table H2O from B -Pad for total = 520 bbls 6272017 Ri Acce ted at 0600: Continue to N/U diverter system & BOPS. Function test same. GOOD. Move water around pits and check lines. Good.;Build high vis pi I &Test hopper and charge pumps. Good. Perform PMs on MP #1&2.;Perform state whiteness diverter test and rig inspection with MR Matt Herrera & Laubenstein, All tests passed. Annular closed in 12 sec & Knife valve opened in 4 sec ;Test gas alarms.;Slate did request the certification showing the math for the N2 Back up system sized for our accumulator. We sent in and added to our O drive paperwork.;Altempt to set wear bushing. Unable to get WB past bag. After function test there is a piece of rubber hanging in the slack. Remove Flow riser to inspect annular.;Dress annular and inspect. Remove loose chunk of annular. Send in pics to town. Annular looks ok to run.;Work on TD leak. Open top panel and remove manifold to get to leak, tighten 11 plugs on hydraulic manifold, re -assemble same, function test system, no Ieaks.;Finish plumbing jet into flow box. Finish installing cellar drain pan.;Install 12 3/8" wear bushing, PJSM. Drift and P/U 210 joints 5" DS -50 drill pipe racking 105 stds in derrick. Load 8.7+ ppg spud mud into pits. Note: tag bltm @ 45'.;Drift and P/U 17 jts 5" HWDP and jars racking in derrick.;NVU top drive on single, Fill diverter stack and lines w/ mud, good. Test mud pumps and surface lines to 3000 psi, good. Pump 700 gpm, flow box works well w/ fluid 3" from top flowline.;WU conductor cleanout BHA, 12 1/4" VAREL RS616GI HX PDC bit, mud motor, 12 1/8" stab, 1012" IBS, X0= 36.11'. WU 1 std 5" HWDP and top drive, break circulation, tag @ 45'. 628/2017 Dr 11 out conductor F/ 45'T1 11L_ 360 GPM, 280 psi, 30 RPM. Circ clean before shutting pumps down 30 min. Working flow line jets & running through bleeder while making connections.;POOH & Stand back HWDP. P/U 2 NMFDC & RIH.;Drill out conductor F/ 160'T/ 177'. Drill ahead F/ 17T T/ 289. @ 360 GPM, 30 RPM, 100-150 FPH. Working flow line jets & Running 500 GPM on bleeder while making conneclions.;Pump out slow letting the hole cleanup F/ 288'T/ 215'. POOH & stand back HWDP & Drill collam.;WU BHA #1, 12.25 PDC Motor BHA. Carry scribe through MWD & UBHO. Check UBHO with Halliburlon Gyro. Good. Download MWD, R/U Gyro & Hang shieve in demick.;TIH to 216', wash down to 288' pumping 350 gpm, 350 psi.;Rotary drill 12 1/4" hole f/ 288' to 309 400 gpm, 720 psi, 40 rpm, 1.5k tq. Note: Run Gyro every stand drilled.;Directional drill @ KOP, 70 deg per DD f/ 309'to 399', Rack 1 std back, M/U single HWDP w/ jam, Gyro survey.;Directional drill f/ 399' to 961'(562') AROP 112 FPH (232 FPH on btm) GPM 480, 1300 PSI WOB 5-8k, 70 RPM, 3.6K TO MW 9.1/ Vis 200, ECD 9.7 PU/SO/ROT 69/69/69 Final gyro @ 72871st MWD survey @ 788';Directional drill f/ 961'to 1763'(802') AROP 133.6 FPH (200 FPH on btm) GPM 583, 1700 PSI W OB 5-10k. 70 RPM, SK TO MW 9.1/210 Vis, ECD 9.9 PU/SO/ROT 81/73/76.;Pump 30 bbl hi vis sweeps @ 967' and 1480' w/ 200% increase at shakers, mostly clay. Note: R/D and release gyro @ 1300' 3.61 slide has, 2.72 rotate hrs. Currently 11.75' above the line, 8.04' righl.;Daily losses to formation= 0 bbls for total= 0 bbls;Hauled 515 bbls cutting to G&I for total = 515 bbls Hauled 0 phis H2O from 6 mile lake for total = 0 bbl 6/29/2017 Directional drill 12 1/4" hole F/ 1763'T/ 2530'(767') AROP 128 FPH (250 FPH on bim) GPM 475- 550,1750 PSI WOB 1-6k, 70 RPM, 5K TO MW 9.21150 Vis, ECD 9.9 PU/SO/ROT 130/87/77.;Sweeps @ 2090'100 % Increase, Dropped vis from 206+ to 120- 150, 500' after permafrost @ 2500'. Screen up from 80s to 100s @ 2000' due to sand content 1%. Perform screen test with new screens.;Directional drill F/ 2530' T/ 3285'(755') AROP 125 FPH (250FPH on blm) GPM 525- 580, 1750 PSI WOB 6-10k, 80 RPM, 8K TO MW 9.2/150 Vis, ECD 9.9 PU/SO/ROT 130/87/77.;Direclional drill F/ 3285' T/ 4145'(860') AROP 143 FPH (246 FPH on him) GPM 530, 1750 PSI WOB 6-10k, 70 RPM, 8-9kK TO MW 9.4/110 Vis, ECD 10 PU/SO/ROT 1421851106.;Pump 25 bbl hi vis sweep @ 3520', sweep back 1000 stks early, 50% increase in cuttings.;Directional drill F/ 4145' T/ 4867'(722') AROP 120 FPH (200 FPH on him) GPM 530, 1800 PSI WOB 6-14k, 80 RPM, 11-13kK TO MW 9.2/110 Vis, ECD 10.3 PU/SO/ROT 158/91/117.;Pump 25 bbl hi vis sweeps @ 4170' and 4725', sweeps back 1000 silks early, 50% increase in cuttings on 1st sweep, 50% increase on 2nd Dump and dilute to help maintain mud wl.;Currenthy.41' below the line, 2.05' right 10.9 rotate Ins, 3.37 slide hm.;Daily losses to formation= 0 bbls for total= 0 bbls;Hauledl254 bbls cueing to G&I for total = 1769 bbls Hauled 390 bbls H2O from 6 mile lake for total = 390 bbi 6/30/2017 Directional drill 12 1/4" surface hole F/ 486T T/5612 '(745') AROP 124 FPH (200 FPH on him) GPM 550, 2150 PSI WOB 4-12k, 80 RPM, 13-161< TO MW 9.2/110 Vis, ECD 10.3 PU/SO/ROT 180/96/130.;Hold back ROP to 150-200 due to G&I Backing up. Add dilution mud to lower ECDs. Pump sweeps @ 4725', 5300', 5880', sweeps back 800 silks late, 20-50% increase.;Directional drill F/ 5612' T/ 6089'(447') AROP 79.5 FPH (110 FPH on him) GPM 550, 2150 PSI WOB 10-20k, 80 RPM, 15-18kK TO MW 9.2/110 Vis, ECD 10.1 PU/SO/ROT 195196/133.;Directional drill F/ 6089'T/ 6600 @ TD'(51 V) AROP 93 FPH (156 FPH on Elm) GPM 550, 2150 PSI WOB 12-14k, 80 RPM, 18-191< TO MW 9.5/110 Vis, ECD 10.5 PU/SO/ROT 200/100/136.;TD surface section 200' past Schrader bluff formation per Hilcorp Geo in heavy clay interval. 1.75 slide hrs. 10.92 rotate hrs. 13.67' above the line, 4.87' left. Verify drill pipe count.;Pump 30 bbl hi vis sweep, Circulate and condition for casing 550 gpm, 2100 psi, 80 rpm, lower YP from 47 to 19 and vis to 60 over 3+ circulations. Sweep back 1000 stks early, 10% increase.;Flowcheck well, static. Pump out of hole 500 gpm, 1500 psi f/ 6609to 6062' w/25k overpull, backream to 6040', continue to pump out f/ 6040'to 5616'.;Daily losses to formation= 0 bbls for total= 0 bbls;Hauled 1254 bible curling to G&I for total = 3023 bbls Hauled 780 bbls H2O from 6 mile lake for total = 1170 bbl Hauled 280 bbls H2O from B-Pad for total = 2560 bbl 7/1/2017 Pump Out of the hole F/ 5616'T/ 3930'. 500 GPM 10-15 K over Pulls. Pulling slow getting heavy mud back. Connections are very tight. Having to take the time to break out slow.;Back ream slow F/ 3930' T/ 3650'& let well clean up. Getting fine sand and silt over shakers & 10 PPG mud in returns. Connections are very tight. Having to take the time to break out slow.;Pump Out of the hole F/ 3650'T/2600'. 500 GPM Over Pulls. 2780' 40K.;Pump Out of the hole F/ 2600' T/2050'500 GPM Over Pulls. Pull slow F/ 2050' T/ 1900' Circ him up before gelling to permafrost. Getting fine sand and silt across shakers. Small chunks of coal.;Pull on elevators F/ 190Y T/ 1700'. Pulling 25K over. Started swabbing.;Continue to Pump Out of the hole F/ 1700'T/1500'. 500 GPM. Pulling good.;Continue to Pump Out of the hole F/ 1500'T/709' @ HWDP pumping 500 GPM, Pulling good.;POOH on elevators F/ 709', L/D 6 jts HWDP ( note: replace HW jt #11 VI/ jt # 12 due to nick on tool face) rack 6 aids HWDP w/ jars in derrick. Note: Strip tool jts packed w/ clay Throughout the tnp.;UD 2 Flex collars, UBHO, Strip clay from BHA, download MWD and UD directional tools, drain motor, UD motor and bit. Grade= 2/3/CT/S/X/I/NO/TD. String stab slight leading edge wear, both in gauge.;Clear and clean rig floor, load out tools from pipeshed. Pull 12 3/8" wear bushing.;R/U 9 5/8" handling equipment, R/U volant tool, torque to 39 fl/lbs, hold plsm with HES, Weatherford, rig crew.;Ensure no debris, P/U, Baker lock and M/U 9 5/8" shoe track, shoe jt w/ 2 centralizers 10' from ea. end over slap collars, 1 centralizer mid tube over stop collar on 2 FC jis.;Ensure proper float operation, Bakerloo and WU BAjt w/ centralizer mid tube over stop collar, PIU and RIH w/ 9 5/8" DWC/C, L-80 40# casing per tally, use BOL 2000 pipe dope.;Utilize dog collar clamp on 1st 5jls ran, torque casing to optimum 32300 f fibs. RIH @ moderate speed, Fill on the fly and every 5 jts ran, RIH to 784' ( 19 its ran );Daily losses to formation= 0 bbls for total= 0 We Hauled 450 bible H2O from L-Pad lake for total = 450 bbl;Hauled 523 We cutting to G&I for total = 3546 bbls Hauled 300 bbls H2O from 6 mile lake for total = 1470 bbl 7/2/2017 Run 9 518 40 # Casing F/ 908'T/ 3090'. Tq Connections to 32000#. Fill on the fly and top off every 5 joints with CRT. Well not loosing on the trip. Break circ every 10 joints.;Had to Rot past ledge at 1193'. 10 RPM 9K tq @ 4 bpm. Went right past.;Circ & condition mud staging pumps up to 6 bpm. ICP 130 FCP 65. Getting 9.7 PPG mud back. Circ two btm up. 9.4 in and out. UP/DN 141/95.;Continue to Run 9 5/8 40# Casing F13090! T/5000'. Tq Connections to 32000#. Fill on the fly and top off every5 joints with CRT. Well not losing on the trip. Break circ every 10joints.;Circ & condition mud staging pumps up to 6 bpm, ICP 200 psi 9.6+/ FCP 170 psi CBU until 9.4+ in and out. UP/DN 2110/110.;Continue to Run 9 518 40# Casing F/ 5000' T/6512". Tq Connections to 32000#. Fill on the fly and top off every 5 joints with CRT. Break circ every 10 joints. Correct displacement on trip in.;Wash last 2 jts down pumping 2 bpm, 180 psi to 6590' on depth, 160 jts ran, 7 jts left out. UP/DN 300/130.;Cimulate and condition for cement job, reciprocate slow 201, rotate 2 rpm, 25k tq, stage pump up slow from 2 bpm, 3 bpm 180 psi, 4 bpm 200 c o-< psi, 5 bpm 210 psi, 6 bpm FCP 170 psi. No losses.:PJSM for pumping 1st stage cement iob. Shut down, close upper and lower IBOP, RIU cement line and valves.;Conlinue to circulate, reciprocate and rotate, stage to 5 bpm, 260 psi, shut down pump, R/U cement line, pump 5 bible water. PT lines to 1000 psi low/ 4000 psi high, good.;Mix and pump 60 6bls 10.5 ppg tuned spacer 3 bpm, 50 psi, note: add red dye to first 10 bbis pumped. shut down, drop bypass plug. `y Y 7 01:22 start batching lead cement.;Pump 307.9 bible 11.7 ppg extends cam lead cement( 700 sx, 224 bbis mix water, 2.248 YP ) 5 bpm, 420 psi, 142 bible away slow pump to 2 bpm 100 psi for 20 bbis w/ bypass plug passes stage tool.;Pump 60.7 bbis 15.8 ppg swift cem tail cement( 295 sx, 35 bble mix water, 1.156 4 \y P ) 3.5 bpm, 400 psi. Shutdown, drop wiper dart, pump 20 bbis water 3.5 bpm, 115 psi. Swap to rig pump.;Displace with 277.6 bbls 9.4+ ppg mud pumping bpm 70 psi,1600 stks slow pump to 2 bpm 30 psi for 20 bible until wiper dart passes ESC tool. 200 bible pump caught pressure 250 psi.;Swap to cementers, [� pump 80 bbis water 5 bpm, 585 ps with pressure climbing to 795 psi. Swap to rig. Note: unable to rotate and reciprocate when pumping water, park casing on depth.;Displace with 112.1 bbls 9.4+ ppg mud pumping 4 bpm 680 psi, FCP 940 psi, bump plug on calculated stks. Pressure up 500 psi over FCP @ 1500 psi, and hold. CIP @ 05:32.;Bleed off pressure float held. Pressure up to 2850 psi and open ESC tool.;Pump 3 bpm, 270 psi lhru ESC @ 200T, 18.6 bbis away see spacer with red dye @ returns, start pumping black water to annulus wl trip tank pump, see cement @ returns 45.88 bbis away.;Spacer and 67 bbis good cement returned to surface. Total estimated losses 62 bbls throughout cement job.;Daily losses to formation= 0 bible for total= 0 bible Hauled 0 bible H2O from L -Pad lake for total = 450 bbl;Hauled 114 bbis cutting to G&I for total = 3660 bible Hauled 600 bible H2O from 6 mile lake for total = 2070 bbl 7/3/2017 Circ out cml from Es end tool @ 2007' after opening tool. 3 bpm, for first btm up. Got back mud push, 67 bbl end and 40 bbl water. Stage up pumps to 6 bpm & circ clean.;Shut down & Flush all surface equipment with black water, Continue to simulate through stage tool @ 6 bpm while waiting on cml. MW 9.4 1n and out.;PJSM second stage cmt tool. Break out Volant tool and re-engage before second stage cmt job.;Pump second stage end job as follow 5 bbl fresh water, 60 bbl 10.5 ppg Tuned spacer, 258.7 bbl Lead cmt,335 SX (ra 10.7 ppg, Perm L Cmt. Pump 36.2 bbl Tail 15.8 PPG, Drop Plug Displace with 20 bbls'Halliburton Displace with 20 bbl H2O, Rig pump 132 bbl mud & bump on calculated strokes. Final lift pressure 630 psi, Pressure up and close cmt tool @ 1200 psi. Pressure up to 2000 psi & Hold good.;Bleed down and check now. Good. CIP @ 15:36. Got back 60 bbl mud push, 185 bbl good 5 end to surface. 9 bbl total losses calculated for second stage cmt job.;R/D Volant tool and Weatherford equipment. Drain stack and flush all surface equipment with black water. Blow down cmt lines, Remove Diverter line, Riser. Pick stack & prep to set slips.;Center up 9 518" casing, set E -slips per wellhead rep with 275k on slips. Welder cut casing, UD cut jt Continue to clean in mud pits.;Set stack down and flange up. Install riser, C/O casing elevators to 6' drill pipe elevators. MJU accumulator hyd lines to stack. M/U flush tool on jt of DP, pump and flush stack. UD flush tool.;N/D stack diverter, break flange bolts, rack back BOP, remove diverter tee from cellar. Vac out cellar box.;Cut off and dress 9 518" casing stub total cut jt 31.27) install 7" x 11" 5m multi bowl and flange up same. Install packing per wellhead rep, test void to 500 /3780 psi 5 min ea. good test.;N/U 11 x 13 5/8" DSA, set BOP stack and flange up to DSA, install kill and choke lines, tum buckles, riser, drip pan and hole fill Iine.;Open BOP doors and inspect ram cavities, button up same. Install 1502 outlets on annulus. Install mouse hole.;R/U test equipment with 5" test jt. ready for State witness BOP test. Load pits with 290 bible 9.5 LSND mud.;lnspect and C/O saver sub;Daily losses to formation= 72.1 bbis for total= 72.1 bbls Hauled 1200 bible H2O from L -Pad lake for total = 1800 bbl;Hauled 2162 bible cutting to G&I for total = 3660 bible Hauled 0 bbis H2O from 6 mile lake for total = 5822 bbl Hauled 0 bbis H2O from B -Pad for total = 2560 bbl 7/4/2017 Change out saver sub on Top Drive.;WU 5" Test Joint. Set test plug. Fill/Purge BOPE.;Shell Test BOPS. Test Annular, UPR/LWR VBR,s, Blind Rams, Unoxe Manifold, Choke/Kill Valves, 5" Floor Valves, Hyd IBOP, Manual IBOP, to 250/3500 psi. 5 min ea.;(1 failure due to air. Bleed down and recycle valves. Test Good.) Perform Draw Down Test: Start 3150 psi, After close 1700 psi, 200 psi build @ 21 sec. Full Recovery 68 seconds. 6 N2 @ 2325 psi ave.;Test PVT and Gas detection System. Test witnessed by AOGCC Rep Adam Earl.;Rig down test equipment. Set 10" ID Wear bushing.;Sewice rig, perform derrick inspection load tools to rig floor.;P/U Clean Out BHA with VM -1 RR Tricone Bit w/no jets, 1.5 deg bend Molor. 11 jts HWDP/Jar = 405.10';Single in hole picking up 40 jts 5" NC -50 DP from 405' to 1660'.;Hang blocks, slip and cut 95' drilling line. Re -calibrate block position and test same.;Single in w/ DS50 DP from 1660' to 1940', wash down and tag plug just above ESC;Drill cmt f/ 2002' to 200T, Drill out plug and ESC f/ 2007' pumping 400 gpm, 450 psi, 40 rpm, web 2-5k, cleanup same, make dry pass, clean. P/U/SO/ROT 83/66/75;Single in w/ 5" DS50 DP f/ 20101 to 3799', TIH w/ stds 5" DP to 6441', correct displacement on trip in. 68 jts total DS50;CBU, Circulate and condition thick mud @ returns pumping 350 gpm, 700 psi,;R/U pump in sub wl circ hose, line up and flood choke and kill line, close upper VBR, press up and test 9 5/8" casing to 3000 psi f/ 30 min charted, 60 psi pressure drop;Check surface equipment, bleed of pressure, re-tes to 3000 psi for 30 min, charted, good. Bleed of pressure, open VBR. 5 bbls pumped, 5 bbis bled of.;Wash down f/ 6441' to 644T tag TOC, drill cement and FE. Drill cement from 6441' to Baffle adaptor @ 6461', Drill baffle adaptor @ 6461';;Daily losses to formation= 0 bible for total= 72.1 bble Hauled 150 bible H2O from L -Pad lake for total = 1950 bbl;Hauled 114 bbis cutting to G&I for total = 5936 bbis Hauled 0 bbis H2O from 6 mile lake for total = 2070 bbl 7/5120 Continue Drill cement and FE from 6461' to 6600'. Drill 20' new formation to 6620';Displaced well to 9.5 LSND Mud System.;Pull into shoe, KU and Pertorm ` FIT to 13.5 opo EMW usina 9.5 opp MW. Apply 1024 psi. 3 bible pumped. Bleed 2 114 bible back. RID lest equipment.;Monitor static well. POOH from 6566 / S 74960'. (UD single @ 6472' to rotate breaks, UD Jt @ 6000' w/bad hard band and replace w/1st jt UD) Pump Slug @ 4960'. POOH to Surface. UD Bit/MTR;CIean and clear rig floor. Prep to PU Geo Pilo7Under Reamer BHA.;PU RSS w/ UR BHA #3 w/ 8.5" SFE46D PDC bit, download MWD, shallow hole pulse test. Finish MIU BHA w/ riptide UR, RIH w/ 3 stds 5" HWDP, jars, i It 5" HWDP, well commander, 2 stds 5" HWDP= 515.82';Drif and PIU 9 jts 5" NC: DP RIH f/ 515' to 770', RIH w/ stds U 770' to 1500', M/U top drive. pump 500 gpm, 1100 psi, break in geo pilot bearings.;Continue to RIH f/ 1500' to 4000', M/U TD, rill pipe, continue RIH to 6551' above shoe. UD std # 42 due to worn hard bands. Correct displacement on TIH;Fill pipe, Wash and ream to bottom @ 6620' pumping 500 gpm, 1450 psi, 30 rpm 14.5k iq. Get SPRs PU/SO/ROT 200/1021137;Drill 8 1/2" hole f/ 6620' to 6800' putting UR 99' past 9 5/8" shoe. AROP 45 GPM 500, 1450 PSI WOB 10k, 70 RPM, 15.2K TO MW 9.5/53 Vis, ECD 10.3 PU/SO/ROT 192/96/133;Currently 13.26 above the line, 4.68' Ief;;Daily losses to formation= 0 bbis for total= 72.1 bbis Hauled 0 bbis H2O from L -Pad lake for total = 1950 bbl;Hauled 829 bbis cutting to G&I for total = 6765 bbis Hauled 450 bible H2O from 6 mile lake for total = 2520 bbl ,ball, pull t/bit depth of 6726', open Reamer & observe 100 psi pressure drop, ream down U6732'. 500 gpm, 1430 psi, 120 rpm, 16.8 Tq. PU to 6726' and rive 7K over pull and verify reamer open.;Continue to ream down to 6799' up to 12K WOB, PUW 215K, SOW 97K, RWT 136K;Dnll ahead f/6799'to 6863'. GPM, 1670-1800 PSI, 120 RPM, 16K Tq,18 WOB, 12K DWOB, 10.3 ECD. (Observed Pressure drop to 1440 psi @ 6829'. Return flow stabil and MWD all function properly. S;(Observed Pressure drop to 1440 psi @ 6829'. Return flaw stabil and MWD tools all function properly. Suspect reamer fully led.);POOH f/6863't/6829'. Begin SR up to 6789'. Ream full stand back to 6863'.550 GPM, 1350 PSI, 100 RPM, 16K Tq, 5K WOB.;Lost hi line power @ f prior to connection. Switch to rig power, drill 2' and lost power again. Production give ok to go back on high Line.;Drill 9 7/8" hole F/ 6863' T/ 7146' ') AROP 38 FPH (44 FPH on him) 1600, 1780 PSI WOB 24k, 140 RPM, 16.5K TO 9.5/53 Vis, ECD 10.5 SO/ROT 240/901139 OB 20K;Drill 9 7/8" hole F/ 7146'T/ 7475'(329') AROP 54.8 FPH (73 FPH on him) 1600, 1780 PSI WOB 20k, 140 RPM, 17-18K TO 9.5150 Vis, ECD 10.44 i0/ROT 250/95/140 OB 18K;Drill 9 7/8" hole F/ 7475' T/ 7806'(331') AROP 55.1 FPH (72 FPH on btm) 1600, 1850 PSI WOB 20-22k, 160 RPM, 18-19K TO 9.5152 Vis, ECD 10.5 i0/ROT 262191/143 JB 19K;Pump 35 bbl hi vis sweep @ 7560', sweep back on time w/100 % increase 8.05' above the line, 1.01' Ieft.;;Daily losses to formation= 0 bbls for total= 72.1 bbls Ibis H2O from L -Pad lake for total = 1950 bbl;Hauled 285 bbls cutting to G&I for total = 7050 bbls M bbls H2O from 6 mile lake for total = 2970 bbl 9 715' hole F/ /6Ub11 6120' (31 J) AHOY J3tYN (J/ 1-1'N On him) A 600, 1890 PSI WOB 20k, 160 RPM, 18-19K TO 9.5/52 Vis, ECD 10.4 3O/ROT 265/95/147 OB 15K;Pump hi visc nut plug sweep @ 8125'. 200 % increase cuttings at shakers. ning 2% lube. Both centrifuges on Iine.;Drill 9 7/6" hole F/ 8120' T/ 8501' (381) AROP 64 FPH ( 77 FPH on him) A 600, 1920 PSI WOB 20-25k, 160 RPM, 18-20K TO 9.5/52 Vis, ECD 10.4 30/ROT 265/95/147 DB iSK;Start turning azimuth from 8380'w/ 70% @ 80L TF.;Drill 9 7/8" hole F/ 8501'T/ 887T (372') AROP 62 FPH (73 FPH on blm) A 540, 1750 PSI WOB 20-25k , 120 RPM, 19-20K TO in/out 10.2/9.7 Vis 50, ECD 11 30/ROT 241/118/159 OB 20K:Pump 30 bbl hi vis nut plug sweep @ 8627', sweep back on time wl 10% increase.;At 8800' increase MW before drilling into HRZ @ 9054' f/ 9.5 to 10.5 ppg adding 12 ppg LSND mud w/ black product from vac trucks to system over 2 circulations until 10.3+ ppg in/out;Drill 9 7/8" hole F/ 8873' T/ 2' (129) AROP 64.5 FPH ( 73.5 FPH on him) A 550, 1750 PSI WOB 20-25k, 120-140 RPM, 18-20K TO in/out 10.3+ Vis 47, ECD 11.2 30/ROT 245/114/157 OB 20K;Add barite to finish increasing MW f/ 10.3+ ppg to 10.5 ppg in/out before drilling past 9002' (50' above HRZ) pumping 600 gpm, 2200 psi, rotating work pipe.;Gel new parameters w/10.5 ppg MW IS ppb black product/ 2% Iubes;Drill 9 7/8" hole F/ 9002' T/ 9100' (98') AROP 39.2 FPH (49 FPH on 1500, 1750 PSI WOB 15-20k. 120-140 RPM, 19-20K TO indout 10.5 Vis 49, ECD 11.3 10/ROT 230/120/161 )B 12K;Continue w/ build and turn. 100% deflection, RSS giving avg of 4.71 deg 1100' output : Encounter severe slip stick entering HRZ @ 9054' ently 3.24' above the line, 0.67' right;;Daily losses to formation= 0 bbls for total= 72.1 bbls ed 0 bbls H2O from L -Pad lake for total = 1950 bbl;Hauled 456 bbls cuffing to G&I for total = 7506 bbls ed 600 bbls H2O from 6 mile lake for total = 3570 bbl 1197/8" hole F/ 9100' T/ 9230' (130') AROP 37 FPH (43 FPH on btm) PM 500, 1750 PSI WOB 15-20k, 120-160 RPM, 15-23K TO N in/out 10.5 Vis 49, ECD 11.3 J/SO/ROT 242/114/156 NOB 12-15K;Pump sweep @ 9195';Lost swab on MP# 2. PU off bottm, reduce pump to 300 gpm, Circulate out sweep with MP 1 while replace swab on MP ;Service Rig and Continue to circulate while change out PistoNWear plate on pump #2.300 gpm/715 psi.;Drill 9 7/8" hole F/ 9230' T/ 9408' (178') AROP 27 rH ( 47.5 FPH on b1m) PM 525, 1875 PSI WOB 10-25k, 130-170 RPM, 15-23K TO N in/out 10.5 Vis 49, ECD 11.3 XSO/ROT 242/114/156 NOB 15-20K;Last survey 9349', V low and 15' right of plan. ;sembly not putting out the planned 6° doglegs. Drilling through the HRZ, having frequent periods of low ROP due to high stick slip and;erratic torque which not helping build rates. ojecting ahead with 4.75' doglegs, we can achieve the inclination required for T' casing point but will be around 200' off to the right of plan.;Drill 9 7/8" hole 9408' T/ 9563' (155') AROP 25.8 FPH ( 31.9 FPH on btm) PM 500, 1900 PSI WOB 15-25k , 130 RPM, 17-20K TO err N in/out 10.45 Vis 51, ECD 11.2 J/SO/ROT 242/112/161 NOB 13-18K;9445' pump 30 bbl hi vis sweep w/ walnut. 100% increase @ sweep returns.;Drill 9 7/8" hole F/ 9563' T/ 9725' (162') AROP 27 FPH (36 FPH i btm) PM 550, 2100 PSI WOB 15-25k, 120 RPM, 18-20K TO N in/out 10.4+ Vis 50, ECD 11.3 J/SO/ROT 257/113/163 NOB 18-20K;Very slow drilling 0 9590'to 9617' ROP dropped f/ 25 fph to 7 fph or less, suspect balled bit, Pump 30 bbl hi vis sweep w/ 30 ppb walnut, as -on as sweep out bit ROP increased to 35-45 FPH.;Build rates drop off with the slow ROP. See sections of 4-7'/100' build rates when getting a consistent DP but not often enough to achieve average desired target outpul.;Currently 3.42' below the line, 45.43' right.;;Daily losses to formation= 0 bbls for total= 72.1 red 0 bbls H2O from L -Pad lake for total = 1950 bbl;Hauled 606 bbls cutting to G&I for total = 8122 bbls red 600 bbls H2O from 6 mile lake for total = 4170 bbl 19 7/8" hole F/ 9725' T/ 9955' (230') AROP 38 FPH ( 46 FPH on blm) 81550, 2424 PSI WOB 18-27k, 110-170 RPM, 13-25K TO I in/out 10.4+ Vis 50, ECD 11.3 SO/ROT 264/112/156 nOB 18-20K;Pump 30 bbl low w1visc nut plug sweep, back on time with 50% increase in cuttings. See 200 psi drop after sweep. Make constant parameter rstments to maintain -50 ROP.;Drill 9 7/8" hole F/ 9955' T/ 10146'(191') AROP 32 FPH ( 37.5 FPH on bm) M 550.2450 PSI WOB 20-27k, 120-170 RPM, 15-25K TO I in/out 10.4+ Vis 50, ECD 11.4 SO/ROT 290/98/157 1013 18-20K;Drill 9 7/8" hole F110146' T/ 1029T @ TO (147') AROP 49 FPH (59 FPH on bm) M 550.2450 PSI WOB 25k, 160 RPM, 18-21 K TO I in/out 10.5 Vis 50, ECD 11.4 SO/ROT 286/98/160 1OB 18-23K;Pump 30 bbl to vis sweep w/ walnut @ 10198', sweep back on time w/ no increase. e: drilling break @ 10240'f/ 60 to 200 fph. in Kuparuk C sand per Geo @ 10293';45.08' below the line, 255.92' right;Pump 35 bbl hi vis sweep 600 gpm, 2500 psi, rotate 120 rpm, working pipe. Inc I f/ 10.5 ppg to 10.8 ppg in/out adding 290 bbls 12 ppg spike fluid. :ep back on time, 10% increase. c gas @ BU 314;Finish weight up to 11 ppg in/out using barite.;Cont to circulate -work pipe while Mixing liner running pill, 130 bbls of 11 ppg , 12 ppb black duct and graphite w/, 4% lube to cover 1372' of OH to 8921' @ 100'+ above HRZ. SO/ROT 273/1091161;Get new SPRs, flow check well, static. POOH 5 stds on elevators 500 fph f/ 10293! to 9979', TIH 500 fph to bttm with no res.;;Daily losses to formation= 0 bbls for total= 72.1 bbls red 0 bbls H2O from L -Pad lake for total = 1950 bbl;Hauled 627 bbls cutting to G&I for total = 8749 bbls red 600 bbls H2O from 6 mile lake for total = 4770 bbl ak Circ @ 500 gpm/1900 psi. Pump 130 bbls of Pill, Chase with 132.8 bbls Mud, follow with 20 bbls slug, chase slug with 7 bbls Mud. N 264K/SOW 117K w/pump. 277K/117K no pump.;TOH on elevators f/10293'to 8000' UD 5" DP @ 500 fph/8 fpm (2293') as per Engineer Swab/Surge r ScheduIe;TOH F/8000' to 7000' UD 5" up @ 1000 fph/16.7 fpm as per Swab/Surge Trip Schedule H F/7000'to 6800' UD 5" dp @ 1500 fph/25 fpm;Circulate 1 hole volume from 6800'@ 600 GPM/2150 psi. Pump SIug;TOH F/6800'to 6000' UD 5" dip @ 0 fph/25 fpm as per Swab/Surge Trip Schedule;TOH F/6000'to 5000' UD 5" dip @2000 fph/33 fpm as per Swab/Surge Trip Schedule;TOH F/5000'to V UD 5" up @ 2500 fph/41.7 fpm as per Swab/Surge Trip Schedule;TOH F/4000' to HWDP' UD 5" dp @ 3000 fph/50 fpm as per Swab/Surge Trip iedule e: last 20 jts over torqued to 60k, have to warm up tool jts to breakout. rect displacement on trip out;Flow check well, static. TIH with 6 stds excess 5" DP in Derrick from 515' to 890'@ 50 fpm.;TOH R 890'to HWDP' UD 5" dip 1000 fph/50 fpm as per Swab/Surge Trip Schedule;UD HWDP, Well Commander, Jars and Ripe Tide Under Reamer. Down Load MWD, UD remaining 4. Bit Graded: 1,1,WT,A,X,I,ER,TD d out drill pipe and BHA f/ pipe shed.;Note: recovered 71/2" wide x 12" long piece of curved metal, resembling pad of ES cementer shift sleeve wedged on er stab of geo-pilot.;Clear and clean rig floor, pull 10" ID wear bushing.;Close blind ram, C/O upper VBR to 7" casing rams.;;Daily losses to formation= 0 for total= 72.1 bbls red 0 bbls H2O from L -Pad lake for total = 1950 bbl;Hauled 119 bbls cutting to G&I for total = 8868 bbls red 300 bbls H2O from 6 mile lake for total = 5070 bbl 7/1112017 Continue with changing to 7" Pipe Rams. Rig up test equipment. Test 7" Solid body rams to 250/3500 psi. Rig down Test equipment.;Service Rig;Rig up to run 7" 26#, L-80, 563 Hyd Casing. MU WOT Volant w/ Cement Swivel/Bail Extensions. Rig up power tongs ect.;PU Landing joint, MU Fluted Mandrel Casing Hanger. Drift run casing hanger. Adjust TD Lube oil pump PSI. PJSM on running casing.;P/U Shoe track any. With thread lock. Flash light Jts verify no debris. Fill Pipe, Check Floats, Floats good.;Run T'26# 563 Hyd Casing to 4000' @ 3000 fph/50 fpm as per Swab/Surge Trip Schedule;Run 7" Casing from 4000 to 6000' @ 2000 fph/33 fpm as per Swab/Surge Trip Schedule;Run T' Casing from 6000 to 6600' (9 5/8" Csg Shoe)@ 1500fph/25 fpm as per Swab/Surge Trip Schedule;@ the 9 5/8" Shoe, Break circulation and CBU staging up to 8 bpm. 2 bpm / 226 psi, 3 bpm / 275 psi, 4 bpm / 320 psi, 5 bpm 1360 psi, 6 bpm / 400 psi, 7 bpm / 450 psi, 8 bpm / 500 psi. Full returns;Run 7" Casing from 6800 to 7000' @ 1500 fph/25 fpm as per Swab/Surge Trip Schedule Run 7" Casing from 7000 to 8000' @ 1000 fph/16.71pm as per Swab/Surge Trip Schedule;Run T' Casing from 8000 to 8845' @ 500 fph/8.3 fpm as per Swab/Surge Trip Schedule. Clean trip to 8845' MD. Proper displacement.;@ 8845', Break circulation staging pump up slowly to 5 BPM / 535 psi while reciprocating pipe. Had full returns for 12 min @ 5 BPM before psi drop and diminishing returns.;Reduce pump rate staging down from 5 bpm to 1 bpm 1220 psi (ICP was 295 psi) attempting to establish circulation. Had slight returns that were intermittent. 91 bbls loss to formation;234k Up, 125k Dn- Wts clean with no indications of differential sticking. Attempt to obtain rpm parameters. Stalled @ 13k but could establish slight intermittent 1-2 rpm when working pipe.;Unable to establish notable returns. Discuss options with drilling team. Decision made to POOH and attempt to establish circulation every 5 jts. Static losses @ 0 BPH.;POOH laying down casing from 8846- T/ 7997' MD. Attempt to establish circulation every 200' while pulling out of hole at 500 fph.;Hauled 114 bbls cuffing to G&I for total = 8868 bbls Hauled 150 bbls H2O from 6 mile lake for total = 5220 bbls Hauled 0 bbls H2O from L-Pad for total = 1950 bbls;Hauled 0 bbls H2O from B-Pad for total = 2560 bble Daily losses 91 bible to formation for total = 163 bbls 7/12/2017 Cont POOH laying down casing from 7997'- T/ 7810" MD. No isuues laying down casing.;Break circ @ 1 bpm/155 psi, no returns. 1.5 bpm/185 psi w/slight returns, staging pump up to 2 bpm/210 psi. Work pipe, attempt to establish returns, pump on up stroke, no pump on down stroke.;Stan lowering MW from 11.0 to 10.5 ppg w/25 ppb LCM BG. No sucess establishing sufflcent returns. Loss rate @ 150 BPH while circulate/Hole static with pump off.;Established slightly better returns w/slight displacement returns on down stroke with no pump.;POOH laying down additional 5 jts casing from 7810' to 7609;Bring on pump @ 1 bpm/210 psi staging up to 2.5 bpm/255 psi. See 30 % returns w/initial —105 bph loss rate. Use higher pump rate on up stroke and 1 bpm as working rate for down stroke.;lncrease pump rate .5 bpm in 30 min intervals as loss rate decreased and return flow increased. Staged up to 3.5 bph w114 bph loss rate. Increased pump to 4 bpm w/30 bph loss rate.;Remain @ 3.5 bph with loss rate diminsh U 30 bph to 0 bph, w/ 10.5 mw in and 10.6 out. continue bring 10.5 mw to surface @ 3.5 bph/250 psi.See 10.5 MW out @ 868 bbls pumped. 345 bible over calculated;RIH wl 7", 26#, L-80, Hydril 563 casing F/ 7600' - T/ 8427' MD. Broke circulation @ 8021' MD staging up to 3.5 / 255 psi (full returns).;Attempt to circulate @ 8427' MD. Psi up to 600 psi with no circulation. bleed off and psi up to 700 psi w/ same results several times. Troubleshoot surface equipment (good).;Pull 2 jts and UD F/ 8427' - T/ 8340' MD. Psi up to 1000 psi and work pipe to clear obstruction in casing string. Re-establish circulation stage up to 3.5 BPM /282 psi w/ no losses. Circ 30 bbls;Wash do csg F/8340'- T19380' MD. 2 BPM/330 psi 122% flow. 121k dn, 244k up. Consistently saw 150-200 over psi when breaking circulation each jt then pressure would fall back to normal.;Over pressures seemed to be time sensitive. The longer the pumps were down, the more pressure it took to re-establish circulation. Tagged @ 9365' w/ 9k dn. Stuck @ 9365' MD.;Packed off @ 700 psi. Bleed psi off and break free. Stick pipe while simultaneously packing off @ 700 psi. Bleed psi off, rotate @ 1-2 rpm w/ 14k tq.;Free string and re-establish circulation w/ rot. Stage up pumps to 2 BPM w/ 320 psi. 35% returns.;Pump @ 2 BPM, 320 psi w/ 15% flow w/ 35% returns while reciprocating pipe @ 6 fpm. 121k dn, 244k up. Condition hole to re-establish full returns. Pump 25 bible 11#, 40 ppb LCM pill.;Hauled 62 bbls cuttings to G&I for total = 8930 bbls Hauled 300 bbls H2O from 6 mile lake for total = 5520 bbls Hauled 0 bbls H2O from L-Pad for total = 1950 bbls;Hauled 0 bible H2O from B-Pad for total = 2560 bbls Daily losses to formation 426 bbls for total = 498 bbls 7/13/2017 Continue establish returns @ 9365', Stage pump f/2 bpm to 4 bpm as return flow increases and loss rate decrease. Had innitial 46 bph loss rate @ 4 bpm. Remain @ 4 bpm up stroke and 2 bpm down stroke.;Obtain 2nd loss rate @ 4bpm w/39 bph loss rate. 10.5 ppg to surface at 17400 silks. Pumping 4 bpm w/7.9 bph loss rate. Pumped total of 1,075 bbls to achieve full returns with 10.5 ppg in/out.;Wash down w/casing from 9380'. Work through bridge and pack offs @ 9399 pumping 3.5 bpm/310 psi. PUW 255/SOW 120K W/Pump. Break circulation on up stroke. @ 9525, Encounter 500 to 700 ps PUW 296K. At;@ 9525, see pack off to 700 psi, fight pack off issues with no success. Bleed to zero, pressure back up to 700-800 on casing several times, with no bleed off while working pipe.;POOH laying down casing f/9525 to 938V attempting to re establish circulation on each joint LlD. Pipe stuck @ 9354'w/no circulation. Work pipe w max straight pull 475K,;Pressure up casing 800-1500 psi w/attempting to work pipe free. Begin to stage pump up to 2000 psi, see fluid movement @ 1800 psi, continue work pipe and see consistent pump psi drop.;Park @ neutral wt, stage pump to 4 bpm /450 psi, straight pull to 465K and free pipe.;Circulate and condition hole reciprocating pipe F/ 9387'- T/ 9346' MD. Rot @ 3-6 rpm, 20k tq, Initial circulating rate staged up to 3.5 BPM, 390 psi w/ 50% returns. Staged up to 6 BPM, 415 psi.;Losses consistently diminished as we staged up to 6 BPM. Pump 25 bbls 50 ppb LCM pill while staging pumps up. Had full returns just prior to LCM pill clearing shoe.;CBU after establishing full returns. Saw moderate amounts of sand @ shakers w/ no significant shale cuttings obsewed.;Wash and Ream casing down F/ 9387'- T/ 9536' MD. At connections, Hold 180 psi on backside while making up jts via annular to stabilize shales and loss zone. Saw full returns after each connection.;Wash an @ 300 fph, 6 BPM, 390 psi w/ 47% flow. 3-6 rpm w/ 20k tq. Saw 3-8k bobbles past 9520' MD. Work pipe down 4-6 feet increments before moving forward when in ratty hole.;Stalled, packed off and look wl @ 9536' MD. 8-10k tag. Stuck casing @ 9536 w/ diminished returns (85% losses). Work tight hole F/ 9536'- T/ 9509' MD.;Work pipe staging up to 480k max up w/ and without pumps and rotary (20k tq).;Ramp pumps up (1-6 BPM) and bleed off while holding tq and up wf @ 480k. Hold 470-480k up and work rotation oscilating pipe w/ max tq 25k w/ and without pumps. Maintain slight returns when pumping;1830 max psi @ 6 BPM pump rate. 3 BPM, 1715 psi w/ 13% returns.;Hauled 67 bbls cuttings to G&I for total = 8997 bbls Hauled 300 bbis H2O from 6 mile lake for total = 5820 bbls Hauled 0 bbls H2O from L-Pad for total = 1950 bbls;Hauled 0 bbls H2O from B-Pad for total = 2560 bbis Daily losses to formation 296 bbls for total = 794 bbls 7/14/2017 Continue work stuck pipe @ 9510' MD. Max straight pull 480k. Max tq 30k. 2 BPM, 1675 psi. 10% returns. Attempt all possible parameters w/ no progress. Pump 25 bbl (50ppb) LCM pill-no change.;Continue work stuck pipe @ 9510' (no progress). Lost all circulation. Inject @ 6 BPM, 1850 psi when attempting to surge pumps and work free.;Perform full derrick inspection (good). Grease TDS, Blocks, Crown and Drawworks.;Conlinue working stuck pipe @ 9510' MD. 480k max pull, 30k max tq while oscilating. No circulation. Attempt to circulate with pump rales ranging .5 to 12 BPM wl max injection psi 2450 psi (no go).;No progress from 9510' MD.;N/D flow riser and unflange adapter flange from top of annular. R/U airslips below table on top of annular. Set slips w/ 162k string wt. Install safety clamp. Attempt to break out CRT (no success);CRT stuck in joint of casing. R/U to UD CRT w/ joint of casing. P/U and reset airslips w/ 165k string wt. Close annular w/ reduced psi @ 730 psi. Re-install safety clamp.;R/U power tongs w/ double snub lines and breakout jt. UD jt with CRT.;Hauled 0 bible cuttings to G&I for total = 8997 bbls Hauled 450 bbls H2O from 6 mile lake for total = 6270 bible Hauled 150 bbis H2O from L-Pad lake for total = 2100;Hauled 0 bbls H2O from B-Pad for total = 2560 bible Dail losses to formation 1511 bible for total = 2305 bbl 7/1512017 MN xo pup (HTTC pin x Hydril box). WU 10' Hydril pup it. P/U string and release air slips. N/U flow riser.;Clean and Paint rig. Perform PM on rig equipment while waiting on wireline services.;R/U Pollard E -line. RIH w/ 7" "K -i" CIBP (BOT) to tag depth of 9404' (soft tag - 50 lbs) on .25" E -line. 2100# up, 400# dn. Pick up and place CIBP on depth @ 9250' MD w/ 2100# line lension.;Set CIBP and observe 600# drop on line tension indicating CIBP set on depth as designed. P/U 20' and slack back off tagging CIBP on depth.;POOH w/ E -line. R/D Pollard E -line and stage equipment on locatlon.;N/D flow riser and set air slips on top of annular w/ 1851k string wt. B/O xo and pup It, UD same. WU T' cutoff It to protect collar during drill pipe trips. Install containment for flow box.;C/O DS -50 saver sub to HT -38 saver sub. Service TDS.;PJSM, MN 6-1/8"BHI STXAMilltooth (3x16s), bit sub (ported float installed) and xo sub (5.3' total length). Single in hole w/ 4", HT -38, 149, 5-135 drill pipe to 3402' MD (108jts). 2.33" drift;Hauled 57 bbls cutting to G&I for total= 9054 bbls Hauled 150 bbls H2O from 6 mile lake for total = 6420 bbls Hauled 300 bbis H2O from L -Pad lake for total = 2400 bbls;Hauled 0 bbis from B -Pad for total = 2560 bbls Daily losses to formation 100 bbis for total = 2405 bbis 7/16/2017 Continue to single in hole picking up 4" DP from 3402' to 6286' (200 Its total);Slip and out 188' Drill Iine.;Service Rig;POOH and set back 4" DP from 6286' to surface. Prep to PU 4" DP.;Single in hole picking up remaing 100 Its 4" DP;POOH, set back 50 stands 4" DP. 6/0 bit, bit sub, and xo. UD same.;R/D 7" cutoff trip nipple with containment. M/U 7" pup its and R/U test equipment. Test 7" casing to CIBP @ 9250' MD. 3100 psi w/ 15 min hold (good). R/D test equipment.;N/D air slips from top of annular, Remove choke and kill lines. Break wellhead flanges. Lift stack. Set "C" 22 E -slips w/ 1501k string w1. Rough out 7". Remove and UD cutoff It 15.52'.;Dress 7" csg. Attempt to set packoff (no go). Remove and inspect bowl (good). Redress packoff w/ dove tail seal removed. Set stack. IWU packoff on running tool and set from floor (good). RILDS.;N/U BOP stack, choke and kill lines, tighten flanges and install riser.;C/O upper rams from 7" to VBR's (2-7/8" x 5-12'). Inspect ram body. Charge Koomey.;Install test plug w/ 4" lest It. Flood stack, choke manifold and lest equipment. Test BOP equipment 250/3500 wl 5 min hold on each. Chart and record same. AOGCC rep Lou Laubenstein waived witness;Hauled 0 bbis cutting to G&I for total = 9054 bible Hauled 150 bhls H2O from 6 mile lake for total = 6570 bbis Hauled 0 bbls H2O from L -Pad for total = 2400 bbls;Hauled 0 bbls H2O from B -Pad for total = 2560 bbis - I Dalh, losses to formation 0 bbis for total 2405 bbls 7/17/2017 Continue Test BOP equipment 250/3500 w/ 5 min hold on each. Chart and record same. AOGCC rep Lou Laubenstein waived witness. No Failures. Test Gas alarms and PVT Systems. Perform Accumulator Test.;Blow Down and rig down lest equipment. PU landing It w/Pack off running tool . Pull Pack Off. Close in Well and test Flange breaks to 3500 PSi.;Service Rig;R/U Pollard, RIH with E -line. Could not get to 9250'. Put guns on depth @ 9215' btm shot and 9210'top shot. Fire guns with good indication of detonation. POOH w/E-Line. Set E -Line aside.;Close Blind Rams and establish circulation through parts @ 9210', taking returns out annulus valve to cellar box. Stage pump U7 bpm/310 psi to 8 bpm/690 psi. Pumped 43 bbis lotal.;Rig down PESI while rig up return line from annulus to choke Ilne.;CBU x2 staging pump to 5 bpm, taking returns through choke. Stage up pumps to 7 BPM, 605 psi ICP / 505 FCP w/ 9.5 MW IN , 9.6 MW OUT. 6-15 units BGG. Initial loss rate 70 BPH @ 6 BPM T/ 0 Iosses.;Slarted seeing pit gain as MW out was getting closer to targeted 9.5 ppg MW. Shut down and monitor well via Trip Tank w/ 9.6 MW . Flow @ 60 BPH and falling off to 12 BPH before continuing opemtions;Well was ballooning. annulus @ 360 psi, casing @ 80 psi. Monitored flaw per minute with reducing rate and vol @ trip tank #1 taking returns through choke. Bleed down casing to 0 psi, Csg @ 6 psi.;Open Blinds -monitor well (static)Cont monitor T'x9-5/8" annulus w/down trending flow to trip tank. Shut blinds and establish circulation through parts (good). Open well back up and monitor (static).;PJSM, M/U "K-1" Mach. 3BB - 7" cmt retainer on Snap latch setting tool. Verify setting tool in properly located for running in hole. RIH on 4" DP out of derrick T/ 8187' @ 100 fpm as per BOT;Monitor trip displacement on pill pit #2 and monitor flowback from annulus on trip tank #1 (5 BPH) and continuing to trend down.;Hauled 461 bbls cuttings to G&I for total = 9515 bbls Hauled 150 bbis H2O from 6 mile lake for total = 6720 bbls Hauled 600 bbis H2O from L -Pad for total = 3000 bbls;Hauled 0 bbis H2O from B -Pad for total = 2560 bbis Daily losses to formation 267 bbls for total = 2672 bbls .5-1 gallon hydraulic spill from water truck. MP Environmental notified. 7/18/2017 RIH on 4" DP F/ 8187' T/ 9134'. Close in well & establish up to 4 bpm @ 880 psi. Took 1000 psi to break circ @ 1 bpm. Set cmt retainer @ 9160' as per baker. Snap in and out good.;Set down 30k on cmt retainer. Test back cmt retainer to 3000 psi for 5 min. Good. Establish circ through cmt retainer taking returns through the annulus to the choke and stage up pumps to 5 bpm.;Circ & condition while waiting for Halliburton to rig up @ 5 bpm, 915 psi.;PJSM, Line up to Haliburton & pump 5 bbl water to test lines. test lines to 3500. Good. Swap to rig & continue to circ while waiting on Halliburton to batch up.;Line up and pump 15 bbl water, 38.2 bbl 15.8 cmL 186 sx, Chase with 5 bbl water, Lineup to rig and displace with 90 bbl 9.5 mud, with FCP @ 670.( Caught pressure @ 20 bbl away);P/U & unsling from retainer. Saw pressure drop. Pump 2 bbl leaving 1.3 bbl in the pipe. R/D circ lines. Pull 5 stands dry. Drop wiper ball & circ two btm up. No cmt in returns.;CIP @ 13:43. Est TOC @ 8404' MD Annulus shut in with 60 psi after unstinging from retainer. Showing .81bbl over on G/L after displacing.;Sewice rig.;POOH F/ 8820' T/ surface. UD running tool.;PJSM, M/U T' Python composite plug as per BOT rep. RIH on 4" DP @ 100 fpm running speed from surface to 7117' MD.;132k UP, 761, DN. P/U m7110' (btm of plug). Drop 1-7/16" phenolic ball do dp. Pump do @3 bpm, 303 psi. Reduce rate @ 700 stks to 2 BPM, 220 psi.;Ball on seat @ 909 stks (1195 calc stks). Psi up to 2000 psi, set plug. P/U to 151k shear off "Python" plug,;Psi drop to 0 psi, wt indicator showed drop from 151k to 84k static. P/U 20' and slack back off with light tag (3K) on depth @ 7108' MD (top of plug).;Pump 20 bbl dryjob. POOH mcking back 4" dp F/ 7108' - T/ 2331' MD. Hole took proper displacement.;Continue POOH laying down 4" dp (74 Its) F/ 2331'- T/ surface. B/O and Clean, UD running tool.;Bring Baker tools to floor. NUU 5.5" body cutters w/ 2-1/4" blades (8.538" max OD), spiral 6" OD stab, xo (total BHA length = 8.73). RIH on 4" DP F/ surface - T/ 5976' MD.;Hauled 351 bible cuttings for total = 9866 bbis Hauled 0 bbls H2O from 6 mile lake for total = 6720 bbls Hauled 600 bbis H2O from L -Pad for total = 3600 bbls;Hauled 0 bbis H2O from B -Pad for total = 2560 bbis Daily losses 0 bbis to formation for total = 2672 bbis 7/192017 RIH on 4" dip with Baker Knives F/ 5984' T/ 6994. Set knives at 7015'. Middle of 7" Joint. Take parameters as per baker. ROT 80 rpm, & stage up pumps to 990 psi. Saw pressure dump to 550 psi.;Slack off and mill. Shut down pump & pick up off the casing stump. Bring on pump with no rotary & slack off. Saw pressure dump to at set down. Good indication of out . Also flowing out annulus more.;Shut annular and break circ @ 1 bpm @ 120 psi. Full returns out annulus. Shut down monitor annulus flow. Slowing down from 10 bpm to 3 bpm. Fluid dropping in the casing. U tubing.;POOH F/ 7015'T/ Surface and UD Knives. Clean and clear the rig floor. Monitor annulus. Flowing 10 6ph. Let fluid drop in the casing and flow slowed to .5 bpm in 1 hr.;Close blinds and change top rams to 7". Set dummy pack off & test plug. Test 7" rams and choke line to 250/3500 psi. R/D testing equipment.;WU baker spear & spear casing stump. Work wt up to 365K. We got movement at 300 but slips were sliding on the casing and we were unable to go back down. Pulled casing stump up 2'.;Break circ in to cellar up to 4 bpm. No help. Shut down and consult drilling engineer. R/D spear. Decided to MU cutters and RIH to 50' in the shoe and cut 7".;M/U 5.5" body cutters w/ 2-114" blades (8.538" Max OD), Spiral Stabilizer w/ 6" OD, XO (Total BHA length = 8.73) and RIH on 4" DP out of derrick to cut depth of 6540' MD.;Obtain parameters - 80 rpm, 6.3k tq, 1.7 BPM / 325 psi, 4.3 BPM / 850 psi. Cut 7" casing @ 6540' MD. 80 rpm's w/ 4.3 bpm flow.;7 mins into cutting operations, significant psi drop from 1000 psi to 490 psi, Tq dropped from 6.3k to 5.6k.;Felt pipe sever and notable bump on rig floor. PIU Band observe cutters engage free pipe w/ psi increase and slight increase in up wt. Shut down monitor well (static).;POOH F/ 6540' - T/ surface. B/O and LID cutter assy. Good indicators on cutter blades of cut on casing. 500' midnight depth. BOP drill while tripping @ 23:00 hrs (38 sec to secure well).;P/U working single. M/U spear wl 6.220" grapple, packoff and 8-1/4" stop ring. Drain stack and annulus. RIH and engage TOF @ wellhead. P/U with good latch on fish.;P/U to 215K, Saw bobble and wt indicator drop to l68k. Pulled free pipe to surface with 175k up. Monitor well via trip tank. Separate "E" slips and remove same from cutoff jt.;Bring casing equipment to dg floor. RAJ Weatherford casing. Monitor well via trip tank (static).;PJSM, Attempt to breakout cutoff jt w/ spear assy. Unable to break casing connection using power tongs and rig tongs together @ 30k tq. Heat connection with hammer (no go);PJSM, Hot work permit. Close annular, cover rotary table with fire blanket, maintain continuous atmospheric monitoring. Welder heat connection. Break with power tongs. UD spear assy w/ cutoff jt.;Monitorwell (static). Continue pulling 7" HTTC casing F/ 6540' - T/ 5884' MD. Continue heating connections to breakout.;Hauled 114 bible cuttings to G&I for total = 9980 bbis Hauled 150 bbis H2O from 6 mile lake for total = 6870 bbis Hauled 0 bbis H2O from L-Pad lake for total = 3600 bbls;Hauled 0 bbis H2O from B-Pad for total = 2560 bbis Daily losses 0 bbis to formation for total = 2672 bible 7/202017 Continue POOH w/ 7" casing F/ 5884' - T/ surface. Heat every connection to breakout and Iaydown.;Clean and clear rig floor. R/D Weatherford casing equipment. Set 10" ID wear bushing ;Rig service. Grease traveling equipment.;Mob fishing tools to floor. Verify measurements with printed BHA (good). R/U 4" handling equipment.;P/U T' cutoff jt w/ spear assy. Breakout spear easy and laydown 7" cutoff jt. M/U BOT ITCO-Type spear w/ 6.220' grapple (re-run), inspect same (goad). P/U remaining BHA.;BHA as follows - Spear,bumpers, oil jars, xo, 6 jus 6" spiral DC's, xo, accelerators, bottleneck XO (total length BHA = 234.22').;RIH F/ 234'- T/ 6525' MD. Obtain Parameters @ 6526 MD, 130k up, 83k dn.;S/0 engage TOF on depth @ 6549. NO GO @ 6550' MD (10' swallow). Tag w/ 4k, P/U to 1501k, Set do 20k to cock jars, PAJ 2001k and bleed off jars to seat grapple (fish on).;Fire jars staging up from 2501k up to 275k up. Stage up from 275k to 325k post firing jars each time with straight pull. Fired jars a total of 7 times.;Saw movement on 7th fire with straight pull of 310k before breaking over and falling back to 150k. S/O and re-tag on depth. PIU w/ 145-1501k up wt (7" fish calculated wt 11,200 Ibs).;POOH F/ 7015' - T/ 737' MD racking back all 4" dip. Hole took proper displacement.;UD BOT fishing easy F/ 737' - T/ 503' MD. Bottleneck XO, DC's, XO,all jars & acceleratom.;R/U Weatherford Casing equipment. UD 7" cutoff jt w/ spear, C/O elevators, ready TIW. Continue Laying down 7" casing F/ 503'+1- to 175' MD. Heat each connection to breakout.;Hauled 0 bbis cuttings to G&I for total = 9980 bbls Hauled 150 bbis H2O from 6 mile lake for total = 7020 bible Hauled 0 bbis H2O from L-Pad lake for total = 3600 bbls;Hauled 0 bbis H2O from B-Pad lake for total = 2560 bbis Daily losses 0 bible to formation for total = 2672 bbis 7/2112017 Continue to Pull 7" 563 Heating up each connection with torch to break. F/ 400' To surface. UD out off joint. 33.35 cut. UD Fishing equipment.;Service rig.;Change top rams from 7" to 2 7/8 X 512 VBRs. Test to 250/3500 psi with 3.5 & 4" Test joint. GOod.;R/U 2 7/8 handling equipment. WIJ cmt stinger & P/U 16 Joints of 2 7/8 tubing to 499'. Change handling equipment to 4" & RIH T/ 6590'. Take parameters at shoe.;RIH F/ 6590' - T/ 7108' MD tag on depth w/ 4k. P/U off tag to 7106 MD. 122k up, 80k dn.;R/U pump in assyw/ cmt line. Circulate and condition hole @7105' MD. 4 BPM, 300 psi, 38%flow. Pumped 3x string vol.;PJSM w/ cmbs, wet lines, PT lines 1000/3000 (good). Batch up @ 20:10 hrs. Pump 1st cant plug as follows - 27 bbls H2O, 32.9 bbis 15.8 ppg cmt, 4 bbis H2O then turnover to dg. Pumped cmt @ 3.7 BPM.;Cmh's driver side pump had erratic psi and delivery. Shutdown @ 1.2 bbls into cmt job and changed over to passenger side pump. Continued pumping as per detail with no other issues.;Displace w/ rig - 62 bbls, 9.6 LSND mud 4.5 bpm, FCP 400 psi. Caught cmt @ 21.5 bbis into displacement. CIP @ 21:00 his. Est TOC @ 6698' MD (no pipe in hole). (9.4 bbis lost during disp).;R/D cmt line and UD single with pump in easy. POOH F/ 7105'- T/ 6570' MD @ 20 fpm. Slightly wet connections every stand. Tried pulling slower @ 15 fpm w/ no change. No issues pulling out;Drop wiper ball and circulate cmt string clean @ 11.7 BPM, 1360 psi, 59% flow. No traces cement back to surface. Circulate a total of 1.5x surface to surface. Pump dry job.;POOH F/ 6576 - T/ 4480' racking back 4" dp. Hole showed proper displacement.;Continue POOH F/ 4480' - T/ 500' with 4" DP. Monitor well (static).;C/O handling equipment. POOH F/ 500'- T/ surface w/ 2-7/8" cant stinger. Clean and inspect (good).;RIH F/ surface - T/ 500' MD with 2-7/8" cmt stinger. WU XO and C/O handling equipment to 4".;Continue RIH F/ 500' (cmt stinger) - T/ 5220' MD with 4" HT-38, 1411, S-135 drill pipe.;Hauled 389 bbis cuttings to G&I for total = 10369 bbis Hauled 0 bbis H2O from 6 mile lake for total = 7020 bbis Hauled 0 bbis H2O from L-Pad for total = 3600 bbls;Hauled 0 bbis from B-Pad for total = 2560 bbls Daily losses 9.4 bbls to formation for total = 2682 bbis 7222017 RIH F/ 5220' T/ 6590'. Establish parameters @ shoe. Wash down @ 3 bpm & Tag cmt @ 6754'.;UD one single. R/U side entry sub & cmt hose @ 5750'. Circ & condition @ 4 bpm @ 350 psi while conducting cmt PJSM.;Line up Halliburton & pump 5 bbl water. Test lines to 3000 psi. Good. Batch up 15.8 cmt & Pump 22 bbl water ahead, 32 bbl 15.8 cmt & 4 bbl water to chase.;Displace with rig @ 5 bpm 61 bbl. R/D circ hose & POOH @ 15 FPM. Pulling wet. POOH T/ 6099. CIP @ 9:45.;Pump down wiper ball & Circ & condition @ 500 GPM @ 1250 psi. Saw trace cmt back at btm up. Circ clean. Pump 10 bbl 11.7 Dry job.;POOH F/ 6090' T/ Surface and clean 2 718 cmt slinger;RlH with 2 718 & 4" Dp T/ 5974'.;Cut and slip drilling line (106'). Re-calibrate floor and crown saver.;RIH F/ 5974'- T/ 6225' MD. Kelly up and wash do F/ 6225'- T/ 6286' MD. 112k up, 78k dn, 84 gpm, 120 psi. Saw slight increase in pump psi (10-20) and slight drag (3-4k) (possible green cmt).;Saw 250 pressure spike after making connection while washing down. Broke over and fell back to 120-140 psi, NO TAG.;P/U T/ 6284' MD. CBU @ 540 gpm, 1545 psi, 15% flow, 5 rpm, 5.1 k tq. Saw wt increase @ titans up 9.6 to 9.9. Appeared to be stringer cmt in contaminated mud.;Continue washing down F/ 6284'- T/ tag depth of 6386 MD @ 84 gpm, 110 psi. Tag w/ 5k set do (2x). TOC @ 6385' MD.;P/U and CBU 2x @ 6375' MD. 540 gpm, 1545 psi, 5 rpm, 5.1 k tq.;POOH F/ 6375'- T/ 6220' MD. R/U to test casing. Test 9-5/8" casing w/ cant plug @ 6385' MD. Test to 3000 w/ 30 min hold (test good). Chart and record. 5.5 bbis pumped, 5.5 bbis bled back.;RIH F/ 6220'- T/ 6345' MD. Displace well - Pump 32 bbis 8.5 ppg, 141 vis spacer pill, Chase w/ 8.5+ ppg seawater @ 9 BPM, 1400 psi. Circulated a total of 627 bbis seawaler.;Monitor well (static). POOH laying down 4" dip F/ 6345'- T/ 5093' MD. RIH w/ excess 4" out of derrick F/ 5093'- T/ 6202' MD. POOH laying down 4" F/ 6202'- T/ 2891' MD.;Hauled 900 bbis cutting to G&I for total = 11269 bible Hauled 150 bbis H2O from 6 mi lake for total = 7170 bbis Hauled 300 bbls H2O from L-Pad lake for total = 3900 bbls;Hauled 0 bbls H2O from &Pad lake for total = 2560 bbis 7/23/2017 Lay down 4" DP from 2891' to 500'.;C/0 handling equipment to 2=718". POOH laying down 2 7/8" dp F/ 500'to surface.;Sewice rig, perform derrick inspection, RID 2 7/8" handling equipment, clean and clear rig floor.;Pull wear bushing. R/U for 7" casing. Run mule shoe and 3 joints of HTTC 26 lb L80 7" casing to 136'. MU landing joint, pup, and hanger and land same at 165.26'. Install pack off.;Change handling equipment from 7" to 3 1/2". Run mule shoe+ 103 joints of 3-1/2", EUE 8rd, 9.3 #, tubing. N11U hanger and landing joint and land same. RILDS. 58k up, 51k dn.;Set TWC. Flush and blow down all surface equipment in sub. N/D stack, choke, kill and fill up lines. Set back on slump and secure. N/D DSA. Continue cleaning pits.;N/U dry hole tree. Test void 500/5000 with 5110 min hold (good). Test tree 500/5000 w/ 5 min hold on each (good). RID test equipment. Remove T WC. Secure we11.;R/U to freeze protect well w/ LRS in morning. Clear 4" handling equipment and associated subs from floor.;C/O saver sub to DS-50. Continue cleaning mud pits and flush surface equipment. Blow down and drain same. C/O valves in pits as needed. Tear down MP's and inspect valve and seats.;Make parts list and schematic for additional vac system. Clean and prep pipeshed. Load and tally 215 jts DS-50 drill pipe for C-45 surface.;Hauled 946 bbis cuttings to G81 for total = 12215 bbis Hauled 0 bbis H2O from 6 mile lake for total = 7170 bbls Hauled 0 bbis H2O from L-Pad lake for total = 3900 bbls;Hauled 0 bbis H2O from B-Pad lake for total = 2560 bbis Daily losses 0 bbis to formation for total = 2682 bbis 7/24/2017 R/U LRS and freeze protect well w/ 150 bbis diesel (2000'+/-). Pump down OA taking returns back thru tbg @ 3.5 BPM, 250 psi. U-tube diesel 2 hrs. R/D lines and clean out cellar box.;Set BPV and secure well. Adjust skate motor mount. Perform PM's on TDS. Continue cleaning throughout rig w/ misc painting projects. C/O hopper 3" butterfly hopper valve.;lnspect TDS. CIO dies on grabber. Inspect and tighten grating bolts throughout rig as needed. Adjust drag chain tension. Begin install of electrical panel plugin board for break shack and envirovac;lnstall baffle plate in pit #1, remove and inspect dresser sleeve on mix pump, charge pump suction and associated lines. Re plumb gun line in pill pit #1. Install gauges for hydraulics on rig floor.;Cont welding projects in mud pits (security notified of non permit confined permit), trough, possum belly dump and install dresser sleeve on charge pumps. Clean and clear rig floor on excess equip.;lnstall additional bolts for spinner stop blocks. Continue load and tally total of 215 its DS-50 drill pipe in shed. Continue cleaning and paintings projects throughout rig.;Continue painting radiator lines in gen rm. Touch up paint previous welding projects throughout rig. Pressure wash exterior of rig. Continue load and tally drill pipe in shed.;Hauled 432 bbls cuttings to G81 for total = 12647 bbis Hauled a total of 7170 bbis H2O from 6 mile lake Hauled a total of 2560 bible H2O from B-Pad lake Hauled a total of 7170 bbls H2O from L-Pad Iake;Total losses to well 2682 bbis -SND mud. 7/2512017 Wait on ASR to finish up on C-46. Pressure wash cattle chute area, paint as needed. Install new gauges on hydraulic system on rig floor. C/O centrifuge #2 feed pump shaft seals. C/O ODS cathead chain.;Assist welder on penetrations for electrical receptacles. Re-plumb pill pit #2 gun line. ASR RDMO C-46.;ASR continues to RDMO C-46, Well support tie in C-46 and prep for wire line. Perform derrick inspection, bridal up. Continue painting on rig, welder install chains on hopper room loading dock.;Finish electrical panel modifications.;Well support continues to tie in C-46 and prep for wire line. PJSM, scope down derrick, re-assemble both mud pumps. Continue to paint around rig. Rig released from C-47 @ 06:OO.;Hauled 0 bbis cuttings to G81 for total = 12647 bbis Hauled a total of 7170 bbis H2O from 6 mile lake Hauled a total of 2560 bbis H2O from B-Pad lake 'led a total 7170 bbis H2O L-Pad lake Toa lose to well 2682 bible LSND mud 12126/2017 Hoist/Secure landings. General pre rig move Prep while W/O trucks. Peak on location @ 0800 hrs. Break down Rig Modules and stage Same. Walk Sub off well and rotate same. Install Rear Tires on Sub .PJSM, Demob rig from F-pad @ 15:30 hrs. On C-Pad location @ 1800 hrs n Well Name: MP C-47 Field: Milne Point County/State: , Alaska (LAT/LONG): avation (RKB): API #: Hilcorp Energy Company Composite Report Spud Date: 5/2112 01 8 Job Name: 1811546D MPC -47 Drilling 2018 Contractor Innovation AFE #: AFE $: Activity Date. Ops Summary 011 5/16/2016 Prep rig for move. In plug power and start cold start. R/D last of inner connect lines. Dress up unions. Raise stairs on all mods and secure for travel. On going loader work cleaning up the pad. Jack all mods up and install jeep under motor mod.;Peak on location at 08:00. Move rig components to travel. (Sub, Catwalk, Pipe Shed, Mud Mod and Gen Mod).;Start pulling rig mats. Walk sub off of well with stompers. Turn sub 90'.;Tow mods with Peak from F -Pad to C-Pad.;Spot Sub, Catwalk, Pipe Shed and Cont. to transport misc from F -Pad to C-Pad.;Spot Mud Pump and generator mod.;R/U Steam, air and water. R/U mud lines in mezzanine inner connects. Spot cutting box, Break Shack, bathroom and shop. Take on water. Scope up Derrick.;Hauled 0 bbls cuttings to G&I for total = 0 bals Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 0 bbls Hauled 0 able H2O from L -Pad lake for total = 0 bbls Hauled 0 bible H2O from Lake 2 for total = 0 bbls 5/17/2018 Bridle down, Remove Pennets from TD & store under Beaver slide. Work on Rig acceptance Check List. Hang rig tongs. Open Gripper foot on TD and inspect Grabber Dies/Saver Sub. Circulate FW through Mud Pits. Tighten fittings on Kearney Unit. Welder weld new stick of 1" OD pipe for Derrick Pin Linkage.;Load 8.5ppg Sea Water in pits. Berm Cuttings Box Continue to Mobilize Misc Equipment f/F-Pad to C pad. Finsh rig acceptance check list. Well Head Hand Pull BPV. RU circulating lines to Tree and MICA. Stage and R/U flow back Tank for capturing DSL FP. Accept rig @ 1500 hrs.;PJSM. Pump down tubing & Circulate out 150 bbis diesel freeze protect to flow back tank. Take returns through both OA and IA valves to displace DSL cap between 9 5/8 x 7" & 7" x 3 1/2".;PT 9 5/8" to casing to 3000 psi on chart for 30 minutes. Test Good. Bleed off pressure, blow down and R/D.;Set TWC N/D Dry Hole Tree.;N/U BORE. Install spacer spool on top of well head. Set stack on spool. Install choke and kill lines. Install riser and air boots. Obtain IRKS LLLD 23.02' . Install long mouse hole.;N/U Choke line and clean cellar.;PJSM Obtain upper and Annular measurements on 3.5" test Jnt. M/U 5" test JIM. Function test BOPE. Fluid lines W/ H2O. Perform shell test 250/3,500. Good.;Test BORE W/ 5" test Jnt. Test Annular, Dart, # 1 & 2 TIW, Upper & Lower IBOP, Mez Kill, Kill and Choke HCR, Kill and Choke manual , Choke manifold valves 4-15. Perform Koomey draw down recharge 200 psi, 30 Sec., total charge 103 Sec. 6 Nitrogen bottle average 2,275.;Hauled 0 bbls cuttings to G&I for total = 0 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbis; Hauled 520 bbls H2O from 6 mi lake for total = 520 bbls Hauled 0 blots H2O from L -Pad lake for total = 0 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 5/18/2018 Continue test BOP: UD 5" Test A and PU 3 1/2" Test A. Test Bag and UPR to 3 1/2" Pipe size to 3500 psi. Test Gas Alarms and PVT system. Test Witness Waived by Jeff Jones. RID Test Equipment. Blow down choke manifold and Iines.;R/U Weatherford Power tongs. M/U 5" DP x 3rd landing Jt. Pul TWC, BOLDS, Unseat Tbg Hgr w/62K, Pull Hgrto floor and UD same. UD landing Jt.;C/O elevators to 3 1/2". POOH standing back 3000' 3 1/2" eue 8rd tubing. (103jts+ 1 mule shoe.);P/U/MU 5" test equipment. Test LPR to 250/3500 psi, Hold 5/5 min. RID UD test equipment.;RU 7" elevators/Slips. P/U 7" Landing Jt w/ Pack Off running Tool. Pull Pack off and hanger as per Well head Rep. Hanger unseat at 40K. Pull and UD 3 joints + 26' mule shoe jt of HTTC 26 Ib L80 7" casing.;R/D T' handling equipment. R/U 3 1/2" Handling equipment. PJSM for RIH 3.5" EUE 8 RD 9.3# L-80.;TIH with 3000'3 112" sue 8rd from Derrick to 3,200' MD.;C1O handling Equip. to 5". RID Weatherforn tongs. P/U MU Retrieve -O -Matic 9-5/8" packer to 3.5" Work String. RIH P/U 2 stands 5" DP on top of PKR. Set Packer 1/2 turn to left. Slack off losing string weight of 54K to block weight 35K. Set 91-5/8" test packer 2 stands below rig floor at 115' MD.; POOH racing back 5" D.P.;Prep to test packer. Fluid pack surface lines with sea water. Close blinds and test packer from above to 1500 psi for 10 Min.;PJSM on N/D ROPE. Pull mouse hole. BID Kill and Choke lines, bleed Kearney down. Remove Kill and Choke lines. Prep to pull well head. Pull well head with well head representatives present. Set back BOP stack and old well head. Prep cellar for welding transition nipple.;Install the 9 5/8 T-109 bushing and weld ID and OD to 9 5/8 Csg stub. SIMOPS Service top drive and crown. Check oil in top drive and agitators. General house keeping. Bring on drilling to pfts.;Hauted 307 bbls cuttings to G&I for total = 307 bible Daily losses to formation= 0 blas. Total Lost to formation = 0 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 520 bbls Hauled 0 bible H2O from L -Pad lake for total = 0 boas Hauled 0 bbls H2O from Lake 2 for total = 0 bible 5119/2018 Cont weld transition nipple U9 518" CSG Stub as per procedure. Take on LSND Mud System in pits. Fix MP #1 Lube Pump leak. Inspect all slip dies & C/O as needed. Grease Choke Manifold. And BOP Stack Valves. Remove Dry Hole tree from cellar. General House keep throughout the Rig.;@ 08:30 Pre heat Transition Nipple to 600 deg, wrap in insulation and control cool as per procedure).;While waiting on Welds to cool PU/MU 5" NC-50 DP in mouse hole and set back Same. (Note: Transition Nipple @ 440 deg. Continue take on LSND mud in pits.) Plumb in grease lines for Drag Chain Bearings. Take on 9.5 ppg LSND to pits. General house keeping.;Continue PU and set back 5" NC-50 DP while wait on welds to cool.(107 Stds in Derrick @ 18:00) Note: Transition Sleeve @ 300 deg @ 14:00. Well head Rep test PT welds to 1000 psi with N2. Hold for 15 min. Test good. Temp reading @ 18:00 hrs = 140 deg.;Well head Temp. at 79 Deg. Install Cameron Well Head as per Rep onsite. Test transition seal to well head to 1,000 PSI for 15 Min. Co Rep onsite.;Set stack with spool on well head. Install choke and kill lines, flow riser and air boots. Secure stack. Obtain RKB measurements. Install long mouse hole. Bring wear bushing, retrieving tool and test plug to rig floor.;Fill stack with H2O. R/U test Equip. Body test BOPE to 250/ 3,500 PSI for 5 Min. on chart. R/D test Equip. Shut annulus and clean cellar.;Set wear ring. Wear ring out of tolerance to running tool. File and rework wear ring till in Spec, as per well rep onske. Wear ring ID 9.125".;M/U cut lip over shot to 5" Pup. RIH with 2 stands from Derrick and tag on depth (115' MD) Engage over shot P/U 10K. Set back down and M/U TD. Open internal valve WI 9 turns to the right. Check for Press. Disengage slips and POOH. UD Retrieve-O-Matic.;Hold PJSM W/ all parties for POOH and laying down 3.5" Tubing. R/U 3.5" handling Equip.;POOH UD 3.5" EUE 8 RD 9.3# L-80 101 Jnts to pipe shed.;Hauled 124 bbls cuttings to G&I for total = 431 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbls; Hauled 0 bbls H2O from 6 mi lake for total = 520 bbls Hauled 0 bbls H2O from L-Pad lake for total = 0 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 5/20/2018 Continue POOH UD 3 1/2" work String from 589' to surface. R/D 3 1/2" Handling equipment and Power Tongs. R/U 5" handling equipment.;P/U 8.5" Kick Off assy w/Varel PDC Bit, Mtr, DM, TM HOC, 2-NMDC, Float Sub, 12 x 5" HWDP, Combo Jar, 1 HWDP = 544.09' Shallow test tools. Test Goods.;TIH from 544'.Fi1I pipe with LSND Mud every 2509. Wash Dn last stand and tag TOC @ 6374'. Tag Hard CMT.;Drill cmt from 6374' to 6508'. w/500 gpm/1500 psi, 40 rpm/11.8k Tq, 25K WOB, 160 psi Diff, PU/SO/Rot 173/110/136k.;Drill cement F/ 6,508' to 6,600' MD. 500 GPM, 1,580 PSI, 40 RPM, 11.5K TRQ, WOB 25K, P/U 182, SLK 112K, ROT 134K.;Start directional drilling F/ 6,600'to 6,620' MD (4,907' TVD) 500 GPM, 1,580 PSI, 40 RPM, 11.5K TRQ, WOB 25K, P/U 183K, SLK 112K, ROT 132K.;POOH F/ 6,620' to 6,572' MD. CBU @ 500 GPM, 1,475 PSI.;Monilor well for 10 Min. static. R/U to perform FIT to 13 ppg EMW. Press. up to 890 PSI hold for 15 Min. total pumped 1.98 bbl, bleed back 1.9 bbl.;RIH and Cont. directional drilling F/ 6,620 to 6,790' MD, 500 GPM, 1,789 PSI, 80 RPM, 15-16K TRQ, WOB 25K, P/U 204K, SLK 98K, ROT 136K.;CBU 500 GPM, 1 575 PSI. Monitor well for 10 Min. static.;Hauled 731 bbls cuttings to G&IfoTlotal=1,162 WIS. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbls;Hauled 400 bbls H2O from 6 mi lake for total = 920 bbls Hauled 0 bbls H2O from L-Pad lake for total = 0 bbls Hauled 0 b Is H20 from Lake 2 for total = 0 bhIs 5/2112018 POOH on elevators from 6790' to 544'. Hole f11 correct. Noted 20K over pull f/6695'-6688'. Work through clean.; UD 2 jts HWDP, Rack back remaining HWDP. UD BHA. Bit Graded 1-1-WT-A-E-1-NO-TD. Prep to PU RSS/UR BHA.;PU RSS/UR BHA#5 w/ 8.5" REED SK616M PDC bit, Geo-Pilot, DM, DGR, ILS, EWR-P4, PWD, HCIM, ALD, CTN, TM HOC, IBS, Pony Collar, NOV Ander reamer, Float Sub, Pony Collar, IBS, 6-HWDP, Jar, 5-HWDP. = 528.22'. (Bit to UR = 122.89').;RIH singles 5" D.P. NC50 F/ 528' to 4,754' MD. Cont. RIH from Derrick F/ 4,754' to 6,583' MD. Filling D.P. every 2,000'.;Sewice rig: Grease crown, blocks, IDS350PE and wash pipe.;Cont. to RIH W/ 5" D.P. F/ 6,583' to 6,773' MD.;Wash last stand down to 6,790' MD. Tag @ 10K. Obtain parameters for Anderreamer. PIU break connection and drop 1.375" steel ball. Pump down at 400 GPM 1,130 PSI at 30 RPM. At 1,080 strokes observed tool activation and 100 PSI drop to 1,030 PSI. Start drilling with Anderreamer.;P/U and pull into ledge with 15K over for pull test. Drill ahead as per Sperry DD.;Drill 8.5" hole with Anderreamer F/ 6,790' to 6,930' MO (5,117' TVD). 575 GPM, 1,780 PSI, 150 RPM, TRQ 15-16K, WOB 25K, ECD 10 ppg EMW, P/U 226K, SLK 95K, ROT 134K. Max Gas 34 Units. Distance to plan 2.2', 1.77 low, 1.34 Ieft.;Hauled 57 bbls cuttings to G&I for total = 1,219 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbls;Hauled 130 bbls H2O from 6 mi lake for total = 1,050 bbls Hauled 0 bbls H2O from L-Pad lake for total = 0 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 5/22/2018 Drilling ahead 8.5" X 9.875" hole FI 6,930' to 7,014' MD. 600 GPM, 1,900 PSI, 140-150 RPM, TRQ 16.2 K, WOB 32K, ECD 10 PPG, P/U 222K, SLK 99K, ROT 141 K. Pump sweep @ 6,940' MD. (14 ppb Nut Plug W/ Condenl low weight, low Vis. Chase W/ low weight high Vis) 10% increase at shakers.;P/U F/ 7,014' to 7,015.5' Circ. 600 GPM, 1,878 PSI, 60 RPM, TRQ 18.6K. Discuss changing drilling parametem.;POOH F/ 7,014' to 6,880' 600 GPM, 1,910 PSI, 60 RPM, TRQ 18.2K.;SIow pump rate to 100 GPM, 250 PSI to close Anderreamer. Stage up RPM F/ 60 RPM to 120 RPM, 80 RPM TRQ 17- 18K, 100 RPM TRQ 17-18K, 120 RPM TRQ 18-19K. Stable TRQ at 18.5K. Make an attempt to clear clay off BHA.;Wash down F/ 6,880'to 7,014' MD 570 GPM, 1,700 PSI, 60 RPM, TRQ 18K, pump off weight P/U 230K, SLK 110K, ROT 145K.;Drill ahead 85'X 9.875" hole F/ 7,014'to 7,087' MD 157' total (14.27' AROP) . 400- 600 GPM, 1,500- 1,900 PSI, 60-150 RPM, TRQ 16-17K, WOB 10-40K, ECD 10 ppg. P/U 224K, SLK 99K, ROT 144K. Attempt various parameters to increase ROP. Pump tandem sweep at 7,022' MD. No increase at shakers.; Distance to plan 1.11', 0.99' low, 0.50 Ieft.;Circualte B/U to POOH 540 GPM, 1,630 PSI, 60 ROM, TRQ 18K. Max Gas 0 U., Obtain SPR at 7,087' MD MP #1 32/48 225 low 280 high. MP #2 32/48 225 low/ 285 high W/ 9.5 ppg MW.;Monitor well for 15 Min, static. POOH on elevators F17,087' to 6,420' MD. Observed no issue going through shoe with Anderreamer or BHA. No over pull observed.;Break Circ. and pump 11.5 ppg dry job at 50 GPM 60 PSI to prevent Andereamer from engaging.;Cont. to POOH on elevators F/ 6,420' to 528' MD. Monitor well via trip tank. No Iosses.;Rack Back 5" HWDP and Jars. Visually inspect NOV Anderreamer and appeared to show no wear with minor clay. Same with upper Stab. PJSM W/ all parties for nuclear source. Unload source and down load tool as per MWD rep onsite. Cont. to lay down BHA tools for rerun.;Bit Sleeve had both flow paths packed off with clay. 8.5" Bit had one jet plugged from extremely hard clay on the outside of bit. No wear on bit and all stabilizers are in gauge.;PJSM with all parties for PIU BHA #6. Left out the Bit Sleeve, 6 3/4" ALD Collar, Stabilizer and 6 3/4" CTN Collar from original BHA. Inspect 8.5" bit with no visual signs of wear. Replaced bit jets from 14/32 to 13/32 as per NOV rep onsite.;RIH 8.5" Reed PDC, Geo-Pilot, Stab, Ref Housing Stab, 6 3/4" DM Collar, 6 3/4" DGR Collar, 8 3/8" Inline Satb, 6 3/4" EWR-P4 Collar, 6 314" PWD, 6 3/4" TM HOC, 8 318" Integral Blade, Pony Collar, 9 7/8" Anderreamer, Float Sub, Pony Collar, 8 1/2" Intergral Blade, 6 Jnt 5" HW DP,;6 1/4" Weaterford Combo Jars and 5 Jnts 5" HWDP.;RIH 8.5" X 9.875" drilling BHA F/ 499' to 4,000' MD. Filling D.P. every 2,000'.;Hauled 342 bible cuttings to G&I for total = 1,561 WIS. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bible. Total Lost to formation = 0 bbls; Hauled 310 bbls H2O from 6 mi lake for total = 1,360 bbls Hauled 0 bbls H2O from L-Pad lake for total = 0 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 5/23/2018 Continue trip in hole F/ 4283' - T/ 6491' MD. Hole took correct displacemenl.;Cut and slip 63' drilling Iine.;Service rig. Grease crown, drawworks and traveling equipment.;Continue trip in hole F/ 6491' -T/ 6934' MD, Wash down F/ 6934- T/ 7058' MD. Reamer took wt on depth @ 7058' MO. Ream do F/ 7058' to 7087' MD. 535 gpm, 1585 psi, 60 rpm, 18k tq, 2k web.; Drlg 8.5" x 9.875" (reamer) hole F/ 7087' - T/ 7439 MD. 352' total (54 fph AROP). 600 gpm, 1960 psi, 53% flow, 140 rpm, 18.9k tq 10.3 ECD.; Drill ahead 8.9'X 9.875" F/ 7,439'to 7,787' (5,595' TVD) 348' total (58' AROP) 600 GPM, 2,026 PSI, 140 RPM, TRQ 19.5K, WOB 12K, ECD 10.4 ppg, P/U 236K, SLK 91K, ROT 138K. Mud weight 9.5 ppg. Encountered slower ROP around 7,720' MD, change drilling parameters to increase ROP.;Pumped 25 bbl 5 ppb Nut Plug sweep with no real increase in ROP.;Drill ahead 8.5" X 9.875" F/ 7,787' to 7,923' (5,653' TVD) 136' total ( 22.6' AROP) 600 GPM, 2,025 PSI, 80-150 RPM, TRQ 19.5K, WOB 12-15K, ECD 10.1 ppg, P/U 231 K. SLK 100K, ROT 138K. Mud weight 9.5 ppg. Encountered slower ROP <20 FPH around 7,866' MD, change drilling parameters to increase ROP.;Pumped 35 bbI 15 ppb Nut Plug W/ Condent low weight/ low vis sweep with no real increase in ROP. Distance from plan: 6.86', 2.09 high, 6.53' Ieft.;Adding 30 bbls per hour of water to reduce MBT & running both centrifuges.; Hauled 342 bible cuttings to G&I for total = 1,903 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbls;Hauled 260 bbls H2O from 6 mi lake for total = 1,620 bbls Hauled 0 bbis H2O from L -Pad lake for total = 0 bbls Hauled 0 bbis H20 from Lake 2 for total = 0 bbl 5/24/2018 Drill ahead 8.5" X 9.875" Hole F/7.923'- T/ 8,145'. 222' total (37' AROP) 600 GPM, 2,020 PSI, 100-150 RPM, 13.5K TRQ, 13K WOB, 236K P/U, 105K SLK, 146K ROT. ECD 10.2 ppg, MW 9.5 Adjust drilling parameters as needed to increase ROP.; Drill ahead 8.5" X 9.875" Hole F18,145'- T/ 8,511'. 366' total (61' AROP) 600 GPM, 2,133 PSI. 120 RPM, 21.8K TRQ, 15K WOB, 247K P/U,97K SLK, 148K ROT. ECD 10.4 ppg, MW 9.5 Adjust drilling parameters as needed to increase ROP.;SPR @ 8,320' MO ( 5,816' TVD) MW 9.5 ppg. MP #1 SPM 32- 261 PSI, 48 323 PSI. MP #2 SPM 32- 263 PSI, 48 327 PSI;Drill ahead 8.5" X 9.875" Hole F/8,51 V- T/ 8,845'. 334' total (56' AROP) 600 GPM, 2,180 PSI. 120 RPM, 23.3K TRQ, 15K WOB, 270K P/U,96K SLK, 150K ROT. ECD 10.4 ppg, MW 9.5 Adjust drilling parameters as needed to increase ROP. Pump tandem sweep at 8,575' MD 75% increase at shakers of heavy clay.;Sweep was low weight, low vis W/ 5 ppb Nut Plug and Con Dent followed by Hi Vis. Sweep returned as calculated.; Drill ahead 8.5" X 9.875" Hole F/8,845' - T/ 9,203'.(6,281' TVD) 358' total (60' AROP) 600 GPM, 2,280 PSI. 100-140 RPM, 23.5K TRQ, 15K WOB, 286K P/U,99K SLK, 153K ROT. ECD 10.5 ppg, MW 9.5. Adjust drilling parameters as needed to increase ROP. Max Gas 46U.;Oistance to plan: 7.1', 6.72' low, 2.28' left. Adding 30 bbis per hour of water reduce mud weight/ MBT & both centrifuges running.;Hauled 570 bbis cuttings to G&I for total = 2,473 bbis. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbls;Hauled 710 bbls H2O from 6 mi lake for total = 2,330 bbis Hauled 0 bbis H2O from L -Pad lake for total = 0 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbls 5/25/2018 Drill ahead 8.5" X 9.875" Hole F/9,203'- T/ 9,392'. 489' total (98' AROP). 600 GPM, 2,375 PSI, 100-120 RPM, 25K TRQ, 16-18K WOB, 315K P/U, 110K SLK, 154K ROT. ECD 10.7 ppg, MW 9.5. Adjust drilling parameters as needed to increase ROP.;Pump tandem sweeps ( Low Weight/ low Vis W/ 5 ppb Nut Plug and Con Dent followed by High Vis sweep) Sweep back 100 Stks late W/ 50% increase at shakers. CBU 2x @ 9392' MD. P/U 330k, SLK 100k, 10.8 ECD's, 24.5k TO prior to cleanup cycle.; Rotate and reciprocate pumping 600 gpm, 2160 psi, 54% flow, 60 rpm, 22k tq, 300k up, 110k dn, 10.3 ECUS (parameters post 2x BU). Increase mud weight to 9.8 ppg prior during CBU's. Negligible gas 30 U. Monitor well, static.;SPR @ 9,362' MD (6,398 TVD) Wl 9.5 ppg. MP #1 Strk 32- 235 PSI, 48-305 PSI. MP #2 Strk 32- 235 PSI, 48-300 PSI.;POOH F/ 9392'- Tl 6554' MD. P/U 218K, SLK 90K. Hole took 4 bbls over calculated. Pulled up into shoe without issue. No overpulls for trip.;Service rig. Grease crown, IDS 350 PE and wash pipe. Inspect Derrick and crown.;Tdp in hole F/ 6,554'to 9,332' MD. Filling 5" D.P. every 2,000'. P/U 300K, SLK 113K.;Obsewed proper displacement for trip in hole. Wash down Fl 9,332'to 9,392' MD 410 GPM, 1,260 PSI, 60 RPM, TRQ 23K. Begin adding 11.8 ppg spike fuid to mud system to obtain 10.3 ppg.;Drili ahead 8.5"X 9.875" Hole F19,392' - T/ 9,519' MD. 127' total (85' AROP) 600 GPM, 2,280 PSI, 120 RPM, TRQ on 21K, TRQ off 21-23K, 16-18K WOB, P/U 305K, 104K SLK, 158K ROT. Cont.weighting up mud system with 11.8 ppg spike fuid to 10.3 ppg MW.;Change out swab and liner on mud pump #1. Reciprocate 1 stand at 60 RPM, 100 GPM. SPR at 9,516' MO (6,519' DVD) MW 10.3 PPG MW MP #1 Stks 32- 290 PSI/ 48- 360 PSI MP #2 Stks 32- 290 PSI/ 48-360 PSI.;Drill ahead 8.&'X 9.875" Hale F/9,519'- T/ 9,964' (6,901' TVD). 445' total (56' AROP) 600 GPM. 2,470 PSI. 120 RPM, 21-23 TRQ K, 16K WOB, P/U 299K, SLK 113K, ROT 167K. ECD 11.1 ppg Max Gas 188U, MW 10.3 ppg.;lnitial assessment onsite at -9,800' MD, 6,762' TVD Gamma showed coming into HRZ and correlated from previous well work. Last survey 9,805.96, 29.86° Inc, 11.06" Azm, Distance to plan: 6.34', 0.83' high, 6.29' right. Adding 15 bbls per hour of water reduce MBT and both centrifuges.;Hauled 456 bbis cuttings to G&I for total = 2,929 bbis. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbls;Hauled 360 bbls H2O from 6 mi lake for total = 2,690 bbis Hauled 0 bbis H2O from L -Pad lake for total = 0 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbls 5/26/2018 Drill ahead 8.5"X9.875" Hole F/9,964' - T/ 10137'. 173'total (29' AROP). 600 GPM, 2,475 PSI. 110 RPM, 21-23 TRQ K, 16-20K WOB, PIU 315K, S/O 113K, ROT 170K. ECD 11 ppg Max Gas 1990, MW 10.4 ppg.;Still seeing bit balling issues. Pickup and wipe 20-30' when ROP slowly diminishes to re- establish good ROP. Drilling started getting a little erratic with TRQ and psi @ 10,060' MD.;Started gradually increasing MW from 10.3 to 10.5 ppg while drilling slow intervals and seeing very small amounts of shale slivers at shakers. Started adding lubes due to high tq and drag. Tandem sweep @ 10,083' MD, 75% increase and on time.;Drill ahead 8.5" X 9.875" Hole F]10,137'- T/ 10,250'. 113' total (45' AROP). 600 GPM, 2,470 PSI. 110 RPM, 21-23K TRO, 17K WOB, ECD 11.5 ppg Max Gas 60U, MW 10.4 ppg.;Drill ahead 8.5" X 9.875" Hole F/10,250'- T/ 10,466'. 216' total (62' AROP) 575 GPM, 2,509 PSI, 160 RPM, 29K TRQ, 15-19K WOB, PIU 350K, SLK 110K, ROT 176K. ECD 11.4 ppg Max Gas 430U, MW 10.5 ppg Reduced flow rate due to ECD's.;SPR at 10,218' MD (7,123- TVD) MW 10.5 ppg MP #1 Strk 32-298 PSI, 48-363 PSI MP #2 Strk 32-296 PSI, 48-366 PSI.;As per Radu Girbacea - Geo Top Kuparuk C: 10,249' MD Base Kuparuk C: 10,271' MD Top Kuparuk A: 10,438.;Drill ahead 8.5" X 9.875" Hole F/10.466'- T/ 10,492'. 26' total (13AROP) 575 GPM, 2,480 PSI. 160 RPM, 28.51K TRQ, 13K WOB, PIU 350K, SLK 110K, ROT 176K. ECD 11.4 ppg Max Gas 232U, MW 10.5 ppg Observed 2% and 10 bbl increase while drilling. Shut down rotary and space out D.P.;Observed 30K over pull spacing out. Shut down pumps. 900 U Gas at surtace.;Obsewed flow with no pumps, monitor well for 10 Min with 25 bbls back with reduction in flow out. Max Gas was 985U and falling. Started pumps up to circulate gas out and seen an increase to 1,928 U of Gas with a pit gain of 10 bbls.;Decision was made to shut in the well at 18:58. Max Gas 1,928U. AOGCC notified via email of well shut in due to flow and pit gain. Initial SIDPP 163 PSI and a SICP of 273 PSI. Start circulating through choke at 2 bpm. During circulating BU mud weight out varied from 10.6 ppg to as low as 9.0 ppg.;At 23:30 moved D. P. broke over going down at 112K, up 353K. After bottoms up we now have a SIDPP 250 PSI and SICP 490 PSI while holding our gain/loss to a barrel in and a barrel out. We are seeing a 10.6 ppg In and a 9.8 ppg out MW with 440U of back ground gas after circulating a B/U.;Our casing Press. climbed from reducing the hydrostatic by cutting back our 10.6 mud with the water influx coming from what we believe to be the Kuparuk "A" sands.;Shut down and monitor well. Initial shut in Press. SIDPP 230 PSI SICP 500 PSI. Build LCM Pill. Build 57 bbl 10.6 ppg 40 ppb Calcium Carbonate pill. After one hour SIDPP 174 PSI, SICP 504. Break circulation at 2 bpm initial SIDP 367 PSI, SICP 504 PSI. Established returns right away.;Final circulating SIDPP 400 PSI, SICP 504 PSI.;Start pumping at 2 bpm, 57 bbl 10.6 ppg 40 ppb LCM pill. Initial circulating SIDPP 427 PSI, SICP 487 PSI. Maintained about a SIDPP 420 PSI and SICP 495 PSI, 23% open choke. Spot on back side with 12.6 ppg MW. Max back ground gas was 514U.;Monftor well, pumps off initial SIDPP 196 PSI, SICP 535 PSI. Shut in press. at 05:15 SIDPP 202 PSI, SICP 532 PSI. At 05:30 SIDPP 180 PSI, SICP 534PSI. Work D.P. broke over at 106K down and 340K up. Press. at 05:45 SIDPP 156, SICP 533 PSI. Press. at 06:00 SIDPP 131 PSI, SICP 534 PSI.;Lost to formation today: 40 bbl. Total lost to formation: 40 bbl. Distance from plan: 13.57', 12.95' high, 4.07' Iow.;Hauled 556 bbls cuttings to G&I for total = 3,485 blots. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 0 bbls.;Hauled 390 bbls H2O from 6 mi lake for total = 3,080 bbls Hauled 0 bbls H2O from L -Pad lake for total = 0 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 5/27/2018 Cont. to monitor shut in pressure. SIDPP 126 PSI, SICP 536 PSI. At 08:00 SIDPP 119 PSI, SICP 533 PSI. Broke pipe over with PIU 362K, SLK 100K. Build 40 bbl 11.0 ppg 40 PPB LCM pill. Break Circ. at 2 bpm, SIDPP 354 PSI, SICP 569 PSI. SIMOPS Remove links and tighten drag chain. General cleaning.;Start bumping at 2 bpm to spot 2 nd LCM pill, with choke closed bullhead 1 st 40 bbl LCM pill into loss zone. Open choke circulating at SIDPP 350 PSI, SICP 533 to 543 PSI. Weight in 10.6 ppg, out 9.8 ppg. 450U back ground gas. Over displace 5 bbls.;FCP SIDPP 415 PSI, SICP 540 PSI. Shut down Press. SIDPP 220 PSI, SICP 563 PSI.;Monitor shut in Press. SIDPP 150 PSI, SICP 566 PSI. Work pipe at 13:00 PIU 346K, SLK 126K. Build 3 rd 56 bbl, 11.0 ppg 40 ppb LCM pill. At 14:45 SIDPP 87 PSI, SICP 569 PSI. Break Circ. at 2 bpm ICP SIDPP 354 PSI, SICP 569 PSI. SIMOPS C/O spinner cylinder, general housekeeping.;Spot 3rd 56 bbl LCM pill at 2 bpm ICP SIDPP 320 PSI, SICP 570 PSI. Circ. Press. SIDPP 338 PSI, SICP 580 PSI. Bull head 35 bbl and then open choke to 23% taking returns through choke. Increase to 3 bpm at 1,150 Strks, SIDPP 400, SICP 540 PSI with 350U back ground gas.;10.6 ppg in weight, 9.35 ppg out weight. FCP SIDPP 482 PSI, SICP 574 PSI. Slow pumps down to 0.5 bpm SIDPP 300 PSI, SICP 580 PSI. Shut in. Break pipe over P/U 336K, SLK 120K. SIDPP 215 PSI, SICP 589 PSI.;Monitor shut Press. SIDPP 214 PSI, SICP 591 PSI. AT 18:00 SIDP 155 PSI, SICP 591 PSI. Weight up active pits to 10.6 ppg.;Monftor shut Press. SIDPP 155 PSI, SICP 591 PSI. Bull head 2 bbis 10.6 ppg to prevent freeze up. ICP SIDPP 285 PSI, SICP 600 PSI. From 18:10 to 19:10 shut in Press. changed from SIDPP 132 PSI, SICP 590 PSI to SIDPP 98 PSI, SICP 588 PSI. At 19:00 break pipe over at PIU 355K, SLK 122K.;At 19:15 bullhead 2 bbls ICP SIDPP 250 PSI, SICP 597 PSI, At 20:00 shut in Press. changed from SIDPP 118 PSI, SICP 588 PSI to SIDPP 98 PSI, SICP 588 PSI. Cont. to weight up active system to 10.6 ppg.;ISP SIDP 97 PSI, SICP 589 PSI. Bled back 1.6 bbls through choke at 20%, Press. was SIDPP 94 PSI, SICP 578 PSI. After 5 Min. stable SIDPP 94 PSI, SICP 590 PSI, Bled back 2.7 bbls through choke at 20%, Press. was SIDPP 93 PSI, SICP 568 PSI. After 5 Min stable SIDPP 93 PSI, SICP 591 PSI.;Bled back 2.6 bbls through choke at 20%, Press. was SIDPP 91, SICP 570 PSI. After 5 Min. stable SIDPP 88 PSI, SICP 592 PSI. Break pipe over at PIU 355K, SLK 122K.;Initial shut in Press. SIDPP 88 PSI, SICP 592 PSI. PJSM for spotting 4th 60 bbl 10.85 ppg 20 ppb Steel Seal, 20 ppb Calcium Carbonate LCM pill of Vac Truck. Bull head first 40 bbl at 2 bpm at 20 bbls away SIDPP 380 PSI, SICP 615 PSI fell to SIDPP 342 PSI, SICP 611 PSI. Cont, bullheading at same rate;lnitial Press. prior to opening choke SICPP 345 PSI, SICP 609 PSI. Open choke to 23% ICP SIDPP 330 PSI, SICP 570 PSI. Holding one to one returns while spotting pill with 10.6 ppg MW. FCP SIDPP 410 PSI, SICP 563 PSI. SIP SIDPP 150 PSI, SICP 593 PSI.;At 60 bbls away observed gas fall to 10u and rise again at 120 blots away. Max back ground observed 398U. Mud weight wait 9.2 to 9.4 ppg out during all pumping. Break pipe over at P/U 250K, SLK 118K.;Monitor shut in Press. SIDPP 246 PSI, SICP 578 PSI. Break pipe over @ 23:19 P/U 350K, SLK 118K. At 00:15 SIDPP 183 PSI, SICP 593 PSI. Bullhead 2 bola at 1 bpm SIDPP 437 PSI, SICP 610 PSI. At 01:00 pressure SIDPP 143 PSI, SICP 593 PSI. Break pipe over at 01:00 P/U 353K, SLK 118K.;Bullhead 2 blots at 1 bpm SIDPP 330 PSI, SICP 607 PSI. Waiting up mud system to 10.6 ppg MW.;Initial shut in Press. SIDPP 115 PSI, SICP 587 PSI. PJSM for spotting 5th 45 bbl 10.85 ppg 20 ppb Steel Seal, 20 ppb Calcium Carbonate LCM pill of Vac Truck. Bull head last 65 bbl pill at 2 bpm ICP SIDPP 350 PSI, SICP 383 PSI.;At 20 bbls away SIDPP 380 PSI, SICP 615 PSI jumped up to SIDPP 620 PSI, SICP 600 PSI. Pressure was erratic until done bull heading. Open choke to 23% ICP SIDPP 360 PSI, SICP 410 PSI.;Holding one to one returns while spotting pill with 10.6 ppg MW. FCP SIDPP 410 PSI, SICP 531 PSI. Observed mud weight out 9.2 to 9.4 ppg. Max back ground gas 398U.;Monitor well pressure SIDPP 240 PSI, SICP 551 PSI. Break pipe over at 04:15 P/U 356K, SLK 113K. At 05:00 SIDPP 188 PSI, SICP 555 PSI. At 0 3,IDPP 160 PSI SICP 560 PSI. Break pipe over at 05:30 P/U 341 K SLK 115K.'Bull head 2 b Is at 1 borin ICP SIDPP 350 PSI. SICP 573 PSI, F'na 5/2 812 01 8 Monitor well pressures. SIDPP 122 / SICP 580 @ 06:00 hrs. Build active volume back to a 10.6 ppg MW. Build 13# hi wt I hi vis mud cap pill. Build 200 blols 11.2 ppg MW for mud cap displacement. Pump 2 blols every hour to prevent freeze up, Move pipe every 2 hrs - 120k dn. 340k up.;Move pipe - 120k dn. 330k up. Break circulation @ 2 BPM with erratic psi ranging from 350 to 1000 psi then packing off. Troubleshoot surface equipment for possible freeze up or plugged string. Determined string to be packed off. Work tight pipe up and on ranging from 50k do to 400k up.;Applied 12k tq slowly while moving pipe. Freed pipe 385k up and established circulation @ 2 BPM, ICP @ 305 psi, 580 psi on casing. Spot 60 bola, 13# ppg, 298 vis mud cap pill outside BHA. Disp with 11.2 ppg mud. Kept 1 to 1 returns via choke while pumping. MW out 9.4-9.6 ppg w/ 460 bgg.;FCP @ 472 psi on drill pipe. Casing held 575 psi while circulating and the same once we shutdown. 9.6 MW at tail end of displacement w/ 460 units bgg. SIDPP 200 psi, SICP 580 psi.; Lineup on TT #2. Bleed do drill pipe to 0 and monitor returns via TT. Had slight flow from drill pipe. Bled back .7 bbls over 9 min interval. B/O and rack back std #159. Been working with TDS @ crown, able to work string with TDS @ floor.;Initial shut in Press. SIDPP 31 PSI, SICP. Attempted to work string through Annular at 7 f imin, pulled 410K. Slacked back down to break overweight 112K. Made several more attempts trying to pull tool joint through bag, adjusting Annular Press. SIDPP 132K, SICP 573K.;Pressure SIDPP 103 PSI, SICP 573 PSI. Space out string in ROPE. Close LPR and bleed off BOPE pressure between LPR and Annular. Verify no pressure. Open Annular and inspect, no wear was observed. Closed Annualr, equalized pressure and opened LPR.;SIDPP 13 PSI, SICP 562 PSI. Work tool joint through Annular pulling max 410K up. Work pipe string through Annular up to 10,442' MD. Slacked back down to 10,464' MD broke over at 118K. Made several attempts to come up hole.;Bull headed at 1 bpm for 4 bbis to ensure cuing was not packing off. ICP DP 325 PSI, SICP 574 PSI. FCP DP 259 PSI, SICP 578 PSI. Shut in Press. SIDPP 85 PSI, SICP 554 PSI. Cont to work drill string F/ 10,467' to 10,442' MD. Max pull 420K, SLK 112K.;SIDPP Started climbing to 300 PSI, SICP decreased from 554 to 531 PSI. Appeared like the float was not holding. Started pumping at .5 bpm staging pressure up from 600 PSI to 1,000 PSI working string F/ 10,461' to 10,448' MD. Keeping tool joint above the Annular.;Added 3 RPM with 15K TRQ limiter set to break axial friction. Max pull 380K, SLK 71 K. Worked the string several times until pump psi started falling to normal Circ press at 376 PSI, SICP 577 PSI. Was able to establish slack off weight at 112K, Bull headed 60 bbls into formation.;Strip out of hole F/ 10,461' to 10,249' MD. Max pull was 413K, we were averaging PIU 350-380K . We bled off the SIDPP to zero with minimal flow during connections.;lt appeared to pull more consistent on the last two stands. SIDPP increased to 440 PSI and we broke circulation to ensure we were not packed off.;Monitor well SIDPP 184 PSI, SICP 621. Work pipe at 04:45 P/U 345K, SLK 114K Build 11.7 ppg kill weight mud.;Hauled 82 bbis cuttings to G&I for total = 3,567 bbls. Total fluid hauled to ORT: 500 blots Daily losses to formation= 75 bbls. Total Lost to formation = 266 blols: Hauled 130 bbis H2O from 6 mi lake for total = 3,340 blots Hauled 0 bbls H2O from L -Pad lake for total = 0 bible Hauled 0 bbis H2O from Lake 2 for total = 0 bbls 5/29/2018 Continue monitoring wellbore pressures. Continue wt up active to 11.7 ppg MW. SIDPP 310 psi / SICP 570 psi. Continue work pipe every 2 hrs and break circulation every 1 hr. 110k on / 343k up.;Temporarily detained @ 10,249' MD. Work pipe 60k do / 410k up. 14k tq to break pipe free. Work pipe free @ 10,249' MD w/ clean wts up/dn. 106k do / 342k up.;Continue monitoring wellbore pressures. Continue wt up active to 11.7 ppg MW. SIDPP 165 psi I SICP 555 psi. Continue work pipe and break circulation every 1 hr. 110k do / 343k up. Becoming more difficult to move fluid and break pipe free. Received ix truck from mud plant (waiting on 1x more).;Seeing erratic pressures while pumping then levels out. 2 BPM / 360 psi.;Continue working pipe and breaking circulation everyhour. Packing off with max pressure 800 psi. Work 410K up and 501(down to free pack off. Second truck with 11.7 ppg MW on location. prep pits.;Attempt to pump 11.7 ppg fluid, packing off at 1/2 bpm 800 psi. Work pipe 440K (10213') up weight, 50K down weight. Some rotary in downstroke (2 rpms, stalling). Workpumps 1/2 bpm - 1 bpm up to 1000 psi. Increase torque limiter to 28K, able to get 5 rpms in downstroke.;Work pipe down (40K) gaining 6' downstroke. Regain circulation at 2 bpm 1000 psi, observing an increase in casing pressure. Open up choke and hold 500 psi, bbl in bbl out.;Continue circulation, staging pumps up to 3 bpm/1000 psi ICP, FCP 550psi. Opening choke as casing pressure increases. Work pipe up - pipe free. Continue circulating at 3 bpm until 11.7 ppg fluid is at bit, holding back pressure for bbl in bbl out. Max gas 496U, MW out 9.4ppg. PUW 344K, SOW 102K.;Shut down and monitor pressures. ISIDPP 148, ISICP 438. After 10 minutes SIDP126, SICP 445 psi. Bleed off drill pipe to 0 psi and monitor, after 10 minutes SIDPP 11 psi.;Strip out of hole to above the HRZ (9808') from 10190' to 9800'. PUW 323K, SOW 106K.;Monitor pressures: SIDPP 21 psi, stable. ISICP 624 psi PJSM. Continue displacing backside to 11.7 ppg fluid at 1 bpm 1000 psi, PUW 335K, SOW 90K. No issues working pipe. bring pumps up to 1.5 bpm/1500 psi. Initial MW out 9.8 ppg, falling to 9.5 ppg.;Hauled 0 bbis cuttings to G&I for total= 3,567 bbis. Total fluid hauled to ORT: 500 bible Daily losses to formation= 214 bbis. Total Lost to formation = 480 bbls;Hauled 60 bbis H2O from 6 mi lake for total = 3,400 bbis Hauled 0 bible H2O from L -Pad lake for total = 0 bbis Hauled 0 blols H2O from Lake 2 for total = 0 bbis 513012018 Unable to establish good circulating rate. Work string to unplug. Pump 11.7 mud down @ 9804' (above HRZ) @ 1.5 BPM w/ 1500 psi max.;Max gas @ btms up 895 units / leveled off @ 820 bgg. 11.7 In / 10.8 non -psi out / 11.4 psi out reciprocate and rot pipe while circulating. 282k up, 118k dn, 1-2 rpm w/ 7-10k tq. 10.5 bbl loss for total displacement. SICP 18 psi, SIDPP 0 psi.;Shut down and monitor well (slight flow). Open annular and monitor well. Gas breaking out and had slight to moderate flow. Shut in and monitor SICP (110 psi).;Reduce annular psi and begin stripping out from 9804' MD - T/ 8890' MD. Casing psi climbed while stripping out to 300 psi. Bled off casing to 100 psi but climbed back to 300 psi.;Set psi limit to 300 psi and 12 spm max. Pump out while stripping up against closed choke.;Continue to strip out of hole from 8890' to 793T PU/SO 2201115K. Pumping 0.25 bpm with pressure limit at 300 psi, ensuring to overdisplace pipe displacement.;Tight at 7937', pull 275 (50K over). slack off 25K; free movement down. Pick up working single and Continue working tight spot up to 100K overpull. RIH to 8030' and establish circulation at 112 bpm 450 psi and 5 rpms/13Kft-lbs. maintain bbl in bbl out with choke. Work pipe up to 7937'. Slowing;speed as torques increases to 25000ft-lbs and observe torque falling off gaining 3'. Continue working pipe, stalling out top drive and staging up to 350K, slacking off to 45K gaining 20', while staging pumps/pressure up to 1-1.5bpm/1500 psi, and back down to 0.25/300 psi.;MW out 10.7 - 10.9 ppg. Max gas 1062U.;Strip in hole to 8098' with no issues, rotating 5 rpms/13Kft-lbs 1-1.5bpm/1500psi. Ream out to 791T with no issues. 2 trucks of 13.3 ppg fluid on Iocation.;Continue to work tight hole from 7917' to 7909', pulling slowly to prevent stalling rotary with 10rpms/15-25Kft-lbs 1.5 bpm/2000 psi.;Continue stripping out of hole from 7909'to 7312', pumping 0.5 bpm with pump limiter at 450 psi against a closed choke with 330 psi on casing. Gas 441.;Hauled 114 bbls cuttings to G&I for total = 3,681 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 57 bbls. Total Lost to formation = 537bbls;Hauled 60 bbis H2O from 6 mi lake for total = 3,460 bible Hauled 0 bola H2O from L -Pad lake for total = 0 blots Hauled 0 bible H2O from Lake 2 for total = 0 bbls 5/31/2018 Continue strip out of hole F/ 7312' - 6586' MD while pumping out @ 1/2 BPM (380 psi set limit). 1821k up / 106k dn. Maintain 300 psi casing pressure. Pulled into shoe clean without issue.;Strip back in well F/ 6586' - T/ 6712' MD to clear reamer from 9-5/8" casing. Displace dip volume w/ 115 bbis of 13.3 KWM. 2 BPM, 1500 psi ICP / 1440 FCP. SICP 265.;Strip up F/ 6712' - T/ 6547' MD. Lineup and bullhead down 9-50x 5" annulus w/ 263 bbls of 13.3 ppg KWM. Stg up to 3 bpm, 370 ICP / 15 FCP. Shutdown and monitor well.;Monifor well @ choke manifold, 0 psi. Verify with kill line psi, 0 psi. Verify well on vac. Open annular and monitor from rig floor. Fluid dropping in well. Fill backside w/ 11.7 mud. 205 bph initial loss rate. 60 bph loss rate after 2 hrs,;TOH on elevators F/ 6547' - T/ 4168' MD. 125k up, 90k dn. Maintain 20-30 bph loss rate using 11.7 mud w/ 13.3 spike fluid as needed. 20 fpm max pulling speed.;Notified AOGCC of upcoming BOP test via email @ 16:59. Replied back to give 2 his notice prior to start of BOP test.;Continue to TOH on elevators from 4168' to 530' MD, 16-24 bph loss rete with 11.7 ppg mud. 20 fpm max pulling speed.;Monitor well. Fluid dropping. Establish 1 hr loss rate = 14 bph.;PJSM. Rack back HWDP, UD 1 it HWDP and Jars. UD Stabilizer, float sub, Anderreamer (1 -0 -BT -P -X -1 -NO -HP), and stabilizer. Plug in and download. Continue to UD BHA. Stabalizem in gauge. Bit completely plugged with cuttings: 1-0-PN-A-X-1-DL-N-HP.;Clean and clear rig floor.;Pull wear bushing. Drain stack. Set test plug. Fill stack. Rig up to fill hole through annulus valve. Rig up to test BOPE's. Loss rate 15bph.;Hauled 107.7 bbls cuttings to G&I for total = 3,788.7 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 886 blots. Total Lost to formation = 1423 bbls;Hauled 0 blots H2O from 6 mi lake for total = 3,460 bbis Hauled 0 bbls H2O from L -Pad lake for total = 0 bbis Hauled 0 bbls H2O from Lake 2 for total = 0 bbl 6/1/2018 Finish rigging up test equipment. R/U trip tank to 9-5/8" x 5" annulus and monitor same (10-20 bph avg loss rate). Flood stack, choke and kill lines, choke manifold and purge air from system. Test BOP components 250 low / 3500 high (including annular) w/ 5 min hold on each. No failures on equip.;AOGCC rep Austin McLeod witnessed test. Test gas alarms 10/20 ppm H28, 20/40% LEL and PVT's (good). Perform Koomey drawdown Start psi - 3025, Drawdown - 1600, 200 psi inc - 28 secs, Full charge - 96 sec. 6 bottle N20 avg - 2300 psi.;R/D test equipment. 3 BPH loss rate when finished testing. Lineup and bullhead down annulus 5 bbis 13.3 bbis mud. 130 ICP, 110 FCP. Well (static).;PJSM, M/U 8.5" tricone cleanout assy wl circ sub. Float is non ported, Open jets on bit.;TIH W/ 8.5" cleanout assy T/ 3388' MD. Fill pipe every 1500' MD. Avg loss rate 12 BPH. 112k up / 88k dn.;Continue TIH W/ 8.5" cleanout assy T/3820'. Observe incorrect displacement; MW in 12.5 ppg, MW out 11.7 ppg. Monitor well, slight flow.;Prep pits. Circulate 12.5 ppg fluid all the way around at 10bpm/400psi. Monitor well, fluid level falling.;Continue to RIH to 6537'. Loss rale 12 bph.;Circutate annular volume, 12.5 ppg mud in 12.3 ppg out, stage pumps up to 9 bpm 494 psi, observe 80 bph losses, slow rate down to 5 bpm/260 psi losses 50 bph. Shut down and observe well, falling. Empty trip tanks.;Continue to TIH from 6540' to 8350' PUW/SOW 210/110k. Aver. Loss rate 50 bph. Work through tight spot from 7955' to 8000' and wipe (60K down, 30K up). Observe losses slow to 6 bph after wiping through tight spot and slowing down.;Fill pipe, circulate 186 bbls staging pumps up to 7 bpm/670 no losses. Flow check, observe gas breaking out. continue circulating hole volume at 9 bpm/563 psi. Max gas 3267u; MW in/out 12.0 ppg no losses. Flow check, slight flow. Continue circulating weighing up to 12.2 ppg;at 5 bpm/330 psi to 6.5 bpm. Start observing losses 62 bbls from surface to surface; 48 bph at 6bpm. Shut down and monitor well. Static.; Hauled 158.7 bbis cuttings to G&I for total= 3,947.4 bbis. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 228.9 bbis. Total Lost to formation = 1651.9 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 1300 bbis H2O from L -Pad lake for total = 440 bbls Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/2/2018 Continue TIH F/ 8350' - T/ 9612' MD. 245k up, 115k dn. Observed 20k drag starting @ 9397' to tag depth of 9612' MD. 11 bbl loss to 9612' MD. Tag @ 9612' MD w/ 30k dn. 30k over pull to break over.;Attempt to wash and ream past obstruction @ 9612' MD. 330 gpm, 500 psi, 15 rpm, 15k tq dn, 19k tq up. Saw 100 psi spike with light tag and tq spike (20k) @ 9612'. Tag 2x with same results (no go). 12.2# in / 12# Out mud.;Circulate 2x btms up. Rot and recip pipe F/ 9570 - T/ 9610'10D. 8.9 BPM, 574 psi, 44% flow, 15 rpm, 17k tq. Saw 8.7-9 ppg water at btms up (dumped 56 bbls) w/ 18k chlorides. Max gas @ btms up 2835u. Shakers blinded off w/ fine silt/sand then unloaded with med sized sand (beach sand).;Gas reduced to 155u bgg. 12 bph loss rate while circulating.;Shut down monitor well (slight flow). Lineup on trip tank and monitor flow rate. 8.3 bph initial flow rate and increased to 10.2 bph.;Wash and ream down F/ 9612' - TI 9835' MD. 10 bpm, 830 psi, 15-50 rpm, 15-22k tq, 2-5 fpm running speed. Consistently saw packing off and differential sticking once washing past 9612' MD. Logs show 4' thick sand @ 9610' MD. Saw another 1900u gas spike @ btms up from 20 min monitoring well.;Continue washing and reaming from 9835' to 9887', staging pumps up to max 14 bpm/1800 psi 30-80 rpms/ 15-28K torque max gas 1278U. Consistent pack -off, top drive stalls and over pulls. Adjust running speed and slack off weight to work through shales. Maintain consistent;12.2 ppg MW in. Observe crushed fine to medium shale over shakem.;Continue washing and reaming from 9887' to 9942', 12-14 bpm/1400-1800 psi 80 rpms/ 21-28K torque max gas 753U. Consistent pack -off, top drive stalls and over pulls. Adjust running speed and slack off weight to work through shales. Maintain consistent;12.2 ppg MW going in. Loss rate 20bph at 12 bpm. PUW 295, SOW 125K, ROTW 160K.;Spine rd closed due to winter breakup flooding @ 14:14, 6/2/18.;Hauled 116 bbls cuttings to G&I for total = 4063 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 251 bbis. Total Lost to formation = 1903 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 130 bbls H2O from L -Pad lake for total = 570 bbis H.,.I.d Q hhls H20 from Lake 2 for total = 0 bbis 6/3/2018 Wash and ream F/ 9942'- T/ 9960' MD. 100 rpm, 21k tq, 515 gpm, 1500 psi, 295k up, 125k dn, 160k rot.;Hung up @ 9960' MD. Work pipe - 40k dn, 430k up (fire jars est 15 times w/ 100-200k overpull). Using rotary (15-100 rpm)(15-26k tq). Work pump 2-12 bpm. Established limited circulation (4 bpm) after freeing pipe w/ good rotation.;Rack back stand and PIU working single (31.44'). Work pipe and establish good circulation staging up very slowly to prevent packing off. Stage up to 12.3 BPM, 1485 psi, 53% flow, 80 rpm, 19k tq, 160 bgg. Shakers unloaded at btms up shale cuttings w/ sand. No significant signs of running shates.;Wash and ream F/ 9960' - T/ 9975' MD. 80 rpm, 19-23k tq, 515 gpm, 1490 psi, 295k up, 125k on, 160k rot. Set running speed @ 5.5 fpm and ream w/ 20-40k wob.;Packed off. Work pipe and slowly stage pumps up to 12.2 bpm, 1485 psi, 54% flow, 80 rpm, 19k with occasional stalls. Pump 48 bbis hi vis/nut plug/condet sweep (100% inc) 28 bbis Iate.;Wash and ream F/ 9975- T/ 9985' MD. 80 rpm, 19-23k tq, 515 gpm, 1490 psi, 310k up, 100k dn, 164k rot. UD working single and make connection.;Wash and ream from 9985' to 10037'MD, 100 rpms/21-26Kft-lbs, 12-14.7bpm/1380-1800 psi. Work packoff and stalls, and over pulls. maintain 12.2ppg MW going in. Max gas 655U. PUW310, SOW 110, ROTW 162. No Iosses.;Packed-off at 10,037', work pipe and establish rotary and pumps staging backup to 100rpms/14.7 bpm Max gas 791 U at bottoms up after being packed off.;Continue Wash and ream from 10037to 10139'MD, 100 rpms/21-26Kft-lbs, 12-14.7bpm/1380-1800 psi. Work packoff and stalls, and over pulls. maintain 12.2ppg MW going in. Max gas 761 U. PUW 310, SOW 110 ROTW 162. Pump high viscosity sweep at 10079' (50%, 93 bbis late).;Loss rate 8-10 bph. No packoffs past 10,075', still erratic torque.;Hauled 251 bbls cuttings to G&I for total = 4314 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 125 bbls. Total Lost to formation = 2028 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbis Hauled 200 bbls H2O from L -Pad lake for total = 770 bbls Hauled 0 bbis H2O from Lake 2 for total = 0 bbls 614/2018 Continue wash and ream down F/ 10.139'- T110,390' MD. 60 fph optimum to minimize stalls and hang ups. 620 gpm, 1880 psi, 54% flow, 100 rpm, 20-25k tq, 2-5k wob. 180 avg bgg, 671 u max gas. 12.2 MW in/out. Attempt to wash do past 10390 @ 3bpm, no rot (8k do / no go). 340k up, 109k dn, 169k rot.;Circulate and condition hole @ 10,390' MD ix btms up w/ 12.2 MW. Rol and Recip pipe. 80 rpm. 20k tq, 620 gpm, 1885 psi, 54% flow. ECD's calc 13.05 (620 gpm, 12.2 MW). 8-12 bph loss rate. Wt up F112.2 to 12.4 with reduced pump rale 380 gpm (Calc ECD's 13.05), 925 psi.;Continue to weigh up mud from 12.2 ppg to 12.4 ppg with reduced pump rate of 380gpm to minimize ECD's FCP 900psi, 80 rpms120Kft-lbs reciprocating pipe. Monitor well, slight drop.;POOH on elevators from 10,390' to 6540'; pulling 10-20fpm to minimize swab. Tight at 9753' with 60K overpull, 10k slack off, wipe once and pulled clean. Monitor well inside casing shoe, slight drop.;Slip and cut 130' of drilling line. Service rig: top drive, crown, draw works. Monitor well on trip tank; loss rate 2 bph.;Continue to POOH with cleanout assembly from 6540' to 3703'. PUW 122K SOW 86K. Displacement this far: calculated 47.5, actual 56.4 bbls.;Hauled 289 bbis cuttings to G&I for total = 4603 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 233 bbls. Total Lost to formation = 2261 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 390 bbls H2O from L -Pad lake for total = 1160 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbIs 6/5/2018 Continue to POOH with cleanout assembly from 3703' to 550' at 30fpm to prevent swabbing.;PJSM on laying down BHA. Monitor well on trip tank - static.;Rack back HWDP. UD jarsand collars. Break bit. Bit grade 5 -4 -WT -A -E -2 -CD -BHA, all three cones showed cone drag.;Clean and clear rig floor. Prep pipe shed to pickup ECP. Rig up fill up line. Bring crossovers to rig floor.;Service rig: top drive, draw works, crown.;Lay down excess HWDP in derrick no needed for ECP run.;Pick up ECP. Check floats- good. RIH with ECP to 2020' drifting out of the derrick, filling on the fly. 30 fpm to minimize surge pressures.;Continue to RIH with ECP from 2020' to 6540' drifting out of the derrick, filling on the fly. 30 fpm to minimize surge pressures.;Sewice rig: lop drive, draw works, crown, washpipe.;Continue to RIH with ECP from 6540' to drifting out of the derrick, filling on the fly. 30 fpm to minimize surge pressures. Start observing drag setting down 20K at 8000', work through. Continue to see 5-10K drag, set down at 8280' 20K unable to wash through. Establish circulation;/ bpm/300 psi and wash down to 8330'. Continue tripping from 8330' with 5-10K drag down to 8500' to 9656' set down 20K. Work down to 9659'. Pickup working single and establish circulation 1.5 bpm/400 psi. Attempt to wash down. PUW 240K SOW 115K.; Hauled 0 bbis cuttings to G&I for total= 4603 bbis. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 11 bbis. Total Lost to formation = 2272 bbis; Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 130 bbis H2O from L -Pad lake for total = 1290 bbls Hauled 0 bbis H20 from Lake 2 for total = 0 bbl 6/6/2018 Cont TIH w/ECP & attempt to work past 9659'. Set Dn 25K Max per BOT Rep. Circulate @ 1.5 - 3.75 bpm 500 psi set point per BOT Rep. PUW 240K, SOW 115Kw/pumps on. Reciprocate 30' clean, no over pulls observed. Lost returns @ 112 btms up. Attempt to reestablish returns with varying rates.;Lost 100 bbis during circulation.;Pump OOH f/9659'to 9470' @ 1/2 bpm attempting to regain circulation. Line up on Trip tank and monitor static loss rate. Observed loss rate decrease from 30 bph to 16 bph over 20 minutes. Decision made to TOH for 2 7/8" CMT String.;POOH on elevators from 9470' to 6560'. w/32 bbis over displacement. Observed 6 bph static loss rate inside the Shoe.;CBU staging rate to 3 bpm 260 ICP, 200 FCP. PU/SO 167K/100K. Observed up to 50 bph loss rate w/circulating. As low as 11.9 MW out, Max gas 98u. Lost 124 bbis on circulation. Tour Loss 262 bbls.;Monitor well on trip tank for 10 min. w/24 bph loss rate. POOH from 6560' to 70'. Break crossovers and UD ECP. Calculated displacement 75 bbis, actual 176 bbls. Start building 150 bbis of mud.;Clean and clear rig floor. Rig up Weatherford tongs, C/O Elevators. PJSM. Loss rate 9bph.;Pick up and single in the hole with cement string, 2-7/8" EUE to 869. PUWlSOW 44K.;Continue to RIH with cement string on drill pipe from 866' to 6540' PUW 154 SOW 97. Calculated displacement 42.5bbls actual displacement 20.8bbls.;Establish circulation at 1.5 bpm 175 psi, stage up to 3 bpm 240 psi loss rate 60 bph, slow pumps to 2 bpm 195 psi loss rate 30 bph. MW coming out 12.0 ppg. Monitor static loss rate while blending active mud with 12.5 ppg to maintain 12.4 ppg going in. Static loss rate 3bph.;Hauled 0 bbls cuttings to G&I for total = 4603 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 363 bbis. Total Lost to formation = 2635 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbls Hauled 230 bbis H2O from L -Pad lake for total = 1520 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/7/2018 Wash in hole from shoe with 2 7/8' CMT Stinger on 5" DP, pumping 14 to % bpm as to not plug stinger. @ 7240' start loading LCM pill in pipe while washing down. Work through set On @ 9138'. @ 9500' start seeing slight increase in returns. @ 9560' increased returns with 25% Iosses.;Ease in hole washing down f/ 9560'to 9659' with LCM pill exiting the stinger @ 1 bpm/300 psi, PU/SO 2151115. Encounter 10K Set Dn @ 9660', work through tight spot w/2.8K Tq, 1/2 bpm, gained 6' while working pipe, then broke through.;Wash down f/9666'to 10,395'@ 1 bpm/300 psi, PU/SO 2401115, observe 20 bph Ave Loss Rate. (10105', 101 44'set On 10k and work through with no issues.);Pump 48 bbis LCM Pill and begin displacing @ 2 bpm/450 psi. Observed up to 55 bph (45% loss) loss rate while displacing, reciprocating pipe. Begin building 200 bbis of 12.4 ppg mud. HES begin batching up cement spacer. Slow pumps to 1 bpm/330 psi once sweep exits stinger to conserve mud. Loss;mte 41 bpm (69% loss mte).;PJSM on cementing. Slow pumps down to 1/2 bpm. Observe fluid level falling in stack at 1/2 bpm. Increase rate to 2 bpm/429 psi to gain circulation. Loss rate 60 bpm (71 % loss rate). Continue building 200 bbis 12.4 ppg fluid. Shut down and monitor on trip tank while rigging up cement Iines.;Static loss rate 15 bph.;Cement as per detail. Fill lines and PT 100012000 psi. Pump 26 bbis 13.5 ppg Tuned Spacer III at 3bpm/630 psi followed by 65 bbis 15.8 ppg class G cement 4bpm/560 psi, 4 bbis 13.5 ppg Tuned Spacer III followed by 165 bbls of 12.4 ppg drilling fluid. Begin displacement at 5 bpm ICP 355 psi;lo catch cement and slow to 4 bpm/357psi after 93 bbis; 3 bpm (FCP 506 psi) last 25 bbis. Tuned spacer had 1/2 ppb LCM (Polyflake). Lost 132.2 bbis (50% loss rate). CIP at 00:21.;POOH from 10390'to 9130'. PUW 198, SOW 110K.;Break circulation at 2 bpm. Drop drill pipe wiper ball and circulate drill pipe clean. ICR 3bpm/345 psi with initial loss rate of 144bph. Slow to 2 bpm/340psi with 74 bph loss rate (63%).;Continue to POOH from 9130' to 7366'. PUW 178K, SOW 100K. Calc hole fill 20 bbis, actual 55.8 bbls.;Hauled 87 bbis cuttings to G&I for total = 4690 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 678 bbis. Total Lost to formation = 3313 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 390 bbis H2O from L -Pad lake for total = 1910 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/8/2018 Continue to TOH with cement string f/7366' Casing Shoe. monitor well on trip tank f/30 min with 14 bph loss rate.;Service rig.;Cut & Slip drill line. Perform inspection of drill line past proposed cul. Cut 56' off drum, slip 56' new line. Check Broke tolerances. Monitor well w/10 bph static loss rate.;MU top Drive, Stage pump up to 4 bpm1400 psi and spot 54 bbls/75 ppb LCM Pill in the annulus.;POOH (/6543' to 866'. (Calculated hole fill 70 bbls, Actual 148 bbls).;RU to lay down 2 7/8" Tubing, monitor well on Trip tank with 7 bph static loss rate. POOH UD 2 7/8" Cmt String. R/D @ 7/8" Handling Equipment. RU 5" Handling equipment.;PU Bit, organize BHA in Pipe shed. Strap and Tally 11 jts HWDP.;MU BHA: NOV tricone bit, 7" mud motor, DM collar, RLL collar, float sub. drill collar. Plug in and upload. Continue to M/U BHA (2) Drill collar, (6) HWDP, Jars, HWDP, Circ sub, (4) HWDP. Shallow pulse test.;RIH with cleanout assembly from 556 to 6548' filling pipe every 2500'. 17.4 bbis under calculated displacement.;Circulate hole cutting mud weight to 11.7ppg. Stage up from 4bpm/585 psi with 20bph loss rate up to 9 bpm/1320 psi minimal losses ECD's 12.4 ppg. Increase background LCM concentration to 27 ppb. PUW 173K, SOW 107K. Shut down and monitor, slight flow showing down. Circulate drill pipe volume.;Monitor well. Slight flow. Initial rate 6.3 bph consistently slowing to 0.4 bph.;Hauled 132 bbls cuttings to G&I for total = 4822 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 311 bbis. Total Lost to formation = 3624 bbis; Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 390 bbis H2O from L -Pad lake for total = 2300 bbls Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/9/2018 Continue to RIH with directional cleanout assembly from 6548' to 9638'. PUW 294K, SOW 114K.;Wash down from 9638' at 400 gpm/1720 psi; Tag stringer at 9940' with 60 psi diff and 3-4K WOB. Tag up hard cement at 10,050'. Pickup and drytag with 15K down. Pickup and establish parametem.;Drill cement from 10,050' to 10,065' at 400 gpm/1720 psi, 60rpms/22000 ft -lbs WOB 8-12K. PUW 300K, SOW 120K, ROT 174K. Torque stalled, packed off.;Work pipe, start jarring at 350K staging up to 480K. Vary parameters, applying torque (up to 26Kft-lbs) and pressure (2850 psi) while working pipe. No movement, no circulation. Turn on hole fill pump to monitor well while working pipe.;Perform derrick inspection.;Work pipe, jarring up to 480K. Vary parameters, applying torque (up to 26Kft-lbs) and pressure (2850 psi) while working pipe. No movement, no circulation. Continue monitoring well on trip tank while working pipe, no Iosses.;Hauled 57 bbls cuttings to G&I for total = 4879 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 108 bbls. Total Lost to formation = 3732 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbis Hauled 230 bbls H2O from L -Pad lake for total = 2530 bbis Hauled 0 bbls H2O from Lake 2 for total = 0 bbis 6/1 012 01 8 Work pipe, jarring up to 480K. Vary parameters, applying torque (up to 26Kft-lbs) and pressure (2850 psi) while working pipe. No movement, no circulation. Continue monitoring well on trip tank while working pipe, no losses.; Post jarring derrick inspection.;Work pipe, jarring up to 480K. Vary parameters, applying torque (up to 26Kft-lbs) and pressure (2850 psi) while working pipe. No movement, no circulation. Continue monitoring well on trip tank while working pipe, no Iosses.;Service rig, grease crown.;Work pipe, jarring up to 480K. Vary parameters, applying torque (up to 26Kft-lbs) and pressure (2850 psi) while working pipe. No movement, no circulation. Continue monitoring well on trip tank while working pipe, no losses. Inspect drilling line periodically. Prep for E -Line Ops.;Rig up Pollard E -line. M/U free point tool. Pass tool through well commander on surface to ensure it will go.;RIH with free point tool on E -line to 4550', set down multiple times with no overpull. Appears 4" centralizer unable to pass through tool joint. POOH.;Add weight bar to free point tool and resize centralizer from 4" to 3.5". RIH with E -line to 9552', 2 HWDP above well commander. Set tool and calibrate. RIH 1 HWDP and confirm calibration. RIH to 9867' (last joint of HWDP above collars). Set tool and confirm pipe is free.;Set at 9872' to double check. RIH to 9973' just above float sub last NMDC. Set tool and confirm pipe is free. POOH with E-Line.;Hauled 57 bbis cuttings to G&I for total = 4879 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 0 bbis. Total Lost to formation = 3732 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbis Hauled 130 bbls H2O from L -Pad lake for total = 2660 bbls Hauled 0 bbis H2O from Lake 2 for total = 0 bbls 6/11/2018 Set Pollard E -line aside after Free Point Run. Pipe Free all the way to Float Sub. M/ top drive. Hold detailed PJSM, discuss plan for back off.;Back Off Ops: , Install left hand tq into string in 2 turn segments, working tq down each time pulling 350k, S/O 115-110K. 8 left turns total, 22K max tq, after working tq down 15.5K tq. Set and tie slips handles together. Hold torque with tongs, set rotary lock, clear rig floor, break out of TD,;install pump in sub and pack off, Stab a -line tools in pipe. Re -latch elevators, RIH w/ 640 grain shot on a -line Log BHA w/ CCL and locate the tool it on 1st jt HWDP above NMDC . Park w/ CCL @ 9854.5, TS @9856', BS @ 9861'. Fire shot with good indication in unit, no indication on floor.; POOH with E -Line. Set Eline aside. Make up Top Drive. Release rig tongs & see 15.51K Tq still in string. Work pipe w/350 Up/115 Dn, Tq not falling. Apply more LH Tq to pipe 1/4 turn segments to 18.6K final/8 3/4 LH Wraps. Set 155K in slips. Go in with 820 grain string shot.; Fire shot across same tool jt as previous run, with good indication in unit, no indication on floor. Set E -Line aside, Release Tq from tongs and take over with TD. TD reading 17.5K. Work pipe from 110K to 360K staging Tq to 19K before breaking over and falling to 4.8K.; Establish circulation staging up to 16 bpm 1630 psi, 60 rpm/19-21 k Tq. Dispalce hole to w/ 11.7 ppg/2%lube. Wash Dn to TOF multiple times wl no rotary. TOF @ 9865'. Confirm with 13K tag. Max Gas 454u. PU/SO/Rt 254k/118k/164k. Saw spacer/cmt/LCM and fine sands on circulation. No large debris.;Monitor well on trip tank while R/D manual elevators/bail extensions and install hyd elevators. Slight flow consistently slowing to 0.6 bph after 30 minutes.;Altempt to POOH on elevators, swabbing. Pump out of the hole at 4 bpm/300 psi pulling 40rpm (70% annular velocity) PUW 286K, SOW 116K. Flow check after 5 stands, static still swabbing. Pump out of hole to 6433' inside shoe. Monitor well, static. 4.31bbls over calculated displacement.;Circulate 2 x annular volume staging pumps up to 14 bpm/ 1046 psi, while inspecting drill Iine.;Cut and slip drilling line. Grease crown. Perform derrick inspection. Recalibrate blocks.;Attempt to POOH on elevators, still observe swabbing. Pump out of hole at 7 bpm to 5995'. POOH on elevators to 5430'.;Hauled 114 bbis cuttings to G&I for total = 4993 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 3732 bbis; Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 100 bbis H2O from L -Pad lake for total = 2760 bbls Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/12/2018 POOH on elevators to 5430'to surface racking back DP and 4 stds HWDP. UD jars, Well Comanderand 3 jts HWDP. Inspect back off jt. Pin end in good condition. Clean and Clear Rig Floor. Hole fill calculated 75 bbls, Actual 83.3 bbls.;Mobilize tools to rig floor. MU BHA as per BOT Fishing Rep. 4 1/2" Screw in Sub, Safety Jt, Rupture disc Sub (2,700 PSI), Bumper Sub, Oil Jar, 10-6 %" H-90 DC's, XO sub, Intensifier. Total BHA = 347.25' with the Jars 25' above the top of fsh.;TIH with fishing BHA from 347' to 6589'. PU/SO 186K/108K.;Change out saver sub on TD. Inatall 4 1/2"DS-50 SVR Sub. Grease wash pipe, crown cluster, blocks and TD. Monitor well opn TT. Well static.;Continue TIH from 6589'to 7,665' MD. P/U 215K, SLK 106K. Wash F/ 7,665' to 7,728' MD 210 GPM, CP 320 PSI. Cont. to RIH on elevators F/ 7,728' to 8,864' MD. Broke circulation due to possible pipe plugging off. Circulate at 290 GPM, CP 500 PSI. No indication of plugging.;Wash down F/ 8,864' to 9,666' MD. Rotate 30 RPM, 21.51K TRQ, 240 GPM, CP 240 PSI. working through tight spot at 9,666' to 9,675'MD. Cont. to wash down to 9,864' MD. Slow pump rate to 84 GPM, 185 PSI, wash down TOF @ 9,874' MD. Set down 5K and pump pressure increase to 320 PSI.; Reciprocate F/ 9,838'to 9,862' MD. Circ. Bottoms up at 500 GPM, 1,140 PSI, 60 RPM, TRQ 19-21 K.;Attempt to engage fish with working single F/ 9,860' to 9,890' MD. 84 GPM, 200 to 500 PSI, 0-20 RPM, TRQ 18-25.5K, HST 305K, SLK 126K. No positive conformation of engaging fish.;UD working single and Kelly up on stand from Derrick. Wash down trying to engage fish F/ 9,866' to 9,928' MD. 84 GPM, 160 to 527 PSI, 30 RPM, TRQ 19-25k. No real erratic torque or pressure increase to indicate washing past top of fish. Pipe stalled out at 25K and had to pull 40K over to get free.;Rack back one stand, P/U M/U working single and make several attempts to find TOF F/ 9,851' to 9,870' MD. 84 GPM, 130 to 280 PSI, 0-30 RPM, TRQ 15K, HST 305K, SLK 121 K. No indication of tagging TOF.;POOH on elevators F/ 9,870' to 8,770' MD. Monitor 10 stands pulling off bottom with no swabbing. Pump 12.5 ppg dry job. Cont. POOH on elevators F/ 8,770' to 4,161' MD.; Hauled 39 bbis cuttings to G&I for total= 5,032 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 4 bbls. Total Lost to formation = 3,736 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 130 bbis H2O from L-Pad lake for total = 2,890 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/13/2018 Continue POOH f/4198'to 347' rack back DP. PU/SO 60K/60K. Calculated hole fill on trip.; POOH UD Spiral DC"s & Baker fishing tools. Clean and clear rig floor.;R/U to handle 2 7/8" Tubing Cmt String. Load Strap and tally same.;PU and RIH with 2 7/8" Cement String to 837'. R/D 2 7/8" Handling equipment. RU 5" Handling equipment.;TIH with cement string on 5" DP f/837to 6575'. PU/SO 152K100K. Correct displacement on trip to shoe.;Service rig . Monitor well. Well Static.;Break circulation @ shoe. Stage pumps to 7 bpm/540 psi. No Losses. Continue TI from 6575'to 8404' breaking circulation through cmt stinger every 10 stands. PU/SO 186K/71 OK.;Cont. to RIH W/2 7/8" Stinger Assy. on 5" D.P. F/ 8,404' to 9,607' MD. Break Circ. every 10 stands. Wash down F/ 9,607' to 9,857' 125 GPM, 385 PSI, P/U 210K, SLK 118K.; Break Circ. stage up to 7 bpm, 775 PSI with no losses. Max Gas 189U. CBU reciprocate F/ 9,790' to 9,853' MD. Attempt to rotate not to exceed 2,500 ft/lb, no success.;Have PJSM with all parties.;Stinger at 9,857' MD. Haliburton pump 3.5 bbis H2O PT low press 890 PSI KO @ 1,100 PSI, high press 3,450 PSI. Pump 26.9 bbl 13.5 ppg Tuned Spacer III Yield 1.10113/sk, 5.91 gal/sk. 2.24 bpm, 280 to 300 PSI. Pump 47.6 bbl 15.8 ppg Premium G Yield 1.154 ft3/sk, 4.98 gal/sk. 4 bpm 740 to 474 PSI.;2 bbis 13.5 ppg Tuned Spacer III chased with 1 bbl H2O to clear line. Turn over to rig, rig pumped 11.65 ppg -SND at 7 bpm to catch cement at 20 bbl away. Cont. to pump at 7 bpm ICP 650 PSI. Reduce pump rate to 6 bpm at 1,677 strokes (104 bbl) 780 PSI.;Cont. pumping at 6 bpm FCP 827 PSI. Shut down pumps at 2,530 strokes. (156.86 bbl) CIP @ 12:40. TOC at 9,357' MD.;Rig down cement lines, drill pipe static. POOH 9 stands F19,857' to 9,287' MD. Put 5" wiper ball in drill string.;Pump 5" wiper ball down string and CBU. Stage pumps up to 7 bpm, 665 PSI. Max Gas 9U.;PJSM with all parties. RIH F/ 9,287' to 9,351' MD. M/U Cement Equip. break Circ. at 84 gpm, 240 PSI. Stinger at 9,351' MD. Haliburton pump 3.0 bbis H2O PT low press 1,048 PSI KO @ 1,000 PSI, high press 3,324 PSI. Pump 27 bbl 13.5 ppg Tuned Spacer III Yield 1.10113/sk, 5.91 gal/sk. 3.05 bpm, 350 to 380 PSI.;Pump 50 bbl 15.8 ppg Premium G Yield 1.154113/sk, 4.98 gal/sk. 3 bpm 352 to 200 PSI. 2 bbis 13.5 ppg Tuned Spacer III chased with 1 bbl H2O to clear line. Turn over to rig, rig pumped 11.65 ppg LSND at 7 bpm to catch cement at 24 bbl away.;Cont. to pump at 7 bpm ICP 622 PSI. Reduce pump rate to 6 bpm at 1,607 strokes (100 bbl) 635 PSI. Cont. pumping at 6 bpm FCP 521 PSI. Shut down pumps at 2,336 strokes. (144.83 bbl) CIP @ 05:23. TOC at 8,829' MD.;Rig down cement lines, drill pipe static. POOH F/ 9,351' to 9,039' MD. P/U 215K, SLK 110K.;Hauled 29 bbls cuttings to G&I for total= 5,061 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 0 bbis. Total Lost to formation = 3,736 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 100 bbis H2O from L-Pad lake for total = 2,990 bbls Hauled 0 bbis H2O from Lake 2 for total = 0 bbls 6/14/2018 Continue TOH from 9039'to 8780', pulling above calculated TOC. PU/SO 206K/1 06K. No Wiper ball pumped through stands 127-135.; Load wiper ball, Circulate ball down top clean DP. Continue circulate STS treating mud, staging up to 10 bpm/1225 psi. Reciprocate pipe, PU/SO 198K/108K. Sht Dn and monitor well. Well Static.;POOH from 8780' to 6542'(Shoe) PU/SO 152K1100K. Monitor well, well static. Hole fill correct.;Continue to TOH from 6542' to 837'. PU/SO 45K/45K. Calculated hole f11 on trip.;R/U Weatherford Power tongs and 2 7/8" handling equipment. POOH and UD Same. R/D Weatherford, clean and clear rig floor.;Pull Wear Bushing. R/U to Test ROPE on 5" Pipe size.;BOP Test: Test W/ 5" test joint, low Press. 250 PSI, high 3,500 PSI all on chart. Choke Manifold Valves 1-15, Mezz Kill, Manual Choke and Kill, HCR Kill, Annular, Upper and Lower Pipe Rams, Blind Rams, Super Choke and Manual Choke. HCR Choke did not test and was rebuilt.;TIW tested good initially, then started leaking. Replaced TIW with new one and tested good.;Attempt to retest Choke HCR, was unable to get test. Open Valve body and found damaged seals. Replaced seals and reassembled. Test Choke HCR, passed. Test blind Rams. Perform Koomey draw down 200 PSI increase 23 sec, full charge 95 sec. 6 Bottles average 2,287 PSI.;Test ROPE to 250/3500 psi. Test witness waived by Matt Herrera.;R/D test Equip. Blow down choke and kill. Install 9.125" ID Wear Bushing.;PJSM P/U M/U 8.5" Clean out BHA.;Hauled 139 bola cuttings to G&I for total= 5,200 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 0 bbis. Total Lost to formation = 3,736 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 360 bbis H2O from L-Pad lake for total = 3,350 bbis Hauled O bbis H2O from Lake2 for total - 6/15/2018 PU clean out BHA: Hughes VM-1 Tricone , Bit Sub, Non-mag Stabilizer, 2-NM Flex Collar, 6 x5" HWDP, Jar, 1 x 5" HWDP, Well Commander, 4 x 5" HWDP. Total Length 455.99'.;TIH elevators 1/455' to 6448' (Shoe) Hole took proper fII.;Service Rig.;CBU before going into Open Hale @ 12 bpm/ 1,055 psi. No Losses on circulation.;TIH on elevators to 6574' to 8330'.(wash through set Dn @ 8271' to 8276').;Wash/Ream from 8330'to 9415' looking for hard cement. See stringers @ 9200'w/5-8K web drilling off, @ 9290 see firm cmt w110k web. @ 9311' wt fell off to 1-2k wob.;Wash and ream F/ 9,415' to 9,600' MD 450 GPM, 1,275 PSI, 50 RPM, TRO 19-24K, WOB Intermittent 1 OK drilling off to 2K. Cont. F/ 9,600' to 9,650' MD. WOB 1 OK drilling off to 8K. P/U 254K, SLK 117K, ROT 162K.;Rotate and reciprocate F/ 9,650'to 9,600' MD 450 GPM, 1,275 PSI, 50 RPM, TRQ 19-24K, Circ. BU and started seeing hard cement at BU. P/U 285K, SLK 114K, ROT 162K. No losses to fonnation.;Monitor well for 10 Min, static. POOH F/ 9,650' to 9,352' MD 5 stands and monitor well while pulling. Pump 13.1 ppg dry job. Cont to POOH on elevators F/ 9,352'to 6,560' MD;Put floor valve in. Monitor well. Grease crown, IDS 850 PE and clear rig floor. Work on shot pin on IDS 850 PE.;Monitor well 10 Min, static. POOH F/ 6,560' to 5,555' MD. No losses to formation.;Hauled 173 bbis cuttings to G&I for total = 5,373 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 0 bbis. Total Lost to formation = 3,736 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 130 bbis H2O from L-Pad lake for total = 3,480 bbis Hauled 0 bbIs H20 from Lake 2 for total = 0 bbis 6/16/2018 TOH from 5565' to 455'. Monitor well @ HWDP. Well static. Prep floor to UD BHA.;Lay down BHA from 455'to surface. Bit graded:1-2-BT-G-E-1-BHA.;Clean and clear rig floor. RU Weatherford 2 718" handling equipment.;PU 26 jts (836') 2 7/8" tubing with cmt stinger. R/D 2 7/8" handling equipment. RU 5" Handling equipment.;TIH on elevators with 5" DP from 836' to 6572' with correct hole fill.;Circulate drill string volume 2 the shoe. 375 gpm/890 psi, PU/SO 157K/96K.;Continue TIH on elevators from 6572' to 9,606 MD., Break circulation every 10 stands to ensure stinger is not plugged. Wash down F/ 9,606'to 9,650' MD tagged with 31K down. 504 GPM, 1,745 PSI, P/U 218K, SLK 107K.;Cont. circ. BU at 9.650' stage up pump rate to 504 gpm, 1,737 PSI. Max gas at BU 90U. Attempt to rotate, was unable not to exceed 2,500 TRO. Prep for cement job. Blow down IDS850 PE, R/U Halliburton and cement Equip. Cont. Circ. 295 GPM, 960 PSI.;PJSM with all parties. Stinger at 9,634' MD. Haliburton pump 6.0 bbls H2O PT low press 1,160 PSI KO @ 1,178 PSI, high press 3,561 PSI. Pump 25 bbl 13.5 ppg Tuned Spacer III Yield 1.10 fl3/sk, 5.91 gal/sk. 3.36 bpm, 105 to 542 PSL. Pump 60 bbl 15.8 ppg Premium G Yield 1.154 R3/sk, 4.98 gal/sk. At 3.8 bpm 830 to 187 PSI. 3.5 bbls 13.5 ppg Tuned Spacer III chased with 1 bbl H2O to clear Iine.;Turn over to rig, rig pumped 11.65 ppg LSND at 10 bpm to catch cement at 5 bbl away. Cont. to pump at 7 bpm ICP 506 PSI. Reduce pump rate to 5 bpm at 2,075 strokes (128 bbl) 705 PSI.;Cont. pumping at i bpm FCP 288 PSI. Shut down pumps at 2,370 strokes. (147 bbl) CIP @ 00:24. TOC at 9,016' MD.;Rig down cement lines, drill pipe slightly out of balance. POOH at 30 FPM 13 stands F/ 9,634'to 8,781' MD. P/U 208K;Put 5" wiper ball in drill string pump at % bpm for 4 bbls to clear cement out of stinger Assy. Increase circulating rate to 294 GPM, 640 PSI. Circulate BU. No indication of spacer at shakers.;POOH on elevators F/ 8,785' to 3,426' MD. P/U 225K, SLK 115K.;Hauled 171 bbls cuttings to G&I for total = 5,544 bbls. Total fluid hauled to ORT: 500 bible Daily losses to formation= 0 bbls. Total Lost to formation = 3,736 bbls;Hauled 0 bible H2O from 6 mi lake for total = 3,460 bbls Hauled 130 bbls H2O from L-Pad lake for total = 3,610 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 6/17/2018 Continue to TOH w/ cement string from 3421' to 836'. Correct hole fII.;Change out handling equipment to 2 7/8". R/U Weatherford Tongs. POOH and UD 2 7/8" tubing from 836' to surface. R/D Weatherford. Clean and clear rig floor.;Service Rig. Adjust counter balance valve. Replace ground on lube pump. Replace elevator pressure switch. Pressure wash Top Drive.; PU clean out BHA: Hughes VM-I Tricone , Bit Sub, Non-mag Stabilizer, 2-NM Flex Collar, 6 x5" HWDP, Jar, 1 x 5" HWDP, Well Commander, 4 x 5" HWDP. Total Length 455.99'.;TIH f/455' to 6570'. Correct displacement on trip in.;Circulate drill string volume @ 310 gpm/580 psi.;Cut and slip Drill Line. Cut 107' of drilling llne.;RIH on elevators F/ 6,570' to 8,784' MD. Hole taking proper hole fill. Fill pipe every 2,509. P/U 230K, SLK 106K.;Wash down F/ 8,784'to 9,099' MD. 400 GPM, 1,088 PSI, TRQ 19-21 K, WOB intermitent 0-5K. Taking weight at 9,077' MD WOB 6K drilling off to 4K. P/U 225K, SLK 107K, ROT 153K.;CBU Rotate and reciprocate F/ 9,099' to 9,036 MD 460 GPM, 1,308 PSI, 50 RPM, TRQ 19-21 K. PIU , SLK, ROT Saw drilled hard cement at Shakers from stringers. P/U 240K, SLK 100K, ROT 153K No Iosses.;Wash and ream F/ 9,099'to 9,135' MD 400 GPM, 1,088 PI, 50 RPM, TRQ 19-20K, Intermittent WOB 8K till 9,123' MD. Drilled cured cement F/ 9,123' to 9,135' MD W/ IOK WOB. P/U 240K, SLK 104K, ROT 153K.;CBU rotate and reciprocate F/ 9,135' to 9,099' MD 460 GPM, 1,308 PSI, 50 RPM, TRO 19K, P/U 238K, SLK 100K, ROT 153K. Saw cured cement at shaker at BU. No lossses.;POOH on elevators F/ 9,135' to 455' MD. Monitor well for 10 Min. Pulled 5 stands monitoring well. Pump 13.3 ppg Dry Job. Break connections between 127-138 stands looking for cement rings. P/U 89K, SLK 74K.;UD 8.5" Clean out BHA as per DD.;Hauled 276 bbls cuttings to G&I for total = 5,820 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 3,736 bbls; Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 250 bbls H2O from L-Pad lake for total = 3,870 bbls 1-IntilM n hKIs H20 from Lake 51 for total = 0 bbls 6/18/2018 PJSM, Prep floor to PU BHA. Stage Components on Rig Floor. PU Mud Mtr & change AKO to 1.2 to 1.5, Off Set =145.34. PU/.MU BHA as per DD/MWD Reps. RIH with Same to 520'. Shallow test MWD.;TIH on elevators to 6576. Correct displacement on TIH.;Service Rig.;Circulate drill sting volume before entering open hole. 310 gpm/850 psi. PU/SO 187K/108K.;TIH on elevators from 6576 to 8975'. Wash down F/ 8,975' to 9,135' MD. 500 GPM, 2,165 PSI, PIU 248K, SLK 107K.;Orientate mud motor and slide, time drill at 5 FPH F/ 9,135'to 9,137' MD. 500 GPM, 2,150 PSI, WOB 1-2K, P/U 256K, 107K. Max Gas 12U.;Slide, time drill at 5-10 FPH F/ 9,137' to 9,190' MD. 500 GPM, 2,150 PSI, WOB 1-5K. At 9,190' MD Obtain survey at 9,157.62' MD, 44.32" and 5.86' AZI for a 1+ degree in both. Cont. to control drill W/ rotation. P/U 254K, SLK 104K, ROT 157K.; Directional drill F/ 9,190' to 9,440' MD 305' total (61' AROP) 500 GPM, 2,593 PSI, 70 RPM, 20-21 K TRQ, WOB 15K, P/U 242K, SLK 104K, ROT 158K. Max Gas 55u, MW 11.65 ppg.;Last survey 9254.56', 41.52" Inc, 4.49° Azm, Distance to plan: 3.71', 1.70' low, 3.29' Ieft.;Water running 5 bph, dumped 150 bbl and added 50 bbl new 11.65 ppg LSND.; Hauled 114 bbls cuttings to G&I for total = 5,934 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 3,736 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 230 bbls H2O from L-Pad lake for total = 4,100 bbls Hauled 0 bbls H20 from Lake 2 for total = 0 bbl 6/19/2018 Directional drill 8.5" hole F/ 9,440'to 9,730' MD (6,710' TVD) 290' total (58' AROP) 550 GPM, 2,890 PSI, 80 RPM, 20.8K TRQ, WOB 8-10K, P/U 250K, SLK 112K, ROT 160K. ECD 12.18 ppg.;High line power went out at 07:15, on rig power at 07:18. Switch back to high line power at 10:OO.;Circulate and conditioned mud. Relaxed MW F/ 11.7 to 11+ ppg. Pump Hi Vis 30 bbl sweep at 9,730' MD Returned to surface on time. 20°% increase at shakers. Max Gas 1000. 550 GPM, 2,816 PSI, 60 RPM, TRQ 21.5K.;SPR at 9,760' MD (6,710' TVD) W/ 11.05 ppg MW. MP #1 32-278, 48-360. MP #2 32-280, 48- 360.;Monitor well, static. POOH on elevators F/ 9,730' to 9,095' MD. P/U 267K, SLK 127K. Tight spots 9,162'- 9,425'and 9,611'- 9,635' MD. Work through pulling 10-15K.;RIH F/ 9,095' to 9,730' MD No Iosses.;Slide 8.5" hole F/ 9,730' to 9,769' MD (6,744' TVD) 39' total (39' AROP), 552 GPM, 2,890 PSI, WOB 4K, PIU 258K, SLK 122K, ROT 160K. ECD 11.93 ppg.;Trouble shoot Sperry MWD tools down hole at 9,769' MD.;Slide 8.5" hole F/ 9,769' to 9,793' MD (6,736' TVD) 24' total (48' AROP) 552 GPM, 2,890 PSI, WOB 4K, P/U 258K, SLK 122K, ROT 160K. ECD 11.93 ppg.;High line power went out at 17:23, Rig generator power on at 17:27.;Trouble shoot Sperry MWD tools down hole. Perform hard shut down for 15 Min with pumps off. Reciprocate pipe P/U 267K, SLK 126K.;Break Circ. Decision was made to POOH due to MWD tool failure. Monitor well for 10 Min, static.;POOH on elevators F/ 9,793' MD to 520' MD. Pulled 5 stands off bottom, no swabbing. Pump 12.65 ppg Dry job and POOH. No Iosses.;Rack back 5" HWDP and flex collars. Remove internal components from TM tool, P/U and plug into download data. Was unable to read tools. Decision was made to replace all MWD tools. UD BHA as per DD and MWD. Pull up and inspect mud motor and Bit.;Bit grade 1,1, WT, A, I, PN, DTF.;PJSM W/ all parties. Prep floor to P/U BHA. Stage short BHA on floor. Rerun 8.5" bit and Mud Motor, 6. 75" DM Collar, 6.75" DGR Collar, 8 5/16" ILS , 6.75" EWR, 6.75" PWD, 6.75" HCIM, 6.75" TM, 6.75" Float Sub, 6.75" FC, 6 ea 5" HWDP, 6.25" Jar, 1 ea 5"HWDP, Well Commander.;4ea 5" HWDP. Total length 526.76'. Shallow hole test MWD and LWD tools.;RIH 8.5" BHA on 5" D.P. F/ 526' to 2,707' MD.;Hauled 460 bbls cuttings to G&I for total = 6,394 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 3,736 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 260 bbls H2O from L-Pad lake for total = 4,360 bbls Hauled 0 bbis H2O from Lake 2 for total = 0 bbls 6/20/2018 Continue trip in hole with BHA #17, 8.5" drilling assy F/ 2670' - T/ 6582' MD. Hole took proper displacement. 192k up, 104k dn.;Sewice rig just inside 9-5/8" shoe - Grease top drive, crown, pipe spinners. Inspect floor equipment.;Continue trip in hole F/ 6582' - T/ 9739' MD. Fill pipe and wash down F/ 9739 - T/ btm @ 9793' MD. 500 gpm, 2340 psi, 60 rpm, 23.3k tq. 250k up, 115k dn, 162k rot.;Drilling ahead w/ 8.5" mtr assy F/ 9793'- T/ 10,115' MD. 322 total (54' AROP)550 GPM, 2,850 PSI, 80 RPM, TRQ 21.81K, WOB 10-15K, ECD 12.1 ppg, P/U 264'K, SLK 120K, ROT 171 K.. Last survey 10,020.27', 32.34' Inc, 353.66° Azm, Distance to plan: 19.12', 10.24' low, 16.15' left.;SPR at 9,927' MD (6,873' TVD) MW 11.05 ppg MP #1 32-272, 48-350 MP #2 32-270, 48- 350.;Shut in well at 17:24. Total gain 18.3 bbl. SIDPP 95 PSI, SICP 420 PSI. Observed pit gain in flow, P/U and spaced out, shut down pumps and well was flowing. Shut in well and notified Tooipusher and Co Rep. Gather info and make forward plan.; Drilled 15' into the Kauparuk D.; Pump down drill string to open solid float. SIDP 385 PSI, SICP 426 PSI. Bleed down SICP F/ 242 PSI to 350 PSI, waft 5 Min. Pressure stabilized at 424 PSI SICP in 1 Min. Repeat bleed down again with same result.;Well assumed not breathing. Decision was made to CBU at 3 bpm. ICP 745-768 PSI holding casing pressure at 424-450 PSI. Max Gas during CBU 3,474U MW out non-pressurized scale MW 9.3 ppg. Could see oil at shakers with Gas cutting out.;Gas dropping to 1,318U at BU, non- pressurized MW 9.8 ppg. Lost about 9 bbls at surface. Adjust Annular Press. And move DP F/ 10,115'to 10,107' P/U break over at 323K P/U 223k, SLK break over 90K SLK 93K. Circ. Press at Surf to Surf DPP 761 PSI, CP 390 and Gas 1,320U.;Decision was made to weight up to 11.9 ppg. Start initial Circ. Weight at 11.3 ppg and perform weight up over three Circ. To 11.9 ppg.;Maintain circulating rate as Gas units decreased F/ 1,190U to 872U at 02:30. Increased mud weight to 11.3 ppg while making room in pits to decrease total volume. Pumped 390 bbl 6,300 Stks of 11.3 ppg. MW out Press. scale 11.0 ppg Non 10.4 ppg.;lncreased mud weight to 11.5 ppg and was able to maintain weight due to mud weight out. Shut down at Surf to Bit W/ 11.5 ppg. SIDPP 379 PSI, SICP 377 PSI. Perform bleed down on CP F/ 368 to 318 PSI, After 5 Min SICP 366 PSI, SIDPP 356 PSI.;Start pumping BU at 3 bpm 28% DPP 705, CP 443, Gas 802U. At 1,600 strks 30%, DPP 712 PSI, CP 345 PSI, 735U Gas.;Move D.P. at 02:30 Broke over at 309K P/U 294K, Down 94K, SLK 97K. Maintain DPP 700- 712 PSI, CP 343-348 PSI. At 2,774 strokes into 11.5 ppg mud weight up the back side lost circulating Press. Shut down and look over surface Equip. 11.5 ppg top was at 6,375' MD.;Inftial SIDPP 234 PSI, SICP 218 PSI. Gas 690U. Pressure bled down to SIDPP 218 PSI, SICP 200 PSI. Annular appeared to have a slight leak. Increased Annular Press. 1,300 PSI. Started pumping at 3 bpm ICP DPP 538 PSI, CP 190 PSI. Annular not Ieaking.;Pumped additional 1,375 stoke for a total of 4,149 strokes of 11.5 ppg to surface. Saw about a 50% reduction on returns at surface. Lost rate was 84 bph and pumped away 42 bbls. Shut down to pump 60 bbl LCM Pill.;Hauled 120 bbls cuttings to G&I for total = 6,514 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 0 bbls. Total Lost to formation = 3,736 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 230 bbls H2O from L-Pad lake for total = 4,590 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 6/21/2018 Continue circ 11.6 ppg mud In/out via choke. 3 BPM, 402 psi, 60-70 casing psi (choke position 39%). Pumped 50 bbls LCM pill (60 ppb). 30 ppb LCM background in 11.6 mud. Losses gradually got better. 75% returns while circulating. Elms up gas peaked @ 4998 units. Slowly dropped to 1530 bgg.;Wt up from 11.6 to 11.75 ppg MW in w/ 11.65 out. 3 BPM, 408 psi, 405 bgg and still gradually dropping. 92% returns W/ 11.75 MW. 15 BPH loss rate w/ 11.75. Continue move pipe on the hour (282k up, 118k dn).;Shut down pumping and shut in choke. Monitor pressures. 32 psi SICP over 15 mins then stabilized.;Bring pumps on at 3 bpm increasing mud weigh to 11.8 ppg. DPP 400 PSI, full open choke. After 400 strokes away reduced circulating rate to 2 bpm due to 21 bph loss rate. DPP 300 PSI, full open, Gas 327U. Loss rate 10-12 bph.;At 4,400 stroke into pumping 11.8 ppg loss rate increased to 22-27 bph DPP 297 PSI, full open choke. 241 U Gas. MW in 11.85, Out weight 11.7 ppg, non press. 11.4 ppg. At 5,900 strokes away reduced pump rate F/ 2 bpm to 1.5 bpm due losses increasing to 29 bph.;At 1.5 bph loss rate is 10 -12 bph. Continue to move pipe every hour P/U 284K, SLK 117K.;Cont. Circ. rate at 1.5 bpm, 100% choke, DPP 259 PSI, Gas 1721J. Loss rate at 10-12 bph at 11,200 strokes into pumping 11.8 ppg. Mud weight out 11.75 ppg, non Press. 11.5 ppg. At 11,00 strokes increase rate to 2 bpm due to reduction in losses to 6-7 bph. Losses increased to 22 bph at 13,500 strokes.; Reduced pump rate to 1.5 bph 100% Choke, DPP 250 PSI, Gas 150U, loss rate 10-12 bph. Continue move pipe on the hour (P/U 292k, SLK 98k).;Shut down pumps at 14,426 strokes into pumping 11.85 ppg in, 11.75ppg out. Initial shut in Press. SIDPP 9 PSI, SICP 4 PSI. Bleed down DP and CP to O PSI. Monitor for 15 Min. SIDPP 12 PSI, CP 4 PSI. Open choke and monitor for flow for 15 Min., Static. Open well and well static.;Break Circ. at 2 bpm, 298 PSI to establish circulating parameters. Attempted to reciprocate pipe past established point while shut in. Started packing off and worked pipe down to reestablish Circ. rate at 2 bpm, 298 PSI. P/U 290K, SLK 128K. Work on staging pumps up to 4-6 bpm.;Water running at 10 bph.;Hauled 0 bbls cuttings to G&I for total= 6,514 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 482 bbls. Total Lost to formation = 4,218 bbls; Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 230 bbls H2O from L-Pad lake for total = 4,820 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 6/22/2018 Continue circulating 11.8 mud In/Out while trying to manage losses. Work pipe while circulating w/ 20 rpm. Losses increased after working pipe. Continue trying to heal wellbore with pipe static, 2.6 bpm, 365 psi, 14.2% flow, 25% returns.; Pump 50 bbls 60 ppb LCM pill (11.7 ppg). LCM pill did not show any change in loss rate (120 bph loss rate).;Shut down and drop 2.115" steel ball to open well commander. Pump down @ 3 bpm, 390 psi. On seat @ 848 stks. Psi up slowly to 2200 psi then shifted open. Establish circ @ 3 bpm, 255 psi. Drop BHA isolation ball 2.063" steel ball. Pump on @ 3 BPM, 255 psi. On seat @ 860 stks. 3 bpm, 270 psi.;Shut down and monitor well (fluid dropping slowly in stack). Build surface volume 11.8 ppg mud w/ 30 ppb background LGM. Build 2 heavy LCM pills. Stage in pill pits to be pumped in tandem.;10113' MD Pump 48 bbl 70 ppb 11.8 ppg LCM Pill (10 ppb Steel Seal 400, 10 ppb Steel Seal 50, 10 ppb Baracarb 150, 10 ppb Baracarb 1200, 10 ppb Baro-Seal, 20 ppb Barofiber) Pump 45 bbl 50 ppb 11.8 ppg LCM Pill( 10 ppb Steel Seal 50, 10 ppb Baracarb 5, 10 ppb Baracarb 50, 20 ppb Barofiber);at 3 bpm, 365 PSI. Loss rate about 66 bph. Move pipe every 45 Min. P/U 285K, SLK 128K.;Losses appeared to slow toll bph during circulating LCM pills into open hole. Losses increased to 22-26 bph at 3.5 bpm, step down flow rate to 1.5 bpm loss rate 10- 12 bph. Build volume in Ph 5.;Cont. Circ. at 1.5 bpm 200 PSI, F/O 13.7% Loss rate at 10-13 bph. Build 2 more LCM pills same as before. At 23:00 245 bbl 12.4 ppg Vac arrived on Iocation.;Pump 32 bbl 70 ppb 11.8 ppg LCM and 47 bbl 50 ppb 11.8 ppg LCM pill at 2-3 bpm. Displace at 2 bbpm 275 PSI, increase rate to 3 bpm while LCM pills exit Well Commander.;Work Pipe F/ 10,115 to 10,045' MD. Pulling 329K working pipe. P/U 285K, SLK 130K. Rack back one stand, Drop 2.115" Ball. Circ. ball down at 3 bpm, 315 PSI. Pressbroke over at 1,750 PSI to zero and came back to 2,000 PSI. Bleed off Press. and work pipe.;Pick up stand and attempt to work string. Rack back stand and P/U working single. Work pipe with P/U 340K, SLK 80K. Attempt to function Well Commander performing pressure cycles at 2 bpm to 2,500 PSI as per MI Swaco procedure. Appears some injection to formation at 2,000 PSI.;Hauled 58 bbls cuttings to G&I for total = 6,572 bbls Total fluid hauled to ORT: 500 bbls Daily losses to formation= 791 bbls. Total Lost to formation = 5,009 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 430 bbls H2O from L-Pad lake for total = 5,250 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 6/23/2018 Continue working stuck pipe @ 10,052' MD. Attempt to work pipe down w/ 280k up and smacking do to 50k. Vary parameters w/ max 25k right hand tq, Psi range used from 0-1000 psi.;Continue working pipe up w/ little progress (1' progress). Jar @ max up 465k w/ straight pull 485k. Varying parameters w/ 25k tq and working pumps w/ max psi 2500 psi.;Drop 2.115" activation ball to open well commander. Work pipe while allowing ball to drop (2 hrs). Bring on pumps and immediately establish circulation @ 3 bpm, 360 psi with 65% returns. Appears Well Commander had shifted to open position while working pipe.;Saw psi increase to 600 psi (stall) @ 1118 stks. Assumed to be ball on seat. Stg up in 500 psi increments to 3300 psi wl 30 secs to 1 min holds between psi increases as per MI Swaco procedure. Saw no shift for well commander. Held 3k psi and continue work pipe.;While working pipe holding psi, saw psi start to decrease from 3000 to 2000 psi. Pressure held @ 2000 while working pipe. Bring pumps on w/ a max pressure setpoint of 2400 psi. Establish injection rate of 3 BPM, 2390 psi. 22 bbl pumped away while working pipe.; Drop 2.115" activation ball to reopen well commander sub. Work pipe without firing jars while allowing ball to fall for 2.5 hm, Work pipe 280k up, 50k do with varying parameters. Discuss options with town. Decision made to work pipe while waiting on E-Line for backoff operations.;Circ. @ 1 bpm, 650-1,000 PSI 4.6% returns. Stage up to 1.5 bpm 1,300-1,400 PSI 7.8% returns. At 578 strokes pressured up to 1,750 PSI. Pump stall out and no returns. Bled off Press. Press. Up to 1,000 PSI, increased Press. In 500 PSI increments to 2,000 PSI two times. No returns.;Appeared to be injecting into formation at .75 bpm, 2,000 PSI, 3 bpm 2,330 PSI no returns. 4.5 bpm 2,550 PSI with no returns. Shut down pumps.;Perrorm Derrick inspection. Resume jarring operations at 10,051' MD. Highest jar up 443K, most pulled 460K. No movement up. Attempt to jar down with bumper sub, no movement. Perform Well commander pressure cycles with no success.;Pollard and Baker on location. LID working single, blow down IDS 850PE. Prep for back off operations. No static losses to formation.;PJSM with all parties. Perform left hand TRQ into string. Worked in 18.3K W/ 10 1/8 wraps into string. Hold torque with rig tongs and rotary table. Set in slips with 155K.;PJSM with all parties. R/U Elmo and RIH with 4' bar 640 grain shot. Correlate with CCL at 9,850' ELM. Witnessed by Co Rep and Baker. No visual indication on surface.;POOH W/ Eline F/ 9,850' ELM. Visual verified shot fired. UD ELine tools.; Kelly upon string. Put 18K left TRQ to release longs and pull slips. Work 355K up and 126K down. Increase left hand torque to 20K. Work string several more times. Saver sub broke free from drill string. Re torque saver sub 3 times to 32K.; Let out left hand torque and re torque string to the left to 18K. ELine redress shot to 740 grain. No losses to formation.;Hauled 58 bbis cuttings to G&I for total = 6,630 bbis. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 328 bbis. Total Lost to formation = 5,337 bbls; Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 100 bbis H2O from L-Pad lake for total = 5,350 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/24/2018 Finish working 18.1 k left hand tq downhole wl 120k - 350k. 1 O-1/8th left hand wraps total. Install breakout tongs and set slips wl 130k in slips. Breakout TDS. R/U Pollard E-line w/ 4.5' bar dressed with 720 grain shot below 1.8' CCL.;Zero tool at floor. RIH w/ E-line backoff easy F/ surface to 9890' MD (non mags). No issues running past Well Commander or Jars. P/U and correlate HWDP collars as per pipe tally, BHA and 1st run. Place middle of backoff charges @ 9858' MD. 1850 lbs up wt prior to setting off charge.; Fire charge @ 9858' MD (ELM). Saw 50 Ib line jump inside unit. No other surface indicators of detonation observed on surface.;POOH w/ 2nd run backoff assy on Pollard E-line F/ 9858' to surface. RID packoff head and sheave. Stage on floor.;Kelly up TDS. Apply 18k left hand tq to relieve breakout tongs from holding backup. Pull slips and remove tongs. Work pipe attempting to free connection and backoff HW DP @ 9858' MD (ELM) -Work pipe stg do F/130k to 80k and 285k-350k holding 18k left tq in string. 0 losses per hour (static).;PJSM W/ all parties. R/U Pollard ELine free point tools.;Release left hand tq and workout of drill string. M!U 1.375" free point tool (3.4" centralizers) with two 5' wt bars. RIH to a max depth of 8840' ELM before losing down wt. Attempt to work E-line past 8840' with no success. POOH w/ E-line and discuss options.; POOH F/ 8,840' ELM. UD 1.375" free point tools.;PJSM W/ all parties. R/U for back off operations. Bring down Derrick sheave and R/D long bails. Move and fire jars at 340K to ensure free. Saw Bumper Sub travel @ 300K.;Work string weight F/ 100K to 285K while putting left hand torque in 2K increments to 18.3K , 9 %wraps. Set in slips W/ 125K.;R/U ELine and RIH W/ 2 ea 4weight bars, CCL and 5' back off bar with 720 grain shot to 7,271' ELM. Attempt to work tools down with no success.;Stand back Eline and Equip. Kelly up, apply 18k left hand TRQ to breakout tongs from holding backup. Pull slips and remove tongs. Release left hand torque to zero.;Attempt to pump through drill string. Cycle Well commander 3 times up to 2,500 PSI. Attempt injection at 3 bpm to 2,700 PSI with no success.;Work left hand torque in F/ 100K to 285K in 2K increments to 18.3K , 8.5 wraps. Set in slips W/ 150K.;Install breakout tongs and set slips w/ 150k in slips. Breakout TDS. R/U Pollard E-Iine.;Blow down choke manifold and service rig.;Decision was made to attempt to reestablish circulation while jarring. Pulling to a maximum of 360K and 3,300 PSI firing Jars. Max straight pull 460K. RID ELine and allow them time to redress firing pin.;Hauled 0 bbis cuttings to G&I for total = 6,630 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 0 bbls. Total Lost to formation = 5,337 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 60 bbls H2O from L-Pad lake for total = 5,410 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/25/2018 Work 18.6k left hand tq in string. Work between 100k do and 285k up. Park in slips @ 150k. 9-5/8 total wraps (left). M/U tongs for backup and set slips (tie handles). B/O TDS and R/U E -line. Run E -line in hole dressed w/ 720 grain backoff shot to a max depth of 6933' ELM. No Go.;B/O TOS and R/U E -line. Run E -line in hole dressed w/ 720 grain backoff shot to a max depth of 6933' ELM, No Go.;Correlate collars and place backoff charge on 5" dp connection @ 6924' ELM. Clear floor and make announcement. Attempt to detonate but had no significant indicators either on floor or in unit. POOH w/ E -line F/ 6924' to surface.; Detonator showed misfire due to broken wire. Redress shot rod w/ new 720 grain backoff charge and new detonator. Surface test E -line circuit to firing head (good). M/U same and RIH. Perform derrick inspection while redressing misfired 720 grain charge.; E -line run 95. RIH w/ 720 grain backoff charge to max depth of 6882' ELM. Correlate connections with previous runs. P/U and place charge on connection @ 686T ELM. Clear floor and make announcement. Fire charge with 125# line drop and positive indicators of backoff on rig floor.;POOH and R/D E -line (detonator fired). Clear rig floor and UD E -line tools and equipment. M/U TDS to string and R/D backup tongs and pull slips. Release 1.5k left hand residual tq. P/U and break over @ 180k. Establish circulation. 172k up, 110k dn, 130k rot @ 20 rpm, 10k tq. Confirmed backoff.;Stage pumps up to 10 bpm, 600 psi w/ minimal losses. Remove 7" csg from shed and ship out. Pump remaining LCM pills and shut down once surface to surface. Monitor well (slight flow). Cont circ with 11.8 In/Out surface to surface. Shut down and monitor well (slight flow). Lineup on trip lank.;Monitor well on trip tank showing 6 bph flow rate initially but reduced to 3 bph over next 15 mins. Cont monitoring.;CBU reciprocating pipe F/ 6,860' to 6,830', staging up F/ 5 bpm 300 PSI to 10 bpm 630 PSI 60 RPM, TRQ 11.8. Saw about 10 bph loss rate. Max 20U. Slight Crude Oil in mud at the Shakers.;Shut down monitor well. Change out working joint in string. Well on very slight flow. Pumped out of hole at 3 bpm checking torque on all connections F/ 6,867' to 6,548' (all connections good). No losses. Shoe at 6,590' MD.;Monitor well, still slight flow. Weight up mud system F/ 11.8 to 11.9 ppg. Circ. surface to surface 8,763 strokes 6 bpm 300 PSI, mud weight in and out 11.9 ppg. 4 bph loss rate. Shut down and monitor well. Still slight flow.;Circ. to 11,000 strokes 4 bpm 290 PSI and shut down. No Iosses.;Monitor well, Initial flow rate 2.5 Min 28 bph to 1.1 bph after 1 Hour. Total 4.4 bbl returned to surface during monitoring the well. SIMOPS Weight surface mud to 12.05 ppg.;Circ. at 6 bpm 320 PSI increasing mud weight F/ 11.9 ppg to 12.05 ppg. 2 bbls lost to formation during circulating.;Monitor well, Initial flow rate 5 Min 22.8 bph to 1.1 bph after 30 Min. Total back to surface 2.3 bbl.; POOH on elevators 5 stands monitoring well. F/ 6,545' to 6,224' MD. Checking torque on all connections. Monitor well for 10 Min, slight seepage loss. Cont. to POOH on elevators. F/ 6,224' to 4,397' MD. P/U 168K, SLK 105K. Well has slight seepage .5 bph.;Hauled 115 bbis cuttings to G&I for total = 6,780 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 9 bbis. Total Lost to formation = 5,346 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbls Hauled 60 bbis H2O from L -Pad lake for total = 5,470 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/26/2018 Continue POOH on elevators F/ 4,380'- T/ surface. Left 42 stands 5" DP in hole w/ BHA. TOF @ 6867' as per dip tally. 15 min monitor @ 1000' prior to finishing trip out (static).;Clean and clear rig floor.;Cut and slip drilling line (100'). Inspect drawworks, Remaining drilling line in use, blocks, derrick and crown.;Drain stack. Pull wear bushing. Set test plug. R/U test joint and testing equipment. Flood stack and choke manifold.;Test BOPE 25013500 on 5" test joint. AOGCC right to witness waived by Bob Noble. F/P on IBOP, function and retest -good. Accumulator drawdown: initial pressure 3050, final 1550. First 200 psi recharge 20 seconds, full recharge 90 seconds, N2 average 2241 psi.;R/D test joint. Pull test plug. Set wear bushing. Blow down Iines.;M/U ECP as per BOT. RIH 3 stands and check floats -good. Continue to RIH to 6587' at 1 min/stand to minimize surge with ECP on drill pipe filling on the fly with clean (no LCM) 12.05 ppg fluid, topping off every 5 stands.;Obsewe slight flow, monitor well initial rate 4.8 bph, final i bph. Mud weight coming out 11.75 ppg, filling pipe with 12.05ppg.;Continue to RIH with ECP tagging up at 6873' with 4K down. Fill pipe. PUW 173K, SOW 103K.;Break circulation and stage pumps up to 5 bpm1275 psi. Drop ECP setting dart and pump down initial rate 5 bpm slowing to 2.5 bpm.;Hauled 115 bbls cuttings to G&I for total= 6,895 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 7 bbls. Total Lost to formation = 5,353 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 60 bbis H2O from L -Pad lake for total = 5,470 bbis Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6 /2 712 01 8 Continue psi up on ECP dart F/ 600 psi to 1110 psi in 200 psi increments w/ 1 min holds between. Saw shift @ 1110 psi. Hold for 10 min allowing ECP time to inflate. Final PSI 920 psi. Continue psi up to release. Saw release @ 2400 psi. P/U off ECP and break circulation. Top of ECP @ 6846' MD.;Stg up to 10 bpm, 320 psi, 10 rpm, 9.7k tq with 0 losses. Circulate a total of 1.5 btms up. Max gas 45 units, 20 bgg. 12.05 Mud In/Out.;Pull 5 stds wet monitoring displacement F/ 6846'- T/ 6,570' MD. Well static.;Pump dry job. B/D TDS. POOH on elevators F/ 6,570'- T/ surface. UD ECP running tool. Hole took proper displacement for trip. 170k up, 101 k dn.;R/U WOT w/ 2-7/8" handling equipment. M/U 2-7/8" defuser cmt stinger, RIH to 906 (29 total its). R/D WOT and R/U 5" handling equipment.;Continue trip w/ cmt stinger F/ 906' to 6840' MD. Wash down F/ 6840'to tag depth of 6873' MD. PIU to 6846' (projected top of ECP).;Circulate and condition mud @ 6846' MD. Stg up 9 bpm, 920 psi.;PJSM, pump P&A cmt plug as follows: 25 bible 13.5 ppg spacer, 50 bbls 15.8 ppg class "G" cement, 4.5 bbis 13.5 ppg spacer. Displace with rig 89.9 bible 12 ppg mud. CIP @ 23:44.;POOH dry pipe slowly 11 stds from 6846' to 6141' MD.; Break circulation. Drop wiper ball and circulate pipe clean @ 5 bpm, 375 psi. Sawa trace of mud push @ BUS.;Monitor well (very slight flow). POOH 5 stds wet monitoring displacement. Monitor well (fluid dropping slightly then static). Continue pulling wet to 3681' while monitoring displacement close (hole took calculated displacement). 6/28/2018 Continue to POOH from 3681' to 908' with proper hole fII.;Rlg up Weatherford power tongs. Change out pipe handling equipment.; Lay down 2-7/8" EUE cement stinger, Observe 114" washout on mid joint #15.;Rig down weatherford. Change out pipe handling equipment.;M/U 8-1/2" bit and bit sub. RIH to 6059' on drill pipe.;Wash down from 6059' at 3 bpm 214 psi from 6059 to 6438'.;Circulate annular volume staging pumps up to 10 bpm 820 psi, 20 rpm, No cement returns observed at surface.;Continue to wash down from 6438' at 2 bpm/138psi and tag at 6854' with 51K down x 2.;Circulate annular volume staging up to 10 bpm/820 psi. Observe 12.5 ppg MW at bottoms up and a slight increase in pH.;POOH to 6550'. Monitor well, slight flow, initial rate 0.85 bph slowing to 0.52 bph. POOH 5 stands to 6252'. Monitor well, slight drop in fluid.;Continue to POOH from 6252' to surface. Break bit. Proper hole fill on trip out.;Rig up Weatherford tongs. Change out pipe handling equipment.;Pick up and RIH with 2-7/8" cement stinger to 888'.;Rig down Weatherford tongs, change out pipe handling equipment.;Hauled 354 bible cuttings to G&I for total = 7,307 bbis. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 3 bbls. Total Lost to formation = 5,361 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 60 bbis H2O from L -Pad lake for total = 5,470 bbls Hauled 0 bbis H2O from Lake 2 for total = 0 bbis 6/29/2018 Continue tripping in hole w/ 2-718" cmt string F/888' -T/ tag depth of 6853' MD. Hole took proper displacement. 156k up, 101k dn. Tagged 2x w/ 4k.;Circulate and condition mud @6853' MD. Stage up to 7 bpm, 1010 psi, 12 MW In/Out.;PJSM, Pump cement plug as follows: Wet lines and PT to 2k (good). Pump 3 bbis water 25 bbls 13.5 ppg spacer 61 bbis 15.7 ppg class "G" cmt 5 bbls 13.5 ppg spacer 2 bbls H2O.; Displace with rig 89 bbis of 12 ppg mud. 7 bpm, 1390 psi until last 3 bbls. Disp last 3 bbis @ 3 bpm, FCP 366 psi. No shut down during job. CIP @ 13:41 hrs. Lost a total of 9.6 bbls;POOH F/ 6853- T/6096 MD @ 30 fpm on elevators. Stds pulled slightly wet with no flowback at stump.; Drop 5" wiper ball and circulate STS. Stg up 10 bpm, 1160 psi, 5 rpm, 7.3k tq. Trace of spacer back to surface. Saw 12.4 MW @ btms up.;Monitor Well (Static). Pump dry job and blow down TDS.;POOH on elevators F/ 6095' - T1888' MD. Hole took proper displacement.; R/U WOT 2-7/8" handling equipment. Continue trip outlaying down 2-7/8 cmt stinger string F/ 888' - T/ surface. Rig down Weatherford, change out pipe handling equipment.;M/U 8-1/2" bit, bit sub with solid float. RIH on drill pipe to 5999' filling pipe every 2700'. PUW 153K, SOW 92K. Proper displacement.;Cut and slip 56' of drilling line. Check brake pad tolerance.;Sewice rig. Grease swivel packing, TDS, Blocks and crown.;Wash down from 5999 to 6430' 3 bpm/340 psi.;Circulate annular volume staging pumps up to 10 bpm/1000 psi; 20 rpms(10,000 R-Ibs.;Continue to wash down 3 bpm/330 psi from 6430'. Tag up at 6851' with 10K x 2. PUW 167K SOW 100.;Circulate and condition mud staging up to 10 bpm/1080 psi 20 rpms/10K reciprocating pipe.;Hauled 86 bbis cuttings to G&I for total= 7,393 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 10 bbis. Total Lost to formation = 5,371 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 230 bbls H2O from L -Pad lake for total = 5,700 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbls 6/30/2018 Circulate and condition mud @ tag depth of 6851' MD (2' higher than previous runs tag). 10 bpm, 1000 psi. 12.6 mud wt @ btms up with no cement returns to surface. No Iosses.;Monitor well (static). POOH 5 stds wet F/ 6851' - T/ 6565' MD (inside shoe).;Close pipe rams and perform injectivity test. Pump 1 bpm, psi climbs to 725 before breaking over and stabilized @ 660 psi. Increase rate to 2 bpm, 1040 psi stabilized. Pumped a total of 6.6 bbls, 1 bbl bled back. Open well (slight flow).; POOH 5 stands wet F/ 6565 - T/ 6233' MD. Monitor well (static). Hole showing good hole fill.;Pump dry job, B/D TDS. POOH on elevators F/ 6,233' - Tl surface. LID Bit w/ sub. Hole took 7.1 bbls over calculated for trip.;Clean and clear rig floor.; Rig service.;Pick up Baker K-1 Mach. ement retainer. RIH on drill pipe to 6520', correct displacement. PUW 169k, SOW 100K;Set retainer at 6520' (TOR 6518') as per Baker: rotate 15 turns to right. Pick up 40K over pull, slack off 40K x 2. Pick up to PUW and rotate 15 turns to right to release stinger. Pick up and unsting from retainer. Confirm depth and ability to sting/unsting x 2.;While unstung, establish circulation and obtain pump pressures for rates from 2-6 bpm. Sting into retainer and perform \ injectivity test. At i bpm pressure built to 1050 psi and broke over, stabilized at 450 psi, 2 bpm built to 770 stabilized at 510 psi, 3 bpm built to 1320 psi /D stabilized at 450.;23 bbis injected during test. Monitor hole to ensure retainer set and held - no returns.;Batch up Tune Spacer. Rig up on rig floor. PJSM.;Unsting from retainer. Flood lines with water and PT 1000/4000 psi - good. Shut annular. Hold back pressure to ensure cement doesn't fall; bbl in bbl out. Cementers pump 5 bbls of 13.5 ppg Tuned s acer 2 b m 397 psi, 44 bbls 15.8 Class G cement 3.3 bpm 1132 psi,5 bbls 13.5 ppg tuned spacer.;Shut down pumps an s in choke. ine up or rig to displace. Rig pumped 51 bbls of mud at 5 bpm 1126 psi still holding back pressure and monitoring gain/loss to ensure cement doesn't fall. Slow rate to 2 bpm 774 psi with 10 bbis to go. 5 bbis prior to spacer exiting stinger shut down.;strip through annular to sting back in retainer. Open annular and monitor hole while injecting - no flow. Start injecting 5 bbls mud, 5 bbis of spacer and 36 bbls Class G Cement (20% OH excess + casing vol = 35 bbis) at 1 bpm staging up to 2 bpm ICP 161 psi up to 756 psi at 2 bpm.;Slow rate to 1 bpm/540 psi with 5 bbls to go. Close annular and choke and strip out of retainer. Bleed DP pressure - on vac. Slowly open choke to allow cement to fall Open annular. RID cement head, BO pup joint. Fluid falling in drill pipe. CIPat 01:19.;POOH to 6195', first three stands 10fpm to allow cement to fall. Pipe pulling dry. PUW 160 SOW 95.; Break circulation. Drop wiper ball. Stage pumps up to 6 bpm1440 psi. Monitor well, static.; POOH from 6195' to 2903' with proper hole fill. PUW 91 K, SOW 73K;Hauled 262 bbls cuttings to G&I for total = 7,655 bbis. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 10 bbls. Total Lost to formation = 5,371 bbis; Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbls Hauled 130 bbls H2O from L -Pad lake for total = 5,830 bbls Hauled 0 bbls H2O from Lake 2 for total = 0 bbis 7/1/2018 Continue POOH racking back 5" drill pipe F/ 2727' - T/ surface. BIO and LID retainer running tool.;M/U 8.5" cleanout assy and RIH F/ surface to 6061' MD. 150k up, 80k dn.;WOC for compressive strength to exceed 1700 prior to tag. Change oil, filters on top drive and drawworks. Reduce surface mud volume. Start cleaning pits and ready for displacement.;Wash do 1/2 bpm, 140 psi F/ 6061' to tag depth of 6505' MD. Tag 2x w/ 10k dn. Hard lags. Tag witnessed by AOGCC Adam Earl.;P/U off plug 30' and circulate STS. 13.5 bpm, 1525 psi, 59% flow. Saw spacer interface @ btms up w/ max MW 12.3. Dumped 28 bbls mud push/mud from active.;Rig up to test casing. Test casing to 1500 psi for 30 minutes - good. Rig down testing equipment. Blow down lines and choke manifold. Grease choke. Start psi 1683, 15 min psi 1662, 30 min psi 1655.;Build spacer to displace to seawater. Service rig: grease TD, blocks, wash pipe and crown cluster.;displace to seawater, pump 32 bbls 10.1 ppg high vis spacer followed by 448 bbis corrosion inhibited seawater. 6 bpm FCP 190 psi 30 rpms, reciprocating pipe. Bypass shakers and dump mud. Clean shakers and under shakers during displacement. Fill trip tank. Monitor well, static.;POOH laying down drill pipe from 6502' to 2825'. RIH with stands from the derrick to 3700'. Continue to POOH laying down drill pipe to surface.. Dope pin and box ends prior to installing thread protectors. Clean pits.;Pull wear bushing. Pickup stack washing tool. Washout BOP.; Hauled 919 bbls cuttings to G&I for total = 8,574 bbls. Total fluid hauled to ORT: 500 bbis Daily losses to formation= 10 bbls. Total Lost to formation = 5,371 bbls;Hauled 0 bbls H2O from 6 mi lake for total = 3,460 bbis Hauled 180 bbls H2O from L -Pad lake for total = 6,010 bbis Haute 0 bbls H2O from Lake 2 for total = 0 bbl 7/2/2018 Flush BOP equipment and all mud lines with fresh water. Flush gas buster, degasser and clean #1 centrifuge.;Install dummy 7" packoff and slip assy. RILDS and LID running tool.;R/D hawk jaw and LID same. RID hydraulic elevators and R/U 4.5" handling equipment and power tongs.;M/U mule shoe jt and RIH with a total of 60 jis (mule shoe included), 2 pups and hanger for a total depth of 2336.81' MD (22' RKB to ULDS - Innovation). Landed hanger w/ 57k do (59k up) leaving 22k string wt. RILDS. RID Weatherford Casing and release.;Remove excess tools, handling equipment and subs from rig floon;C/O lower pipe rams from fixed body 5" to 2-7/8"x5-1/2" VBR's. Pull mousehole, N/D riser, Pull flowline, remove turnbuckles and hook up bridge cranes. Remove choke and kill lines and koomey lines. Break bolts on spacer spool. Rack back BOP's. Remove spacer spool.;lnstall tree. PT hanger void 500/5000 psi - good. Pull BPV, set TWC. Test tree 500/5000 psi - good. Rig down testing equipment. Continue cleaning pits, gas buster, rig floor and derrick. C/O rollers on spinners. Mud pump maintenance. Set herculite and rig mats on E-21.;Continue cleaning pits, rig floor, windwalls, and cellar. Change out rig ton weight buckets for new tongs. Continue setting rig mats on E-21.;Continue cleaning pits. Install bridle pennets and lines. Raise TD. Install retainer pin in bridle sheaves. Scope derrick down Disconnect geronimo line, wt bucket Iines.;Blow down steam and pull all traps. Finish cleaning pits. Clean out cellar box. Blow down water. Disconnect interconnects. Freeze protect tbg and IA w/ 160 bbis diesel.;Hauled 798 bbls cuttings to G&I for total = 9,372 bbls. Total fluid hauled to ORT: 500 bbls Daily losses to formation= 10 bbls. Total Lost to formation = 5,371 bbls;Hauled 0 bbis H2O from 6 mi lake for total = 3,460 bbis Hauled 670 bbls H2O from L -Pad lake for total = 6,680 bbis Hauled 0 bbls H2O from Lake 2 for total = 0 bbis 7/4/2018 MIRU CTU #6 w/ 14,680' of 2" coil. BOPE test to 250 psi low and 3,500 psi high. No failures. Full test: (Stripper, Blind/shear, Blind/shear, 2" slip, 2" pipe, Choke, Kill, Check). 715/2018 CTU #6: 14,680' of 2" coil. CV = 37.5 bbls. M/U BHA: 2.0 " CTC, 2.0" DBPV, 2" XO,2 x 2.0' Straight Bars, 2" XO, @' Ball Drop Jet Swirl Nozzle.. DAL = 9.16'. Stab onto the well. P/T lubricator and surface lines to 250 psi low and 4,100 psi high. Open swab. WHP = 0 psi.;RIH and tag top of cement at 6,484'. P/U weight is 20,000 -lbs. PIU to neutral weight and correct depth to 6,505. R/U cementers. POH to 6,400' and paint Flag. RBIH to 6,505'.;Pump 5 bbls fresh water, 5 bbls 15.8 ppg cement, 15 bbls fresh water, 20 bbls PowerVis, diplacing with 1 % KCL. At 2 bbls of cement out of nozzle, POH laying in cement 1:1. Circulate and contaminate to 6,440' Circulate BU volume.;POH while circulating at 3.5 BPM to surface.;At surface. Close Swab. Wait on cement for tag with AOGCC. 7/6/2018 CTU #6: RIH and tag TOC at 6,448'. Witnessed by AOGCC Matt Herrera. POH. RDMO. / r 5Pd41� 3 r ML- Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-47 PB1 50029235777000 Sperry Drilling Definitive Survey Report 19 July, 2017 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU C47 Project: Milne Point TVD Reference: MPU C47 Actual @ 42.09usft - Site: M Pt C Pad MD Reference: MPU C-47 Actual @ 42.09usft Well: MPU C47 North Reference: True Wellbore: MPU C-47 PBI Survey Calculation Method: Minimum Curvature ' Design: MPU C-47 Pet Database: Sperry EDM - 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 D4 Using geodetic scale factor Well MPU C47 Audit Notes: To Well Position +N/S 0.00 usft Northing: 6,029,004.74 usft Latitude: 70' 29'23.490 N 26.89 +E/ -W 0.00 usft Easting: 558,156.85 usft - Longltude: 149° 31'28.533 W Position Uncertainty (usft) 0.00 usft Wellhead Elevation: 42.09 usft Ground Level: 15.20 usft Wellbore MPU CA7 PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (1) (nn BGGM2017 6126/2017 17.69 81.04 57,508 Design MPU G-47 PB1 Audit Notes: To Version: 1.0 Phase: ACTUAL Tie On Depth: 26.89 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction 788.64 (usft) (usft) (usft) (I 6,644.07 26.89 0.00 0.00 310.00 Survey Program Date 7/1 912 01 7 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 728.00 SRGSS (MPU C-47 P81) SRG-SS Surface readout gyro single shot 0 612 6/2 01 7 788.64 6,554.36 MWD+IFR2+MS+sag(1)(MPU C-47 PB MWD+IFR2+MS+sag Fixed:v2:11FR dec&3-axis correction + sag 06/29/2017 6,644.07 10,262.15 MWD+IFR2+MS+sag(2)(MPU C-47 PB MWD+IFR2+MS+sag Fixed:✓2:IIFR dec 83 -axis correction + sag 07/10/2017 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) ('1100') (ft) Survey Tool Name 26.89 0.00 0.00 26.89 -15.20 0.00 0.00 6,029,01NI34 558,156.85 0.00 0.00 UNDEFINED 100.00 0.46 30.95 100.00 57.91 0.25 0.15 6,029,004.99 558,157.00 0.63 0.05 SRG-SS(1) 200.00 0.54 2.72 200.00 157.91 1.07 0.38 6,029,005.81 558,157.22 0.26 0.39 SRG-SS(1) 232.00 0.64 21.04 231.99 189.90 1.38 0.45 6,029,006.13 558,157.29 0.66 0.59 SRG-SS(1) 294.00 1.30 47.98 293.98 251.89 2.18 1.10 6,029,006.93 558,157.93 1.27 0.56 SRG-SS(1) 356.00 3.05 64.42 355.94 313.85 3.36 3.11 6,029,008.13 558,159.93 2.97 -0.22 SRG-SS(1) 417.00 5.70 60.05 416.76 374.67 5.57 7.20 6,029,010.37 558,164.00 4.38 -1.93 SRGSS(1) 479.00 8.12 64.89 478.30 436.21 8.97 13.83 6,029,013.82 558,170.61 4.01 4.93 SRG-SS(1) 539.00 8.84 70.54 537.65 495.56 12.30 22.02 6,029,017.22 558,178.77 1.83 -8.96 SRG-SS(1) 600.00 9.56 71.46 597.86 555.77 15.48 31.24 6,029,020.46 558,187.96 1.20 -13.98 SRG-SS(1) 60.00 11.19 69.51 659.83 617.74 19.28 41.92 6,029,024.35 558,198.62 2.65 -19.72 SRG-SS(1) 728.00 13.80 71.83 723.28 681.19 23.91 55.20 6,029,029.07 558,211.86 4.09 -26.92 SRGSS(1) 7119/2017 11:41:35AM Page 2 COMPASS 5000.1 Build 81D Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU C47 Project: Milne Point TVD Reference: MPU C47 Actual @ 42.09usft Site: M Pt C Pad MD Reference: MPU C-47 Actual @ 42.09usft Well: MPU C47 North Reference: True Wellbore: MPU C47 PB1 Survey Calculation Method: Minimum Curvature Design: MPU C-47 P81 Database: Sperry EDM - NORTH LIS +CANADA Survey 7/19201711:41:35AM Page 3 COMPASS 5000.1 Build 61D Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El Vl Northing Easting DIS Section (usft) (°) (^) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 788.64 15.51 75.21 781.95 739.86 28.23 69.91 6,029,033.51 558,226.53 3.15 -35.41 MWD+IFR2+MS+sag(2) 851.56 18.13 75.03 842.17 800.08 32.91 87.51 6,029,038.33 558,244.09 4.16 -05.88 MWD+IFR2+MS+sag(2) 915.56 19.89 73.91 902.68 860.59 38.50 107.59 6,029,044.08 558,264.12 2.81 -57.67 MWD+IFR2+MS+589(2) 977.20 2242 73.82 960.16 918.07 44.68 128.96 6,029,050.42 558,285.44 4.10 -70.07 MWD+IFR2+MS+sag(2) 1,039.64 25.67 72.30 1,017.18 975.09 52.11 153.28 6,029,058.05 558,309.70 5.30 -83.92 MWD+IFR2+MS+sag(2) 1,100.98 29.14 71.09 1.071.62 1,029.53 61.00 18008 6,029,067.14 558,336.43 5.73 -98.74 MWD+IFR2+M8+sag(2) 1,166.20 32.42 69.76 1,127.65 1,085.56 72.19 211.51 6,029,078.58 558,367.77 5.14 -115.62 MWD+IFR2+MS+sag(2) 1,228.55 36.21 68.95 1,179.14 1,137.05 84.59 244.39 6,029,091.23 558,400.55 6.12 -132.84 MWD+IFR2+MS+sag(2) 1,291.42 39.21 68.81 1,228.87 1,186.78 98.45 280.26 6,029,105.37 558,436.30 4.77 -151.41 MWD+IFR2+MS+sag(2) 1,353.94 41.78 65.97 1,276.42 1,234.33 114.08 317.72 6,029,121.29 558,473.63 5.06 -170.06 MWD+IFR2+MS+sag(2) 1,417.37 44.17 60.70 1,322.84 1,280.75 133.51 356.31 6,029,141.02 558,512.07 6.80 -187.13 MWD+IFR2+MS+sag(2) 1.479+61 45.42 58.20 1,367.01 1,324,92 155.80 394.06 6,029,163.60 558,549.64 3.47 -201.72 MWD+IFR2+MS+sag(2) 1,542.77 43.96 56.04 1,411.91 1,369.82 179.90 431.36 6,029,187.99 558,586.75 3.34 -214.80 MWD+IFR2+MS+sag(2) 1,605.69 43.83 55.15 1,457.25 1,415.16 204.55 467,36 6,029.212.92 558,622.55 1.00 -226.53 MWD+IFR2+MS+sag(2) 1,668.53 43.23 56.38 1,502.81 1,460.72 228.90 503.13 6,029,237.55 558,658.13 1.65 -238.29 MWD+IFR2+MS+sag(2) 1,731.19 44.57 55.35 1,547.96 1,505.87 253.29 539.09 6,029,262.21 558,693.89 2.42 -250.16 MWD+IFR2+MS+sag(2) 1,794.80 45.49 54.89 1,592.92 1,550.83 279.02 576.01 6,029,288.23 558,730.60 1.53 -261.90 MWD+IFR2+MS+sag(2) 1,857.38 45.19 55.18 1,636.90 1,594.81 304.53 612.49 6,029,314.02 558,766.88 0.58 -273.44 MWD+IFR2+MS+sag(2) 1,921.47 43.70 56.44 1,682.66 1,640.57 329.75 849.60 6,029,339.53 558,803.79 2.70 -285.66 MWD+IFR2+MS+sag(2) 1,983.37 44.20 56.97 1,727.22 1,685.43 35334 685.51 6,029,363.39 558,839.51 1.00 -29801 MWD+IFR2+MS+sag(2) 2,04608 45.60 57.95 1,771.64 1,729.55 377.14 722.83 6,029,387.49 558,876.64 2.49 -311.30 MWD+IFR2+MS+sag(2) 2,106.86 47.38 57.49 1,814.86 1,772.77 401.46 761.32 6,029,412.10 558,914.93 2.88 -325.15 MWD+IFR2+MS+sag(2) 2,171.71 48.48 55.84 1,856.98 1,814.89 427.10 800.29 6,029,438.04 558,953.70 2.62 -338.52 MWD+IFR2+MS+sag(2) 2,234.03 47.47 55.63 1,898.70 1,856.61 453.16 838.55 6,029,464.40 558,991.75 1.64 35108 MWD+IFR2+MS+sag(2) 2,297.18 46.36 55.23 1,941.83 1,899.74 479.33 876.53 6,029,490.87 559,029.52 1.82 363.35 MWD+IFR2+MS+sag(2) 2,360.12 45.26 55.91 1,985.70 1,943.61 504.85 913.75 6,029,516.67 559,066.54 1.91 -37546 MWD+IFR2+MS+sag(2) 2,423.15 46.30 53.32 2,029.66 1,987.57 531.01 950.57 6,029,543.12 559,103.14 3.38 -386.85 MWD+IFR2+MS+seg(2) 2,485.68 46.39 53.02 2,072.83 2,030.74 558.13 986.78 6,029,570.51 559,139.14 0.38 -397.16 MWD+IFR2+MS+sag(2) 2,548.89 47.54 54.01 2,115.97 2,073.88 585.60 1,023.93 6,029,598.27 559,176.07 2.15 407.96 MWD+IFR2+MS+sag(2) 2,611.66 46.90 5424 2,158.60 2,116.51 612.60 1,061.26 6,029,625.56 559,213.18 1.05 419.20 MWD+IFR2+MS+sag(2) 2,675.09 45.80 53.71 2,202.38 2,160.29 639.59 1,098.38 6,029,652.84 559,250.09 1.84 430.29 MWD+IFR2+MS+sag(2) 2,737.61 46.62 55.09 2,245.65 2,203.56 665.85 1,135.07 6,029,679.39 559,286.57 2.06 441.51 MWD+IFR2+MS+sag(2) 2,800.59 47.96 54.95 2,288.37 2,24628 692.39 1,172.99 6,029,706.21 559,324.28 2.13 453.51 MWD+IFR2+MS+sag(2) 2,863.43 46.97 64.75 2,330.85 2,288.76 719.04 1,210.85 6,029,733.16 559,361.92 1.59 465.37 MWD+IFR2+MS+sag(2) 2,926.45 45.88 54.79 2,374.29 2,332.20 745.38 1,248.14 6,029,759.79 559,399.01 1.73 477.01 MWD+IFR2+MS+sag(2) 2,989.39 46.66 55.33 2,417.79 2,375.70 771.43 1,285.43 6,029,786.12 559,436.08 1.39 488.83 MWD+IFR2+MS+sag(2) 3,052.06 46.20 56.72 2,460.99 2,418.90 796.80 1,323.08 6,029,811.79 559,473.53 1.77 -501.36 MW13+11FR2+MS+sag(2) 3,114.78 47.31 54.98 2,503.96 2,461.87 822.45 1,360.88 6,029,837.73 559,511.13 2.69 513.83 MWD+IFR2+MS+sag(2) 3,177.77 47.20 55.22 2,546.72 2,504.63 848.92 1,398.82 6,029,864.49 559,548.85 0.33 -525.88 MWD+IFR2+MS+sag(2) 3,240.78 47.15 54.71 2,589.55 2,547.46 875.45 1,436.66 6,029,891.31 559,58648 0.60 -537.82 MWD+IFR2+MS+sag(2) 7/19201711:41:35AM Page 3 COMPASS 5000.1 Build 61D Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-47 MPU C47 PB1 MPU C-47 PB1 Local Co-ordinate Reference: Well MPU C-47 TVD Reference: MPU C47 Actual @ 42.09ustt MD Reference: MPU C-47 Actual @ 42.09usft North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +FJ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Toot Name 3,303.61 46.45 55.33 2,632.56 2,590.47 901.71 1,474.19 6,029,917.86 559,623.80 1.33 -549.69 MWD+IFR2+MS+sag(2) 3,366.40 45.77 55.61 2,676.09 2,634.00 927.36 1,511.46 6,029,943.80 559,660.67 1.13 561.76 MWD+IFR2+MS+sag(2) 3,429.58 45.36 55.60 2,720.32 2,678.23 952.84 1,548.69 6,029,969.57 559,697.89 0.65 -573.89 MWD+IFR2+MS+sag(2) 3,492.45 46.73 56.37 2,763.96 2,721.87 978.15 1,586.20 6,029,995.18 559,735.20 2.35 -586.36 MWD+IFR2+MS+sag(2) 3,555.26 47.14 56.67 2,806.85 2,764.76 1,003.47 1,624.48 6,030,020.78 559,773.28 0.74 -599.41 MWD+IFR2+MS+sag(2) 3,618.16 47.05 56.79 2,849.67 2,807.58 1,028.74 1,663.00 6,030,046.36 559,811.59 0.20 -612.67 MWD+IFR2+MS+sag(2) 3,681.00 46.97 56.88 2,892.52 2,85043 1,053.89 1,701.48 6,030,071.80 559,849.87 0.16 -625.98 MWD+IFR2+MS+sag(2) 3,744.01 47.06 57.11 2,935.48 2,893.39 1,079.00 1,740.13 6,030,097.21 559,888.32 0.30 -639.45 MWD+IFR2+MS+sag(2) 3,806.54 46.72 57.46 2,978.21 2,936.12 1,103.67 1,778.54 6,030,122.18 559,926.53 0.68 -653.02 MWD+IFR2+MS+sag(2) 3,869.51 45.54 57.19 3,021.85 2,979.76 1,128.18 1,816.75 6,030,146.98 559,964.55 1.90 -666.54 MWD+IFR2+MS+sag(2) 3,932.72 44.72 58.58 3,065.44 3,024.35 1,151.99 1,854.69 6,030,171.09 560,002.30 2.03 -680.29 MWD+IFR2+MS+sag(2) 3,994.68 45.69 58.37 3,110.10 3,068.01 1,174.98 1,892.17 6,030,194.37 560,039.59 1.58 -694.22 MWD+IFR2+MS+sag(2) 4,058.78 46.47 59.06 3,154.56 3,112.47 1,198.96 1,931.63 6,030,218.65 560,078.86 1.44 -709.04 MWD+IFR2+MS+sag(2) 4,121.67 46.94 57.21 3,197.69 3,155.60 1,223.12 1,970.50 6,030,243.12 560,117.53 2.27 -723.28 MWD+IFR2+MS+sag(2) 4,184.26 47.37 55.49 3,240.25 3,198.16 1,248.55 2,008.70 6,030,268.84 560,155.53 2.13 -736.20 MWD+IFR2+MS+sag(2) 4,247.01 46.62 55.68 3,283.05 3,240.96 1,274.49 2,046.55 6,030,295.07 560,193.18 1.22 -748.53 MWD+IFR2+MS+sag(2) 4,310.04 47.22 54.00 3,326.11 3,284.02 1,301.00 2,084.18 6,030,321.87 560,230.60 2.17 -760.31 MWD+IFR2+MS+sag(2) 4,373.03 46.89 51.99 3,369.02 3,326.93 1,328.75 2,121.00 6,030,349.91 560,267.19 2.39 -77068 MWD+IFR2+MS+sag(2) 4,436.03 46.36 52.01 3,412.29 3,37020 1,356.94 2,157.09 6,030,378.38 560,303.05 0.84 -780.20 MWD+IFR2+MS+sag(2) 4,498.85 46.18 52.64 3,455.71 3,413.62 1,384.68 2,193.02 6,030,406.40 560,338.76 0.78 -789.89 MWD+IFR2+MS+sag(2) 4,561.58 46.58 52.33 3,498.99 3,456.90 1,412.34 2,229.04 6,030,434.33 560,374.56 0.73 -799.71 MWD+IFR2+MS+sag(2) 4,624.57 46.37 53.12 3,542.37 3,500.28 1,440.00 2,265.38 6,030,462.27 560,410.68 0.97 -809.77 MWD+IFR2+MS+sag(2) 4,687.61 46.23 54.15 3,585.92 3,543.83 1,467.02 2,302.08 6,030,489.58 560,447.17 1.20 -820.51 MWD+1FR2+MS+sag(2) 4,75D.64 45.74 54.07 3,629.72 3,587.63 1,493.60 2,338.80 6,030,516.44 560,483.68 0.78 -831.56 MWD+IFR2+MS+sag(2) 4,813.36 45.50 54.83 3,673.59 3,631.50 1,519.66 2,375.27 6,030,542.78 560,519.94 0.95 -842.75 MWD+IFR2+MS+sag(2) 4,876.56 45.17 55.08 3,718.01 3,675.92 1,545.47 2,412.07 6,030,568.88 560,556.53 0.59 -864.35 MWD+IFR2+MS+sag(2) 4,939.16 46.57 55.44 3,761.60 3,719.51 1,571.07 2,449.00 6,030,594.76 560,593.25 2.27 -866.17 MWD+IFR2+MS+sag(2) 5,002.29 48.48 54.13 3,804.23 3,762.14 1,597.93 2,487.03 6,030,621.91 560,631.07 3.39 -878.05 MWD+IFR2+MS+sag(2) 5,065.05 48.33 54.87 3,845.89 3,803.80 1,625.18 2,525.24 6,030,649.46 560,669.06 0.91 -889.80 MWD+IFR2+MS+sag(2) 5,127.96 48.63 54.80 3,887.60 3,845.51 1,652.31 2,563.75 6,030,676.89 560,707.35 0.48 -901.86 MWD+IFR2+MS+sag(2) 5,190.74 48.74 54]8 3,929.04 3,886.95 1,679.50 2,602.27 6,030704.38 560,745.66 0.18 -913.90 MWD+IFR2+MS+sag(2) 5,253.18 47.98 55.52 3,970.53 3,928.44 1,706.16 2,640.56 6,030,731.34 560,783.74 1.51 -926.09 MWD+IFR2+MS+sag(2) 5,316.43 47.31 55.65 4,013.14 3,971.05 1,732.58 2,679.12 6,030,758.05 560,822.08 1.07 -938.65 MWD+IFR2+MS+sag(2) 5,379.24 4656 55.35 4,056.03 4,013.94 1,758.57 2,716.94 6,030,784.34 560,859.69 1.24 -950.91 MWD+IFR2+MS+sag(2) 5,442.18 45.92 55.56 4,099.56 4,057.47 1,784.35 2,754.38 6,030,810.40 560,896.93 1.05 -963.02 MWD+IFR2+MS+sag(2) 5,504.86 45.05 56.28 4,143.51 4,101.42 1,809.39 2,791.40 6,030,835.73 560,933.75 1.61 -97528 MWD+IFR2+MS+sag(2) 5,567.71 44.23 57.11 4,188.23 4,146.14 1,833.64 2,828.31 6,030,860.27 560,970.46 1.60 -987.96 MWD+IFR2+MS+sag(2) 5,630.99 45.28 56.40 4,233.16 4,191.07 1,858.07 2,865.57 6,030,884.99 561,007.52 1.84 -1,000.81 MWD+IFR2+MS+sag(2) 5,693.66 46.21 56.94 4,276.90 4,234.81 1,882.73 2,903.07 6,030,909.84 561,044.83 1.61 -1,013.68 MWD+IFR2+MS+sag(2) 5,756.43 47.58 57.14 4,319.79 4,277.70 1,907.66 2,941.52 6,030,935.17 561,083.08 2.19 -1,027.11 MWD+IFR2+MS+sag(2) 7/192017 11:41:35AM Page 4 COMPASS 5000.1 Build 81D Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-47 MPU C-47 PB1 MPU C-47 Pet Local Coordinate Reference: Well MPU C-47 TVD Reference: MPU C-47 Actual @ 42.09usft MD Reference: MPU C-47 Actual @ 42.09usft North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US +CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/ -W Northing Easting DLS Section (usft) (°) (°) just) (usft) (usft) (usft) (t) (ft) (°1100') (ft) Survey Tool Name 5,819.15 47.46 57.85 4,362.15 4,320.06 1,932.52 2,980.53 6,030,960.33 561,121.89 0.86 -1,041.02 MWD+IFR2+MS+sag(2) 5,882.52 47.54 57.89 4,404.96 4,362.87 1,957.37 3,020.10 6,030,985.48 561,161.26 0.13 -1,055.36 MWD+IFR2+MS+sag(2) 5,945.31 46.64 58.18 4,447.71 4,405.62 1,981.72 3,059.11 6,031,010.13 561,200.08 1.47 -1,069.59 MWD+IFR2+MS+sag(2) 6,007.96 46.97 55.89 4,490.60 4,448.51 2,006.57 3,097.43 6,031,035.28 561,238.19 2.72 -1,082.97 MWD+IFR2+MS+Sag(2) 6,071.22 48.82 54.83 4,533.01 4,490.92 2,033.25 3,136.03 6,031,062.26 561,276.59 3.18 -1,095.39 MWD+IFR2+MS+sag(2) 6,133.99 48.28 55.84 4,574.56 4,532.47 2,060.01 3,174.73 6,031,089.32 561,315.07 1.48 -1,107.83 MWD+IFR2+MS+sag(2) 6,196.90 47.55 55.28 4,616.73 4,574.64 2,086.41 3,213.23 6,031,116.02 561,353.36 1.34 -1,120.36 MWD+IFR2+MS+sag(2) 6,260.01 46.99 55.19 4,659.55 4,617.46 2,112.85 3,251.32 6,031,142.75 561,391.23 0.89 -1,132.54 MWD+IFR2+MS+sag(2) 6,322.70 46.72 55.80 4,702.42 4,660.33 2,138.76 3,289.01 6,031,168.95 561,428.72 0.83 -1,144.76 MWD+IFR2+MS+Sag(2) 6,385.49 46.74 55.40 4,745.46 4,703.37 2,164.59 3,326.73 6,031,195.07 561,466.23 0.46 -1,157.06 MWD+IFR2+MS+ssg(2) 6,448.29 46.63 56.00 4,788.54 4,746.45 2,190.34 3,364.48 6,031,221.11 561,503.77 0.72 -1,169.42 MWD+IFR2+MS+sag(2) 6,511.55 46.46 55.90 4,832.05 4,789.96 2,216.05 3,402.53 6,031,247.12 561,541.62 0.29 -1,182.04 MWD+IFR2+MS+sag(2) 6,554.36 46.33 55.66 4,861.57 4,819.48 2,233.48 3,428.16 6,031,264.75 561,567.11 0.51 -1,190.47 MWD+IFR2+MS+sag(2) 6,644.07 45.97 56.44 4,923.72 4,881.63 2,269.61 3,481.82 6,031,301.29 561,620.48 0.74 -1,208.35 MWD+IFR2+MS+sag(3) 6,707.33 45.64 56.12 4,967.82 4,925.73 2,294.79 3,519.55 6,031,326.76 561,658.01 0.64 -1,221.07 MWD+IFR2+MS+sag(3) 6,769.48 46.17 57.56 5,011.07 4,968.98 2,319.20 3,566.92 6,031,351.46 561,695.18 1.87 -1,234.00 MWD+IFR2+MS+sag(3) 6,830.30 46.22 56.81 5,053.17 5,011.08 2,342.99 3,593.80 6,031,375.54 561,731.88 0.89 -1,246.97 MWD+IFR2+MS+sag (3) 6.895.66 4620 56.95 5,09040 5.056,31 2,368.77 3,633.32 6,031,401.62 561,771.19 0.16 -1,260.67 MWD+IFR2+MS+sag(3) 6,958.73 45.97 56.62 5,142.15 5,100.06 2,393.66 3,671.33 6,031,426.80 561,809.00 0.52 -1,273.79 MWD+IFR2+MS+sag(3) 7,021.27 45.86 56.77 5,185.66 5,143.57 2,418.32 3,708.88 6,031,451.76 561,846.34 0.25 -1,286.70 MWD+IFR2+MS+sag(3) 7,084.57 45.72 57.10 5,229.79 5,187.70 2,443.08 3,746.90 6,031,476.81 561,884.17 0.43 -1,299.91 MWD+IFR2+MS+sag(3) 7,142.34 45.57 56,00 5,270.18 5,228.09 2,465.85 3,781.37 6,031,499.84 561,918.45 1.39 -1,311.68 MWD+IFR2+MS+sag(3) 7,210.80 45.59 55.74 5,318.10 5,276.01 2,493.28 3,821.84 6,031,527.69 561,958.71 0.27 -1,325.05 MWD+IFR2+MS+Sag(3) 7,273.37 46.28 55.62 5,361+61 5,319.52 2,518.63 3,858.97 6,031,553.23 561,995.64 1.11 -1,337.20 MWD+IFR2+MS+sag(3) 7,336+68 46.69 55.95 5,405.21 5,363.12 2,544.44 3,896.94 6,031,579.34 562,033.40 0.75 -1,349.69 MWD+IFR2+MS+sag(3) 7,398.77 46.60 55.20 5,447.83 5,405.74 2,569.97 3,934.18 6,031,605.15 562,070.43 0.89 -1,361.81 MWD+IFR2+MS+sag(3) 7,462.09 46.58 55.14 5,491.35 5,449.26 2,596.24 3,971.94 6,031,631.71 562,107.98 0.08 -1,373.85 MWD+IFR2+MS+sag(3) 7,524.48 46.60 54.91 5,534.22 5,492.13 2,622.22 4,009.07 6,031,657.98 562,144.91 0.27 -1,385.60 MWD+IFR2+MS+sag(3) 7,587.54 46.44 55.71 5,577.61 5,535.52 2,648.26 4,046.70 6,031,664.31 562,182.32 0.95 -1,397.68 MWD+IFR2+MS+sag(3) 7,646.27 46.43 55.66 5,618.09 5,576.00 2,672.25 4,081.85 6,031,70857 562,217.28 0.06 -1,409.18 MWD+IFR2+MS+sag(3) 7,713.38 46.41 55.08 5,664.35 5,622.26 2,699.88 4,121.85 6,031,736.51 562,257.06 0.63 -1,422.07 MWD+IFR2+MS+sag(3) 7,776.51 46.44 55.96 5,707.87 5,665.78 2)25.77 4,159.55 6,031,762.69 562,294.55 1.01 -1,434.31 MWD+IFR2+MS+sag(3) 7,839.24 46.11 55.97 5,751.23 5,709.14 2,751.14 4,197.12 6,031,788.36 562,331.92 0.53 -1,446.78 MWD+IFR2+MS+sag(3) 7,902.04 46.24 55.41 5,794.71 5,75262 2,716.68 4,234.54 6,031,814.18 562,369.14 0.68 -1,459.03 MWD+IFR2+MS+sag(3) 7,965.12 45.71 55.46 5,838.55 5,796.46 2,802.41 4,271.89 6,031,840.21 562,406.28 0.84 -1,471.10 MWD+IFR2+MS+sag(3) 8,028.05 45.86 56.04 5,882.44 5,840.35 2,827.80 4,309.17 6,031,865.88 562,443.36 0.70 -1,483.34 MWD+IFR2+MS+sag(3) 8,090.89 45.47 55.77 5,926.35 5,884.26 2,852.99 4,346.39 6,031,891.36 562,480.38 0.69 -1,495.66 MWD+IFR2+MS+sag(3) 8,153.91 45.35 55.96 5,970.60 5,928.51 2,878.18 4,383.54 6,031,916,83 562,517.33 0.29 -1,507.93 MWD+IFR2+MS+sag(3) 8,216.94 45.23 56.07 6,014.94 5,972.85 2,90322 4,420.68 6,031,942.16 562,554.27 0.23 -1,520.29 MWD+IFR2+MS+sag(3) 8,275.18 45.18 56.50 6,055.97 6,013.88 2,926.16 4,455.06 6,031,965.37 562,588+46 0.53 -1,531.88 MWD+IFR2+MS+sag(3) 7/192017 11:41:35AM Page 5 COMPASS 5000.1 Build 81D Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU C-47 Project: Milne Point TVD Reference: MPU C-47 Actual @ 42.09usft Site: M Pt C Pad MD Reference: MPU C-47 Actual @ 42.09usft Well: MPU C-47 North Reference: True Wellbore: MPU C-47 PBI Survey Calculation Method: Minimum Curvature Design: MPU C-47 PB1 Database: Sperry EDM - NORTH US+CANADA Survey Map Map Vertical Mn Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) (1) (•) (usft) (usft) (usft) (usft) (ftl (ft) (.1100') (ft) Survey Tool Name 8,342.52 45.07 56.97 6,103.48 6,061.39 2,952.33 4,494.96 6,031,991.85 562,628.15 0.52 -1,545.62 MWD+IFR2+MS+Sag(3) 8,405.50 44.66 55.37 6,148.12 6,10603 2,977.06 4,531.87 6,032,016.87 562,664.86 1.91 -1,557.99 MWD+IFR2+MS+sag(3) 8,468.34 44.81 52.68 6,192.77 6,150.68 3,003.04 4,567.65 6,032,043.12 562,700.44 3.02 -1,568.71 MWD+IFR2+MS+sag(3) 8,531.11 45.46 48.40 6,237.06 6,194.97 3,031.31 4,601.98 6,032,071.65 562,734.54 4.94 -1,576.83 MWD+IFR2+MS+sag(3) 8,593.72 46.31 43.94 6,280.65 6,238.56 3,062.43 4,634.38 6,032,103.03 562,766.69 5.29 -1,581.65 MWD+IFR2+MS+sag(3) 8,656.74 46.62 40.53 6,324.07 6,28198 3,096.25 4,66508 6,032,137.08 562,797.12 3.95 4,583.43 MWD+IFR2+MS+sag(3) 8,719.70 46.10 35.91 6,367.53 6,325.44 3,132.02 4,693.26 6,032,173.07 562,825.02 5.37 -1,582.02 MWD+IFR2+MS+sag(3) 8,782.62 45.95 32.02 6,411.23 6,369.14 3,169.56 4,718.55 6,032,210.80 562,850.01 4.46 -1,577.26 MWD+IFR2+MS+sag(3) 8,845.67 46.48 27.94 6,454.86 6,412.77 3,208.98 4,741.28 6,032,250.39 562,872.43 4.75 -1,569.34 MWD+IFR2+MS+sag(3) 8,908.42 46.81 23.62 6,497.95 6,455.86 3,250.04 4,761.11 6,032,291.61 562,891.94 5.03 -1,558.13 MWD+IFR2+MS+sag(3) 8,971.67 46.99 2016 6,541.18 6,499.09 3,292.87 4,778.36 6,032,334.56 562,908.85 3.89 -1,543.82 MWD+IFR2+MS+sag(3) 9,034.25 48.03 16.62 6,583.45 6,541.36 3,336.64 4,792.94 6,032,378.44 562,923.09 4.60 -1,526.85 MWD+1FR2+MS+sag(3) 9,097.10 48.31 13.96 6,625.37 6,583.28 3,381.80 4,805.28 6,032,423.69 562,935.08 3.18 -1,507.28 MWD+IFR2+MS+sag(3) 9,160.01 48.58 10.35 6.667.11 6,625.02 3,427.81 4,815.19 6,032,469.77 562,944.62 4.32 -1,485.29 MWD+IFR2+MS+sag(3) 9,222.98 49.18 6.58 6,708.53 6,666.44 3,474.72 4,822.16 6,032,516.73 562,951.23 4.61 -1,460.49 MWD+IFR2+MS+sag(3) 9,285.91 50.50 4.02 6,749.12 6,707.03 3,522.60 4,826.59 6,032,564.64 562,955.28 3.75 -1,433.10 MWD+IFR2+MS+sag(3) 9,349.09 52.27 1.98 6,786.55 6,746.46 3,571.89 4,829.17 6,032,613.94 562,957.47 3.77 -1,403.39 MWD+IFR2+MS+sag(3) 9,411.63 53.82 089 6,826.15 6,784.06 3,621.85 4,830.41 6,032,663.91 562,958.33 284 -1,372.23 MWD+IFR2+MS+sag(3) 9,474.33 55.95 0.01 6,862.21 6,820.12 3,673.13 4,830.81 6,032,715.19 562,958.32 3.59 -1,339.57 MWD+IFR2+MS+sag(3) 9,537.25 57.42 357.97 6,896.77 6,854.68 3,725.70 4,829.88 6,032,767.74 562,956.98 3.58 -1,30507 MWD+IFR2+MS+sag(3) 9,600.33 59.13 356.20 6,929.95 6,887.86 3,779.28 4,827.14 6,032,821.29 562,953.82 3.61 -1,268.53 MWD+IFR2+MS+sag(3) 9,663.05 61.06 354.60 6,961.21 6,919.12 3,833.47 4,822.77 6,032,875.44 562,949.03 3.79 -1,230.35 MWO+IFR2+MS+sag(3) 9,722.75 62.59 353.75 6,989.40 6,947.31 3,885.82 4,817.43 6,032,927.74 562,943.28 2.85 -1,192.61 MWD+IFR2+MS+sag(3) 9,788.79 64.56 351.21 7,018.79 6,976.70 3,944.44 4,809.68 6,032,986.29 562,935.07 4.56 -1,148.99 MWD+IFR2+MS+sag(3) 9,850.83 66.09 350.12 7,044.69 7,002.60 4,000.06 4,800.53 6,033,041.84 562,925.49 2.94 -1,106.23 MWD+IFR2+MS+sag(3) 9,914.23 67.62 349.24 7,069.61 7,027.52 4,057.41 4,790.09 6,033,099.10 562,914.60 2.73 -1,061.36 MWD+IFR2+MS+sag(3) 9,975.54 70.30 348.09 7,09162 7,049.53 4,113.51 4,778.84 6,033,155.10 562,902.91 4.71 -1,016.69 MWD+IFR2+MS+seg(3) 10,040.37 72.90 346.98 7,112.09 7,070.00 4,173.57 4,765.56 6,033,215.05 562,889.16 4.33 -967.91 MWD+IFR2+MS+sag(3) 10,103.38 75.59 344.90 7,129.20 7,087.11 4,232.39 4,750.82 6,033,273.74 562,873.97 5.32 -918.81 MWD+IFR2+MS+sag(3) 10,165.93 78.76 344.28 7,143.08 7,100.99 4,291.18 4,734.61 6,033,332.40 562,857.30 5.16 -868.61 MWD+1FR2+MS+sag(3) 10,228.76 80.89 342.40 7,154.18 7,112.09 4,350.41 4,716.88 6,033,391.49 562,839.11 4.49 -816.95 MWD+IFR2+MS+sag(3) 10,262.15 8280 342.47 7,158.91 7,11682 4,381.92 4,70691 6,033,422.92 562,828.89 5.72 -789.05 MWD+IFR2+MS+sag(3) 10,293.00 82.80 342.47 7,162.78 7,120.69 4,411.11 4,697.69 6,033,452.03 562,819.45 0.00 -763.23 PROJECTED to TO J Checked By: madW.Mphallitwrtonmm 2onu71919 o9:43s3os'oa Approved By: Michael Calkins"' -- Date: 7/19/17 7/1912017 11:41:35AM Page 6 COMPASS 5000.1 Build 61D Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-47 P132 i 50029235777100 Sperry Drilling Definitive Survey Report 29 June, 2018 HALLIBURTON Sperry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well RIG: MPU C-47 Project: Milne Point TVD Reference: MPU C-47 Actual @ 42.09usft Site: M Pt C Pad MD Reference: MPU C-47 Actual @ 42.09usft Well: MPU C-47 North Reference: True Wellbore: MPU C-47 PB2 Survey Calculation Method: Minimum Curvature Design: MPU C-47 PB2 Database: Sperry EDM - NORTH US + CANADA aroject Milne Point, ACT, MILNE POINT Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU C-47 Well Position +N/_S +E/ -W Position Uncertainty Wellbore MPU C-47 PB2 Magnetics Model Name 0.00 usft Northing: 6,029,004.74 usfl 0.00 usft Easting: 558,156.85 usfl 0.00 usft Wellhead Elevation: 15.15 usfl Sample Date Declination (°) BGGM2017 5/1/2018 17.20 Design MPU C-47 PB2 Audit Notes: Version: 1.0 Vertical Section: Phase: ACTUAL Depth From (TVD) +N/ -S (usft) (usft) 26.94 0.00 Latitude: 70° 29'23.490 N Longitude: 149" 31'28.533 W Ground Level: 15.15 usft Dip Angle Field Strength P) (nT) 81.02 57,481 Tie On Depth: 6,554.36 +E/ -W Direction (usft) (1) 0.00 39.25 Survey Program Date 6/13/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 728.00 SRG-SS (MPU C-47 PB1) 2_Gyro-SR-GSS H047Ga: Surface readout gyro single shot 06/26/2017 788.64 6,554.36 MWD+IFR2+MS+sag (1) (MPU C-47 PB 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec 8 multi -station analysis + sa 06/29/2017 6,600.00 10,436.74 MWD+IFR2+MS+sag (MPU C47 PB2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec 8 multi -station analysis +sa 05/11/2018 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) ("/100') (ft) Survey Tool Name 26.94 0.00 0.00 26.94 -15.15 0.00 0.00 6,029,004.74 558,156.85 0.00 0.00 UNDEFINED 100.00 0.46 30.95 100.00 57.91 0.25 0.15 6,029,004.99 558,157.00 0.63 0.29 2_Gyro-SR-GSS(1) 200.00 0.54 2.72 200.00 157.91 1.07 0.38 6,029,005.81 558,157.22 0.26 1.07 2_Gym-SR-GSS(1) 232.00 0.64 21.04 231.99 189.90 1.38 0.45 6,029,006.13 558,157.29 0.66 1.36 2_GymSR-GSS(1) 294.00 1.30 47.98 293.98 251.89 2.18 1.10 6,029,006.93 558,157.93 1.27 2.38 2_GyroSR-GSS(1) 356.00 3.05 64.42 355.94 313.85 3.36 3.11 6,029,008.12 558,159.93 2.97 4.57 2_Gyro-SR-GSS(1) 417.00 5.70 60.05 416.76 374.67 5.57 7.20 6,029,010.37 558,164.00 4.38 8.87 2_Gyro-SR-GSS (1) 479.00 8.12 64.89 478.30 436.21 8.97 13.83 6,029,013.82 558,170.61 4.01 15.70 2_Gym-SR-GSS(1) 539.00 8.84 70.54 537.65 495.56 12.30 22.02 6,029,017.21 558,178.77 1.83 23.46 2_Gyro-SR-GSS(1) 600.00 9.56 71.46 597.86 555.77 15.48 31.24 6,029,020.46 558,187.96 1.20 31.75 2_GyroSR-GSS(1) 663.00 11.19 69.51 659.83 617.74 19.28 41.92 6,029,024.35 558,198.62 2.65 41.46 2 GynoSR-GSS (1) 728.00 13.80 71.83 723.28 681.19 23.91 55.20 6,029,029.07 558,211.86 4.09 53.44 2_Gyro-SR-GSS(1) 6/292018 12:02:43PM Page 2 COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well RIG: MPU C-47 Project: Milne Point TVD Reference: MPU C-47 Actual @ 42.09usft Site: M Pt C Pad MD Reference: MPU C-47 Actual @ 42.09usft Well: MPU C-47 North Reference: True Wellbore: MPU C-47 PB2 Survey Calculation Method: Minimum Curvature Design: MPU C-47 PB2 Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (^1100•) (ft) Survey Tool Name 788.64 15.51 75.21 781.95 739.86 28.23 69.91 6,029,033.51 558,226.53 3.15 66.10 2_MWD+IFR2+MS+Sag (2) 851.56 18.13 75.03 842.17 800.08 32.91 87.51 6,029,038.33 558,244.09 4.16 80.85 2_MWD+IFR2+MS+Sag(2) 915.56 19.89 73.91 902.68 860.59 38.50 107.59 6,029,044.08 558,264.12 2.81 97.88 2_MWD+IFR2+MS+Sag (2) 977.20 22.42 73.82 960.16 918.07 44.68 128.96 6,029,050.42 558,285.44 4.10 116.19 2_MWD+IFR2+MS+Sag(2) 1,039.64 25.67 72.30 1,017.18 975.09 52.11 153.28 6,029,058.04 558,309.70 5.30 137.34 2_MWD+IFR2+MS+Sag(2) 1,100.98 29.14 71.09 1,071.62 1,029.53 61.00 180.08 6,029,067.14 558,336.43 5.73 161.17 2_MWD+IFR2+MS+Sag(2) 1,166.20 32.42 69.76 1,127.65 1,085.56 72.19 211.51 6,029,078.58 558,367.77 5.14 189.73 2_MWD+IFR2+MS+Sag(2) 1,228.55 36.21 68.95 1,179.14 1,137.05 84.59 244.39 6,029,091.23 558,400.55 6.12 220.14 2_MWD+IFR2+MS+Sag(2) 1,291.42 39.21 68.81 1,228.87 1,186.78 98.45 280.26 6,029,105.37 558,436.30 4.77 253.56 2_MWD+IFR2+MS+Sag (2) 1,353.94 41.78 65.97 1,276.42 1,234.33 114.08 317.72 6,029,121.29 558,473.63 5.06 289.36 2_MWD+IFR2+MS+Sag(2) 1,417.37 44.17 60.70 1,322.84 1,280.75 133.51 356.31 6,029,141.02 558,512.07 6.80 328.82 2_MWD+IFR2+MS+Sag(2)M 1,479.61 45.42 58.20 1,367.01 1,324.92 155.80 394.06 6,029,163.60 558,549.64 3.47 369.98 2_WD+IFR2+MS+Sag (2) 1,542.77 43.96 56.04 1,411.91 1,369.82 179.90 431.36 6,029,187.99 558,586.75 3.34 412.24 2_MWD+IFR2+MS+Sag(2) 1,605.69 43.83 55.15 1,457.25 1,415.16 204.55 467.36 6,029,212.92 558,622.55 1.00 454.10 2_MWD+IFR2+MS+Sag (2) 1,668.53 43.23 56.38 1,502.81 1,460.72 228.90 503.13 6,029,237.55 558,658.13 1.65 495.60 2_MWD+IFR2+MS+Sag(2) 1,731.19 44.57 55.35 1,547.96 1,505.87 253.29 539.09 6,029,262.21 558,693.89 2.42 537.23 2_MWD+IFR2+MS+Sag (2) 1,794.80 45.49 54.89 1,592.92 1,550.83 279.02 576.01 6,029,288.23 558,730.60 1.53 580.52 2_MWD+IFR2+MS+Sag (2) 1,857.38 45.19 55.18 1,636.90 1,594.81 304.53 612.49 6,029,314.02 558,766.88 0.58 623.35 2_MWD+IFR2+MS+Sag (2) 1,921.47 43.70 56.44 1,682.66 1,640.57 329.75 649.60 6,029,339.53 558,803.79 2.70 666.37 2 MWD+IFR2+MS+Sag(2) 1,983.37 44.20 56.97 1,727.22 1,685.13 353.34 685.51 6,029,363.39 558,839.51 1.00 707.35 2_MWD+IFR2+MS+Sag (2) 2,046.08 45.60 57.95 1,771.64 1,729.55 377.14 722.83 6,029,387.49 558,876.64 2.49 749.39 2_MWD+IFR2+MS+Sag (2) 2,108.86 47.38 57.49 1,814.86 1,772.77 401.46 761.32 6,029,412.10 558,914.93 2.88 792.58 2_MWD+IFR2+MS+Sag (2) 2,171.71 48.48 55.84 1,856.98 1,814.89 427.10 800.29 6,029,438.04 558,953.70 2.62 837.09 2_MWD+IFR2+MS+Sag(2) 2,234.03 47.47 55.63 1,898.70 1,856.61 453.16 838.55 6,029,464.40 558,991.75 1.64 881.48 2_MWD+IFR2+MS+Sag(2) 2,297.18 46.36 55.23 1,941.83 1,899.74 479.33 876.53 6,029,490.87 559,029.52 1.82 925.78 2_MWD+IFR2+MS+Sag (2) 2,360.12 45.26 55.91 1,985.70 1,943.61 504.85 913.75 6,029,516.67 559,066.54 1.91 969.09 2_MWD+IFR2+MS+Sag (2) 2,423.15 46.30 53.32 2,029.66 1,987.57 531.01 950.57 6,029,543.12 559,103.14 3.38 1,012.64 2_MWD+IFR2+MS+Sag(2) 2,485.68 46.39 53.02 2,072.83 2,030.74 558.13 986.78 6,029,570.51 559,139.14 0.38 1,056.55 2_MWD+IFR2+MS+Sag(2) 2,548.89 47.54 54.01 2,115.97 2,073.88 585.60 1,023.93 6,029,598.27 559,176.07 2.15 1,101.33 2_MWD+IFR2+MS+Sag(2) 2,611.66 46.90 54.24 2,158.60 2,116.51 612.60 1,061.26 6,029,625.56 559,213.18 1.05 1,145.85 2_MWD+IFR2+MS+Sag (2) 2,675.09 45.80 53.71 2,202.38 2,160.29 639.59 1,098.38 6,029,652.84 559,250.09 1.84 1,190.24 2_MWD+IFR2+MS+Sag (2) 2,737.61 46.62 55.09 2,245.65 2,203.56 665.85 1,135.07 6,029,679.39 559,286.57 2.06 1,233.80 2_MWD+IFR2+MS+Sag(2) 2,800.59 47.96 54.95 2,288.37 2,246.28 692.38 1,172.99 6,029,706.21 559,324.28 2.13 1,278.33 2_MWD+IFR2+MS+Sag(2) 2,863.43 46.97 54.75 2,330.85 2,288.76 719.04 1,210.85 6,029,733.16 559,361.92 1.59 1,322.93 2_MWD+IFR2+MS+Sag (2) 2,926.45 45.88 54.79 2,374.29 2,332.20 745.38 1,248.14 6,029,759.79 559,399.01 1.73 1,366.92 2 MWD+IFR2+MS+Sag (2) 2,989.39 46.66 55.33 2,417.79 2,375.70 771.43 1,285.43 6,029,786.12 559,436.08 1.39 1,410.68 2_MWD+IFR2+MS+Sag(2) 3,052.06 46.20 56.72 2,460.99 2,418.90 796.80 1,323.08 6,029,811.79 559,473.53 1.77 1,454.16 2_MWD+IFR2+MS+Sag(2) 3,114.78 47.31 54.98 2,503.96 2,461.87 822.45 1,360.88 6,029,837.73 559,511.13 2.69 1,497.94 2_MWD+IFR2+MS+Sag (2) 3,177.77 47.20 55.22 2,546.72 2,504.63 848.92 1,398.82 6,029,864.49 559,548.85 0.33 1,542.44 2_MWD+IFR2+MS+Sag (2) 3,240.78 47.15 54.71 2,589.55 2,547.46 875.45 1,436.66 6,029,891.31 559,586.48 0.60 1,586.92 2_MWD+IFR2+MS+Sag (2) 6129/2018 12:02:43PM Page 3 COMPASS 5000.1 Build 81E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt C Pad Well: MPU C-47 Wellbore: MPU C-47 PB2 Design: MPU C-47 PB2 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well RIG: MPU C-47 MPU C-47 Actual @ 42.09usft MPU C-47 Actual @ 42.09usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,303.61 46.45 55.33 2,632.56 2,590.47 901.71 1,474.19 6,029,917.86 559,623.80 1.33 1,631.00 2_MWD+IFR2+MS+Sag(2) 3,366.40 45.77 55.61 2,676.09 2,634.00 927.36 1,511.46 6,029,943.80 559,660.87 1.13 1,674.45 2_MWD+IFR2+MS+Sag(2) 3,429.58 45.36 55.60 2,720.32 2,678.23 952.84 1,548.69 6,029,969.57 559,697.89 0.65 1,717.74 2_MWD+IFR2+MS+Sag (2) 3,492.45 46.73 56.37 2,763.96 2,721.87 978.15 1,586.20 6,029,995.18 559,735.20 2.35 1,761.08 2 MWD+IFR2+MS+Sag (2) 3,555.26 47.14 56.67 2,806.85 2,764.76 1,003.47 1,624.48 6,030,020.78 559,773.28 0.74 1,804.89 2_MWD+IFR2+MS+Sag(2) 3,618.16 47.05 56.79 2,849.67 2,807.58 1,028.74 1,663.00 6,030,046.36 559,811.59 0.20 1,848.84 2_MWD+IFR2+MS+Sag(2) 3,681.00 46.97 56.88 2,892.52 2,850.43 1,053.89 1,701.48 6,030,071.80 559,849.87 0.16 1,892.66 2_MWD+IFR2+MS+Sag (2) 3,744.01 47.06 57.11 2,935.48 2,893.39 1,079.00 1,740.13 6,030,097.21 559,888.32 0.30 1,936.56 2_MWD+IFR2+MS+Sag(2) 3,806.54 46.72 57.46 2,978.21 2,936.12 1,103.67 1,778.54 6,030,122.18 559,926.53 0.68 1,979.97 2_MWD+IFR2+MS+Sag(2) 3,869.51 45.54 57.19 3,021.85 2,979.76 1,128.17 1,816.75 6,030,146.98 559,964.55 1.90 2,023.12 2_MWD+IFR2+MS+Sag(2) 3,932.72 44.72 58.58 3,066.44 3,024.35 1,151.99 1,854.69 6,030,171.09 560,002.30 2.03 2,065.57 2_MWD+IFR2+MS+Sag(2) 3,994.68 45.69 58.37 3,110.10 3,068.01 1,174.98 1,892.17 6,030,194.37 560,039.59 1.58 2,107.08 2_MWD+IFR2+MS+Sag(2) 4,058.78 46.47 59.06 3,154.56 3,112.47 1,198.96 1,931.63 6,030,218.65 560,078.86 1.44 2,150.62 2_MWD+IFR2+MS+Sag(2) 4,121.67 46.94 57.21 3,197.69 3,155.60 1,223.12 1,970.50 6,030,243.12 560,117.53 2.27 2,193.92 2_MWD+IFR2+MS+Sag(2) 4,184.26 47.37 55.49 3,240.25 3,198.16 1,248.55 2,008.70 6,030,268.84 560,155.53 2.13 2,237.78 2_MWD+IFR2+MS+Sag(2) 4,247.01 46.62 55.68 3,283.05 3,240.96 1,274.49 2,046.55 6,030,295.07 560,193.18 1.22 2,281.82 2 MWD+IFR2+MS+Sag(2) 4,310.04 4722 54.00 3,326.11 3,284.02 1,301.00 2,084.18 6,030,321.87 560,230.60 2.17 2,326.16 2_MWD+IFR2+MS+Sag(2) 4,373.03 46.89 51.99 3,369.02 3,326.93 1,328.75 2,121.00 6,030,349.91 560,267.19 2.39 2,370.94 2_MWD+IFR2+MS+Sag(2) 4,436.03 46.36 52.01 3,412.29 3,370.20 1,356.94 2,157.09 6,030,378.38 560,303.05 0.84 2,415.61 2_MWD+IFR2+MS+Sag(2) 4,498.85 46.18 52.64 3,455.71 3,413.62 1,384.68 2,193.02 6,030,406.40 560,338.76 0.78 2,459.82 2_MWD+IFR2+MS+Sag (2) 4,561.58 46.58 52.33 3,498.99 3,456.90 1,412.34 2,229.04 6,030,434.33 560,374.56 0.73 2,504.03 2_MWD+IFR2+MS+Sag (2) 4,624.57 46.37 53.12 3,542.37 3,500.28 1,440.00 2,265.38 6,030,462.27 560,410.68 0.97 2,548.44 2_MWD+IFR2+MS+Sag(2) 4,687.61 46.23 54.15 3,585.92 3,543.83 1,467.02 2,302.08 6,030,489.58 560,447.17 1.20 2,592.59 2_MWD+IFR2+MS+Sag(2) 4,750.64 45.74 54.07 3,629.72 3,587.63 1,493.60 2,338.80 6,030,516.44 560,483.68 0.78 2,636.40 2_MWD+IFR2+MS+Sag(2) 4,813.36 45.50 54.83 3,673.59 3,631.50 1,519.66 2,375.27 6,030,542.78 560,519.94 0.95 2,679.66 2M_WD+IFR2+MS+Sag (2) 4,876.56 45.17 55.08 3,718.01 3,675.92 1,545.47 2,412.07 6,030,568.88 560,556.53 0.59 2,722.93 2_MWD+IFR2+MS+Sag(2)M 4,939.16 46.57 55.44 3,761.60 3,719.51 1,571.07 2,449.00 6,030,594.76 560,593.25 2.27 2,766.12 2_WD+IFR2+MS+Sag (2) 5,002.29 48.48 54.13 3,804.23 3,762.14 1,597.93 2,487.03 6,030,621.91 560,631.07 3.39 2,810.98 2_MWD+IFR2+MS+Sag(2) 5,065.05 48.33 54.87 3,845.89 3,803.80 1,625.18 2,525.24 6,030,649.46 560,669.06 0.91 2,856.26 2_MWD+IFR2+MS+Sag(2) 5,127.96 48.63 54.80 3,887.60 3,845.51 1,652.31 2,563.75 6,030,676.89 560,707.35 0.48 2,901.63 2_MWD+IFR2+MS+Sag(2) 5,190.74 48.74 54.78 3,929.04 3,886.95 1,679.50 2,602.27 6,030,704.37 560,745.66 0.18 2,947.06 2_MWD+IFR2+MS+Sag(2) 5,253.18 47.98 55.52 3,970.53 3,928.44 1,706.16 2,640.56 6,030,731.34 560,783.74 1.51 2,991.94 2_MWD+IFR2+MS+Sag(2) 5,316.43 47.31 55.65 4,013.14 3,971.05 1,732.58 2,679.12 6,030,758.05 560,822.08 1.07 3,036.79 2_MWD+IFR2+MS+Sag (2) 5,379.24 46.56 55.35 4,056.03 4,013.94 1,758.57 2,716.94 6,030,784.33 560,859.69 1.24 3,080.85 2_MWD+IFR2+MS+Sag(2) 5,442.18 45.92 55.56 4,099.56 4,057.47 1,784.35 2,754.38 6,030,810.40 560,896.93 1.05 3,124.50 2_MWD+IFR2+MS+Sag(2) 5,504.86 45.05 56.28 4,143.51 4,101.42 1,809.39 2,791.40 6,030,835.73 560,933.75 1.61 3,167.31 2_MWD+IFR2+MS+Sag (2) 5,567.71 44.23 57.11 4,188.23 4,146.14 1,833.64 2,828.31 6,030,860.27 560,970.46 1.60 3,209.44 2_MWD+IFR2+MS+Sag (2) 5,630.99 45.28 56.40 4,233.16 4,191.07 1,858.07 2,865.57 6,030,884.99 561,007.52 1.84 3,251.94 2 MWD+IFR2+MS+Sag(2) 5,693.66 46.21 56.94 4,276.90 4,234.81 1,882.73 2,903.07 6,030,909.94 561,044.83 1.61 3,294.76 2_MWD+IFR2+MS+Sag(2) 5,756.43 47.58 57.14 4,319.79 4,277.70 1,907.66 2,941.52 6,030,935.17 561,083.08 2.19 3,338.40 2_MWD+IFR2+MS+Sag (2) 6292018 12:02:43PM Page 4 COMPASS 5000.1 Build 81E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt C Pad Well: MPU C-47 Wellbore: MPU C-47 P62 Design: MPU C-47 PB2 Survey MD Inc (usft) (1) 5,819.15 47.46 5,882.52 47.54 5,945.31 46.64 6,007.96 46.97 6,071.22 48.82 6,133.99 48.28 6,196.90 47.55 6,280.01 46.99 6,322.70 46.72 6,385.49 46.74 6,448.29 46.63 6,511.55 46.46 6,554.36 46.33 6,600.00 46.15 6,630.04 45.78 6,693.44 45.98 6,756.63 46.77 6,803.01 47.61 6,867.42 48.37 6,929.34 49.26 6,992.26 50.37 7,050.98 50.72 7,090.41 51.70 7,154.00 52.86 7,217.33 54.32 7,280.24 55.67 7,343.24 56.50 7,406.09 57.37 7,469.28 58.27 7,532.33 58.47 7,595.70 58.62 7,658.47 59.46 7,721.57 61.62 7,784.03 63.42 7,847.92 65.42 7,910.64 65.56 7,973.68 65.13 8,036.30 65.18 8,099.43 65.79 8,162.61 65.86 Azi (`) 57.85 57.89 58.18 55.89 54.83 55.84 55.28 55.19 55.80 55.40 56.00 55.90 55.66 56.06 52.63 50.18 48.91 49.45 44.43 40.65 37.21 36.56 35.92 32.25 28.80 26.15 23.95 21.28 18.23 15.92 13.92 12.19 9.84 8.45 6.69 6.72 6.89 6.90 7.25 7.18 TVD (usft) 4,362.15 4,404.96 4,447.71 4,490.60 4,533.01 4,574.56 4,616.73 4,659.55 4,702.42 4,745.46 4,788.54 4,832.05 4,861.57 4,893.14 4,914.02 4,958.16 5,001.76 5,033.28 5,076.40 5,117.18 5,157.79 5,195.11 5,219.81 5,258.72 5,296.32 5,332.41 5,367.56 5,401.86 5,435.52 5,468.58 5,501.65 5,533.95 5,564.98 5,593.80 5,621.39 5,647.41 5,673.71 5,700.02 5,726.21 5,752.09 TVDSS (usft) 4,320.06 4,362.87 4,405.62 4,448.51 4,490.92 4,532.47 4,574.64 4,617.46 4,660.33 4,703.37 4,746.45 4,789.96 4,819.48 4,851.05 4,871.93 4,916.07 4,959.67 4,991.19 5,034.31 5,075.09 5,115.70 5,153.02 5,177.72 5,216.63 5,254.23 5,290.32 5,325.47 5,359.77 5,393.43 5,426.49 5,459.56 5,491.86 5,522.89 5,551.71 5,579.30 5,605.32 5,631.62 5,657.93 5,684.12 5,710.00 Halliburton Definitive Survey Report +N/ -S (usft) 1,932.52 1,957.37 1,981.72 2,006.57 2,033.25 2,060.01 2,086.41 2,112.85 2,138.76 2,164.59 2,190.34 2,216.05 2,233.48 2,251.98 2,264.56 2,292.95 2,322.63 2,344.87 2,377.54 2,411.87 2,449.26 2,485.52 2,510.31 2,551.96 2,595.86 2,641.58 2,688.94 2,737.56 2,787.88 2,839.20 2,891.43 2,943.86 2,997.78 3,052.49 3,109.61 3,166.29 3,223.17 3,279.59 3,336.59 3,393.77 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +E/ -W Northing (usft) (ft) 2,980.53 6,030,960.33 3,020.10 6,030,985.48 3,059.11 6,031,010.13 3,097.43 6,031,035.28 3,136.03 6,031,062.26 3,174.73 6,031,089.32 3,213.23 6,031,116.02 3,251.32 6,031,142.75 3,289.01 6,031,168.95 3,326.73 6,031,195.07 3,364.48 6,031,221.11 3,402.53 6,031,247.12 3,428.16 6,031,264.75 3,455.44 6,031,283.46 3,472.99 6,031,296.18 3,508.55 6,031,324.84 3,543.35 6,031,354.79 3,569.10 6,031,377.23 3,604.04 6,031,410.16 3,635.53 6,031,444.73 3,665.72 6,031,482.36 3,692.93 6,031,518.83 3,711.10 6,031,543.76 3,739.27 6,031,585.62 3,765.13 6,031,629.72 3,788.89 6,031,675.61 3,811.02 6,031,723.14 3,831.27 6,031,771.91 3,849.34 6,031,822.37 3,865.10 6,031,873.80 3,879.01 6, 031, 926.14 3,891.17 6,031,978.66 3,901.65 6,032,032.65 3,910.45 6,032,087.42 3,918.03 6,032,144.59 3,924.70 6,032,201.32 3,931.49 6,032,258.25 3.938.31 6, 032, 314.71 3,945.38 6,032,371.76 3,952.62 6,032,428.99 Well RIG: MPU C-47 MPU C-47 Actual @ 42.09usft MPU C-47 Actual @ 42.09usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Easting DLS (ft) ("1106') 561,121.89 0.86 561,161.26 0.13 561,200A8 1.47 561,238.19 2.72 561,276.59 3.18 561,315.07 1.48 561,353.36 1.34 561,391.23 0.89 561,428.72 0.83 561,466.23 0.46 561,503.77 0.72 561,541.62 0.29 561,567.11 0.51 561,594.24 0.75 561,611.69 8.30 561,647.03 2.79 561,681.59 1.92 561,707.16 2.00 561,741.84 5.91 561,773.06 4.81 561,802.95 4.53 561,829.87 1.04 561,847.84 2.79 561,875.68 4.92 561,901.20 4.95 561,924.61 4.06 561,946.36 3.18 561,966.22 3.82 Vertical Section (ft) Survey Tool Name 3,382.33 2_MWD+IFR2+MS+Sag (2) 3,426.60 2_MWD+IFR2+MS+Sag(2) 3,470.14 2_MWD+IFR2+MS+Sag (2) 3,513.63 2_MWD+IFR2+MS+Sag (2) 3,558.72 2_MWD+IFR2+MS+Sag(2) 3,603.92 2_MWD+IFR2+MS+Sag (2) 3,648.73 2_MWD+IFR2+MS+Sag (2) 3,693.30 2_MWD+IFR2+MS+Sag(2) 3,737.21 2_MWD+IFR2+MS+Sag (2) 3,781.08 2_MWD+IFR2+MS+Sag (2) 3,824.90 2_MWD+IFR2+MS+Sag(2) 3,868.89 2_MWD+IFR2+MS+Sag (2) 3,898.61 2_MWD+IFR2+MS+Sag (2) 3,930.19 2_MWD+IFR2+MS+Sag(3) 3,951.04 2_MWD+IFR2+MS+Sag (3) 3,995.53 2_MWD+IFR2+MS+Sag (3) 4,040.53 2_MWD+IFR2+MS+Sag(3) 4,074.04 2_MWD+IFR2+MS+Sag(3) 4,121.44 2_MWD+IFR2+MS+Sag (3) 4,167.95 2_MWD+IFR2+MS+Sag(3) 4,216.01 2_MWD+IFR2+MS+Sag (3) 4,261.31 2_MWD+IFR2+MS+Sag (3) 4,292.00 2_MWD+IFR2+MS+Sag (3) 4,342.08 2_MWD+IFR2+MS+Sag(3) 4,392.44 2_MWD+IFR2+MS+Sag(3) 4,442.87 2_MWD+IFR2+MS+Sag(3) 4,493.55 2_MWD+IFR2+MS+Sag(3) 4,544.01 2 MWD+IFR2+MS+Sag(3) 561,983.90 4.33 4,594.41 2_MWD+IFR2+MS+Sag(3) 561,999.25 3.14 4,644.12 2_MWD+IFR2+MS+Sag(3) 562,012.76 2.70 4,693.37 2_MWD+IFR2+MS+Sag(3) 562,024.50 2.72 4,741.67 2_MWD+IFR2+MS+Sag(3) 562,034.56 4.71 4,790.06 2_MWD+IFR2+MS+S39 (3) 562,042.93 3.49 4,837.99 2_MWD+IFR2+MS+Sag(3) 562,050.07 4.00 4,887.02 2_MWD+IFR2+MS+Sag(3) 562,056.29 0.23 4,935.13 2_MWD+IFR2+MS+Sag(3) 562,062.63 0.72 4,983.48 2_MWD+IFR2+MS+Sag(3) 562,069.01 0.08 5,031.48 2_MWD+IFR2+MS+Sag(3) 562,075.64 1.09 5,080.10 2_MWD+IFR2+MS+Sag(3) 562,082.43 0.15 5,128.96 2_MWD+IFR2+MS+Sag (3) 6292018 12:02:43PM Page 5 COMPASS 5000.1 Build 81E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt C Pad Well: MPU C-47 Wellbore: MPU C-47 PB2 Design: MPU C-47 PB2 Survey MD Inc (usft) (°) 8,226.37 65.79 8,289.27 65.78 8,352.30 65.73 8,416.07 65.86 8,478.88 65.95 8,542.17 66.06 8,604.74 64.34 8,668.34 62.25 8,731.32 60.31 8,794.38 58.38 8,857.63 56.23 8,920.63 54.49 8,983.76 51.50 9,046.72 48.85 9,110.75 46.65 9,173.09 45.01 9,235.94 43.61 9,300.12 42.10 9,363.95 40.29 9,426.86 38.19 9,490.03 36.49 9,553.02 33.92 9,616.35 31.03 9,678.65 29.59 9,742.04 29.74 9,805.95 29.86 9,869.15 29.87 9,932.27 29.60 9,995.61 28.83 10,057.71 30.15 10,121.82 31.18 10,185.23 31.79 10,248.23 31.78 Azi (1) 7.10 6.86 6.54 6.62 6.67 6.97 6.79 6.25 6.17 6.06 5.89 5.69 5.81 5.99 6.64 7.42 8.79 9.65 9.32 8.91 9.58 10.43 13.46 15.49 14.38 11.06 9.33 9.70 10.25 9.74 8.93 8.99 8.86 TVD (usft) 5,778.20 5,804.00 5,829.88 5,856.03 5,881.67 5,907.40 5,933.65 5,962.23 5,992.49 6,024.64 6,058.81 6,094.61 6,132.61 6,172.93 6,215.98 6,259.41 6,304.39 6,351.43 6,399.46 6,448.18 6,498.41 6,549.87 6,603.29 6,657.08 6,712.16 6,767.62 6,822.43 6,877.24 6,932.52 6,986.58 7,041.72 7,095.80 7.149.35 10,310.81 30.55 9.61 7,202.90 10,374.16 29.85 9.45 7,257.65 10,436.74 29.24 9.51 7,312.09 10,491.00 29.24 9.51 7,359.44 TVDSS (usft) 5,736.11 5,761.91 5,787.79 5,813.94 5,839.58 5,865.31 5,891.56 5,920.14 5,950.40 5,982.55 6,016.72 6,052.52 6,090.52 6,130.84 6,173.89 6,217.32 6,262.30 6,309.34 6,357.37 6,406.09 6,456.32 6,507.78 6,561.20 6,614.99 6,670.07 6,725.53 6,780.34 6,835.15 6,890.43 6,944.49 6,999.63 7,053.71 7,107.26 7,160.81 7,215.56 7,270.00 7,317.35 Halliburton Definitive Survey Report +N/ -S (usft) 3,451.49 3,508.43 3,565.51 3,623.29 3,680.24 3,737.65 3,794.04 3,850.48 3,905.39 3,959.33 4,012.26 4,063.83 4,113.98 4,162.08 4,209.18 4,253.56 4,297.02 4,340.11 4,381.57 4,420.86 4,458.68 4,494.44 4,527.70 4,558.14 4,588.45 4,619.43 4,650.40 4,681.27 4,711.72 4,741.83 4,774.09 4,806.80 4,839.59 4,871.55 4,902.98 4,933.41 4,959.55 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: 3,980.19 6,032,658.70 3,986.83 6,032,715.69 3,993.70 6,032,773.15 4,000.50 6,032,829.58 4,006.95 6,032,886.07 4,012.93 6,032,941.02 4.018.71 6, 032, 994.99 4,024.25 6,033,047.97 4,029.48 6,033,099.57 4,034.53 6,033,149.75 4,039.50 6,033,197.88 4,044.70 6,033,245.02 4,050.17 6,033,289.43 4,056.35 6,033,332.94 4,063.34 6,033,376.08 4,070.27 6,033,417.59 4,076.58 6,033,456.92 4,082.73 6,033,494.78 4,089.03 6,033,530.59 4,096.03 6,033,563.90 4,103.88 6,033,594.40 4,111.96 6,033,624.77 4,118.95 6,033,655.79 4,124.52 6,033,686.80 4,129.70 6,033,717.71 4,135.05 6,033,748.20 4,140.35 6,033,778.34 4,145.65 6,033,810.65 4,150.81 6,033,843.39 4,155.96 6,033,876.21 4,161.15 6,033,908.21 4,166.43 6,033,939.68 4,171.51 6,033, 970.15 4,175.89 6,033,996.32 Well RIG: MPU C-47 MPU C-47 Actual @ 42.09usft MPU C-47 Actual @ 42.09usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Map +E/ -W Northing (usft) (ft) 3,959.85 6,032,486.76 3,966.82 6,032,543.75 3,973.53 6,032,600.87 3,980.19 6,032,658.70 3,986.83 6,032,715.69 3,993.70 6,032,773.15 4,000.50 6,032,829.58 4,006.95 6,032,886.07 4,012.93 6,032,941.02 4.018.71 6, 032, 994.99 4,024.25 6,033,047.97 4,029.48 6,033,099.57 4,034.53 6,033,149.75 4,039.50 6,033,197.88 4,044.70 6,033,245.02 4,050.17 6,033,289.43 4,056.35 6,033,332.94 4,063.34 6,033,376.08 4,070.27 6,033,417.59 4,076.58 6,033,456.92 4,082.73 6,033,494.78 4,089.03 6,033,530.59 4,096.03 6,033,563.90 4,103.88 6,033,594.40 4,111.96 6,033,624.77 4,118.95 6,033,655.79 4,124.52 6,033,686.80 4,129.70 6,033,717.71 4,135.05 6,033,748.20 4,140.35 6,033,778.34 4,145.65 6,033,810.65 4,150.81 6,033,843.39 4,155.96 6,033,876.21 4,161.15 6,033,908.21 4,166.43 6,033,939.68 4,171.51 6,033, 970.15 4,175.89 6,033,996.32 Well RIG: MPU C-47 MPU C-47 Actual @ 42.09usft MPU C-47 Actual @ 42.09usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Vertical Easting DLS Section (ft) (°/too.) (ft) Survey Tool Name 562,089.21 0.16 5,178.23 2_MWD+IFR2+MS+Sag(3) 562,095.73 0.35 5,226.73 2_MWD+IFR2+MS+Sag (3) 562,101.99 0.47 5,275.18 2_MWD+IFR2+MS+Sag(3) 562,108.20 0.23 5,324.14 2_MWD+IFR2+MS+Sag(3) 562,114.39 0.16 5,372.44 2_MWD+IFR2+MS+Sag(3) 562,120.81 0.47 5,421.24 2_MWD+IFR2+MS+Sag(3) 562,127.17 2.76 5,469.21 2_MWD+IFR2+MS+Sag(3) 562,133.18 3.37 5,517.01 2_MWD+IFR2+MS+Sag (3) 562,138.73 3.08 5,563.31 2_MWD+IFR2+MS+Sag(3) 562,144.08 3.06 5,608.73 2 MWD+IFR2+MS+Sag(3) 562,149.21 3.41 5,653.23 2_MWD+IFR2+MS+Sag(3) 562,154.04 2.77 5,696.47 2_MWD+IFR2+MS+Sag(3) 562,158.69 4.74 5,738.51 2_MWD+IFR2+MS+Sag(3) 562,163.28 4.21 5,778.89 2_MWD+IFR2+MS+Sag(3) 562,168.12 3.52 5,818.67 2_MWD+IFR2+MS+Sag(3) 562,173.24 2.78 5,856.49 2_MWD+IFR2+MS+Sag(3) 562,179.09 2.70 5,894.06 2_MWD+IFR2+MS+Sag(3) 562,185.74 2.52 5,931.85 2_MWD+IFR2+MS+Sag(3) 562,192.34 2.86 5,968.34 2_MWD+IFR2+MS+Sag(3) 562,198.34 3.36 6,002.76 2_MWD+IFR2+MS+Sag(3) 562,204.20 2.77 6,035.93 2_MWD+IFR2+MS+Sag(3) 562,210.22 4.15 6,067.61 2_MWD+IFR2+MS+Sag (3) 562,216.95 5.24 6,097.80 2_MWD+IFR2+MS+Sag(3) 562,224.56 2.84 6,126.34 2_MWD+IFR2+MS+Sag(3) 562,232.41 0.90 6,154.93 2_MWD+IFR2+MS+Sag (3) 562,239.15 2.59 6,183.33 2_MWD+IFR2+MS+Sag (3) 562,244.48 1.36 6,210.84 2_MWD+IFR2+MS+Sag(3) 562,249.41 0.52 6,238.02 2_MWD+IFR2+MS+Sag(3) 562,254.53 1.29 6,264.99 2_MWD+IFR2+MS+Sag (3) 562,259.60 2.16 6,291.66 2_MWD+IFR2+MS+Sag(3) 562,264.64 1.73 6,320.00 2_MWD+IFR2+MS+Sag(3) 562,269.54 0.96 6,348.59 2 MWD+IFR2+MS+Sag (3) 562,274.44 0.11 6,377.24 2_MWD+IFR2+MS+Sag(3) 562,279.38 2.06 6,405.28 2_MWD+IFR2+MS+Sag(3) 562,284.41 1.11 6,432.95 2_MWD+IFR2+MS+Sag(3) 562,289.25 0.98 6,459.74 2_MWD+IFR2+MS+Sag (3) 562,293.43 0.00 6,48275 PROJECTED to TD ch0"e0.wrlghtghalllbU -,„,t.,.,.� Approved B Mitch Laird �-`=�=^- Date: Checked By: non.com E'-� **�^-a pP Y 06/29/2018 6292018 12:02:43PM Page 6 COMPASS 5000.1 Build 81E Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-47 P133 50029235777200 Sperry Drilling Definitive Survey Report 29 June, 2018 HALLIBURTON Sporry Drilling Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU C-47 Project: Milne Point TVD Reference: MPU C-47 Actual @ 42.09usft Site: M Pt C Pad MD Reference: MPU C-47 Actual @ 42.09usft Well: MPU C-47 North Reference: True Wellbore: MPU C-47 P133 Survey Calculation Method: Minimum Curvature Design: MPU C-47 PB3 Database: Sperry EDM - NORTH US + CANADA Iroject Milne Point, ACT, MILNE POINT Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Aap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU C-47 Well Position +N/ -S +E/ -W Position Uncertainty 0.00 usft Northing: 6,029,004.74 usfl Latitude: 70' 29'23.490 N 0.00 usft Easting: 558,156.85 usfl Longitude: 149° 31'28.533 W 0.00 usft Wellhead Elevation: 15.15 usfl Ground Level: 15.15 usft Wellbore MPU C-47 PB3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2018 6/13/2018 17.20 81.01 57,466 Design MPU C-47 P133 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,110.75 Vertical Section: Depth From (TVD) +NIS +E/ -W Direction (usft) (usft) (usft) (1) 26.94 0.00 0.00 39.18 Survey Program Date 6/28/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 100.00 728.00 SRG-SS (MPU C-47 PB1) 2_Gyro-SR-GSS H047Ga: Surface readout gyro single shot 06/26/2017 788.64 6,554.36 MWD+IFR2+MS+sag (1) (MPU C-47 PB 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +as 06/29/2017 6,600.00 9,110.75 MWD+IFR2+MS+sag (MPU C-47 PB2) 2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 05/11/2018 9,135.00 10,020.27 MPU C-47 MWD+IFR2+MS+Sag (MPU (2_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis +sa O6/13/2018 Survey Map Map Vertical MD (usft) Inc (') Azi (1 TVD (usft) TVDSS (usft) +N/S (usft) +EI -W (usft) Northing (ft) Easting (ft) DLS (=/1681) Section (ft) Survey Tool Name 26.94 0.00 0.00 26.94 -15.15 0.00 0.00 6,029,004.74 558,156.85 0.00 0.00 UNDEFINED 100.00 0.46 30.95 100.00 57.91 0.25 0.15 6,029,004.99 558,157.00 0.63 0.29 2_Gyro-SR-GSS(1) 200.00 0.54 2.72 200.00 157.91 1.07 0.38 6,029,005.81 558,157.22 0.26 1.07 2 Gyro-SR-GSS(1) 232.00 0.64 21.04 231.99 189.90 1.38 0.45 6,029,006.13 558,157.29 0.66 1.36 2_GyroSR-GSS(1) 294.00 1.30 47.98 293.98 251.89 2.18 1.10 6,029,006.93 558,157.93 1.27 2.38 2_Gyro-SR-GSS(1) 356.00 3.05 64.42 355.94 313.85 3.36 3.11 6,029,008.12 558,159.93 2.97 4.57 2_Gyro-SR-GSS(1) 417.00 5.70 60.05 416.76 374.67 5.57 7.20 6,029,010.37 558,164.00 4.38 8.87 2_Gyro-SR-GSS(1) 479.00 8.12 64.89 478.30 436.21 8.97 13.83 6,029,013.82 558,170.61 4.01 15.69 2_Gyro-SR-GSS(1) 539.00 8.84 70.54 537.65 495.56 12.30 22.02 6,029,017.21 558,178.77 1.83 23.45 2_Gyro-SR-GSS(1) 600.00 9.56 71.46 597.86 555.77 15.48 31.24 6,029,020.46 558,187.96 1.20 31.73 2_Gyro-SR-GSS(1) 663.00 11.19 69.51 659.83 617.74 19.28 41.92 6,029,024.35 558,198.62 2.65 41.43 2_GymSR-GSS(1) 6292018 4:08:26PM Page 2 COMPASS 5000.1 Build 81E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt C Pad Well: MPU C-47 Wellbore: MPU C-47 PB3 Design: MPU C-47 PB3 Survey Halliburton Definitive Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU C-47 MPU C-47 Actual @ 42.09usft MPU C-47 Actual @ 42.09usft True Minimum Curvature Sperry EDM - NORTH US + CANADA 62912018 4:08:26PM Page 3 COMPASS 5000.1 Build 81E Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (") (") (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 728.00 13.80 71.83 723.28 681.19 23.91 55.20 6,029,029.07 558,211.86 4.09 53.40 2_Gym-SR-GSS(1) 788.64 15.51 75.21 781.95 739.86 28.23 69.91 6,029,033.51 558,226.53 3.15 66.05 2_MWD+IFR2+MS+Sag(2) 851.56 18.13 75.03 842.17 800.08 32.91 87.51 6,029,038.33 558,244.09 4.16 80.79 2 MWD+IFR2+MS+Sag (2) 915.56 19.89 73.91 902.68 860.59 38.50 107.59 6,029,044.08 558,264.12 2.81 97.81 2_MWD+IFR2+MS+Sag (2) 977.20 22.42 73.82 960.16 918.07 44.68 128.96 6,029,050.42 558,285.44 4.10 116.10 2_MWD+IFR2+MS+Sag (2) 1,039.64 25.67 72.30 1,017.18 975.09 52.11 153.28 6,029,058.04 558,309.70 5.30 137.23 2_MWD+IFR2+MS+Sag (2) 1,100.98 29.14 71.09 1,071.62 1,029.53 61.00 180.08 6,029,067.14 558,336.43 5.73 161.05 2 MWD+IFR2+MS+Sag (2)M 1,166.20 32.42 69.76 1,127.65 1,085.56 72.19 211.51 6,029,078.58 558,367.77 5.14 189.58 2_WD+IFR2+MS+Sag(2) 1,228.55 36.21 68.95 1,179.14 1,137.05 84.59 244.39 6,029,091.23 558,400.55 6.12 219.97 2_MWD+IFR2+MS+Sag(2) 1,291.42 39.21 68.81 1,228.87 1,186.78 98.45 280.26 6,029,105.37 558,436.30 4.77 253.37 2_MWD+IFR2+MS+Sag(2) 1,353.94 41.78 65.97 1,276.42 1,234.33 114.08 317.72 6,029,121.29 558,473.63 5.06 289.15 2_MWD+IFR2+MS+Sag(2) 1,417.37 44.17 60.70 1,322.84 1,280.75 133.51 356.31 6,029,141.02 558,512.07 6.80 328.59 2_MWD+IFR2+MS+Sag(2) 1,479.61 45.42 58.20 1,367.01 1,324.92 155.80 394.06 6,029,163.60 558,549.64 3.47 369.72 2_MWD+IFR2+MS+Sag (2) 1,542.77 43.96 56.04 1,411.91 1,369.82 179.90 431.36 6,029,187.99 558,586.75 3.34 411.97 2_MWD+IFR2+MS+Sag(2) 1,605.69 43.83 55.15 1,457.25 1,415.16 204.55 467.36 6,029,212.92 558,622.55 1.00 453.82 2_MWD+IFR2+MS+Sag (2) 1,668.53 43.23 56.38 1,502.81 1,460.72 228.90 503.13 6,029,237.55 558,658.13 1.65 495.30 2_MWD+IFR2+MS+Sag (2) 1,731.19 44.57 55.35 1,547.96 1,505.87 253.29 539.09 6,029,262.21 558,693.89 2.42 536.91 2_MWD+IFR2+MS+Sag (2) 1,794.80 45.49 54.89 1,592.92 1,550.83 279.02 576.01 6,029,288.23 558,730.60 1.53 580.19 2_MWD+IFR2+MS+Sag(2) 1,857.38 45.19 55.18 1,636.90 1,594.81 304.53 612.49 6,029,314.02 558,766.88 0.58 623.01 2_MWD+IFR2+MS+Sag (2) 1,921.47 43.70 56.44 1,682.66 1,640.57 329.75 649.60 6,029,339.53 558,803.79 2.70 666.01 2_MWD+IFR2+MS+Sag (2) 1,983.37 44.20 56.97 1,727.22 1,685.13 353.34 685.51 6,029,363.39 558,839.51 1.00 706.97 2_MWD+IFR2+MS+Sag(2) 2,046.08 45.60 57.95 1,771.64 1,729.55 377.14 722.83 6,029,387.49 558,876.64 2.49 749.00 2_MWD+IFR2+MS+Sag (2) 2,108.86 47.38 57.49 1,814.86 1,772.77 401.46 761.32 6,029,412.10 558,914.93 2.88 792.17 2_MWD+IFR2+MS+Sag (2) 2,171.71 48.48 55.84 1,856.98 1,814.89 427.10 800.29 6,029,438.04 558,953.70 2.62 836.66 2_MWD+IFR2+MS+Sag(2) 2,234.03 47.47 55.63 1,898.70 1,856.61 453.16 838.55 6,029,464.40 558,991.75 1.64 881.04 2_MWD+IFR2+MS+Sag(2) 2,297.18 46.36 55.23 1,941.83 1,899.74 479.33 876.53 6,029,490.87 559,029.52 1.82 925.32 2_MWD+IFR2+MS+Sag (2) 2,360.12 45.26 55.91 1,985.70 1,943.61 504.85 913.75 6,029,516.67 559,066.54 1.91 968.61 2_MWD+IFR2+MS+Sag(2) 2,423.15 46.30 53.32 2,029.66 1,987.57 531.01 950.57 6,029,543.12 559,103.14 3.38 1,012.15 2_MWD+IFR2+MS+Sag(2) 2,485.68 46.39 53.02 2,072.83 2,030.74 558.13 986.78 6,029,570.51 559,139.14 0.38 1,056.05 2_MWD+IFR2+MS+Sag (2) 2,548.89 47.54 54.01 2,115.97 2,073.88 585.60 1,023.93 6,029,598.27 559,176.07 2.15 1,100.81 2_MWD+IFR2+MS+Sag (2)s 2,611.66 46.90 54.24 2,158.60 2,116.51 612.60 1,061.26 6,029,625.56 559,213.18 1.05 1,145.32 2_MWD+IFR2+MS+Sag(2) 2,675.09 45.80 53.71 2,202.38 2,160.29 639.59 1,098.38 6,029,652.84 559,250.09 1.84 1,189.69 2_MWD+IFR2+MS+Sag(2) 2,737.61 46.62 55.09 2,245.65 2,203.56 665.85 1,135.07 6,029,679.39 559,286.57 2.06 1,233.24 2 MWD+IFR2+MS+Sag (2) 2,800.59 47.96 54.95 2,288.37 2,246.28 692.38 1,172.99 6,029,706.21 559,324.28 2.13 1,277.76 2_MWD+IFR2+MS+Sag(2) 2,863.43 46.97 54.75 2,330.85 2,288.76 719.04 1,210.85 6,029,733.16 559,361.92 1.59 1,322.34 2_MWD+IFR2+MS+Sag(2) 2,926.45 45.88 54.79 2,374.29 2,332.20 745.38 1,248.14 6,029,759.79 559,399.01 1.73 1,366.32 2_MWD+IFR2+MS+Sag (2) 2,989.39 46.66 55.33 2,417.79 2,375.70 771.43 1,285.43 6,029,786.12 559,436.08 1.39 1,410.06 2_MWD+IFR2+MS+Sag(2)M 3,052.06 46.20 56.72 2,460.99 2,418.90 796.80 1,323.08 6,029,811.79 559,473.53 1.77 1,453.52 2_WD+IFR2+MS+Sag(2) 3,114.78 47.31 54.98 2,503.96 2,461.87 822.45 1,360.88 6,029,837.73 559,511.13 2.69 1,497.28 2 MWD+IFR2+MS+Sag(2) 3,177.77 47.20 55.22 2,546.72 2,504.63 848.92 1,398.82 6,029,864.49 559,548.85 0.33 1,541.77 2_MWD+IFR2+MS+Sag (2) 62912018 4:08:26PM Page 3 COMPASS 5000.1 Build 81E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt C Pad Well: MPU C-47 Wellbore: MPU C-47 PB3 Design: MPU C-47 PB3 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU C47 MPU C-47 Actual @ 42.09usft MPU C-47 Actual @ 42.09usft True Minimum Curvature Sperry EDM - NORTH US + CANADA Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +EI -W Northing Easting DLS Section (usft) (1 (') (usft) (usft) (usft) (usft) (ft) (ft) (111001) (ft) Survey Tool Name 3,240.78 47.15 54.71 2,589.55 2,547.46 875.45 1,436.66 6,029,891.31 559,586.48 0.60 1,586.24 2_MWD+IFR2+MS+Sag (2) 3,303.61 46.45 55.33 2,632.56 2,590.47 901.71 1,474.19 6,029,917.86 559,623.80 1.33 1,630.30 2_MWD+IFR2+MS+Sag(2) 3,366.40 45.77 55.61 2,676.09 2,634.00 927.36 1,511.46 6,029,943.80 559,660.87 1.13 1,673.73 2_MWD+IFR2+MS+Sag (2) 3,429.58 45.36 55.60 2,720.32 2,678.23 952.84 1,548.69 6,029,969.57 559,697.89 0.65 1,717.01 2_MWD+IFR2+MS+Sag(2) 3,492.45 46.73 56.37 2,763.96 2,721.87 978.15 1,586.20 6,029,995.18 559,735.20 2.35 1,760.33 2_MWD+IFR2+MS+Sag (2) 3,555.26 47.14 56.67 2,806.85 2,764.76 1,003.47 1,624.48 6,030,020.78 559,773.28 0.74 1,804.13 2_MWD+IFR2+MS+Sag (2) 3,618.16 47.05 56.79 2,849.67 2,807.58 1,028.74 1,663.00 6,030,046.36 559,811.59 0.20 1,848.06 2_MWD+IFR2+MS+Sag (2) 3,681.00 46.97 56.88 2,892.52 2,850.43 1,053.89 1,701.48 6,030,071.80 559,849.87 0.16 1,891.86 2_MWD+IFR2+MS+Sag (2) 3,744.01 47.06 57.11 2,935.48 2,893.39 1,079.00 1,740.13 6,030,097.21 559,888.32 0.30 1,935.74 2_MWD+IFR2+MS+Sag(2) 3,806.54 46.72 57.46 2,978.21 2,936.12 1,103.67 1,778.54 6,030,122.18 559,926.53 0.68 1,979.13 2_MWD+IFR2+MS+Sag(2) 3,869.51 45.54 57.19 3,021.85 2,979.76 1,128.17 1,816.75 6,030,146.98 559,964.55 1.90 2,022.27 2_MWD+IFR2+MS+Sag(2) 3,932.72 44.72 58.58 3,066.44 3,024.35 1,151.99 1,854.69 6,030,171.09 560,002.30 2.03 2,064.70 2_MWD+IFR2+MS+Sag(2) 3,994.68 45.69 58.37 3,110.10 3,068.01 1,174.98 1,892.17 6,030,194.37 560,039.59 1.58 2,106.20 2_MWD+IFR2+MS+Sag(2) 4,058.78 46.47 59.06 3,154.56 3,112.47 1,198.96 1,931.63 6,030,218.65 560,078.86 1.44 2,149.71 2_MWD+IFR2+MS+Sag (2) 4,121.67 46.94 57.21 3,197.69 3,155.60 1,223.12 1,970.50 6,030,243.12 560,117.53 2.27 2,193.00 2_MWD+IFR2+MS+Sag(2) 4,184.26 47.37 55.49 3,240.25 3,198.16 1,248.55 2,008.70 6,030,268.84 560,155.53 2.13 2,236.84 2 MWD+IFR2+MS+Sag(2) 4,247.01 46.62 55.68 3,283.05 3,240.96 1,274.49 2,046.55 6,030,295.07 560,193.18 1.22 2,280.86 2_MWD+IFR2+MS+Sag(2) 4,310.04 47.22 54.00 3,326.11 3,284.02 1,301.00 2,084.18 6,030,321.87 560,230.60 2.17 2,325.19 2_MWD+IFR2+MS+Sag(2) 4,373.03 46.89 51.99 3,369.02 3,326.93 1,328.75 2,121.00 6,030,349.91 560,267.19 2.39 2,369.96 2_MWD+IFR2+MS+Sag (2) 4,436.03 46.36 52.01 3,412.29 3,370.20 1,356.94 2,157.09 6,030,378.38 560,303.05 0.84 2,414.61 2_MWD+IFR2+MS+Sag(2) 4,498.85 46.18 52.64 3,455.71 3,413.62 1,384.68 2,193.02 6,030,406.40 560,338.76 0.78 2,458.82 2_MWD+IFR2+MS+Sag(2) 4,561.58 46.58 52.33 3,498.99 3,456.90 1,412.34 2,229.04 6,030,434.33 560,374.56 0.73 2,503.01 2_MWD+IFR2+MS+Sag (2) 4,624.57 46.37 53.12 3,542.37 3,500.28 1,440.00 2,265.38 6,030,462.27 560,410.68 0.97 2,547.41 2_MWD+IFR2+MS+Sag(2) 4,687.61 46.23 54.15 3,585.92 3,543.83 1,467.02 2,302.08 6,030,489.58 560,447.17 1.20 2,591.54 2_MWD+IFR2+MS+Sag (2) 4,750.64 45.74 54.07 3,629.72 3,587.63 1,493.60 2,338.80 6,030,516.44 560,483.68 0.78 2,635.34 2_MWD+IFR2+MS+Sag(2) 4,813.36 45.50 54.83 3,673.59 3,631.50 1,519.66 2,375.27 6,030,542.78 560,519.94 0.95 2,678.59 2_MWD+IFR2+MS+Sag(2) 4,876.56 45.17 55.08 3,718.01 3,675.92 1,545.47 2,412.07 6,030,568.88 560,556.53 0.59 2,721.84 2_MWD+IFR2+MS+Sag (2) 4,939.16 46.57 55.44 3,761.60 3,719.51 1,571.07 2,449.00 6,030,594.76 560,593.25 2.27 2,765.01 2_MWD+IFR2+MS+Sag(2) 5,002.29 48.48 54.13 3,804.23 3,762.14 1,597.93 2,487.03 6,030,621.91 560,631.07 3.39 2,809.86 2_MWD+IFR2+MS+Sag (2) 5,065.05 48.33 54.87 3,845.89 3,803.80 1,625.18 2,525.24 6,030,649.46 560,669.06 0.91 2,855.13 2_MWD+IFR2+MS+Sag(2) 5,127.96 48.63 54.80 3,887.60 3,845.51 1,652.31 2,563.75 6,030,676.89 560,707.35 0.48 2,900.48 2_MWD+IFR2+MS+Sag(2) 5,190.74 48.74 54.78 3,929.04 3,886.95 1,679.50 2,602.27 6,030,704.37 560,745.66 0.18 2,945.90 2_MWD+IFR2+MS+Sag (2) 5,253.18 47.98 55.52 3,970.53 3,928.44 1,706.16 2,640.56 6,030,731.34 560,783.74 1.51 2,990.76 2_MWD+IFR2+MS+Sag(2) 5,316.43 47.31 55.65 4,013.14 3,971.05 1,732.58 2,679.12 6,030,758.05 560,822.08 1.07 3,035.60 2_MWD+IFR2+MS+Sag(2) 5,379.24 46.56 55.35 4,056.03 4,013.94 1,758.57 2,716.94 6,030,784.33 560,859.69 1.24 3,079.63 2_MWD+IFR2+MS+Sag(2) 5,442.18 45.92 55.56 4,099.56 4,057.47 1,764.35 2,754.38 6,030,810.40 560,896.93 1.05 3,123.27 2_MWD+IFR2+MS+Sag(2) 5,504.86 45.05 56.28 4,143.51 4,101.42 1,809.39 2,791.40 6,030,835.73 560,933.75 1.61 3,166.07 2_MWD+IFR2+MS+Sag (2) 5,567.71 44.23 57.11 4,188.23 4,146.14 1,833.64 2,828.31 6,030,860.27 560,970.46 1.60 3,208.18 2_MWD+IFR2+MS+Sag (2) 5,630.99 45.28 56.40 4,233.16 4,191.07 1,858.07 2,865.57 6,030,884.99 561,007.52 1.84 3,250.66 2_MWD+IFR2+MS+Sag (2) 5,693.66 46.21 56.94 4,276.90 4,234.81 1,882.73 2,903.07 6,030,909.94 561,044.83 1.61 3,293.47 2 MWD+IFR2+MS+Sag (2) 6292018 4:08:26PM Page 4 COMPASS 5000.1 Build 81E Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-47 MPU C-47 P133 MPU C-47 PB3 Local Co-ordinate Reference: Well MPU C-47 TVD Reference: MPU C-47 Actual @ 42.09usft MD Reference: MPU C-47 Actual @ 42.09usft North Reference: True Survey Calculation Method: Minimum Curvature Database: Sperry EDM - NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 5,756.43 47.58 57.14 4,319.79 4,277.70 1,907.66 2,941.52 6,030,935.17 561,083.08 2.19 3,337.09 2_MWD+IFR2+MS+Sag(2) 5,819.15 47.46 57.85 4,362.15 4,320.06 1,932.52 2,980.53 6,030,960.33 561,121.89 0.86 3,381.00 2_MWD+IFR2+MS+Sag (2) 5,882.52 47.54 57.89 4,404.96 4,362.87 1,957.37 3,020.10 6,030,985.48 561,161.26 0.13 3,425.26 2_MWD+IFR2+MS+Sag(2) 5,945.31 46.64 58.18 4,447.71 4,405.62 1,981.72 3,059.11 6,031,010.13 561,200.08 1.47 3,468.78 2_MWD+IFR2+MS+S89(2) 6,007.96 46.97 55.89 4,490.60 4,448.51 2,006.57 3,097.43 6,031,035.28 561,238.19 2.72 3,512.25 2_MWD+IFR2+MS+Sag (2)M 6,071.22 48.82 54.83 4,533.01 4,490.92 2,033.25 3,136.03 6,031,062.26 561,276.59 3.18 3,557.32 2_WD+IFR2+MS+Sag(2) 6,133.99 48.28 55.84 4,574.56 4,532.47 2,060.01 3,174.73 6,031,089.32 561,315.07 1.48 3,602.51 2_MWD+IFR2+MS+Sag(2) 6,196.90 47.55 55.28 4,616.73 4,574.64 2,086.41 3,213.23 6,031,116.02 561,353.36 1.34 3,647.30 2_MWD+IFR2+MS+Sag (2) 6,260.01 46.99 55.19 4,659.55 4,617.46 2,112.85 3,251.32 6,031,142.75 561,391.23 0.89 3,691.85 2_MWD+IFR2+MS+Sag (2) 6,322.70 46.72 55.80 4,702.42 4,660.33 2,138.76 3,289.01 6,031,168.95 561,428.72 0.83 3,735.75 2_MWD+IFR2+MS+Sag(2) 6,385.49 46.74 55.40 4,745.46 4,703.37 2,164.59 3,326.73 6,031,195.07 561,466.23 0.46 3,779.61 2_MWD+IFR2+MS+Sag (2) 6,448.29 46.63 56.00 4,788.54 4,746.45 2,190.34 3,364.48 6,031,221.11 561,503.77 0.72 3,823.41 2_MWD+IFR2+MS+Sag(2) 6,511.55 46.46 55.90 4,832.05 4,789.96 2,216.05 3,402.53 6,031,247.12 561,541.62 0.29 3,867.38 2_MWD+IFR2+MS+Sag (2) 6,554.36 46.33 55.66 4,861.57 4,819.48 2,233.48 3,428.16 6,031,264.75 561,567.11 0.51 3,897.09 2_MWD+IFR2+MS+Sag (2) 6,600.00 46.15 56.06 4,893.14 4,851.05 2,251.98 3,455.44 6,031,283.46 561,594.24 0.75 3,928.66 2_MWD+IFR2+MS+Sag (3) 6,630.04 45.78 52.63 4,914.02 4,871.93 2,264.56 3,472.99 6,031,296.18 561,611.69 8.30 3,949.50 2_MWD+IFR2+MS+Sag(3) 6,693.44 45.98 50.18 4,958.16 4,916.07 2,292.95 3,508.55 6,031,324.84 561,647.03 2.79 3,993.98 2_MWD+IFR2+MS+Sag(3) 6,756.63 46.77 48.91 5,001.76 4,959.67 2,322.63 3,543.35 6,031,354.79 561,681.59 1.92 4,038.97 2_MWD+IFR2+MS+Sag(3) 6,803.01 47.61 49.45 5,033.28 4,991.19 2,344.87 3,569.10 6,031,377.23 561,707.16 2.00 4,072.48 2_MWD+IFR2+MS+Sag (3) 6,867.42 48.37 44.43 5,076.40 5,034.31 2,377.54 3,604.04 6,031,410.16 561,741.84 5.91 4,119.87 2_MWD+IFR2+MS+Sag(3) 6,929.34 49.26 40.65 5,117.18 5,075.09 2,411.87 3,635.53 6,031,444.73 561,773.06 4.81 4,166.37 2_MWD+IFR2+MS+Sag(3) 6,992.26 50.37 37.21 5,157.79 5,115.70 2,449.26 3,665.72 6,031,482.36 561,802.95 4.53 4,214.43 2_MWD+IFR2+MS+Sag(3) 7,050.98 50.72 36.56 5,195.11 5,153.02 2,485.52 3,692.93 6,031,518.83 561,829.87 1.04 4,259.73 2_MWD+IFR2+MS+Sag(3) 7,090.41 51.70 35.92 5,219.81 5,177.72 2,510.31 3,711.10 6,031,543.76 561,847.84 2.79 4,290.42 2_MWD+IFR2+MS+Sag (3) 7,154.00 52.86 32.25 5,258.72 5,216.63 2,551.96 3,739.27 6,031,585.62 561,875.68 4.92 4,340.51 2_MWD+IFR2+MS+Sag (3) 7,217.33 54.32 28.80 5,296.32 5,254.23 2,595.86 3,765.13 6,031,629.72 561,901.20 4.95 4,390.88 2_MWD+IFR2+MS+Sag(3) 7,280.24 55.67 26.15 5,332.41 5,290.32 2,641.58 3,788.89 6,031,675.61 561,924.61 4.06 4,441.33 2_MWD+IFR2+MS+Sag(3) 7,343.24 56.50 23.95 5,367.56 5,325.47 2,688.94 3,811.02 6,031,723.14 561,946.36 3.18 4,492.02 2 MWD+IFR2+MS+Sag(3) 7,406.09 57.37 21.28 5,401.86 5,359.77 2,737.56 3,831.27 6,031,771.91 561,966.22 3.82 4,542.49 2_MWD+IFR2+MS+Sag(3) 7,469.28 58.27 18.23 5,435.52 5,393.43 2,787.88 3,849.34 6,031,822.37 561,983.90 4.33 4,592.92 2_MWD+IFR2+MS+Sag (3) 7,532.33 58.47 15.92 5,468.58 5,426.49 2,839.20 3,865.10 6,031,873.80 561,999.25 3.14 4,642.65 2_MWD+IFR2+MS+Sag(3) 7,595.70 58.62 13.92 5,501.65 5,459.56 2,891.43 3,879.01 6,031,926.14 562,012.76 2.70 4,691.93 2_MWD+IFR2+MS+Sag(3) 7,658,47 59.46 12.19 5,533.95 5,491.86 2,943.86 3,891.17 6,031,978.66 562,024.50 2.72 4,740.26 2_MWD+IFR2+MS+Sag (3) 7,721.57 61.62 9.84 5,564.98 5,522.89 2,997.78 3,901.65 6,032,032.65 562,034.56 4.71 4,788.68 2_MWD+IFR2+MS+Sag(3) 7,784.03 63.42 8.45 5,593.80 5,551.71 3,052.49 3,910.45 6,032,087.42 562,042.93 3.49 4,836.64 2_MWD+IFR2+MS+Sag(3) 7,847.92 65.42 6.69 5,621.39 5,579.30 3,109.61 3,918.03 6,032,144.59 562,050.07 4.00 4,885.71 2_MWD+IFR2+MS+Sag (3) 7,910.64 65.56 6.72 5,647.41 5,605.32 3,166.29 3,924.70 6,032,201.32 562,056.29 0.23 4,933.86 2_MWD+IFR2+MS+Sag(3)M 7,973.68 65.13 6.89 5,673.71 5,631.62 3,223.17 3,931.49 6,032,258.25 562,062.63 0.72 4,982.24 2_WD+IFR2+MS+Sag (3) 8,036.30 65.18 6.90 5,700.02 5,657.93 3,279.59 3,938.31 6,032,314.71 562,069.01 0.08 5,030.28 2_MWD+IFR2+MS+Sag(3) 8,099.43 65.79 7.25 5,726.21 5,684.12 3,336.59 3,945.38 6,032,371.76 562,075.64 1.09 5,078.94 2_MWD+IFR2+MS+Sag (3) 6292018 4:08.26PM Page 5 COMPASS 5000.1 Build SIE Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt C Pad Well: MPU C-47 Wellbore: MPU C-47 PB3 Design: MPU C-47 PB3 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well MPU C-47 MPU C-47 Actual @ 42.09usft MPU C-47 Actual @ 42.09usft True Minimum Curvature Sperry EDM - NORTH US + CANADA 6292018 4:08.26PM Page 6 COMPASS 5000.1 Build 81E Map Map Vertical MD Inc Azi TVD TVDSS +NIS +El -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) ("I100-) (ft) Survey Tool Name 8,162.61 65.86 7.18 5,752.09 5,710.00 3,393.77 3,952.62 6,032,428.99 562,082.43 0.15 5,127.84 2_MWD+IFR2+MS+Sag(3) 8,226.37 65.79 7.10 5,778.20 5,736.11 3,451.49 3,959.85 6,032,486.76 562,089.21 0.16 5,177.15 2_MWD+IFR2+MS+Sag (3) 8,289.27 65.78 6.86 5,804.00 5,761.91 3,508.43 3,966.82 6,032,543.75 562,095.73 0.35 5,225.69 2_MWD+IFR2+MS+Sag(3) 8,352.30 65.73 6.54 5,829.88 5,787.79 3,565.51 3,973.53 6,032,600.87 562,101.99 0.47 5,274.17 2_MWD+IFR2+MS+Sag(3) 8,416.07 65.86 6.62 5,856.03 5,813.94 3,623.29 3,980.19 6,032,658.70 562,108.20 0.23 5,323.17 2_MWD+IFR2+MS+Sag(3) 8,478.88 65.95 6.67 5,881.67 5,839.58 3,680.24 3,986.83 6,032,715.69 562,114.39 0.16 5,371.51 2_MWD+IFR2+MS+Sag(3) 8,542.17 66.06 6.97 5,907.40 5,865.31 3,737.65 3,993.70 6,032,773.15 562,120.81 0.47 5,420.35 2_MWD+IFR2+MS+Sag (3) 8,604.74 64.34 6.79 5,933.65 5,691.56 3,794.04 4,000.50 6,032,829.58 562,127.17 2.76 5,468.36 2_MWD+IFR2+MS+Sag(3) 8,668.34 62.25 6.25 5,962.23 5,920.14 3,850.48 4,006.95 6,032,886.07 562,133.18 3.37 5,516.19 2_MWD+IFR2+MS+Sag(3) 8,731.32 60.31 6.17 5,992.49 5,950.40 3,905.39 4,012.93 6,032,941.02 562,138.73 3.08 5,562.52 2_MWD+IFR2+MS+Sag (3) 8,794.38 58.38 6.06 6,024.64 5,982.55 3,959.33 4,018.71 6,032,994.99 562,144.08 3.0f6 5,607.98 2_MWD+IFR2+MS+Sag(3) 8,857.63 56.23 5.89 6,058.81 6,016.72 4,012.26 4,024.25 6,033,047.97 562,149.21 3.41 5,652.52 2_MWD+IFR2+MS+Sag(3) 8,920.63 54.49 5.69 6,094.61 6,052.52 4,063.83 4,029.48 6,033,099.57 562,154.04 2.77 5,695.80 2_MWD+IFR2+MS+Sag (3) 8,983.76 51.50 5.81 6,132.61 6,090.52 4,113.98 4,034.53 6,033,149.75 562,158.69 4.74 5,737.86 2_MWD+IFR2+MS+Sag(3) 9,046.72 48.85 5.99 6,172.93 6,130.84 4,162.08 4,039.50 6,033,197.88 562,163.28 4.21 5,778.28 2_MWD+IFR2+MS+Sag(3) 9,110.75 46.65 6.64 6,215.98 6,173.89 4,209.18 4,044.70 6,033,245.02 562,168.12 3.52 5,818.09 2_MWD+IFR2+MS+Sag(3) 9,135.00 46.01 6.94 6,232.72 6,190.63 4,226.60 4,046.78 6,033,262.45 562,170.06 2.79 5,832.90 2_MWD+IFR2+MS+Sag(4) 9,191.43 43.63 5.66 6,272.75 6,230.66 4,266.13 4,051.15 6,033,302.01 562,174.13 4.51 5,866.31 2_MWD+IFR2+MS+Sag(4) 9,254.56 41.52 4.49 6,319.23 6,277.14 4,308.67 4,054.94 6,033,344.57 562,177.58 3.57 5,901.67 2_MWD+IFR2+MS+Sag(4) 9,317.78 39.67 1.24 6,367.24 6,325.15 4,349.74 4,057.02 6,033,385.66 562,179.33 4.45 5,934.82 2_MWD+IFR2+MS+Sag(4) 9,381.24 37.60 0.36 6,416.81 6,374.72 4,389.35 4,057.58 6,033,425.27 562,179.58 3.37 5,965.88 2_MWD+IFR2+MS+Sag(4) 9,444.71 36.06 359.30 6,467.61 6,425.52 4,427.40 4,057.47 6,033,463.31 562,179.18 2.63 5,995.31 2_MWD+IFR2+MS+Sag (4) 9,507.40 33.85 356.49 6,518.99 6,476.90 4,463.28 4,056.17 6,033,499.18 562,177.61 4.35 6,022.30 2_MWD+IFR2+MS+Sag (4) 9,570.84 30.73 353.35 6,572.62 6,530.53 4,497.03 4,053.21 6,033,532.90 562,174.38 5.58 6,046.60 2_MWD+IFR2+MS+Sag(4) 9,634.23 30.11 353.24 6,627.28 6,585.19 4,528.91 4,049.47 6,033,564.74 562,170.39 0.99 6,068.94 2_MWD+IFR2+MS+Sag(4) 9,694.46 29.71 353.18 6,679.49 6,637.40 4,558.73 4,045.92 6,033,594.53 562,166.60 0.66 6,089.81 2_MWD+IFR2+MS+Sag(4) 9,766.11 32.08 353.04 6,740.97 6,698.88 4,595.25 4,041.50 6,033,631.01 562,161.90 3.31 6,115.33 2_MWD+IFR2+MS+8ag(4) 9,830.27 33.66 353.08 6,794.86 6,752.77 4,629.82 4,037.29 6,033,665.54 562,157.43 2.46 6,139.47 2_MWD+IFR2+MS+Sag (4) 9,893.37 33.28 353.73 6,847.49 6,805.40 4,664.38 4,033.30 6,033,700.07 562,153.16 0.83 6,163.74 2_MWD+IFR2+MS+Sag (4) 9,956.72 32.68 354.03 6,900.63 6,858.54 4,698.67 4,029.62 6,033,734.33 562,149.21 0.98 6,187.99 2_MWD+IFR2+MS+Sag(4) 10,020.27 32.34 353.66 6,954.23 6,912.14 4,732.63 4,025.96 6,033,768.25 562,145.29 0.62 6,212.00 2_MWD+IFR2+MS+Sag (4) 10,115.00 • 32.34 353.66 7,034.26 6,992.17 4,782.99 4,020.36 6,033,818.57 562,139.30 0.00 6,247.51 PROJECTED to TD Checked By:�� -10-- ""• "i° ^ -- Approved By: Mitch Laird Date: O6/79/9O1 A 6292018 4:08.26PM Page 6 COMPASS 5000.1 Build 81E African, Energy Company CASING & CEMENTING REPORT Lease & Well No. MP 017 Dale Run 3.Jul-17 County State Alaska Sup¢ S. SundedanNO, Yessak CASING RECORD soden, TO &500.00 Shoo Depth: 01590.00 PBTO: 6.161.35 No, Ad. Delivered 187 No. Jls. Run 160 No. Jts Retuned 7 Lenetn Measurements W. Ftg. Delivered 81835.50 Ftg. Run 6558.24 FIg, Returned 280.05 Trued. Ftg. Cut JL 3127 Fig, Balance RKB 20.80 RM to BHF 25.88 RKBto CHF ISO to THF "van. m nook: 275,000 Type Float Colla[ DHE No. Hos to Run: 21.5 CW W3. On Slips: 150.000 Type of Shoe: DHE Casing Crew: WeeMedmd Rated Csg X Yes _ No Rodin Cut X Yes _ Na 15 Ft. Min. 9.4 PPG Fluid Description: Spud mW Liner hanger Info(Make/ModeO: Ememeovry slips Liner top Packers _Yes X No Linerhatgerteslpressure: Floats Held X Yes No Central er Placemen: 2 cenrmlrzers on snoe8.ln 10' ham end merslop cadan.3 cemmlleers 1 ea mid tube over slap talars on 2 FC pis. t cermalYer mk lube over Yap cellar on BA It, 9 Cenhalicers an every other Is over rasing callers to S062'.3 centralims one ea If below ESC over casing whom, 4 wntralliers one ea 3l above ESC over casing collars. 21past commens. ran. CEMENTING REPORT Shue@ 11590 FC® 6515.63 Topof Liner Tuned Spacer III Density gang) 10.5 Volume pumped (BBI.) mfr, EXTENDACEM Sacks: 700 Tcld: (PPB) 117 Volume Pumped SBLS) 307.9 Mixing l Pumping Rate(bpm): SWIFT CEM Sacks: 2% Yield 1.10 (on) 15.8 Volume pumped (BBts) 507 Mixing I Pumping Rate friend: 3.5 ASIA (Spacer) DAmAKy(Gp9) Rategipary Volume: meM: e SPUD MUD Density (ppg) 9.1 Rale Sp r)'. 4 Volume (actual I calculated): 489.74/489.: b: 910 Pumpusedfordlair RIG Bump Plug? X Yes -No Bump press 151 Rotated? _Yes X No Reciprocated? _Yes X No %Resume dudrg lob 75 returns to surface? X Y.N. Spacerrnums? X Yes No Vol to Surf: 67 In Place At 532 Date: 7W017EYimaled TOC 2.07 Used To DMermine TOC: OPEN ESC TOOL. CIRC SPACER & CEMENT TO SURFACE Age Collargg 200737 Type ESC Closure OK W( lush (Spacer) .. TUNED 111 Density (M) 10.5 Volume pumped (BBI.) PERM L Sacks: 335 Yield: city (on) 107 Volume pumped (RBIs) 258] Mixing I Pumping Rate gm): Slurry i. PREMIUM Sacks: 175 Yield: lily (ppg) 15.8 Volume pumpetl (BBU) 36.2 Mixing / Pumping Rale (bpm): (tag) Rale g pm): Volume: SPUD MUD Density(ppJ) 9.4 Race(bpm): Casing (Or Liner) De el 152.1/152. sly 630 Pump saw for dia, Selling DeMe Jts. Camponent SIZa WL Gratle THD Make Len m BoSam Top 1 SHOE 958 Data 7/3201) Estimated TOC: DWUC DHE6590.00 VISUAL 6588.38 1 CAsin 95/8 1 40.0 1 L-80 I DWC/C I VAMTOP 1 41. Am I fi588.38 6546.99 1 FC 95/8 DWC/C DHE 1.36 6,546.99 6545.63 1 Cabin 95/8 40.0 L-80 DWC/C VAMTOP 82.68 6,545.63 6,462.95 1 BAFFLEADAPTO 958 DWC/CHES 1.60 6462.95 6461.35 11 1 Gsi 95/8 40.0 L -8o DWC/C VAkd 1450.85 6461.35 201050 1 ESC 95/8 DWC/C HES 3.13 2,010.50 2,007.37 160 Using 95/8 1 40.0 L-80 DW C I VAMTOP 1 1,981.41 2,007.37 25.96 "van. m nook: 275,000 Type Float Colla[ DHE No. Hos to Run: 21.5 CW W3. On Slips: 150.000 Type of Shoe: DHE Casing Crew: WeeMedmd Rated Csg X Yes _ No Rodin Cut X Yes _ Na 15 Ft. Min. 9.4 PPG Fluid Description: Spud mW Liner hanger Info(Make/ModeO: Ememeovry slips Liner top Packers _Yes X No Linerhatgerteslpressure: Floats Held X Yes No Central er Placemen: 2 cenrmlrzers on snoe8.ln 10' ham end merslop cadan.3 cemmlleers 1 ea mid tube over slap talars on 2 FC pis. t cermalYer mk lube over Yap cellar on BA It, 9 Cenhalicers an every other Is over rasing callers to S062'.3 centralims one ea If below ESC over casing whom, 4 wntralliers one ea 3l above ESC over casing collars. 21past commens. ran. CEMENTING REPORT Shue@ 11590 FC® 6515.63 Topof Liner Tuned Spacer III Density gang) 10.5 Volume pumped (BBI.) mfr, EXTENDACEM Sacks: 700 Tcld: (PPB) 117 Volume Pumped SBLS) 307.9 Mixing l Pumping Rate(bpm): SWIFT CEM Sacks: 2% Yield 1.10 (on) 15.8 Volume pumped (BBts) 507 Mixing I Pumping Rate friend: 3.5 ASIA (Spacer) DAmAKy(Gp9) Rategipary Volume: meM: e SPUD MUD Density (ppg) 9.1 Rale Sp r)'. 4 Volume (actual I calculated): 489.74/489.: b: 910 Pumpusedfordlair RIG Bump Plug? X Yes -No Bump press 151 Rotated? _Yes X No Reciprocated? _Yes X No %Resume dudrg lob 75 returns to surface? X Y.N. Spacerrnums? X Yes No Vol to Surf: 67 In Place At 532 Date: 7W017EYimaled TOC 2.07 Used To DMermine TOC: OPEN ESC TOOL. CIRC SPACER & CEMENT TO SURFACE Age Collargg 200737 Type ESC Closure OK W( lush (Spacer) .. TUNED 111 Density (M) 10.5 Volume pumped (BBI.) PERM L Sacks: 335 Yield: city (on) 107 Volume pumped (RBIs) 258] Mixing I Pumping Rate gm): Slurry i. PREMIUM Sacks: 175 Yield: lily (ppg) 15.8 Volume pumpetl (BBU) 36.2 Mixing / Pumping Rale (bpm): (tag) Rale g pm): Volume: SPUD MUD Density(ppJ) 9.4 Race(bpm): 4 Volume (actual /catenated: 152.1/152. sly 630 Pump saw for dia, RIG BUmPPIW7 X Yes Bump press 20 Retired? _Yes X No Redpmdesed? _Yes _No X No %RelumsduMglob 100 (mums to surface? X Yes_ No Spacer Moms? X Yes _No Vol Is Surf: 185 I In Place Al: 15:38 Data 7/3201) Estimated TOC: p Used To Determine TOC VISUAL Calculated Cmt Vol C 0% excess: 351.22 Total Volume chat Pumped: WA Chat Mumed to surface: 252 CAAIWAAed cement len In wellbore: 110 OH volume Calculated: 3% OH volume actual: 385.7 Actual % Wasbout 7.2 WELLHEAD Make Seaboard Type Multibawl Serial No. 0100-60-215-1.010 sled 11 W.P. 5000 Test henj to 3780 PSIG 5 MIN Ask OK Remarks: 2 170 77 Debra Oudean Hilcorp Alaska, LLL GeoTech 3800 Centerpoint Drive, Suite 1400 29 5 7 8 Anchorage, AK 99503 Tele: 907 777-8339 Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 08/08/2018 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W 7th Ave Ste 100 RECEIVED Anchorage, AK 99501 AUG 0 8 20% AOGCC Digital Data Please include current contact information if different from above. Please acknowledgePceipt by signing an"Liming py of this transmittal or FAX to 907 777.8337 �I = 11"Ir , EJ EMF 8/8/201810:50 AM File folder LAS 7/5/2018 2:01 PM File folder PDF 7/5/2018 2:01 PM File folder TIFF 8/8/201810:51 AM File folder i Log Viewers 8/8/201810:53 AM File folder CGM 8/8/201810:54 AM File folder Definitive Survey 7/5/20182:01 PM Filefolder Please include current contact information if different from above. Please acknowledgePceipt by signing an"Liming py of this transmittal or FAX to 907 777.8337 �I = 11"Ir , EJ 217077 Debra Oudean Hilcorp Alaska, LLC 29 5 79 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8339 I ilrnrp:Up.ka,LLC. Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 08/08/2018 To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W 7th Ave Ste 100 RECEIVED Anchorage, AK 99501 AUG 0 8 2018 R317% 17% 17710 rs= MT AOGCC MPU C-47 PB2 + PB3 Digital Data Please include current contact information if different from above. Please acknowledge Received By: by signing and rXurning one copy of this transmittal or FAX to 907 777.8337 i, EMF 8/8/201810:50 AM File folder LAS 7/5/2018 2:01 PM File folder I PDF 7/5/2018 2:01 PM File folder 1 TIFF 8/81201810:51 AM File folder I . _Log Viewers 8/8/201810:53 AM File folder !. CGM W/2018 AM File folder I, Definitive Survey 7/5/20182:01 PM File folder Please include current contact information if different from above. Please acknowledge Received By: by signing and rXurning one copy of this transmittal or FAX to 907 777.8337 THE STATE OIALA KA GOVERNOR BILL WALKER Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-47 Permit to Drill Number: 217-077 Sundry Number: 318-287 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax 907.276.7542 www.cogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31,05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair -t� DATED this day of July, 2018. RBDMS-2-2� JUL 0 6 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECOVED JUL 0 1 2018 � -5 1614 bAOGCC 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: CT Cmt PlugO 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0 - Stratigraphic ❑ Service ❑ 217-077 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23577-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No ❑+ MPU C-47 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL047434 / ADL047433 I Milne Point / Kuparuk River Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,115' 7,035' 6,505' 4,828' 0 6,520' and 6,846' 6,873' Casing Length Size MD TVD Burst Collapse Conductor 151' 16" 151' 151' N/A NIA Surface 6,564' 9-5/8'. 6,590' 4,886 5,750psi 3,090psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open hole Open hole NA NA NA Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A and NIA N/A and N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Stratigmphic ❑ Development ❑Z Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/4/2018 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman TW Authorized Title: Operations Manager Contact Email: tWellman p hilcor .COm Contact Phone: 777-8449 Authorized Signature: Date: 7/3/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. I _2 Plug Integrity 91, BOP El/Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: ZI/ �, - n .09 , a¢ YLO Ga 1 iM -00 c 71�b.4 d4V--e urG 7"&.v Post Initial Injection MIT Req'd? Yes No El Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: !;sDMsc.1t'--�, AUL o 6 to,e ORIGINAL nf� Form 10-403 Revised 4/2017 Approved application is valid for 12 months fromthedilate of ap ro al. Submit Form and Attachments iQ Duplicate .0ffA176r —7� y8 U Hacmu ANA., LU CT Cement Plug Well: MPU C-47 PTD: 217-077 API: 50-029-23577-00 Well Name: MPU C-47 API Number: 50-029-23577-00 Current Status: Suspended Field: Milne Point Estimated Start Date: July 4, 2018 Rig: CT Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: N/A Regulatory Contact: Tom Fouts Permit to Drill Number: 217-077 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907-444-2881 (M) AFE Number: 1811546D WeIIEZ Input Required? Yes Current BHP (Kuparuk): 4,252psi @ 6,990' TVD (Estimated from KWF used while drilling prior to isolation w/ cement retainer and cement) Equivalent Mud Weight: 11.7ppg MPSP: 0 psi (Hydraulically isolated w/ PT'd cement retainer to 1,500psi on 07/01/18) Brief Well Summary: MPU C-47 sidetrack was attempted which resulted in needing to place a cement plug and to suspend the well to develop a different plan for sidetracking. During the final stages of operations with the Innovation Rig, a cement retainer was placed at 6,520' (top of retainer at 6,518' md) or 70' MD from the 9-5/8" Shoe (6,590' MD). Following this 36 bbls of cement was squeezed beneath the retainer (CH volume + 1.2x OH Volume) and 8 bbls were attempted to be spotted above the retainer for a planned 100' of cement above the retainer. During the 8.5" Cleanout run, top of cement was tagged at 6,505' MD, 37' short of the 50' requested. The casing passed an MIT to 1500psi of the 9-5/8" casing on 07/01/18. Objective: Place a minimum of 37' of cement on top of the 9-5/8" CIBP to complete the 50' of cement required for reservoir abandonment. Volumes: 9-5/8", 40#, ID=8.835", Capacity=0.07583bpf 37ft x 0.07583bpf = 2.81bbls (minimum cement volume to place) Procedure Coil Tubing 1. MIRU CT unit and spot support equipment. Fill uprights with filtered seawater. 2. Pressure test BOPE to 250psi low/ 2,500 high, 5min low and 10min high each test. a. Each subsequent test of the lubricator will be to 2,500 psi Hi, 250 Low to confirm no leaks. b. No AOGCC notification required. -- c. Record BOPE test results on 10-424 form. 3. MU cementing ball drop nozzle and RIH. 4. RIH and tag TOC. a. Innovation tagged solid cement at 6,505' and on 07/01/18. The cement retainer was set at 6,518' md. b. Required TOC for suspension is 50' and above the CIBP. An additional 37' or 2.8bbls of cement is required to be placed on top of the current TOC. Cement Plug Well: MPU C-47 PTD: 217-077 Hilcon, Alaska, U) API: 50-029-23577-00 5. PU and bring pumps online to establish injection rate down coil tubing. a. Returns should be 1:1 as the well passed an MIT of the 9-5/8" casing to 1,500psi on 07/01/18. 6. Begin to mix cement. Once up to 15.8ppg, pump ±5bbls of cement down the coil tubing. a. Use freshwater spacers as needed around the cement. 7. Once 2bbls of cement have exited the nozzle lay in remaining cement at 1:1. 8. Pull up to safety and circulate coil clean and wash down to Circulate coil clean and wash down to 6,440' and and POOH. a. Estimated TOC = 6,440' md. b. Freeze protect well to 500' while POOH. 9. WOC to gain compressive strength and RIH to tag TOC. a. Notify AOGCC inspector 24 hrs in advance to witness tag 10. POOH & RD CT. Contingency 1— Coil Tubing Cement Cap Repeat coil tubing steps #3-9, while adjusting cement volumes to place TOC at a minimum of 6,468' md. K HH,—, ANA., LLC KB Elev Above Sea Level: 41.7'/GL Eley: 15.2' 16" 9-5/8" 590 MD 186' T V I) SCHEMATIC Milne Point Unit Well: MPC -47 PTD: 217-077 API: 50-029-23577-00-00 'r -->• " JEWELRY DETAIL 4-1/2+> ` No. ItemTop MD 1 Cm[ Retainer 6,520' 2 ECP 6,846' TOC tagged (d 6,505' MD 2 OPEN HOLE / PROPOSED CEMENT DETAIL Conductor Driven CASING DETAIL 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16" Conductor 164/A-106B/Weld N/A Surface 151' N/A Surface 40/L-80/DWC/C 8.75" Surface 6,590' 0.0758 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 1 3.958" Surface 2,339' 0.0152 'r -->• " JEWELRY DETAIL 4-1/2+> ` No. ItemTop MD 1 Cm[ Retainer 6,520' 2 ECP 6,846' TOC tagged (d 6,505' MD 2 OPEN HOLE / PROPOSED CEMENT DETAIL Conductor Driven 12-1/4" 1st stage 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg On top of ECP 50 bbls 15.8 ppg Class G 2nd Attempt on Top of ECP 61 bbls 15.7 ppg Class G Thru/Top of Coot Retainer 44 bbls 15.8 ppg Class G, "1 bbl left on top of Retainer 8-1/2" hole 10,115' MD / 7,035' TVD GENERAL WELL INFO WELL INCLINATION DETAIL PBTD=6,505'MD/f4,828'TVD API: 50.029-23577-00-00 KOP @ TD = 10,115' MD / 7,035'TVD Drilled and Cased by Innovation —7/20/18 Max Hole Angle = Max Deviation: Updated by GD 7/3/18 0 PROPOSED SCHEMATIC ua', ,, a1,,,1.,,. t.te KBIA, \bm'e Sea Level: 41.7' / GL F.lev: 15.2' 16.. p Milne Point Unit Well: MPC -47 PTD: 217-077 API: 50-029-23577-00-00 t I JEWELRY DETAIL 4.1/2•+ No. Item Top MO 1 Cmt Retainer 6,520' 2 1 ECP 6,846' TOC tagged @ ±6,440' MD 9-5/8" 6,590 MD 4.886' TVD 2 OPEN HOLE / PROPOSED CEMENT DETAIL Conductor Driven CASING DETAIL 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16" Conductor 164/A-106B/Weld N/A Surface 151' N/A Surface I 40/L-80/DWC/C 8.75" Surface 6,590' 0.0758 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TC-II 3.958" Surface 2,339' 0.0152 t I JEWELRY DETAIL 4.1/2•+ No. Item Top MO 1 Cmt Retainer 6,520' 2 1 ECP 6,846' TOC tagged @ ±6,440' MD 9-5/8" 6,590 MD 4.886' TVD 2 OPEN HOLE / PROPOSED CEMENT DETAIL Conductor Driven 12-1/4" 1st stage 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg Ontopof ECP 50 bbIs 15.8 ppg Class 2ntl Attempt on Top of ECP 61 bbls 15.7 ppg Class G Thru/Top of Cmt Retainer 44 bbls 15.8 ppg Class G, ±6bbl left on top of Retainer 8-1/2" hole 10,115' MD / 7,035' TVD GENERAL WELL INFO WELL INCLINATION DETAIL PBTD=6,505' MD/±4,828' TVD API: 50-029-23577-00-W KOP @ TD = 10,115' MD / 7,035'TVD Drilled and Cased by Innovation -7/20/18 Max Hole Angle= Max Deviation: Updated by GD 7/3/18 COIL BOPE MILNE POINT UNIT MPU C-47 flilcorp Alaska, LL(: _ 7/3/2018 Coil Tubing BOP Lubricator to injmtion head 2.00" Single Stripper 1/16 aaaa�m� �_� Pipe —I_ Pipe Crossover spool 4 1/1610M X 41/16 5M Manual Gate Manual Gate Valva 'W.h. WKM-M 21/85M 21/85M MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector Section: 10 Township: Drilling Rig: CTU Rig Elevation: Operator Rep: Casing/Tubing Data (depths MD): Nick Frazier Conductor: 16" O.D. Shoe@ Surface: 9 5/8" O.D. Shoe@ Intermediate: O.D. Shoe@ Production: O.D. Shoe@ Liner: O.D. Shoe@ Tubing: O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 6, 2018 SUBJECT: Wellbore Plug Verification MPU C-47 Hilcorp Alaska LLC PTD 2170770; Sundry 318-196 13N Range: 10E Meridian: Umiat NA Total Depth: 10,115 ft MD Lease No.: ADL47434 Type Plug Founded on Casing Removal: 151 Feet Csg Cut@ NA Feet 6590 Feet Csg Cut@ NA Feet Feet Csg Cut@ NA Feet Feet Csg Cut@ NA Feet Feet Csg Cut@ NA Feet Feet Tbg Cut@ NA Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Casing Stub' Retainer - 6520 ft MD 6448 ft MD 15.8 ppg C.T. Tag Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I traveled to Milne Point and met with Hilcorp Rep Nick Frazier. Coil Tubing Unit was rigged up on the well to spot cement above retainer previously set by Innovation ri. Cement on top of retainer after clean out run was insufficient to satisfy AGOCC ✓ requirements of 50' above retainer. CTU pumped +/- 5BBL's of 15.8 ppg cement, circulated coil clean and let set to desired compressive strength. CTU ran in hole and tagged TOC. Attachments: none rev. 05-02-18 2018-0706_Plug_Verification_MPU_C47_mh MEMORANDUM TO: Jim Regg -7Ilq/J,9 P.I. Supervisor ' \ �l I FROM: Adam Earl Petroleum Inspector Section: 10 Drilling Rig: HAK Innovation Operator Rep: Township: Rig Elevation: Shane Barber State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 1, 2018 SUBJECT: Wellbore Plug Verification MPU C-47 - Hilcorp Alaska LLC PTD 2170770; Sundry 318-196 " 13N Range: 10E Meridian: Umiat Conductor: NA Total Depth: 10,115 ft MD " Lease No.: ADL47434 Casing/Tubing Data (depths MD): Founded on Depth Btm De th To Casing Removal: Conductor: 16" O.D. Shoe@ 151 Feet Csg Cut@ NA Feet Surface: 9 5/8" O.D. Shoe@ 6590 Feet Csg Cut@ NA Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ NA Feet Production: O.D. Shoe@ Feet Csg Cut@ NA Feet Liner: O.D. Shoe@ Feet Csg Cut@ NA Feet Tubing: O.D. Tail@ Feet Tbg Cut@ NA Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm De th To MW Above Ventied Casing Stub Retainer 6851 ft MD 6505 ft MD'j 12.5 ppg " Drillpipe tag 1. 1+i�l Ir min sn min dF min Result Tubing 1683 1662 - 1655 IA P OA Remarks: Well bore plug (cement retainer) was set at 6520 ft MD in the 9 5/8" surface casing; top of retainer @ 6518 ft MD. Pumped 43 bbls of 16.2 ppg cement. After set time was reached I witnessed two solid tags @ 6505 ft MD, with 10k weight down on the plug each tag. The rig pulled up 30' and circulated surface to surface before a pressure test was conducted (pass). Attachments: none rev. 05-02-18 2018-0701_Plug_Verification_MPU_C-47_ae Schwartz, Guy L (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Saturday, June 30, 2018 12:23 PM To: Rixse, Melvin G (DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Re: [EXTERNAL] Fwd: Hilcorp MPU C-47 (PTD#217-077) Update Thank you, Mel. If you have any other questions please let me know. I will keep you updated as we progress. -Joe On Jun 30, 2018, at 11:21 AM, Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov<mai Ito: melvin.rixse@alaska.gov>> wrote: Subject: RE: Hilcorp MPU C-47 (PTD#217-077) Update Joe, As discussed over the phone: Hilcorp has tried unsuccessfully to lay in two open hole cement plugs from the top of the fish into the 9-5/8" casing shoe. Both attempts showed minimal cement above the fish. As an alternate plan forward, AOGCC approves setting a 9-5/8" cement retainer within 100' of the 9-5/8" casing shoe and down squeezing an open hole volume + 20% of cement from the casing shoe to the top of the ECP, plus a cement volume of casing below the cement retainer. Additionally, Hilcorp will leave a minimum of 50' feet of cement above the retainer. A 24 hour notice to AOGCC will be made to witness a tag of cement inside the 9-5/8" casing and pressure test of the 9-5/8" casing. The pressure test to 1500 psi or .25 psi/ tvd-ft, whichever is greater. Mel Rixse 907-223-3605 From: Joe Engel <jengel@hilcorp.com<mailto:jengel@hilcorp.com>> Date: June 30, 2018 at 10:04:39 AM AKDT To: "Rixse, Melvin G (DOA)" <melvin.rixse@alaska.gov<mai Ito: melvin.rixse@alaska.gov>> Cc: "Schwartz, Guy L (DOA)" <guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov>>, Monty Myers <mmyers@hilcorp.com<mailto:mmyers@hilcorp.com>>, "Shane Barber - (C)" <sbarber@ hilcorp.com<mailto:sbarber@hilcorp.com>> Subject: Hilcorp MPU C-47 (PTD#217-077) Update Hello Mel - As per our conversation, I would like to give you an update on MPU C-47. (For reference, 9-5/8" shoe 6590' MD, OH size 9-7/8") After setting our ECP on the top of the fish at 6873' MD, we pumped our first cement plug, 50 bbl 15.8#, when we went to tag TOC, we tagged at 6853' MD, well below our planned TOC but we did have a solid 10k tag. We then pumped a second cement plug, 61 bbl 15.8#, when going in to tag our second plug we tagged at 6851. At this point we believe that the ECP is not fully sealed around the hole diameter and cement is falling past the ECP. Hilcorp would like to propose the following change to the plug procedure of C-47. - RIH and set 9-5/8" cement retainer —150' inside 9-/8" casing shoe, ensuring not placed in collar --Perform injection test to ensure cement can be pumped away - Sting in to retainer and pump 42 bbl of 15.8# cement (CH volume & OH volume + 20% excess) - Unsting from cement retainer and spot `8 bbl of cement on top of retainer (^'100') - Run killstring as per previous plan Please let us know if you have any questions regarding this plan forward. Thank you for your time. Joe 805-235-6265 Please excuse any spelling errors, this email was sent from my cellphone. MN C-1-7 MI 21-70770 Regg, James B (DOA) From: Shane Barber - (C) <sbarber@hilcorp.com> Sent: Thursday, June 21, 2018 12:44 PM To: Regg, James B (DOA) Cc: Joe Engel Subject: RE: C-47 well control / Innovation I apologize for that. Date: 6/20/2018 @ 17:24 hrs � ✓ Well/Location/PTD: MP C-47, Milne Point, PTD# - 217-077, Sundry# - 318-196 Rig Name: Hilcorp Innovation Operator Contact Info: DSM — Shane Barber, cell# 907-841-5208, office# 907-670-3094. Drilling Engineer—Joe Engel, cell# 805-235-6265, office# 907-777-8395 Ops Summary: Drilling ahead @ 10,115' MD / 7035' TVD. Took 18.3 bbl kick. Shut in well using annular. 425 SICP, 385 SIDPP. Monitored psi via choke. Components used: HCR choke, HCR kill, Annular, CM valves #1,#4,#7,#11 and super choke. Reason for BOPE Use: Stop well from flowing. — Action taken: Circulate out influx. Wt up incrementally to current MW 11.5 while managing losses. Action to be taken: Manage losses and wt up to kill weight fluid. Jim, Hope this helps. Thank you. Shane G. Barber I Drilling Foreman Hilcorp Alaska, LLC Milne Point Office: 907-670-3094 Mobile: 907-841-5208 sbarber@ahi Icorp.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, June 21, 2018 11:49 AM To: Shane Barber - (C) Subject: RE: C-47 well control / Innovation PTD #? Actions to be taken? Other equipment used? Jim Regg Supervisor, Inspections AOGCC 333 W.71h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg(@alaska.gov. From: Shane Barber - (C) [mailto:sbarber@hilcorp.com] Sent: Wednesday, June 20, 2018 7:52 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov> Cc: Joe Engel <jengel@hilcorp.com>; Monty Myers <mmyers@hilcorp.com>; Paul Mazzolini <pmazzolini@hilcorp.com>; Mike Leslie <gleslie@hilcorp.com> Subject: C-47 well control / Innovation Jim, Hilcorp Innovation rig was drilling ahead @ 10,115' MD / 7,035' TVD Milne Point C-47. Driller observed a pit gain. Spaced out drill pipe, shut down pumps and observed well flowing. Shut in well in @ 17:24 hrs with annular. 425 psi SICP, 385 psi SIDPP. 18.3 bbls total pit gain. Current MW 11.05 ppg. Shane G. Barber I Drilling Foreman Hilcorp Alaska, LLC Milne Point Office: 907-670-3094 Mobile: 907-541-5203 sbarber@hileorp.com Rixse, Melvin G (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Thursday, June 14, 2018 9:19 AM To: Rixse, Melvin G (DOA) Cc: Monty Myers; Schwartz, Guy L (DOA) Subject: FW: MPU C-47 (PTD# 217-077) Update Hello Mel — I sent this email update to Guy, but he is out of the office so I wanted to copy you on it as well. I had been keeping Guy up to speed on operations for C-47. Thank you for your time. 0C.Ta Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 From: Joe Engel Sent: Wednesday, June 13, 2018 4:04 PM To: Guy Schwartz (guy.schwartz@alaska.gov) <guy.schwartz@alaska.gov> Cc: Monty Myers <mmyers@hilcorp.com> Subject: MPU C-47 (PTD# 217-077) Update ) Hello Guy — tj I wanted to give you an update on MPU C-47. We were able to isolate the high pressure (�st. 11.7 ppg EMW) water flow from the Kup A, cure our loss zone, as well as pump cement across the Kup C (target) to ensure isolation from the Kup A water. Unfortunately, while drilling up cement to run 7" casing, the motor assembly became stuck. After unsuccessful jarring attempts, we were able to back off the drill string at —9,865' MD, but we were unable to fish the BHA free.g � \ P J Our plan forward is to pump a KOP on top of our fish at - 9,860' to sidetrack the well. Planned kick off depth vi 11 be —9,360' and our new BHL will be — 180' away from the last permitted directional plan. I will keep you posted how progress goes. Please let me know if you have any questions. Thank you for your time. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 II STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION p 6l P.I. Sup" .�11�L2 BOPE Test Report for: MILNE PT UNIT C-47 Comm Contractor/Rig No.: Hilcom Innovation - PTD#: 2170770 - DATE: 6/1/2018 Inspector Austin Mcleod - Insp source Operator: HILCORP ALASKA LLC Operator Rep: Jay Compton Rig Rep: Shane Barber Inspector Type Operation: DRILL Sum ry No: Test Pressures: Inspection No: bopSAM180602141514 Rams: Annular: Valves: MASP: Type Test: BIWKLY 250/3500 " 250/3500 ' 250/3500 2974 Related Insp No: FLOOR SAFTY VALVES: Quantity TEST DATA Upper Kelly 1 _ P, MISC. INSPECTIONS: MUD SYSTEM: P ACCUMULATOR SYSTEM: 1 P P/F _ 1 _ Visual Alarm FSV Misc Time/Pressure P/F Location Gen.: _P . Trip Tank P P System Pressure 3025 P - Housekeeping: _P Pit Level Indicators P P Pressure After Closure 1600 P PTD On Location P Flow Indicator P P 200 PSI Attained 28 P - Standing Order Posted P__ Meth Gas Detector P P Full Pressure Attained 96 P_ Well Sign P " H2S Gas Detector P P Blind Switch Covers: All stations P Drl. Rig P MS Misc NA NA Nitgn. Bottles (avg): _6 (a) 2300 P Hazard Sec. P ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity Size P/F Stripper Quantity P/F Upper Kelly 1 _ P, Lower Kelly _ _ 1 P Ball Type 1 P Inside BOP _ 1 _ P FSV Misc 0 NA BOP STACK: Quantity Size P/F Stripper 0 NA Annular Preventer 1 13-5/8" 5K P #1 Rams 1 . _ 2-7/8"x5.5' ' P #2 Rams I Blinds _ _ P #3 Rams _ 1 _ 5" Solid P #4 Rams 0 NA #5 Rams _ 0 NA _ #6 Rams 0 — NA Choke Ln. Valves 1 . 3-1/8" 5K P HCR Valves 2 3-1/8" 5K P Kill Line Valves _ 1 3-1/8" 5K P _ Check Valve 0 NA BOP Misc 1 - 3-1/8" SK P CHOKE MANIFOLD: Quantity P/F No. Valves 15 - P. Manual Chokes 1— P Hydraulic Chokes 1_ P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Number of Failures: 0 ✓ Test Results Test Time 5.5 Remarks: Test performed with 5" test joint and against lest plug. PvPs, flow and gas alarms tested. Test #7 (on than) was manual choke(on mud cross), the HCR was left shut. Test #9 was a re -test of the manual choke with HCR open downsream. Outermost kill line valve under BOP mist. Schwartz, Guy L (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Friday, June 01, 2018 2:15 PM To: Schwartz, Guy L (DOA) Cc: Monty Myers Subject: Hilcorp MPU C-47 (PTD#217-077) Update Attachments: MPU C-47 8.5 x 9.875 Plan Forward Program Outline 6.1.18.pdf Guy— I wanted to give you an update on MPU C-47. We are out of the hole with our drilling BHA and currently testing BOPEs, the well currently has a static loss rate of 15-20 bph. Our plan forward is to perform a cleanout run and isolate the Kup A water flow from the wellbore with a Baker ECP P&A kit. If we are able to isolate the Kup A, we will attempt to run 7" casing and complete the well as permitted. If we are unable to isolate the Kup A, we will plug back the well and most likely sidetrack. I have attached our program outline for your reference. I will keep you updated as operations progress. Please let me know if you have any questions. Thank you for your time. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 MPC -47: 8.5" x 9.875" Sidetrack Plug & Redrill Outline 6.1.2018 C-47 Actual Formations Tops Well Surface MD TVDSS ND C-47 SB—BASE 6448 -4746 4788 C-47 KOP 6600 -4851 4893 C-47 HRZ 9808 -6727 6769 C-47 KLB 9835 -6750 6792 C-47 KLGM 9930 -6833 6875 C-47 KUP_D 10087 -6970 1 7012 C-47 KUP_C 10249 -7108 7150 C-47 KU P_136 10269 -7125 7167 C-47 KUP A3 1 10437 -7271 7313 Plug Procedure Due to Overpressure Kup A water influx and loss zone, the original sidetrack wellbore will be plugged back to the casing shoe for redrill. Kup A water influx pressure determined to be — 11.7 ppg EMW Circulate 11.7 Surface to Surface Water Influx may cut MW back, document MW out (regular and pressure balance) Inability to get consistent MW in/out due to water influx may prevent over pressuring water influx Strip OOH t/ 9-5/8" Casing shoe Bullhead "'13.3# fluid down 9-5/8" x 5" DP annulus to overbalance water influx Watch for potential wellbore breathing from loss zone after pumps are off Pump until 0 casing pressure Open annular and observe well POOH & LD BHA Test BOPE Equipment used in shut in Notify AOGCC MU 8.5" Cleanout BHA 8.5" Bit open nozzles Well Commander To ensure we can get 7" Inflatable to depth If cleanout run cannot get to bottom, consult town team RIH and cleanout wellbore to TO Circulate BU with 11.7+ MW To attempt to overbalance water influx in Kup A with sufficient rate and hydrostatic Spot heavy, LCM, visc pill at bottom if possible. POOH & LD 8.5" Cleanout BHA Potential to spot LCM across Colville Loss Zone MU Baker 7" ECP P&A Kit and RIH t/ ECP at Kup B, '"10,390' MD ECP P&A assembly would arrive at rig in one piece, with a 3.5 IF Box up P&A kit contains float shoe, float collar, landing collar, 7" pup joint, 7" ECP Drill pipe will not autofill. Cannot rotate to the right, that is backup release for the hydraulic disconnect 8.5" Hole: 10,492' --10,381' MD, 9-7/8" Hole: —10,381' MD -9-5/8" Shoe Target ECP set depth: 10,390' MD, 120' below Kup C & 48' Above Kup A If ECP assembly is unable to get to TD, discuss with town to determine next setting depth PU Cement Head and plug dropper head with dart installed Circulate as needed Release dart from cement head Pump ECP Inflation Cement plus additional cement volume Cement volume on top of ECP: 520' x 49 bbl * 1.3 = 64 bbl 15.8# Class G Chase cement with wiper ball and mud Once dart hits landing collar, pressure up to open ECP ('1000psi) Pump volume to inflate ECP Pressure should stabilize when ECP is inflated, (575psi and ECP will close) Increase pressure and hydraulically release from ECP (2500 psi) Pick up and spot cement on top of ECP —63 bbl (after ECP inflation) 15.8# Class G POOH t/ casing shoe and Wait on Cement Consider closing annular and applying 500 psi of pressure to keep cement in place, if loss rate into Colville isn't too high POOH LD running tools WOC to reach sufficient compressive strength MU 8.5" Cleanout BHA Motor and Directional tools to ensure we do not sidetrack well RI & Tag Cement Drill cement t/ — 50' below Kup C Watch for OH sidetrack MPU C-47 GR/Res Log 0 MPU C-47 ECP P&A Kit t UG 1ES Product Removal Record rypeMtwt: rm-Pa&Svaay mspccwrs: Pkt/aFIrWWr.M' u&[e: sya/rov Threads: 3VYshMtm Wen No.: MK -a Nr: kagvadm Field Insmew: I Dere: Supervisor: apneMrs f3p' 6p3' M an' L1a' T T AL T s93' AT3' sa a' 3A0' 1Ja' 1.s2' Urranmsed Form -Data Rehrenm o* Pump Down Plug s¢e- 2117S• -5.w TOP Fn: M JSTP-M Mlddle Fin: HWVJSTP-051 Midme Fin NWVJSTPJM9 BOtbm Pin: t1WVJ WT 7 a23• DP Haidlina Pup Joint Packer Sla & Threads : YM' W Oox x pin swa' Part No.: IVII OL013 SM: LUlt29 Lra• a3' Crossover She s.3 350^x2,5' Z.- ThreadsMTFBa2-WEUEP Pal No.: 5IJ93]w H SM: 2SN1222 3"n. She : 1050!9561-1 2-m' Haldlina Pup Jam 2.6' Sv ur &Y LJO Kwck tM Rads Rernmaued : Threads : 2-n&^ FUE tna a p:.. a.u• Customer SOock 2Jx' P&A Hvdraufic Relexse Sa❑ Ste: 297^ _ Liam JtYnt Sia: ]Jq" 16/ LJp Threads : 2-7R^ EUE two x wn am' Shea Rele e: 3 pins A 191S psi Rotahwal HNea1e : e P M I M I4 Floor CMlar Pal No.: H `147 ]04 ]Js• control xo.m56wnam z.M• 78 am• ma.® Pavzale Ezremal Casing Packer sve: zw^ zBa LJm Thread:: r InxaIm Shea Vane 1750 em psi MS. COMmI Value : Pal No.: 5IJ93]w H She : 1050!9561-1 Lopkitq SOear N : Yes Kwck tM Rads Rernmaued : Yes Customer SOock �. Liam JtYnt Sia: ]Jq" 16/ LJp 76• ltpeads: Tmr-Pin vf'Jtin 63s� Floor CMlar S'Me : ].00.25& 1-40 78 Threads: TLM ma.® T.m• Float Shoe s.: ]5^xatso Threads: rt Tr: h—,- Regg, James B (DOA) 10 7-76 From: Shane Barber - (C) <sbarber@hilcorp.com> Sent: Sunday, May 27, 2018 12:46 AM To: Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: Monty Myers; Joe Engel; Paul Mazzolini Subject: C-47 Shut in well while drilling / Hilcorp Innovation Guy, We shut in on we MPU C-47 while drilling w/ our 8.5" bit / 9.875" reamer assembly. We drilled to 10,491' MD. Driller noticed flow and a total pit gain of 35 bblwas taken. Driller picked up, spaced out tool jt and shut down pumps. Well was shut in with annular @ 18:58 5/26/18. We've circulated bottoms up at this time and can confirm we have a water influx. We will plan to test used BOP equipment once out of the hole. Thank you and feel free to call me if you have any other questions. Shane G. Barber I Drilling Foreman Hilcorp Alaska, LLC Milne Point Office: 907-670-3094 Mobile: 907-841-5208 sbarber@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 AAr 95 980 "RECEIVE® MAY 2 3 2018 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑✓ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q . Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT FCO w/ N2 E) • 2. Operator Name: 4. Current Well Class: mit to Dri I Number: Hilcorp Alaska LLC Exploratory ❑ Development Stratigraphic ❑ Service ,���p 217 77 3. Address: 3800 Centerpoint Dr, Suite 1400 E&APII� ' Anchorage Alaska 99503 %y.147m,\ -029-23577-00-00 7. If perforating: 8. Wella n umber: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes El No EMPU C-47 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL047434*/ ADL047433 I Milne / paruk River Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi). Plugs (MD): Junk (MD): 10,293' ' 7,162' " 6,385' 6,385' 6,385' N/A Casing Length Size MD TVD Burst Collapse Conductor 151' 16" 151' 151' N/A N/A Surface 6,564' 9-5/8" 6,590' 86' 5,750psi 3,090psi Intermediate 142' 7" 165' 165' 7,240psi 5,410psi Intermediate 2,495' 7" 9,510' 6,882' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 9.3 / L-801 EUE 8rd 3,007' Packers and SSSV Type: ac d SSSV MD (ft) and TVD (ft): " N/A and N/A N/A and N/A 12. Attachments: Proposal Summary LvJ Wellbore schemati 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: 6/5/2018 OIL ❑' WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the rocedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: Chan o hilcor .com Contact Phone: 777-8333 Authorized Signature: Date: Q -1f—"'" l 4 COMMISSION USE ONLY so that a representative may witness Sundry Number: 2 I a - ZI 7 J 1 0 Conditions of approval: N/'d?Yes Plug Integrity ❑ ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT R No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: C-bw 6117.118 Form 10-403 Revised 4/2017 ORIGINAL RBDMSJUN 272018 Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate RI Hilcorp Alaska, LLC May 22, 2018 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Paul Chan Senior Operations Engineer (907)777-8333 RECEIVED Hollis S. French, Chair MAY 1 poi$ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 ^ ®� V Anchorage, Alaska 99501 / 1 RE: Hydraulic Fracturing Application, Milne Point Unit, MP C-47 Dear Commissioner French, Hilcorp Alaska, LLC ("Hilcorp'), as Operator of the Milne Point Unit, herein submits its application to fracture stimulate MP C-47. Please do not hesitate to contact Paul Chan at 907-777-8333 should you have any questions regarding this application. Sincerely, 02 Bo Y k, Operations Manager HILCORP ALASKA, LLC Enclosures: Form 10-403 Sundry Attachments 20 AAC 25.283 (a)(1) Affidavit Affidavit stating that all owners, landowners, surface owners, and operators within a one-half mile radius of the current or proposed wellbore trajectory have been provided a notice of operations that is in compliance with 20 AAC 25.283 (a)(1) VERIFICATION OF NOTICE PER 20 AAC 25.283(a) MILNE POINT UNIT MP C-47 I, PAUL CHAN, Hilcorp Alaska, LLC, ("Hilcorp") do hereby verify the following: I am acquainted with Hilcorp Alaska, LLC's application for sundry approval to the Alaska Oil and Gas Conservation Commission to enhance production of the MP C-47 well via hydraulic fracturing. Pursuant to 20 AAC 25.283(a)(1), I assert that all owners, landowners, surface owners, and operators within a one-half mile radius of the current or proposed wellbore trajectory have been provided notice of Hilcorp Alaska, LLC's proposed operations. DATED at Anchorage, Alaska this 22day of Pa Chan, Sr. bperations Engineer Hilcorp Alaska, LLC STATE OF ALAKSA THIRD JUDICIAL DISTRICT SUBSCRIBED TO AND SWORN before me this day of 2018 NO RY PUB IN AND FOR THE STATE F LSKA My Commission expires: 2to 202 STATE OF ALASKA NOTARY PUBLIC Cortney M. Moore My Commission Expires: April 20, 2021 20 AAC 25.283 (a)(2) A Plat (A) Showing The Well Location; (B) Identifying each Water Well, if any, Located within a One -Half Mile Radius of the Well's Surface Location; and Sec. 4 Sec. 3 Sec. 2 MPU C-47_BHL ADL047434 Frac Zone ADLO 33 Sec. 11 Sec.9 � 1� Sec. 10 ��� i i i � i U013NO10E • i i MPU MPUC-47_SHL�c i i to Sec. 16 .,� Sec �1'S ADL315848 ADL025516 Legend • Top of Frac Zone o Base of Frac Zone • Surface Hole Location (SHL) MPC-47 Well Trajectory —_ MPC-47 (wp13) 1/2 Mile Radius from SHL Pad Footprint Petra Well Database - HAK Milne Point Unit No Wat wp13 No Water Wells Within 1/2 Mile MPC-47 Well N 0 500 1,000 1,500 3800 CenRrroinl or. sme 1400 Mc%a AK, 990] Plat depicting no water wells with 1/2 mile of the MP C-47 SHL oFeet t:, Map Date: 5/2212018 (C) Identifying for all Well Types each Well Penetration Well API PTD Pool Type Status MPC -01 50029206630000 1811430 KR ESP Producing MPC -02 50029208660000 1821940 KR WAG Injecting MPC -03 50029207860000 1820500 KR 1 -OIL Producing MPC -04 50029208010000 1821260 KR 1 -OIL Producing MPC -05A 50029212440100 1842430 KR 1 -OIL Shut In MPC -06 50029212570000 1842410 KR WAG Injecting MPC -07 50029212660000 1850020 KR 1 -OIL Producing MPC -08 50029212770000 1850140 KR WAG Shutln MPC -09 50029212990000 1850360 KR 1-011. Producing MPC -10 50029212780000 1850150 KR WAG Injecting MPC -11 50029213210000 1850590 KR PWI ITS[ MPC -12A 50029213730100 1990910 KR SUSP Suspended MPC -13 50029213280000 1850670 KR ESP Producing MPC -14 50029213440000 1850880 KR ESP Producing MPC -15A 50029213580100 2160700 SR JET Producing MPC -16 50029213640000 1851100 KR SUP Suspended MPC -17 50029214730000 1852630 KR WAG Shut In MPC -18 50029214790000 1852690 P&A P&A MPC -19 50029215040000 1852960 KR WAG Shut In MPC -20 50029219140000 1890150 KR 1 -OIL LTSI MPC -21 50029224860000 1940800 KR 1 -OIL Shut In MPC -22A 50029224890100 1951980 KR ESP Producing MPC -23 50029226430000 1960160 SR JET Producing MPC -24A 50029230200100 2091340 KR 1 -OIL Producing MPC -25A 50029226380100 1960210 KR WAG Shut In MPC -26 50029226340000 1952060 KR JET Producing MPC -28A 50029226480100 2051630 KR WAG Injecting MPC -36 50029228530000 1980010 KR WAG Injecting MPC -39 50029228490000 1972480 KR WAG Injecting MPC -40 50029228710000 2002130 KR JET Producing MPC -41 50029230140000 2010780 SB PWI Injecting MPC -42 50029231960000 2040280 KR WAG Injecting MPC -43 50029232000000 2040390 KR ESP Producing MPC -45 50029232000000 2170920 KR GL Producing MPC -46 50029235760000 2170520 SR 1 -OIL Shut In v 1 1 1 \ C -25A 1 \ 0 \I \ C-12 ,.• \ ) 1 Sec 3 I 1 ♦ Sec. 2 — t ao7 \ 1 I t Secc.4\ 11 + C-04 \ I i � \ \ I \ G12A C42U C-12AP81 I _ FracZonc'— L/ \ c-1sA ••• - —* _ It ■ \ \C,031 I \ _ \ �*,• \` \ \ \ \ \ �•.f� \^ C-11 \ \ 1 \ \ \ Sec.\9 ADL047434 / MILNE \ ,art \\\Sec.101I I POINT `\�\\ ♦y \ /I UNIT \a\� C,26LiP62/ \\ v G26ypCi,-211 LIPB1 / / �C-20 ♦ .� \ \0PB31'� L C-26LI / �1\\�I ♦ \ ♦ C -24W81 `� j / r 6013N010E • ■ a C-01t�� \� 5 MPU C-47 SHLMpU.,�' ■ — `�" — C-15 - ' \ \ Sec Sec. 1 IMPUC-47 BHL i i 1 OC41P8 y _I ■ 18-01 ■ � Sec. 12 i ADL047433 ■ i i Sec. 11 i Milne Point Unit Petra Well Database -HAK 11 MPC -47 Well MPC47wp13 °°OC W�intD,SWMIQO Plat depicting all Well types with 1/2 mile of MP C-47 0 1,000 2,000 MCM1n.z.AK.°°6a° Feet Map Date: 5/22/2018 • \ \ I \ ADL315848�\ \ c-1sA ••• - —* _ c4e _ ` \ C-13'\ C -24W81 ` 01•101• \\ CAD' C-24A'.AD' \� 5 D 2A ! jl — ADL025516 ` `\ \ \ Sec WELLSYMBOL Sec2:3 Sec. 15r ` C-06\ /.\ INJECTOR ` Legend 4 ADBDN �m h 1/2 Mile Radius - Well Bore Well Trajectory Oil and Gas Lease \ p PLUG BACK 1/2 Mile Radius - Frac Zone MPC -47 (wp13) ADL025516 ` \ — — Other Well TrajectoriesME + SHUT-IN — — — • Top of Frac Zone ADL047433 \ Pad Footprint f U Base of Frac Zone --- ._ ' ADL047434 • OIL -ACTIVE 0 Surface Hole Location (SHL) MPC -47 i ADL047437 a �� P&A ,._' �.- ----: ADL315848 Milne Point Unit Petra Well Database -HAK 11 MPC -47 Well MPC47wp13 °°OC W�intD,SWMIQO Plat depicting all Well types with 1/2 mile of MP C-47 0 1,000 2,000 MCM1n.z.AK.°°6a° Feet Map Date: 5/22/2018 20 AAC 25.283 (a)(3) Identification of Freshwater Aquifers There are no underground sources of drinking water within a one-half mile radius of the current wellbore trajectory. Any and all freshwater aquifers lying below the Milne Point Unit are exempted aquifers under Aquifer Exemption Order 2 (AEO-2). See the Conclusion of AEO-2, which states that "The portions of freshwater aquifers lying directly below Milne Point Unit qualify as exempt freshwater aquifers under 20 AAC 25.440." 20 AAC 25.283 (a)(4) Baseline Water Well Sampling There are no water wells located within one-half mile radius of the current wellbore trajectory. A water sampling program is not required. 20 AAC 25.283 (a)(5) Detailed Casing and Cementing Information 9-5/8" 40#/ft L-80 DWC/C surface casing set at 6,590' MD with stage tool at 2,007' MD. First stage cemented with 700 sxs / 308 bbls of 11.7 ppg cement followed by 295 sxs / 60.7 bbls of 15.8 ppg SWIFT Cem cement. Second stage cemented with 335 sxs / 259 bbls of 10.7 ppg PermaFrost L followed by 175 sxs / 36.2 bbls of 15.8 ppg Class G cement. Proposed: 7" 26#/ft L-80 TXP-SR production casing set at -10,688' MD. Cement with 471 ft3 /407 sxs of 15.8 ppg SwiftCEM cement. Detailed Casing Information Size Type Wtt Grade/ Conn Pipe Body Yield (lbs) Collapse Pressure (psi) Internal Yield Pressure (psi) Conductor N/A N/A N/A N/A 9-5/8" Surface 40# / L-80 / DWC/C 916,000 3,090 5,750 7" Production 26# / L-80 / TXP-SR 604,000 5,410 7,240 Detailed Tubing Information 4-1/2" Tubing 12.6 / L-80 / TXP-SR 288,000 7,500 8,430 20 AAC 25.283 (a)(6) Assessment of Each Casing and Cementing Operation Performed to Construct or Repair the Well The 9-5/8" surface casing was set below the base of the Schrader Bluff sands. The first stage cement job was started by pumping 60 bbls of 10.5 ppg tuned spacer with red dye followed by 700 sxs / 308 bbls of 11.7 ppg ExtendaCem lead cement and 295 sxs / 60.7 bbls of 15.8 ppg SwiftCem tail cement at 4 BPM average rate. 62 bbls was lost during the first stage cement job. The stage tool was then opened and the tuned spacer and 67 bbls of green cement were circulated out. The second stage was cemented by first pumping 60 bbls of 10.5 ppg tuned spacer followed by 335 sxs / 259 bbls of 10.7 ppg PermaFrost L lead cement and 175 sxs / 36.2 bbls of 15.8 ppg Class G cement tail at 4 BPM average rate. Recovered 185 bbls of cement at surface. Bumped plug and closed stage tool at 1200 psi. Floats held. 9 bbls were lost during the second stage cement job. The job was pumped with cement to surface indicating a ✓ competent cement job. The 7" production casing has not yet been run and cemented. The 7" CBL will be submitted post -rig. 20 AAC 25.283 (a)(7) Plans to Pressure -Test the Casings and Tubing Installed in the Well The 9-5/8" casing was pressure tested to 3000 psi for 30 minutes on July 23, 2017. The 7" casing will be pressure tested to 3000 psi for 30 minutes. Post rig the 4-%:" tubing will be pressure tested to 4500 psi for 30 minutes. The 4-1/2" x 7" annulus will be pressure tested to 3000 psi for 30 minutes. 20 AAC 25.283 (a)(8) Pressure Ratings and Schematics for the Wellbore, Wellhead, BOPE, and Treating Head Size Weight #/ft Grade API Collapse Pressure (psi) API Internal Yield Pressure (psi) 9-5/8" 40 L-80 3,090 5,750 7" 26 L-80 5,410 7,240 Treating Head 15M Wellhead 5M BOPE N/A H llileary Alaska, LLC TD =10,906 (MD) / TD= 7,725(7VD) PBTD=±10,800' (MD)/PBTD=±7,632'(TVD) Proposed Frac String SchemaLIC TREE & WELLHEAD Milne Point Unit Well: MPU C-47 PTD: 217-077 API: 50-029-23577-00-00 Tree 4-1/16" SM Wt/Grade/Conn Cameron MBS 11" 5M Wellhead 4-1/2" Tubing Hanger OPEN HOLE / CEMENT DETAIL 12-1/4" Stg 1—Lead 700 sx (308 bbls)/ Tail 2955x(61 bbls)-67 bbl returns Wt/Grade/Conn Stg 2 — Lead 335 sx (259 bbls) / Tail 175 sx (36 bbls) —185 bbl returns 8-1/2" 83 bbl 15.8ppg Class "G" in a 8-1/2" x 9-7/8" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 16" Conductor 164/A-1068/Weld N/A Surface 151' 9-5/8" Surface 40/L-80/DWC/C 8.835" Surface 6,590' 7" Production 26/L-80/TXP SR 6.276" Surface 10,906' TUBING DETAIL 4-1/2" 1 Tubing 12.6 / L-80 / TXP SR 3.958" Surface ±10,100' WELL INCLINATION DETAIL KOP@100'MD Max Hole Angle = 66.15° @ 7,891' MD JEWELRY DETAIL No Depth ID Item 1 ±9,930' 3.880 4.5" X 7" Packer 2 ±9,980' 3.456 4-1/2" XN Nipple 3 ±10,100' 3.958 Mule Shoe — Btm @ 10,100' 4 ±10,300 - External Casing Packer PROPOSED PERFORATION INTERVALS Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status KupC ±10,219' ±10,239' 7,124' 7,141' 20 TBD Proposed Revised by: PC 5/17/2018 CAMERON A Srplumhlger Company HILCORP ALASKA 4-1/1, 4-1/16" 4-1/16" 5M 11" 5M 2-1/16" 5M R-24 11"5M R; 2-1/16"5M R-24 k'VjOIL STATES PROPOSAL) Casing Isolation Tool Energy Services (Canada) Inc. Maximum Allowable Pumping Rates SIZE CSG ID 2.250 1 .. 3.760 RATE W/min 1 10 m3/mIn 3 1/2' Big Bore 1.760 .2.760 6 m'/min 2718"831/2' 1.438 2.360 4m31min 23B" 1.000 .1.900 2m3/mIn 3 1/16 8 4 1/16 with tapered mandrel 2.750 4.000 15W/mIn 41/16 X Tool Mandrel 3.610 4.760 24 m3/min OPEN POSmON CLOSED POSmON PA. TO eu Lw uFw4 1,...x01 w .StingerCanadaxom 15M Treating Head 20 AAC 25.283 (a)(9) Data for the Fracturing Zone and Confining Zones (A) a lithologic description of each zone; (B) the geological name of each zone; (C) the measured depth and true vertical depth of each zone; (D) the measured thickness and true vertical thickness of each zone; and (E) the estimated fracture pressure for each zone; The Kuparuk formation is a Cretaceous -aged, fine-grained marine sandstone. The productive Kuparuk interval in the C-47 area is ^'25' TVD thick (Kuparuk Q. The top Kuparuk C Sand in C-47 is expected at lSC4 10,219' MD / 7124' TVD. Th_e estimated fracture gradient for the Kuparuk interval is 0.72 psi/ft. The overlying confining zone consists of -2000' TVD of HRZ shale and Colville siltstones and shales. The top HRZ shale is expected in C-47 at 9664' MD / 6641' TVD. The top of the Colville is expected at —6442' MD/4784' TVD. The estimated fracture gradient for the HRZ is 0.701 psi/ft. The underlying confining zone consists of "'170' TVD of Kuparuk siltstones and shales (B -silts). The top of ?s°" the B -Silts is expected in C-47 at —10,243' MD / 7,146 TVD. The estimated fracture gradient for the B- h C'. Ib Silts is 0.67 psi/ft. 20 AAC 25.283 (a)(10) The Location, the Orientation, and a Report on the Mechanical Condition of Each Well that May Transect the Confining Zones MP C-04: 7" casing set across the Kuparuk sands and cemented with 800 sxs of 15.8 ppg Class G cement. EZSV retainers set at 9,040', 9,155', and 9,175' MD to isolate the Kuparuk A and B sands. Estimated TOC 8,070' MD. MP C-11: 7" casing set across the Kuparuk sands with ECP at 8,676' and 8,698' MD and cemented with 54 bbls / 265 sxs of 15.8 ppg Class G cement with full returns during job. Bump plug with 2750 psi. Estimated TOC 7,850' MD. MP C-47PB: CIBP set at 9,250' MD. Cement retainer set at 9,160' MD. Squeezed 38.2 bbis 15.8 ppg cement below retainer and spot 3.3 bbls of 15.8 ppg cement on top of retainer. Set composite plug at 7,108' MD. Spot first plug of 32.9 bbls of 15.8 ppg cement on top of plug. Spot 32 bbls of 15.8 ppg cement on top of first plug. TOC at 6,385' MD. 18-01: 9-5/8" casing set at 9,822' MD and cemented with 1200 sxs of 15.8 ppg Class G cement. Bridge plugs set at 9,750' and 7,275' MD. Cement plugs from 10,030'- 10,120' and 7,158' - 7,275' MD. Well is P&A. Redacted For Public Disclosure 20 AAC 25.283 (a)(11) The Location of, Orientation of, and Geological Data for Each Known or Suspected Fault or Fracture that May Transect the Confining Zones 20 AAC 25.283 (a)(12) Proposed Hydraulic Fracturing Program 1. Confirm 7" casing has been pressure tested to 3000 for 30 minutes. 2. Pressure test tubing to 4500 psi for 30 charted minutes. 3. RU SL. PT to 1500 psi. Note that the wellbore will be hydraulically isolated from the reservoir with pressure tested cemented 7" casing. 4. Pull ball/rod and RHC ball catcher. 5. Drift 4-1/2" tubing with dummy perf gun to PBTD. 6. RDMO SL. 7. RU a -line and PCE. PT to 3500 psi (MPSP is 2974 psi / estimated Kuparuk River reservoir pressure). 8. Perforate the Kuparuk River formation from ±10,219 -±10,239' MD. Final depths to be determined from OH logs. 9. RDMO a -line. 10. MIRU frac fleet. MIRU frac and slop tanks. MIRU all ancillary support equipment. 11. Fill frac tanks with water. Heat water as needed. 12. Lay all hardlines and manifolds. Install pressure monitoring equipment on wellhead and tree. 13. RU 15K tree saver and hard line. 14. Pressure test all high pressure treating lines to 8000 psi. 15. Set the GORV (gas operated relief valve) at ±6800 psi. Set the staggered pump kickouts between 6800 psi and 6300 psi. 16. Pressurize annulus to 2500 psi. Set annular PRV at 3000 psi. 17. Prepare frac fleet to pump. 18. Pump Kuparuk DFIT and analyze the results to obtain fluid loss coefficients. Adjust frac design. 19. Fracture stimulate Kuparuk interval with 16/20 mesh resin coated proppant in cross-linked gel. See "Pump Schedule" for proposed design. 20. Displace with freeze protect fluid. Underdisplace by 3 bbls. Do not over displace. 21. Shut well in. RDMO. 22. MIRU CTU and associated equipment 23. RU CTU BOPE and PTto 3500 psi. RIH and cleanout frac sand/frac fluid to a portable test separator with filtered 2% KCI brine and N2 as needed to PBTD. 24. POOH jetting liner and tubing clean. RD CTU 25. RU SL / PCE and PT. Drift casing and tag with GR/JB. RDMO. 26. Turn well over to operations. 20 AAC 25.283 (a)(12) (A) Estimated Total Volumes Planned 20 AAC 25.283 (a)(12) (B) Trade Name, Generic Name, and Purpose of each Base Fluid and Additive to be Used; 20 AAC 25.283 (a)(12) (C) Chemical Ingredient Name of, and the Chemical Abstracts Service (CAS) Registry Number Assigned to, each Base Fluid and Additive to be used; 20 AAC 25.283 (a)(12) (D) Estimated Weight or Volume of each Inert Substance, including a Proppant or other Substance injected Client: Hilcorp Alaska, LLC Fracton —79 % 66402-68-4 Well: MPC -47 Schlumberger Guar um <1 % Basin/Field: Milne Point <1 % State: Alaska County/Parish: North Slope Borough Case: 7188546 Disclosure Type: Pre -Job Well Completed: 6/10/2018 Date Prepared: 5/18/2018 2:20 PM Report ID: RPT -55358 The total valume listed in the tables aoaw represents site summatwn of water ane a.... w ssupprea oy nam. CAS Number Chemical Name M�,, Water (Including Mix Water Supplied by Client). Fracton —79 % 66402-68-4 Ceramic materials and wares, chemicals —20 % 9000-30-0 Guar um <1 % 67-48-1 2-h drox-N,N,N-trimethylethanaminium chloride <1 % 1319-33-1 Ulexite < 1 % 107-21-1 Ethylene Glycol <0.1 % 67-56-1 Methanol <0.1 % 68131-40-8 Alcohols, c11 -15 -secondary, ethox lated <0.1 % 7727-54-0 Diammonium peroxidisulphate <0.1 % 1310-73-2 Sodium hydroxide <0.1 % 1303-96-4 Sodium Tetraborate Decahydrate <0.1 % 31726.34-8 Pol o -1,2-ethanedi I , al hahez 1-ome a -h dro - <0.1 % 25038-72-6 Vinylidene chloride/methylac late copolymer <0.01 % 110-17-8 but-2-enedioic acid <0.01 % 91053-39-3 Dlatomaceous earth, calcined <0.01 % 25322-68-3 Poly(oz -1,2-ethanedi I),a-h dro-w-hydrox - Ethane -1,2 -diol, ethoxylated <0.01 % 7631-86-9 Non -crystalline silica (impurity) <0.001% 61789-77-3 Dicoco dimethyl quaternary ammonlum chloride <0.001 % 10377-60-3 Magnesium nitrate <0.001 % 26172-55-0 5 -chloro -2 -meth I-2h-isothlazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 14807-96-6 Magnesium silicate hydrate talc <0.001 % 595585-15-2 Diutan <0.002 % 125005-87-0 Diutan gum <0.001 % 9002-84-0 poly(tetrafluoroethylena) <0.0001 % 67-63-0 Pro an -2 -al <0.0001 % 2682-20-4 2 -meth I-2h-Isothiazol-3-one <0.DD01 % 1446446-1 Cristobalite <0.0001 % 14808-60-7 Quartz, Crystalline silica <0.0001 % mix warel • Meevaluatlan of.H thddomntent ispedormd Basilan the mmposltion oftheidenafiedprnductsto the extent that such compounianalinformation was known to GIC-Chemkals as ofthe date Of the document was praducd. Any new updates will Trot be reflected in this document. 0 Schlumberger 2018. Used by Hilcorp Alaska, LLC bypermisslon. Page: 1 / 1 20 AAC 25.283 (a)(12) (E) Maximum Anticipated Treating Pressure and Information Sufficient to Support a Determination that the Well is Appropriately Constructed for the Proposed Hydraulic Fracturing Program. The 4-% "production tubing will be tested to 4500 psi for 30 minutes and the 7" production casing will be tested to 3000 psi for 30 minutes prior to the fracture stimulation. The maximum differential pressure the tubing will be subjected to will be 4300 psi (6800 psi GORV maximum pressure setting - 2500 psi of pressure on the casing x tubing annulus). The calculated maximum treating pressure is 4,876 psi. 20 AAC 25.283 (a)(12) (F) Designed Height And Length Of Each Proposed Fracture (i) the calculated measured depth and true vertical depth of the top of the fracture: 10,215' MD / 7,079' TVDss (7,121' TVD BKB) (ii) a description of each method and assumption used to determine designed fracture height and length: The MP C-47 fracture stimulation was modeled using FracCADE program. Note —The TVD depths in FracCADE are BKB. Schlumberger Fra c CADE" STIMULATION PROPOSAL Operator : Hilcorp Alaska, LLC Well : MP C-47 Field : Milne Point Formation : Kuparuk C Mark of Schlumberger Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the wall, reservoir and treaunent. The resulas depend on input data provided by the Operator and estimates as to unknown dam and can be no more accurate than the model, the assumptions and such input date. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather then absolute values. The quality of input data, and hence results, may be improved through the use of tartan tests and procedures which Schlumherger can assist an selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to no lythe owner or manners of the well or wells accordingly. Prices quoted are estimates only and are good for 3D days from the date of issue. Actual charges may vary depending upon time, equipment and material ultimately required to perform these services, not to be interred. Well Location North Slope County North Slope State Alaska Country United States Prepared for Paul Chan Service Point Prudhoe Bay Proposal No. Business Phone Date Prepared 21 May 2018 FAX No. Prepared by Gunther Rutzinger Phone 907 273 1788 E -Mail Address grutzinger@slb.com Mark of Schlumberger Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the wall, reservoir and treaunent. The resulas depend on input data provided by the Operator and estimates as to unknown dam and can be no more accurate than the model, the assumptions and such input date. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather then absolute values. The quality of input data, and hence results, may be improved through the use of tartan tests and procedures which Schlumherger can assist an selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to no lythe owner or manners of the well or wells accordingly. Prices quoted are estimates only and are good for 3D days from the date of issue. Actual charges may vary depending upon time, equipment and material ultimately required to perform these services, not to be interred. Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Contents Schlumberger Section 1: Wellbore Configuration.................................................................................................. 3 Section2: Zone Data...................................................................................................................... 4 Section 3: Propped Fracture Schedule.......................................................................................... 5 Section 4: Propped Fracture Simulation Results............................................................................ 7 Section 5: Propped Fracture Simulation.. ....................................................................................... 8 Section 6: Fluid Descriptions........................................................................................................ 10 Section 7: Treatment Fluid Data................................................................................................... 10 Section8: Proppant Data............................................................................................................. 11 Section9: Hole Survey......................................................................... ................................... 12 2 Client Hiloorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Section 1: Wellbore Configuration Bottom Hole Temperature --------------170 degF Deviated Hole------------------------------ YES Treat Down ---------------------- — ........ TUBING Well Type....................................Vertical 3.960 Well Location ............ ._----.-_._-----OnShore TO Tubing Data OD (in) Weight (Ib/ft) ID lin) Depth (ft) 4.500 12.6 3.960 10100.0 Casing Data OD (in) Weight (Ib/ft) ID (in) Depth (ft) 7.000 26.0 6.276 10906.0 Perforation Data Top Top Bottom Bottom Shot Number Diameter MD TO MD TVD Density (ft) (ft) (ft) (ft) Ishot/ftl (in) 10219.0 7124.1 10239.0 7141.6 6.00 120 0.32 Schlumberger Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States toadcase Initial design Section 2: Zone Data Schlumberger Formation Mechanical Prope -as Zone Name Top TVD Ift) Zone Height (ft) frac Grad. (Psi/ft) Insitu Stress (psi) Youngs Modulus (psi) Poisson's Ratio Toughness (psi.in(1.5) Shale 6825.0 89.0 0.836 5742 1.187E+6 0.25 2000 Shale 6914.0 210.0 0.854/ 5996 1.308E+6 0.29 2000 Kup C 7124.0 22.0 0.658 4695 1.847E+6 0.34 800 Kup B 7146.0 68.3 0.718 5153 1.733E+6 0.35 2000 Kup B 7214.3 1 30.7 0.747 5397 1.729E+6 0.34 2000 Kup B 10.0 0 0.767 5562 1.729E+6 0.34 2000 Kup B 1.000 0 0.764 5557 1.729E+6 0.34 2000 Kup A3 a734O.O42. 0 0.691 5055 1.729E+6 0.34 2000 Kup A2 a7340.O42.0 0 0.791 5820 1.729E+6 0.34 2000 Miluveach Ku A2 .0 0.850 6317 4.494E+6 0.35 1000 Formation ansmissibility Properties Zone Name Top TVD (ft) Net Height Ift) Perm (md) Porosity 1%1 Res. Pressure (psi) Gas Sat (%) oil Sat. (°%) Water Sat. (%) Shale 6825.0 1.0 0.001 1.0 3215 0.0 60.0 40.0 Shale 6914.0 1.0 0.001 1.0 3285 0.0 60.0 40.0 Kup C 7124.0 22.0 70.000 20.0 3339 0.0 60.0 40.0 Kup B 7146.0 34.0 1.000 10.0 3360 0.0 60.0 40.0 Kup B 7214.3 1 10.0 1.000 1 10.0 3383 0.0 60.0 40.0 Kup B .0 1.000 10.0 3394 0.0 60.0 40.0 Kup B .0 1.000 10.0 3403 0.0 60.0 40.0 Kup A3 a7340.O42.0 .0 100.000 22.0 3422 0.0 20.0 80.0 Ku A2 100.000 22.0 3445 0.0 20.0 80.0 Miluveach .0 0.001 1.0 3478 0.0 20.0 80.0 Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design 3chludopger Section 3: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length (X,) of 378.4 ft with an nvpranp cnnduntivity (K.wl of 6801 md.ft. Fluid Totals 60000 gal of YF130FIexD 6653 gal of WF130 Proppant Totals 179000 lb of 16/20 CarboBond Lite Pad Percentages % PAD Clean 41.7 %PAD Dirty 36.7 Job Description Job Execution Step Name Pump Rate (bbl/min) Fluid Name Step Fluid Volume (gal) Gel Conc. (lb/mgal) Prop. Type and Mesh Prop. Conc. (PPA) Pad 30.0 YF130FIexD 25000.0 30.0 Cum. Time (min) 0.00 1.0 PPA 30.0 YF130FIexD 2000.0 30.0 16/20 CarboBond Lite 1.00 2.0 PPA 30.0 YF130FIexD 2000.0 30.0 16/20 CarboBond Lite 2.00 3.0 PPA 30.0 YF130FIexD 2000.0 30.0 16/20 CarboBond Lite 3.00 4.0 PPA 30.0 YF130FIexD 8000.0 30.0 16/20 CarboBond Lite 4.00 5.0 PPA 30.0 YF130FIexD 6000.0 30.0 16/20 CarboBond Lite 5.00 6.0 PPA 30.0 YF130FIexD 5000.0 30.0 16/20CarboBond Lite 6.00 7.0 PPA 30.0 YF130FIexD 5000.0 30.0 16120 CarboBond Lite 7.00 8.0 PPA 30.0 YF130FIexD 5000.0 30.0 16/20 CarboBond Lite 8.00 Flush 30.0 WF130 6653.3 30.0 50000.0 0.00 Fluid Totals 60000 gal of YF130FIexD 6653 gal of WF130 Proppant Totals 179000 lb of 16/20 CarboBond Lite Pad Percentages % PAD Clean 41.7 %PAD Dirty 36.7 Job Execution Step Name Step Fluid Volume (gal) Cum. Fluid Volume (gal) Step Slurry Volume (bbl) Cum. Slurry Volume (bbl) Step Prop (lb) Cum. Prop. (lb) Avg. Surface Pressure (psi) Step Time (min) Cum. Time (min) Pad 25000.0 25000.0 595.2 595.2 0 0 4667 19.8 19.8 1.0 PPA 2000.0 27000.0 49.8 645.0 2000 2000 4699 1.7 21.5 2.0 PPA 2000.0 29000.0 51.9 696.9 4000 6000 4675 1.7 23.2 3.0 PPA 2000.0 31000.0 54.1 751.0 6000 12000 4632 1.8 25.0 4.0 PPA 8000.0 39000.0 224.8 975.8 320D0 44000 4569 7.5 32.5 5.0 PPA 6000.0 45000.0 175.0 1150.8 30000 74000 4584 5.8 38.4 6.0 PPA 5000.0 50000.0 151.2 1302.0 30000 104000 4621 5.0 43.4 7.0 PPA 5000.0 55000.0 156.6 1458.6 35000 139000 4688 5.2 48.6 8.0 PPA 5000.0 60000.0 162.0 1620.6 40000 179000 4798 5.4 54.0 flush 6653.3 66653.3 158.4 1779.0 0 179000 4131 5.3 59.3 Client Hilcorp Alaska, LLC Wel MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Summary for This Stage: Average Pump Rate Volume Weighted Average Rate Total Fluid Volume Total Proppant Mass Total Slurry Volume Total Pump Time Pumping Schedule Totals 30.0 bbl/min 30.0 bbl/min 66653 gal 179000 lb 1779.0 bbl 59.3 min 3chlumherger Fluid Based Totals for This Stage Average Volume Total Total Total Total Fluid Pump Weighted Fluid Proppant Slurry Pump Type Rate Average Rate Volume Mass Volume Time Mass (bbi/min) (bbi/min) (gal) (lb) (bbll (min) YF130FIexD 30.0 30.0 60000 179000 1620.6 54.0 WF130 30.0 30.0 6653 0 156.4 5.3 Pro pant Based Totals for This Stage Average Volume Total Total Total Total Proppant Pump Weighted Fluid Proppant Slurry Pump Type Rate Average Rate Volume Mass Volume Time Mass (bbl/min) (bbl/min) (gal) (lb) (bbl) (min) 16120 Carbo Bond Ute 30.0 30.0 35000 171000 1025.3 34.2 Summa for Each Treatment Average Volume Total Total Total Total Treatment Pump Weighted Fluid Proppant Slurry Pump Type Rate Average Rate Volume Mass Volume Time Mass (bbl/min) (bbl/min) (gal) (III) (bbl) (min) Propped Fracture 30.0 30.0 66653 179000 1779.0 59.3 Summary for Each Fluid in Each Treatment Average Volume Total Total Total Total Treatment Fluid Pump Weighted Fluid PrOppant Slurry Pump Type Rate Average Rate Volume Mass Volume Time (bbl/min) lbbl/min) (gal) (lb) (bbl) Imm) Propped Fracture YF130RexD 30.0 30.0 60000 179000 1620.6 54.0 Propped Fracture WF130 30.0 30.0 6653 0 I. 5.3 Client Hilcorp Alaska, LLC SchlUmbergcr Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Section 4: Propped Fracture Simulation Results (1) ACL Fracture Profile and Proppant Concentration Plot FracCADE` Ma �mI1,' L ` ,6 5016 ACL FM<—P:o01e Inn Pmppenl CancenVnYon May 1 FntluM „M,Iatlrn NOS 600 5TN'P8 A0. Mn. a, nennn - In Fmtlure W.I.nnn-n (2) Treating Plot .II ; S.Uomftoie P--- ------ Sortaw P... -'-'-'-' TOUI Inj. Rete EOJ 600 so 60 SOU .II ; i 6 ------------- I 60 I{ I I 400 -.. '' I - 50 40 ............ ......... .............. ,............ i._11 i j 30 300 --� , I i 20 i I-- ---- I i , � - 6 o 0 10 20 30 40 50 60 Twa0nent Time - min 7 70 60 90 100 Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay country United States Loadcase Initial design Section 5: Propped Fracture Simulation 3chlumherger, The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD ------------------------- 7124.0 It Initial Fracture Bottom TO ....................7146.0 ft Propped Fracture Half -Length ---------------- 378.4 ft EOJ Hyd Height at Well------------------------- 138.2 It Average Propped Width---------- ------------- 0.235 in Average Gel Concentration -------------------- 416.8lb/mgal Average Gel Fluid Retained Factor_ ........ 0.59 Net Pressure- ---------------- -...................... 916 psi Efficiency ............................................ 0.338 Effective Conductivity ...........................9003 md.ft Effective Fcd---------------------------- -----._.....0.3 94.6 Max Surface Pressure ---------------------------4876 psi Simulation Results by Fracture Segment From (ftl To (ft) Prop. Conc. at End of Pumping (PPA) Propped Width lin) Propped Height (ft) Frac. Prop. Conc. (Ib/112) Frac. Gel Conc. (Iblmgal) Fracture Conductivity (md.ft) 0.0 94.6 1 9.0 0.250 116.1 2.21 420.4 7081 94.6 189.2 10.4 0.259 118.4 2.30 418.3 7311 189.2 283.8 10.8 0.272 102.6 2.47 396.1 7873 283.8 1 378.4 3.6 1 0.165 88.0 1.50 432.3 5000 Proppant packed at375 It after 141 bbl in step 6 Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Schlumhergcr, Exposure Time Prediction by Step Fracture Geometry Data Per Zone for Production Prediction Fluid Volume (gal) Zone Name Top MD (ft) Top TO (ft) Gross Height (ft) Net Height Fracture Width (in) Fracture Length (ft) Fracture Conductivity (md.ft) Shale 9876.4 6825.0 89.0 1.0 0.000 .0 0 Shale 9978.7 6914.0 210.0 1.0 0.094 326.0 2747 Kup C 10218.8 7124.0 22.0 22.0 0.310 378.4 9003 Kup B 10244.0 7146.0 68.3 34.0 0.268 377.3 7816 Kup B 10322.1 7214.3 30.7 10.0 0.065 232.4 1883 Kup B 10357.2 7245.0 15.0 5.0 0.003 90.2 74 Kup B 10374.3 7260.0 23.0 7.0 0.000 .0 0 Kup A3 10400.6 7283.0 57.0 57.0 0.000 .0 0 Kup A2 10465.8 7340.0 42.0 42.0 0.000 .0 0 Miluveach 10513.8 7382.0 100.0 1.0 0.000 .0 0 Exposure Time Prediction by Step Step Name Fluid Name Pump Rate (bbl/min) Fluid Volume (gal) Perforation Injection Temp. (degF) Exposure at BHSTof 170 degF (min) Exposure aboveWatch Temp. of 165 degF (min) Pad YF130FlexO 30A 25000.0 111 12.8 12.8 1.0 PPA YF130FIexD 30.0 2000.0 94 8.6 8.6 2.0 PPA YF130FIexD 30.0 2000.0 94 8.4 8.4 3.0 PPA YF130FlexD 30.0 2000.0 94 10.0 10.0 4.0 PPA YF130FIexD 30.0 8000.0 93 8.3 8.3 5.0 PPA YF130FIexD 30.0 6000.0 92 0.0 0.0 6.0 PPA YF130FIexD 30.0 5000.0 92 0.0 0.0 7.0 PPA YF130FIexD 30.0 5000.0 92 0.0 0.0 8.0 PPA YF130FIexD 30.0 5000.0 92 0.0 0.0 Flush WF130 30.0 6653.3 Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Section 6: Fluid Descriptions 2% KCI brine • M117, Potassium Chloride 166.00 Ib/mgal YF130FIexD • J580, Gelling Agent 30.00lb/mgal • L071,Temporary Clay Stabilizer 2.00gaVmgal • M002, Caustic Soda Flake 1.50 lb/mgal • J604, Crosslinker 2.50 gal/mgal • J475, EB -CLEAN Breaker 4.00 Ib/mgal • F112, EZEFLO Surfactant 1.00 gal/mgal • M275, Microbiocide 0.30 lb/mgal W F130 • M275, Microbiocide 0.30 lb/mgal • 1-071, Temporary Clay Stabilizer 2.00 gal/mgal • J580, Gelling Agent 30.00 Ib/mgal • F112, EZEFLO Surfactant 1.00 gal/mgal • J475, EB -CLEAN Breaker 5.00 lb/mgal Section 7: Treatment Fluid Data Fluid data is given at 70 md. Schlumberger Fluid Name 2% KCI brine YF130FIexD WF130 Friction Rate Low )bbl/min) 5.0 1.0 1.0 Pressure Low (psV1000ft) 10.0 20.0 1.2 Rate Pivot (bbl/min) 25.0 10.0 30.0 Pressure Pivot( si/1000ft) 400.0 80.0 70.0 Rate High (bbl/min) 60.0 100.0 100.0 Pressure High (psi/1000ft) 1000.0 770.0 300.0 Fluid Loss C. (ft/min0.5) 1.0E+0 7.0E-3 7.0E-3 Spurt (ga1/100ft2) 0.0 0.0 3.5 C, (ft/min0.5) 2.3E-2 6.0E-3 6.0E-3 Rhaalnav Temperature (degF) 170 170 170 Time (hr) 0.0 0.0 0.0 Behavior Index (N') 1.00 0.41 1.00 Consist. Index (K')(Ibf.sAn/ft2) 7.96E-6 9.93E-2 2.09E-5 Viscosity ® Shear Rate (cN 0.381 255.274 1.000 Shear Rate (1/0 170 170 170 10 Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Section 8: Proppant Data Proppant Permeability is calculated based on the following parameters BH Static Temperature: 170 degF Stress on Proppant: 3695 psi Propped Fracture Conc.: 1.00 lb/ft2 Average Young's Modulus: 1.847E+06 psi 3chiumherger, Proppant Data Proppant Name Specific Gravity Mean Diameter (in) Pack Porosity !%) Permeability (md) Jordan Unimin 20/40 2.65 0.022 35.0 154955 16/20 CarboBond Lite 2.66 0.042 39.9 608951 f Proppant Permeability Plot Prop P an i P a rm a a e II tlV 70000 r. 80000 50000 40000 I 20000( I 1000 _____ --_.___..._i___ I 1000 2000 3000 4000 5000 0000 7000 8000 9000 a... St.. y9) Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Section 9: Hole Survey 3chlum6erger 12 Hole Survey MD Ift) ND (ft) Deviation Angle (deg) Deviation Build Rate (de /100ft) Azimuth Angle (de) Azimuth Build Rate (de /100ft) Dogleg Severity (de /100ft) 0.0 0.0 0.0 0.0 1 0.0 0.0 0.0 26.9 26.9 0.0 0.0 0.0 0.0 0.0 100.0 100.0 0.5 0.6 31.0 42.4 0.6 200.0 200.0 0.5 0.1 2.7 -28.2 0.3 232.0 232.0 0.6 0.3 21.0 57.2 0.7 294.0 294.0 1.3 1.1 48.0 43.5 1.3 356.0 355.9 3.0 2.8 64.4 26.5 3.0 417.0 416.8 5.7 4.3 60.0 -7.2 4.4 479.0 478.3 8.1 3.9 64.9 7.8 4.0 539.0 537.6 8.8 1.2 70.5 9.4 1.8 600.0 597.9 9.6 1.2 71.5 1.5 1.2 663.0 659.8 11.2 2.6 69.5 -3.1 2.6 728.0 j 723.3 13.8 4.0 71.8 3.6 4.1 788.6 781.9 15.5 2.8 75.2 5.6 3.2 851.6 842.2 18.1 4.2 75.0 -0.3 4.2 915.6 902.7 19.9 2.7 73.9 -1.7 2.8 977.2 960.2 22.4 4.1 73.8 -0.1 4.1 1039.6 1017.2 25.7 5.2 72.3 -2.4 5.3 1101.0 1071.6 29.1 5.7 71.1 -2.0 5.7 1166.2 1127.6 32.4 5.0 69.8 -2.0 5.1 1228.6 1179.1 36.2 6.1 68.9 -1.3 6.1 1291.4 1228.9 39.2 4.8 68.8 -0.2 4.8 1353.9 1276.4 41.8 4.1 66.0 -4.5 5.1 1417.4 1322.8 44.2 3.8 60.7 -8.3 6.8 1479.6 1367.0 45.4 2.0 58.2 -4.0 3.5 1542.8 1411.9 44.0 -2.3 56.0 -3.4 3.3 1605.7 1457.3 43.8 -0.2 55.2 -1.4 1.0 1668.5 1502.8 43.2 -1.0 56.4 2.0 1.7 1731.2 1548.0 44.6 2.1 55.3 -1.6 2.4 1794.8 1592.9 45.5 1.4 54.9 -0.7 1.5 1857.4 1636.9 45.2 -0.5 55.2 0.5 0.6 1921.5 1682.7 43.7 -2.3 56.4 2.0 2.7 1983.4 1727.2 44.2 0.8 57.0 0.9 1.0 2046.1 1771.6 45.6 2.2 58.0 1.6 2.5 2108.9 1814.9 47.4 2.8 57.5 -0.7 2.9 2171.7 1857.0 48.5 1.8 55.8 -2.6 2.6 2234.0 1898.7 47.5 -1.6 55.6 -0.3 1.6 2297.21941.8 46.4 -1.8 55.2 -0.6 1.8 2360.1 1985.7 45.3 -1.7 55.9 1.1 1.9 12 Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Schlumberger 13 Hole Survey MD (ft) ND (ft) Deviation Angle (deg) Deviation Build Rate (deg/100ft) Azimuth Angle (deg) Azimuth Build Rate (deg/100ft) Dogleg Severity (deg/100ft) 2423.1 2029.7 46.3 1.7 53.3 -4.1 3.4 2485.7 2072.8 46.4 0.1 53.0 -0.5 0.4 2548.9 2116.0 47.5 1.8 54.0 1.6 2.1 2611.7 2158.6 46.9 -1.0 54.2 0.4 1.1 2675.1 2202.4 45.8 -1.7 53.7 -0.8 1.8 2737.6 2245.6 46.6 1.3 55.1 2.2 2.1 2800.6 2288.4 48.0 2.1 55.0 -0.2 2.1 2863.4 2330.8 47.0 -1.6 54.8 -0.3 1.6 2926.4 2374.3 45.9 -1.7 54.8 0.1 1.7 2989.4 2417.8 46.7 1.2 55.3 0.9 1.4 3052.1 2461.0 46.2 -0.7 56.7 2.2 1.8 3114.8 2504.0 47.3 1.8 55.0 -2.8 2.7 3177.8 2546.7 47.2 -0.2 55.2 0.4 0.3 3240.8 2589.5 47.2 -0.1 54.7 -0.8 0.6 3303.6 2632.6 46.5 -1.1 55.3 1.0 1.3 3366.4 2676.1 45.8 -1.1 55.6 0.4 1.1 3429.6 2720.3 45.4 -0.6 55.6 0.0 0.6 3492.4 2764.0 46.7 2.2 56.4 1.2 2.3 3555.3 2806.8 47.1 0.7 56.7 0.5 0.7 3618.2 2849.7 47.0 -0.1 56.8 0.2 0.2 3681.0 2892.5 47.0 -0.1 56.9 0.1 0.0 3744.0 2935.5 47.1 0.1 57.1 0.4 0.3 3806.5 2978.2 46.7 -0.5 57.5 0.6 0.7 3869.5 3021.8 45.5 -1.9 57.2 -0.4 1.9 3932.7 3066.4 44.7 -1.3 58.6 2.2 2.0 3994.7 3110.1 45.7 1.6 58.4 -0.3 1.6 4058.8 3154.6 46.5 1.2 59.1 1.1 1.4 4121.7 3197.7 46.9 0.7 57.2 -2.9 2.3 4184.3 3240.3 47.4 0.7 55.5 -2.7 2.1 4247.0 3283.1 46.6 -1.2 55.7 0.3 1.2 4310.0 3326.1 47.2 1.0 54.0 -2.7 2.2 4373.0 3369.0 46.9 -0.5 52.0 -3.2 2.4 4436.0 3412.3 46.4 -0.8 52.0 0.0 0.8 4498.9 3455.7 46.2 -0.3 52.6 1.0 0.8 4561.6 3499.0 46.6 0.6 52.3 -0.5 0.7 4624.6 3542.4 46.4 -0.3 53.1 1.3 1.0 4687.6 3585.9 46.2 -0.2 54.2 1.6 1.2 4750.6 3629.7 45.7 -0.8 54.1 -0.1 0.8 4813.4 3673.6 45.5 -0.4 54.8 1.2 0.9 4876.6 3718.0 45.2 -0.5 55.1 0.4 0.6 4939.2 3761.6 46.6 2.2 55.4 0.6 2.3 13 Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design Schiudopgcr 14 Hole Survey MD (ft) ND (ft) Deviation Angle (deg) Deviation Build Rate (de /100ft) Azimuth Angle (de) Azimuth Build Rate (deg/100ft) Dogleg Severity (de /100ft) 5002.3 3804.2 48.5 3.0 54.1 -2.1 3.4 5065.0 3845.9 48.3 -0.2 54.9 1.2 0.9 5128.0 3887.6 48.6 0.5 54.8 -0.1 0.5 5190.7 3929.0 48.7 0.2 54.8 -0.0 0.2 5253.2 3970.5 48.0 -1.2 55.5 1.2 1.5 5316.4 4013.1 47.3 -1.1 55.7 0.2 1.1 5379.2 4056.0 46.6 -1.2 55.3 -0.5 1.2 5442.2 4099.6 45.9 -1.0 55.6 0.3 1.0 5504.9 4143.5 45.0 -1.4 56.3 1.1 1.6 5567.7 4188.2 44.2 -1.3 57.1 1.3 1.6 5631.0 4233.2 45.3 1.7 56.4 -1.1 1.8 5693.7 4276.9 46.2 1.5 56.9 0.9 1.6 5756.4 4319.8 47.6 2.2 57.1 0.3 2.2 5819.1 4362.1 47.5 -0.2 57.8 1.1 0.9 5882.5 4405.0 47.5 0.1 57.9 0.1 0.0 5945.3 4447.7 46.6 -1.4 58.2 0.5 1.5 6008.0 4490.6 47.0 0.5 55.9 -3.7 2.7 6071.2 4533.0 48.8 2.9 54.8 -1.7 3.2 6134.0 4574.6 48.3 -0.9 55.8 1.6 1.5 6196.9 4616.7 47.5 -1.2 55.3 -0.9 1.3 6260.0 4659.5 47.0 -0.9 55.2 -0.1 0.9 6322.7 4702.4 46.7 -0.4 55.8 1.0 0.8 6385.5 4745.5 46.7 0.0 55.4 -0.6 0.5 6448.3 4788.5 46.6 -0.2 56.0 1.0 0.7 6511.5 4832.0 46.5 -0.3 55.9 -0.2 0.3 6554.4 4861.6 46.3 -0.3 55.7 -0.6 0.5 6600.0 4893.1 46.2 -0.4 56.1 0.9 0.7 6700.0 4962.0 46.8 0.7 51.3 -4.7 3.5 6800.0 5029.9 47.7 0.9 46.7 -4.6 3.5 6900.0 5096.5 48.7 1.0 42.2 -4.5 3.5 7000.0 5161.7 49.9 1.2 37.9 -4.3 3.5 7100.0 5225.2 51.3 1.4 33.7 -4.2 3.5 7200.0 5286.7 52.8 1.5 29.7 -4.0 3.5 7300.0 5346.0 54.5 1.6 25.9 -3.8 3.5 7400.0 5402.9 56.2 1.8 22.2 -3.7 3.5 7500.0 5457.1 58.1 1.9 18.7 -3.5 3.5 7600.0 5508.6 60.0 2.0 15.3 -3.4 3.5 7700.0 5557.0 62.1 2.0 12.0 -3.3 3.5 7800.0 5602.2 64.2 2.1 8.9 -3.1 3.5 7891.0 5640.4 66.2 2.2 6.2 -3.0 3.5 7900.0 5644.1 66.2 0.0 6.2 0.0 0.0 14 Client Hilcorp Alaska, LLC Well MP C-47 Formation Kuparuk C District Prudhoe Bay Country United States Loadcase Initial design sOlumaerger 15 Hole Survey MD (ft) ND (ft) Deviation Angle (deg) Deviation Build Rate (de /100ft) Azimuth Angle (de) Azimuth Build Rate (deg/100ft) Dogleg Severity (deg/100ft) 8000.0 5684.5 66.2 0.0 6.2 0.0 0.0 8100.0 5724.9 66.2 0.0 6.2 0.0 0.0 8200.0 5765.4 66.2 0.0 6.2 0.0 0.0 8300.0 5805.8 66.2 0.0 6.2 0.0 0.0 8400.0 5846.2 66.2 0.0 6.2 0.0 0.0 8500.0 5886.7 66.2 0.0 6.2 0.0 0.0 8581.0 5919.4 66.2 0.0 6.2 0.0 0.0 8600.0 5927.2 65.5 -3.5 6.2 0.2 3.5 8700.0 5971.4 62.0 -3.5 6.4 0.2 3.5 8800.0 6021.1 58.5 -3.5 6.7 0.2 3.5 8900.0 6075.9 55.0 -3.5 6.9 0.2 3.5 9000.0 6135.7 51.5 -3.5 7.2 0.3 3.5 9100.0 6200.2 48.0 -3.5 7.5 0.3 3.5 9200.0 6269.4 44.5 -3.5 7.8 0.4 3.5 9300.0 6342.7 41.0 -3.5 8.2 0.4 3.5 9400.0 6420.1 37.5 -3.5 8.7 0.4 3.5 9500.0 6501.2 34.1 -3.5 9.2 0.5 3.5 9600.0 6585.7 30.6 -3.5 9.8 0.6 3.5 9616.8 6600.2 30.0 -3.5 9.9 0.7 3.5 9700.0 6672.2 30.0 0.0 9.9 0.0 0.0 9800.0 6758.8 30.0 0.0 9.9 0.0 0.0 9900.0 6845.5 30.0 0.0 9.9 0.0 0.0 9916.8 6860.0 30.0 0.0 9.9 0.0 0.0 9949.8 6888.7 29.0 -3.0 9.9 0.0 3.0 10000.0 6932.6 29.0 0.0 9.9 0.0 0.0 10100.0 7020.1 29.0 0.0 9.9 0.0 0.0 10200.0 7107.5 29.0 0.0 9.9 0.0 0.0 10222.4 7127.2 29.0 0.0 9.9 0.0 0.0 10300.0 7195.0 29.0 0.0 9.9 0.0 0.0 10400.0 7282.4 29.0 0.0 9.9 0.0 0.0 10500.0 7369.9 29.0 0.0 9.9 0.0 0.0 10600.0 7457.3 29.0 0.0 9.9 0.0 0.0 10700.0 7544.8 29.0 0.0 9.9 0.0 0.0 10800.0 7632.3 1 29.0 0.0 9.9 0.0 0.0 10906.1 7725.1 1 29.0 0.0 9.9 0.0 0.0 15 20 AAC 25.283 (a)(13) Description of the Plan for Post -Fracture Wellbore Cleanup and Fluid Recovery through to Production Operations The well will be cleaned up through a portable separation system before turning the well over to Production. Initial returns will be taken to the permitted Milne Point G&I facility for disposal. HHileorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: May 14, 2018 Subject: Changes to Approved Sundry Procedure for Well MP C-47 Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Step HAK Page Date Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date 14 STANDARD WELL PROCEDURE ❑ilrorp Alaska. LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FI NAL v1 Page 1 of 1 Rixse, Melvin G (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Tuesday, June 26, 2018 10:59 AM To: Schwartz, Guy L (DOA); Rixse, Melvin G (DOA); Davies, Stephen F (DOA) Cc: Monty Myers; Cody Dinger; Tom Fouts; Joe Engel Subject: RE: [EXTERNAL] RE: Hilcorp MPU C-47 (PTD#217-077) Update Guy/Steve Hilcorp Alaska respectfully withdraws the 10-403 fracture stimulation sundry for the MP C-47 well. Thanks Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907) 777 — 8333 (w) (907) 444 — 2881 (c) From: Joe Engel Sent: Tuesday, June 26, 2018 10:55 AM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Monty Myers <mmyers@hilcorp.com>; Paul Chan <pchan@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com> Subject: RE: [EXTERNAL] RE: Hilcorp MPU C-47 (PTD#217-077) Update Thank you, Guy. As per our conversation, a schematic of the well will be included with the operational shutdown sundry. Correct, there are no RA sources in this BHA. Regards. -Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 From: Schwartz, Guy L (DOA) [mailto:euv.schwartz@alaska.eov] Sent: Tuesday, lune 26, 2018 8:47 AM To: Joe Engel <jenxel@hilcorp.com>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.Pov> Cc: Monty Myers <mmyers@hilcorp.com>; Paul Chan <pchan@hilcorp.com> Subject: [EXTERNAL] RE: Hilcorp MPU C-47 (PTD#217-077) Update Joe, Davies, Stephen F (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Tuesday, June 12, 2018 7:52 AM To: Davies, Stephen F (DOA) Cc: Wyatt Rivard; Rixse, Melvin G (DOA); Schwartz, Guy L (DOA) Subject: RE: MPU C-47 (PTD #217-077; Sundry #318-217) - Question Steve We are currently fishing a stuck clean out assembly in the open hole. Fishing operation results will let us know if we can still run casing in this hole or have to do something else. Thanks Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907) 777 — 8333 (w) (907) 444 — 2881 (c) From: Davies, Stephen F (DOA)[maiito:steve.davies@alaska.gov] Sent: Monday, June 11, 2018 3:57 PM To: Paul Chan <pchan@hilcorp.com> Cc: Wyatt Rivard <wrivard@hilcorp.com>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwa rtz@alas ka.gov> Subject: RE: MPU C-47 (PTD #217-077; Sundry #318-217) - Question Paul, My work notes indicate that fracture -stimulation operations were scheduled to begin on MPU C-47 sometime this week. I haven't heard anything further from you, so I thought I'd check the progress on this well. I have taken my review of Hilcorp's Sundry Application to fracture stimulate MPU C-47 as far as I can without receiving well log, formation top, casing, and cementing information from the drilled well. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or steve.daviesCaalaska.xov. From: Paul Chan [mailto:pchan@hilcorp.com] Sent: Friday, June 1, 2018 4:19 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.aov> Cc: Wyatt Rivard <wrivard@hilcorp.com>, Subject: RE: MPU C-47 (PTD #217-077; Sundry #318-217) - Question Steve To the best of my knowledge, Hilcorp has not performed TDS or salinity tests for the afore mentioned wells. None of the water from these wells are used for drinking purposes. Regards Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907) 777 — 8333 (w) (907) 444 — 2881 (c) From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.govl Sent: Wednesday, May 30, 2018 11:19 AM To: Paul Chan <pchan@hilcorp.com> Subject: RE: MPU C-47 (PTD #217-077; Sundry #318-217) - Question Thank you Paul. Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or steve.davies(aalaska.gov. From: Paul Chan [mailto:pchan@hilcorp.com] Sent: Wednesday, May 30, 2018 11:18 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: MPU C-47 (PTD #217-077; Sundry #318-217) - Question Steve I am collecting the data for any testing that Hilcorp has done and will forward to you shortly. Below are some prior test results from the previous operator. MPA -02A: TDS = 2575 mg/L, Taken 5/17/2005 MPB-01: TDS = 3160 mg/L, Taken 12/25/1986 MPCFP-01: TDS = 3162 mg/L, Taken 1/3/1986 Thanks Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907) 777 — 8333 (w) (907) 444 — 2881 (c) From: Davies, Stephen F (DOA)(mailto:steve.davies@alaska.eov) Sent: Tuesday, May 29, 2018 1:07 PM To: Paul Chan <pchan@hilcorp.com> Subject: MPU C-47 (PTD #217-077; Sundry #318-217) - Question Paul, Has Hilcorp measured TDS or salinity in water produced from the MPU A -2A, MPU B-1, or CFP -01 water -supply wells? so, could you please provide those values in units of mg1l? Is the any of the water from MPU A -2A, MPU B-1, or MPU CFP -01 used for drinking purposes? Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. L1 Its, ONMENTAL PROTECTION Af')Y 2 i7-�,-_77 osr REGION 10 CONnM J�JEgrFs 1200 SIXTH AVENUE CORnM SEATTLE, WASHINGTON 98101 z COPJM RES _ c_NG +T14 PRO1110\ JUL 0 21987 �:99 ENGi r N a ATTN OF WD -132 l�// / H l.,- W. W. Barnwell, Commissioner '+t_C'f Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive — — Anchorage, Alaska 99501-3192 RE: Conoco Incorporated Aquifer Exemption Request of May 1, 1987 Dear Mr. Barnwell: Based on Conoco's May 1, 1987, letter and June 12, 1987, supplemental, we believe the subject aquifers qualify for an exemption. In addition, I understand that Commissioner Lonnie Smith informed Harold Scott on June 25, 1987, that there were no comments during the public comment period regarding the proposed exemptions. Therefore, we concur with your decision to exempt the aquifers beneath the Milne Point Unit for Class II injection activities only. This is a "non -substantial program revision" in accordance with Section 13 of our Memorandum of Agreement. Sincerely, Robert S. Burd Director, Water Division U. )VIRONMENTAL PROTECTION .6Y REGION 10 'SEO STgr o`'15, 120SIXTH AVENUE �C/ SEATTLE,, WASHINGTON 98101 w o Q MAY 27 1987 ` r z 2 0 REPLY TO ATTN OF: WD -132 W. W. Barnwell, Commissioner l (� �,-,B, Alaska Oil and Gas Conservation Commission 1 "'" 3001 Porcupine Drive Anchorage, Alaska 99501-3192 f` RE: Proposed Aquifer Exemption for Milne Point Unit--ConocoAlasha Oil & Gas Cons. ;lanlm�ssian' Anchorage Dear Mr. Barnwell: On May 13, 1987, we received your May 8, 1987, letter regarding the proposed aquifer exemption for Milne Point Unit. At this time, we are uncertain as to whether the exemption would be a "substantial" or "non -substantial" program revision. Our uncertainty centers around the following two issues: 1. There is inadequate documentation of the TDS levels in the water column areally throughout the Unit to determine whether the ground water is greater than 3,000 mg/l TDS. NOTE: Laboratory analyses submitted by Conoco show the CPF-1 well has a TDS level of 2,500 mg/1. 2. The exemption does not appear to be related to a permit action nor to be an existing enhanced recovery project authorized by rule. According to the Federal Register, a major exemption is one with a TDS level of less than 3,000 mg/l and not related to action on a permit or not an enhanced recovery project authorized by rule. A major exemption requires a "substantial" program revision under 40 CFR 145.32. Aquifers with TDS levels greater than 3,000 mg/1 and not related to action on a permit are minor exemptions processed under our Memorandum of Agreement. Excerpts of the preambles to the Federal Register dated September 2, 1983, and May 11, 1984 are enclosed. In order to evaluate Conoco's request, the following information is needed: 1. Documentation of the TDS levels in the water column at several locations throughout the Unit. At a minimum, laboratory analyses for the source well (A -2A) and calculations of TDS levels (e.g., based on SP logs and Archie's equation) should be provided to show vertical and areal extent of TDS levels throughout the Unit. Enclosed are correspondence between EPA (December 24, 1984) and Conoco (May 15, 1985) illustrating the type of documentation that N U S- 0 O U C LU U r r O C O C N -C ti. 4J .0 O .- N ro U 4- O v +J to +J +J r r .0 •.- i +J •i- r i +J +J +J U C U -0 3 i to a U E to b ro S U N O U +J r 4- t0 E s ro 7 i•J +J 4- •r O •r i +J +J 3 rO ro ro •r- a. o = 'O 04-) U U r .0 7 to U Q C 4- O v tm O U U 3 Q U to rO C U U C b mo i R3 U •r Ln +J•r ^ U U N U C Y U U A O U •FJ i •r- U r "0 U C> E r (N i CO O t CD f0 r •r •r- •r +J r4-) E O +J • O C O O S.. rN +J U Q •r N U C. O i U 'Q C U 4- X Q1 > •r r6 C O U +J S- •r O O C •r O +J S O ID 4- +-� b •r • i +J •r N +J •r •r O X t "0 U N m to N C - i N S- U +J r d Cl. C 7 U S.- 'a O 'r• U N N O U ro i 0- U co > +J U U +J • •r L >> U +J X •FJ LA •r +J U i (O U O U +J ro U •FJ -0 N O U i •r U C ar i r i U U N r- O O N L O.0 Cl }t U +J r- U r- S- O O' o i 3 •r E r C I U ^ N U U O +J U 4- U U U^ N S +J LO L 4- N 0. U •r .0 +J > r` O C3• 7 r6 CO 1 r E N U +J R •r co O d• m 3 0) r_ 4-J O i U •r tr L- 4-3 m > ^ r 7 0 CT U X i +J 7 4- {� •r r � . w O C R4-) O O 4- O (n-0 4- LO r N S LA Cf *0 3 3 U +J O r N O L r N S- +J +J N r- L •r O - O 4- U +J E O v U L U U- r 0) 4-3 fO eC N U L a U U U >1 'O r C L 0-0 0. b 7 +J C .0 L r0 a< ro •r- i r6 U U U 'E O to •r' O •r g �CL.=Y U U+J-O n^ a to c LaJ N C S i co U r +J N C N O r +J CO 3 0 0 0 U - O S.. - +J U L U N C L (O O +> O O C • Ln 'D .0 C U) r ro 4- U .0 U •r r` U 3 f6 C to C O i r - O Ln o .0 ro •r U r C C U •r• U C i to U ^ U Ln r 0 Ln i i 0 ro N 4- r U\ 4- Z7 ro O 'D 3 E y •r O • L Q1 U U U E N N C C 4- +J 'Q L i ra -- o) 3 r 0 O O O► C F- U 0 C C N O U •r •r r4 d-) O •r rO O N O > U +J +J U ro U Mm C O U-0 ro U U M C • 3 •r U O ^ r +J rO i-0 010 b L S- .0 •.-O .0 O C U•r U U O U +J r Ln +J U 4J O 4J +J 'Q r •FJ L U C E •r N Cl to •r .0 M L +J r U C !-• U 7 E E L> m U •r •r 7 •r7 ro i U L U U U O +- Y O U O C .0 4- U O U .1-- X 0. L O .0 U •r +J 0 3 O Cl d -J U O 0- Cl U +J r > r rO M co s C U LO N •-+ C U co iN r O � r +J U N L CL C:r N U S- 0 O U C LU THE STATE °fALASKA GOVERNOR BILL WALKER Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-47 Permit to Drill Number: 217-077 Sundry Number: 318-196 Dear Mr. Myers: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax. 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. tL DATED this t4 'day of May, 2018. Sincerely, tol� 2� Hollis S. French Chair RBDM6Y4-YA1 17 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVED MAY 10 2018 0r3 s7 !118' AOG G 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ �qp emtion hptdow ❑ r'y c' Suspend NGr� wl p ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑+ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Resume Drilling_121 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑+ 1 Stratigraphic ❑ Service ❑ 217-077 3. Address: 6. API Number: 3800 Centerpoint Drive, Anchorage, AK 99503 50-029-23577-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D ' Will planned perforations require a spacing exception? Yes ❑ No MPU C-47 . 9. Property Designation (Lease Number): 10. Field/Pool(s): SHL ADL047434 / PH/BHL ADL047433 Milne Point Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,293' - 7,162' 6,385' 4,745' 2974 6,385' N/A Casing Length Size MO ND Burst Collapse Structural Conductor 151 16" 151' 151• Surface 6,590' 9-5/8" 6,590' 4,886' 5750 3090 Intermediate 165' T. 165' 165' 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,210'- 9,215' 6,702' - 6,704' 3-1/2" L-80 3,007' Packers and SSSV Type: N/A Packers and SSSV MD (ft) and ND (ft): N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑+ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/17/2016 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Monty Mars Contact Name: Joe En el Authorized Title: Drilling Manager Contact Email: Len B hilcor .Com Authorized Signature: — Date: - 1 0 - ZA Contact Phone: 777-8395 COMMISSION USE ONLY Conditions of approval: Notify Co io so that a repres may witness Sundry Number: b '�I Plug Integrity ❑ BOP Test// Mechanical Integrity Test ❑ Location Clearance ❑ Other: 'f 35G� /3 o / 7F .� �aiu �5 J l V q 9 `M RBDMS 1-//– 2018 � � L Post Initial Injection MIT Yes ❑ No ❑ �"'AA�1 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / o "–q Q7 /.(r,�,�,( /pec' I / /VT' (/ APPROVED BY C Approved by: COMMISSIONER THE COMMISSION Date: 7 I +(U o IGINAL �r1�� Form 10-403 Revised 4/2017 Approved applicatTSn is veld For 12 mo�tt Aske the date of approval. worm and Attachments in Duplicate MPC -47:8 5" x 9.875" Sidetrack Drilling Section Outline 5.10.2018 i 9-5/8" Kick Off Plug: 6,385' MD Tagged 7/23/17 3000psi PT 9-5/8" Shoe: 6,590' MD / 4,886' TVD HRZ: 9.665' MD / 6641' TVD Kalubik: 9,879' MD / 6,827' TVD Kuparuk D: 10,042' MD / 6969' TVD Kuparuk C: 10,218' MD / 7,123' TVD Kuparuk A: 10,400' MD / 7,282' TVD Kup A Base: 10,513' MD / 7,381' TVD Planned TD: 10,906' MD / 7,725' TVD Pre -rig prep PT 9-5/8" Casing t. 3000' PSI 30 Min • To confirm casing is isolated from OH • 3000 psi 30 min test Passed 7.23.2017 Drilling Operations: MIRU Innovation NU BOPE & Test Circulate out diesel freeze protect BOLDS. MU Landingjoint. Pull hanger to surface and LD same. MU 9-5/8" test packer to 3.5" Killstring RIH and set 9-5/8" test packer 2 stands below rig floor Test test packer from above to 1500 psi ND BOPE Remove Seaboard Wellhead System jl VI CameronM BS Ww^ NU BOPE & Test RIH and screw into test packer. Check for pressure Directional: Kick Off Build 3.5 DLS: 6,700' MD Hold 66 deg inc Drop 3.5 DLS: 8,600' MD Inc: 30 Azi:10 Hold t/ TD Unseat and POOH and LD workstring/test packer MU 8.5" Motor Kick Off BHA RIH, tag TOC, displace well t/ 9.5 ppg LSND ,.I-1 �f • Cement Plug Tagged at 6,385' MD (7.23.2017) 3-6%&CILSND Fluid Systan Mud weight �.@coslty ,pl� . Yldd Polar FH '-'MT HeHr LGS 9.5-10.8 1 40.53 1 15-25 14-25 9.0-10.0 <15 <11.0 <6% Drill down to shoe, and 20' of new hole POOH t. Casing Shoe `Perform FIT t. 13.0 ppg EMW Drill down to shoe, and kick off, -150-200' of new hole • Confirm Kick off with MWD Surveys, have gyro ready if magnetic interference is present • Ensure enough new hole is drilled to bury RSS & UR CBU POOH & LD BHA MU 8.5" x 9.875" RSS BHA w/ UR • Bit: NOV SK616M-11D, Under Reamer: NOV Anderreamer 9-7/8" RIH t. Bottom, drill until UR has cleared surface casing shoe by - 10' Ensure flow rate does not exceed MWD max with UR closed (UR flow diversion 8-10%) Drop ball and open UR, as per NOV Rep • Watch indications: pump pressure, turbine RPM • Perform pull test but do not ream back to shoe Drill t/ - 300' MD above HRZ, 9,365' MD (HRZ: 9,665' MD) • 9.5 ppg LSND 3.6%&QLSND Fluid System hind Wt(PM%bit vwosity. \ istosih Yield Point pH \tBi HPHT LGS 9.5-105 40-53 15.25 14-25 9.0-10.0 <15 ` <110 <640 • 550 - 600 gpm (200 ft/min AV: 590 gpm) • 120 rpm • WOB as necessary • Watch Torque and S&V, adjust parameters as necessary • Watch ECD model and trends for hole cleaning indication 9 Sweeps as needed • 6 rpm / Tau reading: 1-1.2x hole diameter — for hole cleaning and cuttings transport • Ensure sufficient inhibition for clays • Slowly stage up ROP to get a baseline for drilling ECDs and parameters with the under reamer • Circulate — 1-2 min at Kelly down before making connection to clean around BHA, full rate and RPM Circulate 2-3 BU, at full flow and full rpm Short Trip to casing shoe • Watch UR when POOH to casing shoe, when pumps are on, blades are out • Based upon hole conditions & hole cleaning, short trip can be omitted RIH t/ Bottom and increase MW to 10.5 ppg w. black products • Increased MW for wellbore/shale stability, based upon Polar Plot, Shale Drilling Best Practices and SLB MEM o HRZ drilled through at 30 deg Inc and 9 deg Az Drill 8-1/2" x 9-7/8" hole t/ TD —10,906' Mn • 10.5 ppg LSND with 6% Kcl & Black products • Ensure sufficient black product and increased inhibition is in mud system for drilling through shales • 550 - 600 gpm (200 ft/min AV: 590 gpm) • 120 rpm • WOB as necessary • Pump sweeps as needed, usually no longer effective at high hole angles • 6 rpm / Tau reading: 1-1.2x hole diameter—for hole cleaning and cuttings transport o Keep YP as low as possible, ensuring 6rpm reading is adequate • Watch and track ECD models and trends for hole cleaning indications • Keep ECD < Sppg above static MW, 11.5 ppg EMW max . o This is to reduce severity of pressure cycles on shales from pumps on/off, increase shale stability o IF necessary slow ROP, while maintain 550-600 gpm to keep ECDS below Max • Circulate — 1-2 min at Kelly down before making connection to clean BHA, full rate & RPM o This will facilitate hole cleaning • Do not backream on connections o This is to avoid an unnecessary agitation of the shale sections o If hole conditions dictate, slow ROP or circulate longer at connections • Slowly ramp pumps up and down to not shock formation • Slow in out and out slips • No dedicated Torque and Drag measurements below shales • Hard drilling/ Cap Rock has been seen at Kup D • TD to be called by Onsite Geologist, confirmed with Town Geologist and Drilling Engineer • Notes / Lesson Learned: o MPC -46 PB1 saw water influx (trapped injection pressure) from Kuparuk A, requiring 11.6 ppg to kill. Well also experienced large volumes of losses and ballooning, will be getting SBHP on C-4 o MPC -46 Saw hard drilling in Kup D MPC=w no signs of trapped injections pressure, confirming normal pressure in At TD, Drop ball and close UR CBU x3-4 at full rate and RPM • 600 gpm • 120 rpm • Alternate reciprocation depths to avoid creatine ledges & dropping inclination at TD in Kup A • Avoid performing a short trip and running back to bottom to minimize disturbance of the open shales • Ensure mud system is at 2% lubes after CBU at TO After hole is clean, weight up t/ 10.8 ppg • For shale stability • If possible, utilized spike fluid and weight up in .2/.3 ppg increments • Monitor ECD while weighting up and reduce flow to keep ECDs at or below drilling ECDs • Spot casing running pill: o TD to top of HRZ (with no pipe in hole) 0 12 ppb black product, graphite, 4% lube Pull OOH on elevators to above shales • String Speed: 500 fph max to keep swab pressures to a minimum for wellbore stability • If unable to pull on elevators, RIH 2-3 stands and establish circulation • Start BROOH slowly, high flow and rpm POOH, racking back stands • Follow TOOH Swab Schedule • Do not soft break connections on the way out of the hole, Hawk Jaw will be used to LDDP • For wellbore stability, this will minimize swab cycles seen on shales CBU before pulling BHA into shoe • Keep UR below shoe, as blades will be open while circulating Pull BHA into casing, no rotation or pumps POOH t/ BHA • LD DP t/ pipe shed • Do not RIH with open hole DP and soft break o To minimize shale OH time before getting casing to bottom o DP will be laid down after 7" cement is in place with Hawk Jaw LD BHA Change rams t. 7" Solids, and test RU WOT Volant and Cement"5 vel RIH with 7" 26# UP to TD (Spec Sheet Below) • 7" MUT: MIN —13280 ft -Ib, Opt —14750 ft -Ib, Max, 16230 ft -Ib • Centralization: 7" x 8.5" Centek S2, 1/jt to 500' Above Kuparuk C • 7" Baker ECP to be placed in between Kup A & C for added zonal isolation if Kup A is wet • RIH as per surge schedule o To ensure surge pressure do not exceed wellbore stability EMW o Slow in/out of slips • Monitor Drag while RIH, if necessary stop and CBU • CBU at 9-5/8" Shoe, 200' above HRZ, as necessary if losing SOW o Slowly stage pumps up to 7 bpm (15 min per .5 bbl) to not shock formation o Lesson Learned: Loss zone in Colville has been broken down at 12.5 EMW • Continue RIH to TO as per surge schedule o 7" casing will beset on slips to allow for rotation during cement job Circulate and Condition mud for cement job Pump single stage cement job through CRT Cement Swivel • This will eliminate downtime while PU Cement Head • Plugs will be loaded manually, using a 'push stick' to have clearance with CRT • As per AOGCC REg 20 AAC 25.030(d)(5), required TOC is 500' MD or 250' TVD above hydrocarbon bearing zone. o Asper C-47 wp13, required T is 9,548' MD• • Top Kup D: 10,048' MD D • 500' MD Above Kup D: 9,548' MD • 250' TVD Above Kup D: 9,770' MD • Cement Volumes with 25% OH Excess (more cement maybe pumped to ensure sufficient cement job is achieved while not exceeding ECD limits at Colville) Section: Calculation: Voll Vol (flt3) 9.88" OH x 7" Casing: (10,896'— 9:548`) x 0.04723 Wx 1.25 = 79.5 446.8 ft3 8.5" (pilot hole) Rat Hole: 10'x.0701 x 125 = .87 5 7" Shoe Track: 90'x.038 W= 3.44 193 Total Volume: 83.81 471 • Rotate and reciprocate during cement job if possible o Do not exceed Max Torque on 7" TXP (16,230 ft -Ib) Drop Plug and Dispalce with Rig Pumps • Target Displacement rate: 7 bpm • Monitor returns closely, ensure pits are strapped every 10 bbls of displacement and communicated with Co Rep. If losses are seen, reduce pump rate. • Do not over displace by more than 1.2 shoe track volume Bump plug with 500 psi over displacement pressure Inflate 7" Baker ECP as per Baker Rep Swap to Completion AFE i Cement Slurry System S�,fV System Density 15.8 Wgal Yield 1.16 ft3/& Mixed Water 5.04 tel/ • Rotate and reciprocate during cement job if possible o Do not exceed Max Torque on 7" TXP (16,230 ft -Ib) Drop Plug and Dispalce with Rig Pumps • Target Displacement rate: 7 bpm • Monitor returns closely, ensure pits are strapped every 10 bbls of displacement and communicated with Co Rep. If losses are seen, reduce pump rate. • Do not over displace by more than 1.2 shoe track volume Bump plug with 500 psi over displacement pressure Inflate 7" Baker ECP as per Baker Rep Swap to Completion AFE i RD Cementing equipment, Flush wellhead Observe 9-5/8" x 7" Annulus for a minimum of 3 hrs for no pressure or flow ND, Set slips on 7" casing, set packoff, RILDS. NU. Test void to 250/4000 for 10 min. MU 6-1/8" Cleanout BHA, RIH on 4" DP • Ensure Cement has reached 500 psi compressive strength prior to clean out run. Circulate wellbore with clean kill weight brine at max rate, rotate and reciprocate as needed • KWF Est "'9.8 ppg • Drill out any shoe track as needed PT 7" casing to 3000 psi f/ 30 min. POOH LD work string RU E -line & run CBL/VDL from PBTD to determine TOC. CBL/VDL will be across Kuparuk formation. RD E -line R/U and run 4-1/2" 12.6#/ft TXP-SR L-80 tubing / Frac String as per completion engineer • Est. Packer Depth: 9,886' MD. Final set depth to be confirmed after running CBL/VDL. Land tubing hanger. RILDS. Test tubing hanger, 500 psi low / 5000 psi high Freeze protect [A and tubing Drop Ball and Rod and set Packer PT IA t/ 3500 psi while monitoring tubing to identify any packer leaks Bullhead diesel freeze protect down 9-5/8" x 7" annulus, do not allow flow back Install BPV ND BOPE NU Tree & PT. RDMO Innovation Note: A separate 10-403 sundry will be submitted for post rig well work (perforation, fracture stimulation and tubing swap) C -Pad Data Sheet Excerpt: Y ISeabee (Colville) Interval: PutrnLuiMYin"eroa". slnlma ne tlry NP at fstl. YuI HNiu-I H,9 atm). Tro My In uruveMlurSil"a[Hng.MHPZ FryeS9mePe"4a."r M.a 6.008' NRZ: MvnN Rmc.rs.e z"—, v.y mn. EUL 1K. s1uY. "Bmt. 9me Harte rock V Trm(.exnl.clsn.wuiMa Nlop wlwz TePNPZ V TShale: 6".• KalubikIt i.lCo"rr"aMKI9 ..I"m a�HHI- x -n - EA.' ".� v �nea.em l+sn minim Ka'n�u1R'Num,Jl KaWbik V fan]a czuln9lM.ver. we S..FNO.UNCEL N. Ems. IUWeIR suis. sEE DVERSREssuRE suMeaav .1KPminm,,. rca1l Kuparuk Interval: R\ "D"Shale Tro snwtl"+mp KlrwMr.eAM"n emH MM' D Frp.niatle Yep fb[4'. KUPAR11NWER- rcall 691.' PREssuNE MY DccuR IN THE OSHAIE.� IOA1I LCD o CSAND: v.e.Ime, enM.. ryw.ra OIL BEARING TARGET FOR EAETERN GiOD. 5DEGREE511MFT. HOLE SMOOTHNESS ISNERYIMPORTANT. NGHTIPACKING OFF INTERMEDIATE CASING: CAT. 7-518" CASING STOPPED AT 94131'1155 1NABLE TO RUN DEEPER HAD TO PULL. 'OOR HOLE CLEANING, INSUFFICIENT ;IRCULATING. MADE HOLE OPENER RUN AN ISERVOIR OVER -PRESSURE RESULT WELL FLOWS AFTER PENETRATING "=nnnl ": P.N ILL vn ............ .... zp sp ap H. tto 1aE 10.. u TRANSITION INTERVAL / KALUBIK, "D" SHALE (CAP ROCK): (+/" 6700-6900'): OVER PRESSURE/WELL FLOWING: C -PAD AND OTHER KUPARUK PAD INJECTION WELLS HAVE IN SOME CASES PRESSURED UP THE KALUBIK & KUPARUK D SHALE AS WELL AS THE KUPARUK SANDS. SEE BHPIH2S and HYDRAULIC MANAGEMENT TABLE FOR DATA (upper left). At elevated injection pressures (some above 5000 psi BHP), vertical fracturing reaches into the ''D"cap rock shale and the Kalubik shale. Both of these formations contain clean silt intervals with sufficient porosity to become pressurized. As the injection well pressure lowers the vertical fractures close and the pressure is trapped in the silt intervals in the D shale and Kalubik. Most of the time gas is associated with these over -pressured intervals and as a result gas (gas cut mud) is seen at the surface when the flow is shut in and circulated out. Mud weights as high as 13.2 ppg (C-22) and 13.8 ppg (C-26) have been required on the C -Pad wells drilling into these over -pressure intervals. Use caution when drilling into the Kalubik and Kuparuk D Shale. BE certain the latest up to date analysis has been made by the asset to estimate what over -pressure if any may be encountered. STUCK PIPE: Other pads have had STUCK PIPE at the approximate interface between the Kalubik and OShale "Cap Rock". Be very careful and alert to the possibilities of getting stuck in this interval. Be sure to ream and short trip this interval to keep it in good shape. Also, be cautious on pulling up into this interval if tight holelpacking off develops deeper. Also be aware that a change in BHA after drilling this interval may be troublesome. 4. Use Of Lubricants Yields Good Results: C-25 demonstrated that the use of lubricants (Lubelex, TorgTrim II, EP Mud Lube) was beneficial in maintaining lower torque and successfully drilling a high angle (+1.70 deg) long reach (12,000 ft departure) well. 5. OVER -PRESSURED KUPARUK INTERVALS, WELL FLOWINGIWELL KICK: Be prepared for higher than normal reservoir pressures on C -Pad. Of the last 12 wells drilled, 10 wells encountered over -pressure and / required from 10.6 to 13.8 ppg to stop reservoir flows following a kick and stabilize the wells. The over -pressure was a result of offset injection wells some with BHP's in excess of 5000 psi. Depending on the predicted over -pressure it may be necessaryto top set"the Kuparuk reservoir with casing. C-24 (2001) had gas cut mud after drilling to TO on bottoms up but no well flow or kick. Mud weight was increased to 11.9 ppg. Get the latest information on all offset injection wells for planning new C -Pad wells. C-42 (2004): The prognosed sub -normal Kuparuk pressure of 6.3 to 7.7 ppg was significantly under what was actually encountered. The well flowed with a 9.0 ppg mud weight while POOH. After running back to bottom and circulating out gas cut mud the mud weight had to be increased to 9.7 ppg. Although this was not a highly over -pressured well, it shows the importance of accurate reservoir pressure predictions. 6. OVERPRESSURED KALUBIK AND D SHALE ABOVE THE KUPARUK: c -PAD AND OTHER KUPARUK PAD INJECTION WELLS HAVE IN SOME CASES PRESSURED UP THE KALUBIK AND KUPARUK D SHALE IN , ADDITION TO THE KUPARUK SANDS. SEE LIST OF WELLS AND BOTTOM HOLE PRESSURE DATA FOR SPECIFIC DATA. At elevated injection pressures (some above 5000 psi BHP), vertical fracturing reaches intothe -D- cap rock shale an tithe Kalubik shale. Both of these formations contain clean silt intervals with sufficient porosity to become pressurized. If the injection well pressure decreases, the vertical fractures close and the pressure is trapped in the sift intervals in the D shale and Kalubik. Most of the time gas is associated with these over -pressured intervals and as a result gas (gas cut mud) is seen at the surface when the flow is shut in and circulated out. Mud weights as high as 13.2 ppg (C-22),13.8 ppg (C-26) and 13.0 ppg (C.12A) have been required on the C -Pad wells drilling into these over -pressure intervals. Use caution when drilling into the Kalubik and Kuparuk D Shale. Be certain the latest up to date analysis has been made by the asset to estimate what overpressure if any maybe encountered. Remember that lost returns and sometimes -breathing" maybe associated with the higher mud weights. If necessary top set intermediate casing into the upper Kalubik prior to drilling ahead with higher mud weights. C-42(2004): With over -pressure predicted in the Kalubik silts and a normally pressured Kuparuk. this was the first well to utilize a special casinglliner design to accomodate all reservoir pressure issues _ 10.3/4" surface casing, 7.516" and 5-12" intermediate casing and liner and 3.12" production liner, The HRZ and top part of the Kalubik interval was top set with the first intermediate 7.58" casing string set above the Kalubik Gamma Marker isolating weaker shallower zones in the Seabee. This allowed successfully drilling the pressured part of the Kalubik with elevated mud weights (12.9 ppg) and top setting in the Kuparuk with a 5-112 "liner. Wththe main over -pressure behind casing, the Kuparuk was then drilled with a normal (9.0 ppg) mud weight. However, while POOH at 5132, the well was not taking proper fill and was flawing. Upon running back to bottom gas cut mud was circulated out and the mud weight had to be increased to 9.7 ppg. A 3-12" production liner was then run. This is another lesson of (1) Kuparuk reservoir pressure being higher than predicted and (2) the over -pressure not showing itself until already drilling thru the zone and while POOH. Make frequent monitor stops for well flowing checks. C43 (2004) proved the flexibility of the casing program used on C-42 by again setting intermediate casing in the Colville. drilling lojust above the high pressured silts in the Kalubik and running an open hole FIT and it successful drilling both the Kalubik and production interval to TO with the required mud weight eliminating the second intermediate liner (12.3.12.5 ppg for C-43). 7. LOST RETURNS - "BREATHING' - 8-112" hole & Tr Casing: 15 wells on C -Pad have experienced from partial to full loss of returns while running, circulating and cementing production casing. Three other wells experienced similar lost returns while setting intermediate casing strings. Some of these wells also experienced 'breathing" (the well flowing back) after finshingthe cement job, See list of wells with details render DRILLING DATA SUMMARY, PRODUCTION LOST CIRCULATION - BREATHING. Most of the recent wells experiencing lost returns was a result of the higher mud weights required to control the reservoir over -pressure. Although surface casing was set deep below the Schrader Bluff, faults in the production interval or weak sands in the Seabee (Colville) probably broke down and took the fluid during casing jobs. Be prepared for the possibility of the casing annulus flowing after finishing displacing the cement (bumping the plug). CONTINUED TO THE RIGHT Production Interval: KUPARUK (CONT'D) (+1- 6900-7200'): TIGHT HOLE (CONTINUED): On C-261-1 (2003, CT sidetrack): This wall experienced considerable trouble attempting to build incliretion and drill in the Kuparuk B shale. The rig continuously had problems returning back to the depth just drilled and having to open hole sidetrack due to the instability of this shale intervai. See Sheet2 LOST CIRCULATION I "BREATHING"ll: C-23 (1996 well) had some "breathing" after drilling to TD, losing mud while circulating and then getting it back while pulling out of the hole to run 7" casing. Drillpipe was run back to TD and the well circulated and stabilLmd. C391 also experienced breathing after increasing the mud wt to 11.2 after a well flow. C -39i gained back 150 bbis after losing 240 bbis. After running/cementing the 7" casing in C -39i (losing 240 bbis), the annulus flowed, requiring bull heading 160 bbis down the 7" X 9.5/8" annulus. C -36i did not report lost returns while drilling but had both lost returns and breathing on the casing job. There was also lost returns (30 bph) on C -12A after increasing the mud wt to 12.7 ppg following a well flow. C-24 reported minor lost returns during RFT wireline operations. On C-261-1 (2003, CTsidetrack): Had 7to20bph losses decompletingthe well and 3to4bph losses drilling the horizontal interval. Recent 2006 Sidetrack C -28A: Directionally drilled to 8895 (6815 tvd), crossed fault, hole seeping 15-20 bph, treated w/ LCM, losses slowed to 3-5 bph. Ran and cemented 3-112" liner with full returns. Nearby L and F Pads have also experienced lost circulation I return fluid back problems (breathing) on long reach wells. Be prepared to experience this on high angle long reach wells (ERD) on C -Pad. Normally, the loss of fluid occurs as the well approaches the cap rock, at higher angles and as the ECD exceeds 9.9 to 10.1 ppg. As the well is further weighted up to drill the Kuparuk the loss• es increase. Several wells an those two pads have lost significant fluid while running and cementing 7" and then began flowing back after pumping the plug down. (See C39i and C-361 below). Be prepared for lost returns while running and cementing 7" casing!!! SEE BELOW. Atotal of 16 wells on C -Pad have experienced lost returns during the production casing jobs, some of them also experiencing breathing where the annulus bowed following the cementing jobs. WELL RUN'G CIRC'G CMTG REMARKS C-1 LR LR LR 15 bbis returns on first stage, partial to full 2nd stage. C-2 OK OK PLR 11 bbis lost after ECP set due to high pressure. C-5 OK LR ? LR Recip'g C-6 LR LR LR No returns after joint #106 C-7 LR PR LR Packed off after 35 bbis around shoe. C-8 50% off & on OK C-14 PLR ? OK C-17 OK LR LR Cement thickened early, ECP's set purr ped away 47 bbis. C-19 LR LR ? C-22 OK PLR(35) PLR(42) Intermediate casing set at 6522 ss C-26 LR LR OK Intermediate top set string. Lost 50 bbis running and 88 bbis circulating. C-23 LR LR OK 60 bbis running. 150 bbis circulating C-28 OK OK LR 85 bbis while mixing1displacing. C -39i PLR PLR OK Lost 215 bbis on job, annulus flowing following job, had to bullhead 160 bbis 11.5 ppg mud down annulus. C -36i PVA LR LR Lost 150 bbls establishing circulation and 500 bbis cementing. Annulus flowed back, SICP 172 psi, moni tored until flow stopped. C -12A LR LR LR 4-112" intermediate liner. Lost 26 bbis running, 108 bbis circulating liner and 50 %while cementing. Legend: LR -lost returns: PLR=partial lost returns Rnn Wull Snm mnrf as nn Rha # 7 MPU C-47 Wellhead Schematic MPC -47 DATE 5-3-18 PROPOSED Tree Cap. Chis style, 4 35" ACME 4 1/16• SK, FE,DD L -U PN A33880 -0D3 SN Tbg Hgr, Cameron, 11 x 2 7/8" EUE BOX top and bottom, 21/2" "H" BPV,ported for 2 ea 3/ 8" Control line, w/ 3' pup L-U,DD-NL, PN 13334136-0002 SN 11 x 7, Cameron, Slip casing hanger, PN mo Csg Hgr, Seaboard 5-2213 5/8 x 9 5/8" Slip type hanger LU,DD-NL PN A16232-001 SN Swabvalve Cameron, Model FL, 4 1/16" SK, FE,EE„L-U PN Swabvalve Cameron, Model FL, 41/16” SK, FE,EE„L-U,L-U PN 5N 5SV valve Cameron, Model TO F44 I/1G' SK, FE,EE„L-U ,L- U PN 3 SN Swab valve Cameron, Model FL, 41/16” SK, FE,EE„L-U,L-U PN SN API 11” SK API ll SK " Ili GRADE is 3" below flane face of starter head TXP® BTC ...-051092018 OWide Nameter 7.000n Win. Wall 07.5°% LarnaOcm b (:.Ml in. GEOMETRY lSR in. rnfamss 5 JI Grade LBO GO& NtlnWal W 7d in. P in L1tipM M 0zfi Type i 6.151 ir. Wats TOicbLme O>mn Connect.. 00 REGULAR Plav Eno Waget 25.69 RxR WTolerance RPI optm CWPLMG PIPE BODY Crmp2sann Et.a 100% CPmpes S gW O010 .Im Baily. Red 1st Band, Red Grade LBO Type Grik API Standard 1stlr lkown : Bail: ea&jY dStrenpli MOIAa Mz M Y.W na'm 2 BarA - Brown Co . 5110IW Type Casing wle - 3Ld d_- MAKE-UP TORQUES dfi PIPE BODY DATA 7.050 N. C P!IN L -19M 10100 in. LarnaOcm b (:.Ml in. GEOMETRY lSR in. TXrtaQspern 5 UrtnMtiM OD CNIOn REGULAR NtlnWal W 7d in. P in L1tipM M 0zfi 0n1 6.151 ir. Na.�iat lO 6 in. WYIITNNress &M u. Plav Eno Waget 25.69 RxR WTolerance RPI Crmp2sann Et.a 100% CPmpes S gW O010 .Im M. Al.w8mC, 52'�103It PERFORMANCE les ea&jY dStrenpli MOIAa Mz M Y.W na'm %Ws PoD pai Co . 5110IW CONNECTION DATA GEOMETRY Cemrt .m 7.050 N. C P!IN L -19M 10100 in. LarnaOcm b (:.Ml in. alakenp Loss lSR in. TXrtaQspern 5 UrtnMtiM OD CNIOn REGULAR PERFORMANCE Tsrogn C-Ricienry fp0.0 °n Jo:"ieli Sex,JtF WI.000atOW InLe Pressure 7310.000:2.. Crmp2sann Et.a 100% CPmpes S gW O010 .Im M. Al.w8mC, 52'�103It les E�eemN Pmsu+e Capxiry 5!10.000 Psi MAKE-UP TORQUES M'menum 1f26MfrNs o{timmm 167 ft Mawr. 16230 P, -Ips OPERATION LIMIT TORQUES OpenTg Taryue 2M0Wf Yitl Tq. 236011- n Hii.p AI.A., LLC KB Elcv .\hove Sea Level: 41.7'/GL Elev: 15.2' 9-5/8" 590 MD 186' TVD 7" 3-1/2" TOC tagged L 6,385' MD ill SCHEMATIC Milne Point Unit Well: MPC -47 PTD: 217-077 API: 50-029-23577-00-00 Top 7" 7015' MD / 5,185' TVD IFWFI. RV DETAIL No. Item Top MD CASING DETAIL 9,250 2Cement Retainer 9,160 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16" Conductor 164/A-1068/Weld N/A Surface 151' N/A Surface 40/L-80/DWC/C 8.75" Surface 6,590' 0.0758 7" Fish Intermediate 26/L-80/Hyd 563 6.151" 7,015' 9,510' 0.0383 7" Intermediate 26/L-80/HTTC 6.151" Surface 165' 0.0383 TUBING DETAIL 3-1/2" Tubing 9.3/L-80/8RND 2.922" 1 Surface I 3,007' 1 0.008 Top 7" 7015' MD / 5,185' TVD IFWFI. RV DETAIL No. Item Top MD 1 CIBP 9,250 2Cement Retainer 9,160 3 Composite Plug 7,108 OPEN HOLE / PROPOSED CEMENT DETAIL Conductor Driven 12-1/4" 1st stage 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg 9-7/8" x 7" Squeeze 384.9 bbl 15.8 Class G Above Cant Retainer 3.3 bbl 15.8 Class G Kick Off Plug 64 bbl 15.8 Class G PERFORATION DETAIL No. Btm MO Top MD 1 9,215 1 9,215 NL Bottom 7" 9,510 MD / 6,890' TVD 8-1/2" x 9-7/8" 10,293' MD / 7,162' TVD GENERAL WELL INFO WELL INCLINATION DETAIL PBTD=6,390'MD/t4,745'TVD API: 50-029-23577-00-00 KOP @ 326' TD = 10'293 MD / 7,162'TVD Drilled and Cased by Innovation —July 14, 2017 Max Hole Angle = 85 deg. @ 10,293 MD Max Deviation: SS° Updated by 1PE 7/19/17 K Hileprp Alpha, LLC TD=10,906 (MD) /TD = 7,7250W) PBTD=±10,800' (MD) / PBTD=±7,632'(1VD) Proposed Frac String Schematic TREE & WELLHEAD Milne Point Unit Well: MPU C-47 PTD: 217-077 API: 50-029-23577-00-00 Tree 3-1/8" 5M Wellhead Seaboard Weir, w/11" x SM top flange 8-1/2" 3-1/2" Tubing Hanger OPEN HOLE / CEMENT DETAIL 12-1/4" Stg 1— Lead 700 sx (308 bbls) / Tail 295 sx (61 bbls) —67 bbl returns Wt/ Grade/ Conn Stg 2 — Lead 335 sx (259 bbls) / Tail 175 sx (36 bbls) —185 bbl returns 8-1/2" 1 83 bbl 15.8ppg Class "G" in a 8-1/2" x 9-7/8" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 16" Conductor 164/A-106B/Weld N/A Surface 151' 9-5/8" Surface 40/L-80/DWC/C 8.835" Surface 6,590' 7" Production 26/L-80/TXP SR 6.276" Surface 10,906' TUBING DETAIL 4-1/2" 1 Tubing 12.6 / L-80 / TXP SR 1 3,833"7 Surface I ±10,100' WELL INCLINATION DETAIL KOP@100'MD Max Hole Angle = 66.15° @ 7,891' MD JEWELRY DETAIL No Depth ID Item 1 ±9,875' 3.456 4-1/2" RN Nipple 2 ±9,886' 3.880 4.5 X 7" Premier Packer 3 ±9,932' 3.880 Auto Fill Sub & Mirage Plug 4 ±10,100' 3.958 Mule Shoe — Btm @ 10,100' 5 ±10,300 - External Casing Packer PROPOSED PERFORATION INTERVALS Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status KupC 10,219' 1 10,244' 7,124' 7,146' 25 TBD Proposed KupA 10,400' 1 10,513' 7,282' 7,382' 113' TBD Proposed Revised by: CD 4/20/2018 nProposed Completion Schematic Hilcuro Alaska, LLC KB Elev.: 41.7 / GL Elev.: 75.2' TD =10,906' (MD) / TD = 7,725'(TVD) PBTD =±10,800' (ND) / PBTD=±7,63XM) TREE & WELLHEAD Milne Point Unit Well: MPU C-47 PTD: 217-077 API: 50-029-23577-00-00 Tree 3-1/8" SM 8-1/2" Seaboard Weir, w/11"x SM top flange Wellhead 3-1/2" Tubing Hanger OPEN HOLE/ CEMENT DETAIL 12-1/4" Stg 1— Lead 700 sx (308 bbls) / Tail 295 sx (61 bbls)— 67 bbl returns Stg 2 — Lead 335 sx (259 bbls) / Tail 175 sx (36 bbls) —185 bbl returns 8-1/2" 1 83 bbl 15.8ppg Class "G" in a 8-1/2" x 9-7/8" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 16" Conductor 164/A-306B/Weld N/A Surface 151' 9-5/8"Surface ±4,106' 40/L-80/DWC/C 8.835 Surface 6,590' 7" Production 26/L-80/TXPSR 6.276- Surface 10,906' TUBING DETAIL 2-7/8" 1 Tubing 6.4/13Cr-85/JFE Bear 2.441" Surface ±10,100' WELL INCLINATION DETAIL KOP @ 100' MD Max Hole Angle = 66.15° F7,891' MD PROPOSED JEWELRY DETAIL No Depth ID Item 1 ±2,273' 2.441" STA 11: 2-7/8" 13Cr80 SPMO-1.0M GLM (12/64" Dome) 2 13,457' 2.441" STA 10: 2-7/8" 13Cr805PMO-1.0M GLM (12/64" Dome) 3 ±4,106' 2.441" STA 9: 2-7/8" 13Cr80 SPMO-1.OM GLM (12/64" Dome) 4 ±4,786' 2.441" STA 8: 2-7/8" 13Cr80 SPMO-S.OM GLM (16/64" SO) 5 ±5,465' 2.441" STA 7:2-7/8"13Cr8o SPMO-1.OM GLM (Dummy Valve) 6 ±6,334' 2.441" STA 6:2-7/8" 13Cr80 SPMO-1.01M GLM (Dummy Valve) 7 ±7,204' 2.441" STA 5: 2-7/8" 13Cr80 SPMO-S.OM GLM (Dummy Valve) 8 ±7,945' 2.441" STA 4: 2-7/8" 13Cr80 SPMO-1.0M GLM (Dummy Valve) 9 ±8,657 2.441" STA 3:2-7/8"13Cr80 SPMO-1.0M GLM (Dummy Valve) 10 ±9,275' 2.441" STA 2:2-7/8" 13Cr80 SPMO-1.01A GLM (Dummy Valve) 11 ±9,733' 2.441" STA 1: 2-7/8" 13Cr80 SPMO-1.01A GLM (Dummy Valve) 12 ±9,784' 2.313" 2-7/8" 9Cr XD Sliding Sleeve 13 ±9,831' 2.412" 2-7/8" 13Cr-80 Pressure Intake Gauge (8,494' TVD BKB) 14 ±9,909' 2.313" 2-7/8" 9Cr X Profile 15 ±9,920' 2.360" 7" x 2-7/8" 13Cr-80 PHIL Hydraulic Retrievable Packer 16 ±9,968' --i .205" 2-7/8" 9Cr XN Profile (2.205" No -Go) 17 ±10,100' 2.441" 2-7/8"WLEG 188 ±10,300 - External Casing Packer PROPOSED PERFORATION INTERVALS Sand Top (MD) Btnn (MD) Top (TVD) Btm (TVD) FT Date Status KupC 10,219' 10,244' 7,124' 7,146' 25 TBD Proposed Kup A 10,400' 10,513' 7,282' 7,382' 113' TBD Proposed GENERAL WELL INFO API: 50-029-23576-00-00 Drilled Cased by Innovation #1 Date TBD Revised by: CJD 4/18/2018 Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-47 Plan: MPU C-47 Plan: MPU C-47 wp13 Standard Proposal Report 27 March, 2018 HALLIBURTON Sperry Drilling Services NALLIBURTON Project: Milne Point Site: M Pt C Pad -1500 Well: MPU C-47 Wellbore: Plan: MPU C-47 � Design: Design MPU C-47 wp13 I Z 0 19 F B West( -)/East(+) (1500 uslUin) 1500 2250 0003 MPU G7 "13 Vertical Section at 39.25° (1500 usftfin) �pJ V51 MMPJ HALLIBURTON Sperry Drilling Project: Milne Point Site: MPtCPad Well: MPU C-47 Wellbore: Plan: MPUC-47 Design: MPU C-47 wp13 DDI=6.345 H 9 5/8" HRZ Hilmrp Alaska, LLC REFERENCE INFORMATION Calculation Method. Minimum Curvature Coordinate VD) Reference: Well MPU C47 True NOM e Error System: ISCWSA Vertical JVD) Reference: MPU raC4@W 7 Actual42.09us8 Scan Method: Closest Approach 30 Measured Depth Reference: MPU C-07 Actual @ 42.usfi Error Surface: Elliptical Comb Warning Method: Error Ratio Calwlation Method: Minimum Curvature SECTION DETAILS Sec MD Inc Azi TVD +N/ -S +E/ -W Dleg TFace VSect Target 1 6554.36 46.33 55.66 4861.57 2233.48 3428.16 0.00 0.00 3898.69 2 6600.00 46.15 56.06 4893.14 2251.98 3455.44 0.75 122.06 3930.28 3 7890.97 66.15 6.15 5640.41 3145.67 3929.70 3.50 -60.55 4922.40 4 8581.05 66.15 6.15 5919.40 3773.21 3997.29 0.00 0.00 5451.10 5 9616.76 30.00 9.92 6600.09 4524.41 4095.94 3.50 176.81 6095.21 6 9916.76 30.00 9.92 6859.90 4672.17 4121.78 0.00 0.00 6225.98 MPU C-47 lnterp Tgt wpl3 7 9949.79 29.01 9.92 6888.65 4688.19 4124.58 3.00 -179.96 6240.16 8 10222.44 29.01 9.92 7127.09 4818.44 4147.36 0.00 0.00 6355.43 MPU C-47 wp13 Cot 9 10906.12 29.01 9.92 7725.00 5145.03 4204.47 0.00 0.00 6644.46 End Dir : 9616.76' MD, 6600.09' ND C-47 lnterp Tgt wpl3 _ _ _ _ _ _ _\PB1 CASING DETAILS WELL DETAILS: MPU C47 KLGM _ _ _ _ _ _ _ _ - _ - _ _ _ - �°° KUPD 9949.79' MD, 6888.65'ND Ground Level: 15.15 MPU C47 wpl3 CP7 .- - ---_ ----_- _ TVD TVDSS MD Size +N/ -S +E/ -W Northing Basting Latittude LongAutle _ - _ _ _ KUPA2- _- _- _- 4893.14 4851.05 6600.00 95/81, 0.00 0.00 6029004.74 558156.85 70' 29' 23.490 N 149'31'2 6.533 W 7725.00 7682.91 10906.12 7" x 8 1/2" /2" V\"4o9°T SURVEY PROGRAM Depth From Depth To SurveylPlan Tool 100.00 728.00 SRGSS (MPU G47 PBI) 2_GyroSR-GSS Start Dir 3.5°/100' : 6600' MD, 4893.14'TVD 788.64 6554.36 MWD+IFR2+10S+sag (1) (MPU C47 PB1) 2 MWD+IFR2+MS+Seg 6554.36 10906.12 MPU G47 w l3 (Plan: MPU C47) 2_MWD+IFR2+MS+Sag °O 05- FORMATION TOP DETAILS TVDPath TVDssPam MDPath Formation 4785.09 4743.00 6443.27 SB BASE 6641.09 659900 9664.10 HR2 6731.09 668900 9768.02 KLB O° 6827.09 6785.00 9878.87 KLGM 6969.09 6927.00 10041.77 KUP_D 7124.09 7082.00 10219.01 KUP C O 7146.09 7104.00 10244.16 KUP B6 End Dir : 7890.97' MD, 5640.41' ND 7146.09 7104.00 10244.16 KUP 87 7146.09 7104.00 10244.16 KUP_LCU 7283.09 7241.00 10400.82 KUP_All Ah 7304.09 7262.00 10424.83 KUP_A2 7355.09 731300 10483.14 KUP Al 7382.09 7340.00 10514.02 KUP A BASE ° Start Dir 3.5-/100': 8581.05' MD, 5919.4'ND . °41 End Dir : 9616.76' MD, 6600.09' ND Total Depth : 10906.12' MD, 7725' ND 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 625D 6500 6750 7000 7250 Vertical Section at 39.25° (500 usf lin) C-47 lnterp Tgt wpl3 _ _ _ _ _ _ _\PB1 KLB r 3°/100':9916.76'MD, 6859.9'ND KLGM _ _ _ _ _ _ _ _ - _ - _ _ _ - �°° KUPD 9949.79' MD, 6888.65'ND MPU C47 wpl3 CP7 .- - ---_ ----_- _ - - - - --=-_ KUP_B6KUPB7KUPLCU KUPA3 _ - _ _ _ KUPA2- _- _- _- _-_ _-_- - � - .._ - - - - - - - - - - KUP_A1 MKUPABASE MPU C-47 wp13 /2" V\"4o9°T Total Depth : 10906.12' MD, 7725' ND 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 625D 6500 6750 7000 7250 Vertical Section at 39.25° (500 usf lin) HALLIBURTON Project: Milne Point ev.•ry PHIII o Site: M Pt C Pad ® Well: MPU C-47 Wellbore: Plan: MPU C-47 Plan: MPU C47 wp13 c 4= I WELL DEfAUS: MPU C47 Ground Level: 15.15 ff'N/�S +F�w xo�a . Raenng Uanwe wn®n,ae 0.00 60291104.]4 558156.85 7V 29'23.490N 149°31'28.533W REFERENCE INFORMATION CM1ONIn81e (NIE) Reference: Well MPU C47, Tme Nodh W"1-1(TW) Reference: MPU C47 A u.l A 42 Wnft West( -)/East(+) (400 Wthn) HALLIBURTON Database: Sperry EDM - NORTH US+CANADA Company: Hilcorp Alaska, LLC Project Milne Point Site: M Pt C Pad Well: MPU C47 Wellbore: Plan: MPU C-47 Design: MPU C47 wp13 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well MPU C-47 MPU C47 Actual @ 42.09usft MPU C-47 Actual @ 42.09usft True 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 C Pad, TR -13-10 MPU C47 Site Position: Northing: 6,027,347.71 usft Latitude: 700 29'7.200 N From: Map Easting: 558,058.04 usft Longitude: 149° 31'31.821 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.45 ' Well MPU C47 Audit Notes: Well Position +N/ -S 0.00 usft Northing: 6,029,004.74 usft Latitude: 70° 29'23.490 N +N/ -S +E1 -W 0.00 usft Easting: 558,156.85 usft Longitude: 149° 31'28.533 W Position Uncertainty 0.00 0.00 usft Wellhead Elevation: 15.15 usft Ground Level: 15.15 usft +E/ -W Rate Rate Rate Tool Face (usft) (°) Wellbore Plan: MPU C-47 usft (usft) (usft) (°/100usft) (°/100usft) Magnetics Model Name 6,554.36 Sample Data Declination Dip Angle Field Strength 2,23348 3,428.16 000 0.00 (°) I°) (nT) 46.15 BGGM2017 5/1/2018 1220 81.02 57,481 Design MPU C47 wp13 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,554.36 Vertical Section: Depth From (ND) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) Turn 26.94 0.00 0.00 39.25 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) (0/100usft) ( ) 6,554.36 46.33 55.66 4,861.57 4,81948 2,23348 3,428.16 000 0.00 0.00 0.00 6,600.00 46.15 56,06 4,893.14 4,851.05 2,251.98 3,455.44 0.75 -0.39 0.88 122.06 7,890.97 66.15 6.15 5,640.41 5,598.32 3,145.67 3,929.70 3.50 1.55 -3.87 -80.55 8,581.05 66.15 6.15 5,919.40 5,877.31 3,773.21 3,997.29 0.00 0.00 0.00 0.00 9,616.76 30.00 9.92 6,600.09 6,558.00 4,524.41 4,095.94 3.50 -3.49 0.36 176.81 9,916.76 30.00 9.92 6,859.90 6.817.81 4,672.17 4,121.78 0.00 0.00 0.00 0.00 9,949.79 29.01 9.92 6,888.65 6,846.56 4,688.19 4,124.58 3.00 -3.00 0.00 -179.96 10,222.44 29.01 9.92 7,127.09 7,085.00 4,818.44 4,147.36 0.00 0.00 0.00 0.00 10,906.12 29.01 9.92 7,725.00 7,682.91 5,145.03 4,204.47 0.00 0.00 0.00 0.00 3127/2016 6:54:45PM Page 2 COMPASS 5000.1 Build 81E Halliburton HALLI B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Co-ordinate Reference: Well MPU C-47 Company: Hilcorp Alaska, LLC TVD Reference: MPU C-47 Actual @ 42.09usft Project: Milne Point MD Reference: MPU C47 Actual @ 42.09usft Site: M PIC Pad North Reference: True Well: MPU C-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan: MPU C-47 Depth Inclination Design: MPU C-47 wpl3 TVDss +N/ -S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (^) (_) (usft) usft (usft) (usft) (usft) (usft) 57.91 100.00 0.46 30.95 100.00 57.91 0.25 0.15 6,029,004.99 558,157.00 0.00 0.29 200.00 0.54 2.72 200.00 157.91 107 0.38 6,029,005.81 558,157.22 0.26 1.07 300.00 1.46 51.26 299.98 257.89 2.27 1.21 6,029,007.02 558,158.04 1.17 2.52 400.00 4.96 60.80 399.83 357.74 4.79 5.82 6,029,009.58 558,162.64 3.53 7.40 500.00 8.36 66.98 499.08 456.99 10.20 16.58 6,029,015.07 558,173.35 347 18.39 600.00 9.56 71.46 597.86 555.77 15.48 31.24 6,029,020.46 558,187.96 1.39 31.75 700.00 12.67 70.95 696.03 653.94 21.86 49.12 6,029,026.98 558,205.80 3.11 48.01 800.00 15.98 75.17 792.88 750.79 29.02 72.89 6,029,034.33 558,229.51 3.47 68.60 900.00 19.46 74.16 888.03 845.94 37.06 102.55 6,029,042.59 558,259.10 3.49 93.59 1,000.00 23.60 73.22 981.15 939.06 47.21 137.50 6,029,053.02 558,293.97 4.16 123.56 1,100.00 29.08 71.11 1,070.77 1,028.68 60.84 179.62 6,029,066.98 558,335.98 5.56 160.77 1,200.00 34.47 69.30 1,155.85 1,113.76 78.71 228.96 6,029,085.23 558,385.17 5.47 205.83 1,300.00 39.56 68.40 1,235.50 1,193.41 100.44 285.33 6,029,107,40 558,441.36 5.11 258.32 1,400.00 43.49 62.10 1,310.31 1,268.22 127.75 345.75 6,029,135.18 558,501.55 5.74 317.70 1,500.00 44.94 57.51 1,381.38 1,339.29 163.50 406.31 6,029,171.39 556,561.83 3.51 383.70 1,600.00 43.84 55.23 1,453.15 1,411.06 202.30 464.12 6,029,210.65 558,619.33 1.94 450.33 1,700.00 43.90 55.86 1,525.61 1,483.52 240.99 521.14 6,029,249.78 558,676.04 0.44 516.37 1,800.00 45.47 54.91 1,596.56 1,554.47 281.15 579.04 6,029,290.39 558,733.62 1.70 584.11 1,900.00 44.20 56.01 1,667.20 1,625.11 321.47 637.22 6,029,331.15 558,791.47 1.48 652.13 2,000.00 44.57 57.23 1,739.11 1,697.02 359.65 695.28 6,029,369.79 558,849.23 0.93 718.44 2,100.00 47.13 57.55 1,808.85 1,766.76 397.96 755.83 6,029,408.56 558,909.47 2.57 786.42 2,200.00 48.02 55.75 1,875.81 1,833.72 438.96 817.75 6,029,450.04 558,971.06 1.61 857.35 2,300.00 46.31 55.26 1,943.78 1,901.69 480.49 878.21 6,029,492.04 559,031.19 1.75 927.76 2,400.00 45.91 54.26 2,013.61 1,971.52 521.15 937.11 6,029,533.16 559,089.76 0.82 996.52 2,500.00 46.65 53.25 2,082.68 2,040.59 564.36 995.09 6,029,576.81 559,147.40 1.04 1,066.67 2,600.00 47.02 54.20 2,150.64 2,108.55 607.61 1,054.34 6,029,620.52 559,206.31 0.78 1,137.65 2,700.00 46.12 54.26 2,219.70 2,177.61 650.12 1,112.86 6,029,663.48 559,264.49 0.90 1,207.59 2,800.00 47.95 54.95 2,287.97 2,245.88 692.13 1,172.63 6,029,705.96 559,323.92 1.89 1,277.95 2,900.00 46.34 54.77 2,355.95 2,313.86 734.39 1,232.57 6,029,748.67 559,383.52 1.62 1,348.59 3,000.00 46.58 55.56 2,425.08 2,382.99 775.80 1,291.78 6,029,790.54 559,442.40 0.62 1,418.12 3,100.00 47.05 55.38 2,493.92 2,451.83 816.26 1,351.98 6,029,831.47 559,502.28 0.48 1,487.55 3,200.00 47.18 55.04 2,561.82 2,519.73 858.24 1,412.20 6,029,873.92 559,562.16 0.29 1,558.16 3,300.00 46.49 55.29 2,630.07 2,587.98 900.22 1,472.03 6,029,916.35 559,621.66 0.72 1,628.52 3,400.00 45.55 55.60 2,699.57 2,657.48 940.93 1,531.29 6,029,957.53 559,680.59 0.96 1,697.55 3,500.00 46.78 56.41 2,769.13 2,727.04 981.20 1,590.78 6,029,998.25 559,739.76 1.36 1,766.37 3,600.00 47.08 56.76 2,837.30 2,795.21 1,021.46 1,651.88 6,030,038.99 559,800.53 0.39 1,836.21 3,700.00 47.00 56.95 2,905.48 2,863.39 1,061.47 1,713.12 6,030,079.47 559,861.45 0.16 1,905.94 3,800.00 46.76 57.42 2,973.73 2,931.64 1,101.11 1,774.53 6,030,119.58 559,922.54 0.42 1,975.49 3,900.00 45.14 57.86 3,043.28 3,001.19 1,139.82 1,835.05 6,030,158.77 559,982.75 1.64 2,043.76 4,000.00 45.75 58.43 3,113.81 3,071.72 1,176.98 1,895.41 6,030,196.39 560,042.82 0.74 2,110.73 4,100.00 46.77 57.84 3,182.87 3,140.78 1,214.63 1,957.16 6,030,234.52 560,104.26 1.10 2,178.96 4,200.00 47.18 55.54 3,250.93 3,208.84 1,255.10 2,018.23 6,030,275.46 560,165.01 1.74 2,248.94 4,300.00 47.12 54.27 3,319.28 3,277.19 1,296.68 2,078.22 6,030,317.51 560,224.66 0.93 2,319.10 4,400.00 46.66 52.00 3,387.49 3,345.40 1,340.85 2,136.49 6,030,362.13 560,282.58 1.72 2,390.17 4,500.00 46.19 52.63 3,456.51 3,414.42 1,385.19 2,193.68 6,030,406.91 560,339.42 0.66 2,460.69 3272018 6.54:45PM Page 3 COMPASS 5000.1 Build 61E Halliburton HALL I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US + CANADA Local Coordinate Reference: Well MPU C47 Company: Hilcorp Alaska, LLC TVD Reference: MPU C47 Actual@ 42.09usft Project: Milne Point MD Reference: MPU C47 Actual @ 42.09usft Site: M PIC Pad North Reference: True Well: MPU C47 Survey Calculation Method: Minimum Curvature Wellbore: Plan: MPU C-47 Inclination Design: MPU C-47 wpl3 TVDss +N/ -S 3/27/2018 6:54:45PM Page 4 COMPASS 5000.1 Build 81E Vertical Map Map Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section T (1) (_( (usft) usft (usft) (usft) (usft) (usft) 3,483.34 46.45 5281 3,525.43 3,483.34 1,429.28 2,251.17 6,030,451.44 560,396.56 029 2,531.21 46.13 54.13 3,594.50 3,552.41 1,472.26 2,309.33 6,030,494.87 560,454.37 1.01 2,601.29 45.55 54.67 3,664.23 3,622.14 1,514.16 2,367.49 6,030,537.22 560,512.20 0.70 2,670.53 4,900.00 45.69 55.22 3,734.46 3,692.37 1,555.01 2,425.78 6,030,578.53 560,570.16 0.42 2,739.05 5,000.00 46.41 54.18 3,802.71 3,760.62 1,596.92 2,485.64 6,030,620.90 560,629.69 2.82 2,809.39 5,100.00 48.50 54.83 3,869.09 3,827.00 1,640.23 2,546.61 6,030,664.68 560,690.31 0.50 2,881.50 5,200.00 48.63 54.89 3,935.16 3,893.07 1,683.50 2,607.96 6,030,708.42 560,751.31 0.14 2,953.83 5,300.00 47.48 55.62 4,002.02 3,959.93 1,725.75 2,669.14 6,030,751.15 560,812.16 1.26 3,025.26 5,400.00 46.35 55.42 4,070.33 4,028.24 1,767.12 2,729.32 6,030,792.98 560,872.01 1.14 3,095.37 5,500.00 45.12 56.22 4,140.08 4,097.99 1,807.48 2,788.54 6,030,833.80 560,930.90 1.36 3,164.09 5,600.00 44.77 56.74 4,211.26 4,169.17 1,845.99 2,847.27 6,030,872.77 560,989.32 0.51 3,231.08 5,700.00 46.35 56.96 4,281.28 4,239.19 1,885.23 2,906.91 6,030,912.47 561,046.65 1.59 3,299.20 5,800.00 47.50 57.63 4,349.20 4,307.11 1,924.99 2,968.60 6,030,952.70 561,110.02 1.25 3,369.02 5,900.00 47.29 57.97 4,416.79 4,374.70 1,964.20 3,031.00 6,030,992.40 561,172.11 0.32 3,438.87 6,000.00 46.93 56.18 4,485.16 4,443.07 2,003.32 3,092.60 6,031,031.99 561,233.39 1.36 3,508.14 6,100.00 48.57 55.29 4,552.01 4,509.92 2,045.63 3,153.76 6,031,074.78 561,294.21 1.77 3,579.60 6,200.00 47.52 55.28 4,618.82 4,576.73 2,087.72 3,215.11 6,031,117.33 561,355.23 1.05 3,651.01 6,300.00 46.82 55.58 4,686.87 4,644.78 2,129.43 3,275.35 6,031,159.52 561,415.13 0.74 3,721.43 6,400.00 46.71 55.54 4,755.40 4,713.31 2,170.58 3,335.44 6,031,201.13 561,474.89 0.11 3,791.31 6,443.27 46.64 55.95 4,785.09 4,743.00 2,188.29 3,361.45 6,031,219.04 561,500.76 0.72 3,821.49 SE -BASE 6,500.00 46.49 55.92 4,824.09 4,782.00 2,211.35 3,395.59 6,031,242.37 561,534.72 0.26 3,860.95 6,554.36 46.33 55.66 4,861.57 4,819.48 2,233.48 3,428.16 6,031,264.75 561,567.11 0.45 3,898.69 6,600.00 46.15 56.06 4,893.14 4,851.05 2,251.98 3,455.44 6,031,283.46 561,594.24 0.75 3,930.28 Start Dir 30/100' : 6600' MD, 4893.14'TVD - 9 a/$- 6,700.00 46.82 51.32 4,962.01 4,919.92 2,294.91 3,513.84 6,031,326.84 561,652.30 3.50 4,000.48 6,600.00 47.69 46.70 5,029.91 4,987.82 2,343.07 3,569.23 6,031,375.43 561,707.31 3.50 4,072.82 6,900.00 48.73 42.22 5,096.57 5,054.48 2,396.27 3,621.42 6,031,429.03 561,759.07 3.50 4,147.03 7,000.00 49.94 37.89 5,161.74 5,119.65 2,454.32 3,670.19 6,031,487.45 561,807.38 3.50 4,222.85 7,100.00 51.31 33.72 5,225.19 5,183.10 2,517.00 3,715.38 6,031,550.48 561,852.07 3.50 4,299.98 7,200.00 52.82 29.72 5,286.68 5,244.59 2,584.08 3,756.81 6,031,617.87 561,892.98 3.50 4,378.13 7,300.00 54.46 25.88 5,345.98 5,303.89 2,655.30 3,794.33 6,031,689.38 561,929.93 3.50 4,457.03 7,400.00 56.21 22.20 5,402.87 5,360.78 2,730.41 3,827.60 6,031,764.73 561,962.81 3.50 4,536.36 7,500.00 58.07 18.67 5,457.13 5,415.04 2,809.11 3,857.09 6,031,843.66 561,991.49 3.50 4,615.84 7,600.00 60.03 15.28 5,508.57 5,466.48 2,891.12 3,882.10 6,031,925.86 562,015.85 3.50 4,695.17 7,700.00 62.07 12.03 5,556.98 5,514.89 2,976.14 3,902.73 6,032,011.02 562,035.81 3.50 4,774.06 7,800.00 64.18 8.90 5,602.20 5,560.11 3,063.83 3,918.90 6,032,098.83 562,051.30 3.50 4,852.20 7,890.97 66.15 6.15 5,640.41 5,598.32 3,145.67 3,929.70 6,032,180.74 562,061.45 3.50 4,922.39 End Dir : 7890.97' MD, 5640.41' TVD 7,900.00 66.15 6.15 5,644.06 5,601.97 3,153.88 3,930.58 6,032,186.96 562,062.27 0.00 4,929.31 8,000.00 66.15 6.15 5,684.49 5,642.40 3,244.82 3,940.38 6,032,279.96 562,071.35 0.00 5,005.93 8,100.00 66.15 6.15 5,724.92 5,682.83 3,335.75 3,950.17 6,032,370.96 562,080.43 0.00 5,082.54 8,200.00 66.15 6.15 5,765.35 5,723.26 3.426.69 3,959.97 6,032,461.96 562,089.52 0.00 5,159.16 6,300.00 66.15 6.15 5,805.77 5,763.68 3,517.63 3,969.76 6,032,552.97 562,098.60 0.00 5,235.77 8,400.00 66.15 6.15 5,846.20 5,804.11 3,608.57 3,979.56 6,032,643.97 562,107.68 0.00 5,312.39 3/27/2018 6:54:45PM Page 4 COMPASS 5000.1 Build 81E Halliburton HAL L I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US+CANADA Local Co-ordinate Reference: Well MPU C-47 Company: Hilcorp Alaska, LLC TVD Reference: MPU C-47 Actual @ 42.09usft Project: Milne Point MD Reference: MPU C-47 Actual @ 42.09usft Site: M Pt C Pad North Reference: True Well: MPU C-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan: MPU C-47 Depth Inclination Design: MPU C-47 wp13 7VDss +Nl-S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth 7VDss +Nl-S +E/ -W Northing Easting DLS Vert Section (usft) (_) (1) (usft) usft (usft) (usft) (usft) (usft) 5,844.64 8,500.00 66.15 6.15 5,886.63 5,844.54 3,699+50 3,989.35 6,032,734.97 562,116.77 0.00 5,389.01 8,581.05 66.15 6.15 5,919.40 5,877.31 3,773.21 3,997.29 6,032,808.73 562,124.13 0.00 5,451.10 Start Dir 3.5°1100': 8581.05' MD, 5919.4'TVD 8,600.00 65.49 6.19 5,927.16 5,885.07 3,790.39 3,999.15 6,032,825.93 562,125.85 3.50 5,465.59 8,700.00 62.00 6.41 5,971.39 5,929.30 3,879.52 4,008.99 6,032,915.12 562,134.99 3.50 5,540.83 8,800.00 58.50 6.65 6,021.00 5,978.91 3,965.77 4,018.85 6,033,001.43 562,144.18 3.50 5,613.85 8,900.00 55.01 6.90 6,075.82 6,033.73 4,048.80 4,028.71 6,033,084.54 562,153.39 3.50 5,684.39 9,000.00 51.52 7.18 6,135.62 6,093.53 4,128.33 4,038.53 6,033,164.13 562,162.58 3.50 5,752.18 9,100.00 48.02 7.48 6,200.20 6,158.11 4,204.04 4,048.27 6,033,239.90 562,171.73 3.50 5,816.97 9,200.00 44.53 7.83 6,269.30 6,227.21 4,275.66 4,057.89 6,033,311.59 562,180.78 3.50 5,878.51 9.300.00 41.04 8.21 6,342.68 6,300.59 4,342.91 4,067.35 6,033,378.91 562,189.72 3.50 5,936.58 9,400.00 37.55 8.66 6,420.05 6,377.96 4,405.55 4,076.63 6,033,441.61 562,198.51 3.50 5,990.96 9,500.00 34.07 9.18 6,501.13 6,459.04 4,463.35 4,085.69 6,033,499.47 562,207.12 3.50 6,041.45 9,600.00 30.58 9.80 6,585.62 6,543.53 4,516.08 4,094.49 6,033,552.27 562,215.51 3.50 6,087.85 9,616.76 30.00 9.92 6,600.09 6,558.00 4,524.41 4,095.94 6,033,560.61 562,216.89 3.50 6,095.22 End Dir : 9616.76' MD, 6600.09' rVD 9,664.10 30.00 9.92 6,641.09 6,599.00 • 4,547.73 4,100.02 6,033,583.95 562,220.78 0.00 6,115.85 HRZ 9,700.00 30.00 9.92 6,672.18 6,630.09 4,565.41 4,103.11 6,033,601.66 562,223.74 0.00 6,131.50 9,768.02 30.00 9.92 6,731.09 6,689.00 4,598.91 4,108.97 6,033,635.20 562,229.33 0.00 6,161.15 KLa 9,800.00 30.00 9.92 6,758.79 6,716.70 4,614.66 4,111.72 6,033,650.97 562,231.96 0.00 6,175.09 9,878.87 30.00 9.92 6,827.09 6,785.00 4,653.51 4,118.52 6,033,689.87 562,238.45 0.00 6,209.47 KLGM 9,900.00 30.00 9.92 6,845.39 6,803.30 4,663.92 4,120.34 6,033,700.29 562,240.19 0.00 6,218.68 9,916.76 30.00 9.92 6,859.90 6,817.81 4,672.17 4,121.78 6,033,708.55 562,241.57 0.00 6,225.98 Start Dir 3°1100' : 9916.76' MD, 6859.9'ND 9,949.79 29.01 9.92 6,888.65 6,846.56 4,688.19 4,124.58 6,033,724.59 562,244.25 3.00 6,240.16 End Dir :9949.79' MD, 6888.65' TVD 10,000.00 29.01 9.92 6,932.56 6,890.47 4,712.18 4,128.78 6,033,748.61 562,248.25 0.00 6,261.39 10,041.77 29.01 9.92 6,969.09 6,927.00 4,732.13 4,132.27 6,033.768.59 562,251.59 0.00 6,279.05 KUP_D 10,100.00 29.01 9.92 7,020.01 6,977.92 4,759.95 4,137.13 6,033,796.44 562,256.23 0.00 6,303.67 10,200.00 29.01 9.92 7,107.47 7,065.38 4,807.72 4,145.48 6,033,844.27 562,264.21 0.00 6,345.94 10,219.01 29.01 9.92 7,124.09 7,082.00 4,816.80 4,147.07 6,033,853.36 562,265.73 0.00 6,353.98 KUP_C 10,222.44 29.01 9.92 7,127.09 7,085.00 4,818.44 4,147.36 6,033,855.00 562,266.00 0.00 6,355.43 10,244.16 29.01 9.92 7,146.09 7,104.00 4,828.82 4,149.17 6,033,865.39 562,267.73 0.00 6,364.61 KUP_LCU-KUP_87-KUP_B6 10,300.00 29.01 9.92 7,194.92 7,152.83 4,855.49 4,153.84 6,033,892.10 562,272.19 0.00 6,388.22 10,400.00 29.01 9.92 7,282.38 7,240.29 4,903.26 4,162.19 6,033,939.93 562,280.17 0.00 6,430.50 10,400.82 29.01 9.92 7,283.09 7,241.00 4,903.65 4,162.26 6,033,940.32 562,280.23 0.00 6,430.84 KUP A3 10,424.83 29.01 9.92 7,304.09 7,262.00 4,915.12 4.164.26 6,033,951.80 562,282.15 0.00 6,440.99 31272018 6:54:45PM Page 5 COMPASS 5000.1 Build 81E Halliburton HALLI B U RTO N Standard Proposal Report Database: Sperry EDM - NORTH US+CANADA Local Co-ordinate Reference: Well MPU C47 Company: Hilcorp Alaska, LLC TVD Reference: MPU C-47 Actual @ 42.09usft Project: Milne Point MD Reference: MPU C-47 Actual @ 42.09usft Site: M Pt C Pad North Reference: True Well: MPU C-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan: MPU C-47 Depth Inclination Azimuth Design: MPU C-47 wp13 +NIS +E/ -W Planned Survey Measured Vertical Target Name Hole Depth Depth Diameter Measured -hilimiss target Dip Angle Dip Dir. TVD Vertical +E/ -W Northing Easting Map Map (usft) (usft) Depth Inclination Azimuth Depth TVDss +NIS +E/ -W Northing Easting DLS Vert Section (usft) V) (1) (usft) usft (usft) (usft) (usft) (usft) 7,313.00 MPU C-471nterp Tgt wp13 10,483.14 29.01 9.92 7,355.09 7,313.00 4,942.98 4,169.13 6,03397969 562,286.80 0.00 6,46565 KUP Al 10,500.00 29.01 9.92 7,369.83 7,327.74 4,951.03 4,170.54 6,033,987.76 562,288.15 0.00 6,472.77 10,514.02 29.01 9.92 7,382.09 7,340.00 4,957.73 4,171.71 6,033,994.46 562,289.26 0.00 6,478.70 KUP_A_BASE 10,600.00 29.01 9.92 7,457.29 7,415.20 4,998.80 4,178.90 6,034,035.59 562,296.12 0.00 6,515.05 10,700.00 29.01 9.92 7,544.74 7,502.65 5,046.57 4,187.25 6,034,083.42 562,304.10 0.00 6,557.32 10,800.00 29.01 9.92 7,632.19 7,590.10 5,094.34 4,195.60 6,034,131.24 562,312.08 0.00 6,599.60 10,900.00 29.01 9.92 7,719.65 7,677.56 5,142.11 4,203.96 6,034,179.07 562,320.06 0.00 6,641.88 10,906.12 29.01 9.92 7,725.00 7,682.91 5,145.03 4,204.47 6,034,182.00 562,320.55 0.00 6,644.46 Total Depth : 10906.12' MD, 7726' TVD Targets Measured Vertical Target Name Hole Depth Depth Diameter Diameter -hilimiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape (1) V) (usft) (usft) (usft) (usft) (usft) MPU C-47 wpl3 CP1 0.00 0.00 7,127.09 4818.44 4,147.36 6,033,855.00 562,266.00 - plan hits target center - Point MPU C-471nterp Tgt wp13 0.00 0.00 6,859.90 4,672.17 4,121.78 6,033,708.55 562,241.57 - plan hits target center - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 10,90612 7,725.00 7"x81/2' 7 8-1/2 6,600.00 4,893.14 95/8" 9-5/8 12-1/4 31272018 6:54:45PM Page 6 COMPASS 5000.1 Build 81E Formations Halliburton H ALLI B U R TO N Vertical Standard Proposal Report Database: Sperry EDM - NORTH US+CANADA Local Co-ordinate Reference: Well MPU C-47 Company: Hilcorp Alaska, LLC TVD Reference: MPU C-47 Actual @ 42.09usft Project: Milne Point MD Reference: MPU C-47 Actual @ 42.09usft Site: M Pt C Pad North Reference: True Well: MPU C-47 Survey Calculation Method: Minimum Curvature Wellbore: Plan: MPU C-47 7,146.09 KUP_LCU Design: MPU C-47 wp13 6,731.09 KLB Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology 10,424.83 7,304.09 KUP A2 10,244.16 7,146.09 KUP_B6 10,041.77 6,969.09 KUP_D 10,244.16 7,146.09 KUP_LCU 9,768.02 6,731.09 KLB 10,483.14 7,355.09 KUP_At 10,244.16 7,146.09 KUP_B7 10,219.01 7,124.09 KUP_C 6,443.27 4,785.09 SB BASE 10,400.82 7,283.09 KUP_A3 10,514.02 7,382.09 SUP _A_BASE 9,878.87 6,827.09 KLGM 9,664.10 6,641.09 HRZ Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S -El-VV (usft) (usft) (usft) (usft) Comment 6,600.00 4,893.14 2,251.98 3,455.44 Start Dir 3.5°/100': 6600'MD, 4893.14'TVD 7,890.97 5,640.41 3,145.67 3,929.70 End Dir : 7890.97' MD, 5640.41' TVD 8,581.05 5,919.40 3,773.21 3,997.29 Start Dir 3.5°/100': 8581.05'MD, 5919.4'TVD 9,616.76 6,600.09 4,524.41 4,095.94 End Dir : 9616.76' MD, 6600.09' TVD 9,916.76 6,859.90 4,672.17 4,121.78 Start Dir 3°/100': 9916.76'MD, 6859.9'TVD 9,949.79 6,888.65 4,688.19 4,124.58 End Dir : 9949.79' MD, 6888.65' TVD 10,906.12 7,725.00 5,145.03 4,204.47 Total Depth : 10906.12' MD, 7725' TVD 3/27/2018 6:54:45PM Page 7 COMPASS 5000.1 Build 81E Hilcorp Alaska, LLC Milne Point M Pt C Pad MPU C-47 Plan: MPU C-47 MPU C-47 wp13 Sperry Drilling Services Clearance Summary Anticollision Report 27 March, 2018 Closest Approach 3D Proximity Scan on Current survey Data (North Reference) Reference Design: MPt C Pad - MPU C -07 -Plan: MPU C47MPUC47 wpi3 Well C-modinah s: 6,029,p04.74 N, 558,156.85 E (70. 29' 23.49" N, 149° ¢1' 28SJ" W) Datum Heigh[ MPU C47 Actual@ 42.09usfl Scan Range: 6,554.36 to 10,906 76 ustt. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff Is Unlimited Max Ellipse Separation is 1,500.00 usft Geodetic Scale Factor Applied version: 5000.1 Build: atE Scan Type: Scan Type: 2500 r HALLIBURTON Sperry Drilling Services HALLIBURTON Anticollision Report for MPU C-47 - MPU C-47 wp13 Hilcorp Alaska, LLC Milne Point Closest Approach 3D Proxlmiir $Can on Curren Sunday Data (North Reference) Reference Design: MRCPad-MPUC47-Plan:MPUC41-MPUC47wp13 Scan Range: 6,554.36 to 10,906.76 K. Measured Depth. Scan Radius is Unlimited. Clearance Factor Cutoff is Unlimited. Max Ellipse Separation Is 1,500.00 usN Measured Minimum @Measured Ellipse ahleasured Clearance Summary Based on Sale Nona Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usX) )usm (uck) push) usR EX MP18-01 MP18-01- MP18-01- MP18-01 MP18-01-MP18-01-MP18-01 MP1601- MP1S-01 - MP18-D1 M Pt C Pad MPC -02 - MPC -02 - MPC -02 MPC -11 -MPC -it - Ni MPC -11- MPC -11 - MPC -11 MPU C47 - MPU C-47 PBI - MPU C-47 PEI $Uryey tool monBRI 6,554.36 171345 6.554.36 1381.85 eSos.86 5.55436 1,141.88 8.556.36 1,042.40 6.560.86 6,554.38 1,721.54 8,55436 1.497,79 8,118.03 6,854.36 21.78 6,854.36 10.04 6,853.14 From To SumeylPlan lush) hush) 100 00 728.00 788.64 6,55486 6.554.36 10.906.12 MPU C-47 wpl3 Ellipse error terms are correlated across survey tool Bean paints. Calculated ellipses incorporate surrace errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore causes. Clearance Factor= Distance Between Profiles I (Distance Between Profiles- Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 5.107 Clearance Factor Pass - IIA78 Ellipse Sepmation Pass - 7.694 Clearance Factor Pass - 7.958 Clearance Fador Pass - Survey Tool 2_Gyro-SR-GSS 2 MWD+IFR2+MS+Sag 2 MW IFR2+MS•Sag 27 March, 2018 - fir 53 Page 2 of4 COMPASS HALLIBURTON Anticollision Report for MPU C-47 - MPU C-47 wp13 Dlredion and Coordinates are relative to True North Reference. Vertical Depths are relative to MPU C-47 Adual C 520gus11. Nodhing and Easting arerelative to MPU C47. Coordinate System Is US State Plane 1927 (End solulion), Alaska Zane 04, Central Mandan Is -150.00°, Ord Convergence at Surface is: 0.45'. C y 1950- Ladder Plot 0 I — 2000 4000 6000 8000 10000 Measured Depth (2000 usf I n) Hilcorp Alaska, LLC Milne Point MPC08, MPG08, MPCOBVI MPC -1 D, M P 010, MPC -10 V 1 MP011, MPC -11, MPC -11 V7 WPC -1 2, MPC -12. MPC -12 V9 MPGI2,MP012A, MPC -12A0 MP012, WC-12APB1, WC-12APB1 W MPG13,WG-13,WC-13V4 MP 016, MP 016, MPC -16 V l MPC20,MPC-20, WC -20V1 MPC -M. NW C-22, WC -22 V 1 W C-22, MPG -22A, MP022A V 1 MPC-28,MPC-28,MPC-28V1 MPC -28, MPC -2K MPC -28A W MPC36, MPC -36, W c -S6 V3 MPC39,MPG39, MPc-m W MPU 014, MPU 014, MPU 014 V1 MPU015, MPU 015, MPU015V1 MPU 015,MPUc-ISA,MPU015A W MPUC40,MPUC4O,MPUC4OV19 MPUC4I,MPC4I,MPG41 VO MPUC4l,MPC41L1,MPG41L1 W MPU C41, MPC41 L2, W C-41 U W MPUC4I,MPC41PB1,MPC41PB1W tvP U G1, MPG41 PB2, MPC41 P B2 V2 MPUC45, WU C45,MPU C45 W 27 Marsh, 2018 - 19:53 Page 3 o/4 COMPASS y,¢d ------. fl - - 0 I — 2000 4000 6000 8000 10000 Measured Depth (2000 usf I n) Hilcorp Alaska, LLC Milne Point MPC08, MPG08, MPCOBVI MPC -1 D, M P 010, MPC -10 V 1 MP011, MPC -11, MPC -11 V7 WPC -1 2, MPC -12. MPC -12 V9 MPGI2,MP012A, MPC -12A0 MP012, WC-12APB1, WC-12APB1 W MPG13,WG-13,WC-13V4 MP 016, MP 016, MPC -16 V l MPC20,MPC-20, WC -20V1 MPC -M. NW C-22, WC -22 V 1 W C-22, MPG -22A, MP022A V 1 MPC-28,MPC-28,MPC-28V1 MPC -28, MPC -2K MPC -28A W MPC36, MPC -36, W c -S6 V3 MPC39,MPG39, MPc-m W MPU 014, MPU 014, MPU 014 V1 MPU015, MPU 015, MPU015V1 MPU 015,MPUc-ISA,MPU015A W MPUC40,MPUC4O,MPUC4OV19 MPUC4I,MPC4I,MPG41 VO MPUC4l,MPC41L1,MPG41L1 W MPU C41, MPC41 L2, W C-41 U W MPUC4I,MPC41PB1,MPC41PB1W tvP U G1, MPG41 PB2, MPC41 P B2 V2 MPUC45, WU C45,MPU C45 W 27 Marsh, 2018 - 19:53 Page 3 o/4 COMPASS r- � HALLIBURTON Anticollision Report for MPU C-47 - MPU C-47 wp13 Hilcorp Alaska, LLC Milne Point Clearance Factor Plot Measured Depth versus Separation(Clearance) Factor �— 7—WC-06,MPC-06 MPC -06V1 I MPC_0 MPC -0e MPC08V1 moo - - - I _ MPG10 WC -10 MPC -1 0 V1 MPGA, MPC 11 MPC -11 V1 - _ MPGI2, MPG12, MPG12 V9 ' MPGI2,MPG12A, MPC -12A V3 - MPGI2,MPG12APS1,MPG12APB1 V6 ----_ l --. o VPCI3,MPG13,MPC-13V4 c —Coll een Avoidance Req NoG. Z.. -Step Cnllln9` MPC -16, MPG16, MPGi6 Vi 1VPG20, MPC -20, MPC -2O V 1 MPC-22,MPC-22,1VPC-22V1 - _-- MPG22,MPG22A,MPG22AV1 MPC28,MPC-28,MPC-28 V1 MPG28, MPG28A, MPC -28A V6 MPC-36,MPC36,MPC-36V3 - - MPG39,MPC39,MPG39V3 MPUC-14,10PUC-14,MPUC-14V1 - MPUC-15,MPUC-15,MPUC-15V1 - MPUGI5,MPUC-15A,MPUC-15AVO --- _-T — - MPUC-40,MPUC40,MPUC40V19 MPUG4I,MPC4I,MPC41 VO MPUC4I,MPC41L1,MPC41L1VO MPU C41, MP C41 L2, MPC41 L2 VO MPUC4I,MPC41PB1,MPC41PB1VO MPUC4I,MPC41PB2,MPC-01P1KV2 5600 6600 7000 6000 9000 10000 11600 12000 MPU C45, MPU C45, MPU C45 VO MemrelDepth (2OOL610n) 1VPUC45,MPUC45,MPUC451APO8VO 27 March, 2016 - 19:33 Page 4 f COMPASS Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 11, 2018 11:29 AM To: 'Joe Engel' Cc: Bettis, Patricia K (DOA) Subject: RE: HAK MPU C-47 (PTD: 217-077) Redrill Directional Change Looks like a new sundry is required. Not a revise PTD as we discussed Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz of (907-793-1226) or (Guv.schwartz@alaska.aov). From: Joe Engel <jengel@hilcorp.com> Sent: Tuesday, April 10, 2018 3:45 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Monty Myers <mmyers@hilcorp.com> Subject: HAK MPU C-47 (PTD: 217-077) Redrill Directional Change Guy— Following up from our conversation last week, Hilcorp Alaska is looking to resume operations on MPU C-47 in June 2018. The original target was a lateral in the Kuparuk C formation, unfortunately 7" casing was stuck in the HRZ , the well was plugged back to the surface casing shoe and operations were shutdown. For the 2018 redrill, Hilcorp Alaska would like to drill C-47 as a slant well through the Kuparuk C and A formations, targeting the same fault block as in 2017. The proposed slant well will intersect the prior planned lateral. Attached is a comparison of the 2017 planned/approved directional and the 2018 proposed directional and target, section and plan views of the directional, as well as the geology map. The distance between the toe of the planned lateral in 2017 and the TD of the proposed slant well in 2018 is 2533', again targeting the same fault block. Please advise whether a sundry or PTD revision is required for this directional change. Thank you for your time. -Joe rIM4M90 SVSI00 ' 0090 5BOD00 %i 600 5-24W .-£i°NO o I co � o o C-47 0 4N] A U N a o po 0 S a f� o C -d7 op 0 0 0 0 C- 7 faV o N O c a a 0 0 ry O N a V O O n O (7 a N O CO C d (` a O yO O a a 0 c N 0 a 0 O a a a C] V N a O O ry a 5°54'SO 5°tl2'SJ %5%0 WZ:&X CC _L'iCX 562400 55LZM 0 0 250 1�)O 750 1000 32.90itUS ,10485 rEtaa Debra Oudean GeoTech RECEIVED rtiln,rn :1lavka, Lt.0 SEP 2 1 2``017 `'C DATE 09/21/2017 AOC Hilcorp Alaska, LLC 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 Natural Resource Technician II 333 W 7th Ave Suite 100 Anchorage, AK 99501 F07714 iri's 1771 Minunm Prints: ROP DGR ABG GEO-Pilot At -Bit Gamma EWR-Phase 4 ADR MD TVD CD's MPU C -47P81 CND Logs 9/x/20171:42 PM File folder Please include current contact information if different from above. 21 7077 28614 0A7 LOGGED `1 '26/201-7 M. K. SENDER Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: �^� o A Date: THE STATE °fALASKA GOVERNOR BILL WALKER Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-47 Permit to Drill Number: 217-077 Sundry Number: 317-336 Dear Mr. Mazzolini: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4az��- Hollis S. French Chair s DATED this day of August, 2017. RBDMS Lc AUG - 9 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 70 car. gr 9An RECEIVED .JUL 2 020,177 ,An�GCIG ) 7 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 12 Suspend ❑ 4) Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑+ Plug for Redrill I Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development I] 1 217-077 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-029-23577-00-00- 7. If perforating: 8. Well Name and Number: MPU C-47 What Regulation or Conservation Order governs well spacing in this pool? N/A ' Will planned perforations require a spacing exception? Yes ❑ No 9. Property Designation (Lease Number): 10. Field/Pool(s): Milne Point Field ADL 047434 (SHL, BHL) / ADL047433 PH) ' I Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 1 10,293 . 7,163 ' 9,510 6,890 2974 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 151' 16° 151' 151' Surface 6590' 9-5/8" 6590' 4886' 5,750 3,090 Intermediate 9,510' 7" 9510' 6,890' 7,240 5,410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: N/A Packers and SSSV MD (ft) and TVD (ft): N/A 12. Attachments: Proposal Summary I0 Wellbore schematic Iff 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: 7/15/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑+ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Paul Mazzolini Contact Name: Joe Engel Authorized Title: Drilling Manager Contact Email: en a hilcor .CONI FOA L MN22o61N Contact Phone: 907-777-8395 Authorized Signature: Date: — COMMISSION USE ONLY Conditions of appro ify Commission so that a representative may witness Sundry Number: 3►i-331e Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ t❑ a 7 Cd Other: --Lµc�n LI'L d ir—rs�fi:ti.'t its &, zo A,+C'Z�'. 07 Z. J S//// �c k,r,, GJ1' "';' � 0 R�5 k, xC (rye -u Post Initial Injection MIT Req'd? Yes [I No [I(/ �/ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 0 `Y & APPROVED BY f? Ir I t'1 lS Y Approved by: COMMISSIONER THE COMMISSION Date: -7-3147 caw -71) I � Form 10-403 Revised 412017 RPI e AtAilv-lid for 12 months from the date of approval. RBDMSC L-- AUG - 9 2017 Submit Form and Attachments in Duplicate H Hilmrp Alaska, LLC 7/20/2017 Joe Engel Drilling Engineer Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Sundry Application for Plug for Redrill of MPU C-47 (PTD# 217-077) Dear Commissioner, Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 6395 Email jengel@hilcorp.com RECEIVED JUL 2 0 2017 .AOGCC Hilcorp Alaska, LLC hereby submits for review and approval of the plug for redrill and operational shutdown of the planned onshore production well at Milne Point `C' Pad, well slot 47. This sundry application follows verbal approval to proceed with operations, received on July 15, 2017. Drilling operations commenced on June 26, 2017 While running 7" intermediate casing, the casing became stuck at —9,510' MD. Attempts to establish rotation, reciprocation or circulation were unsuccessful and the decision was made to plug the intermediate hole for redrill.°fhe redrill will occur at a future, undetermined date and operations on MPU C-47 will be shut down. Please find attached the Form 10-403, Application for Sundry Approval, procedure for plug and operational shutdown and the proposed wellbore schematic for MPU C-47. A separate sundry will be submitted for approval for the sidetrack of MPU C-47..— If you have any questions, or require further information, please do not hesitate to contact myself (Joe Engel) at 777- 8395 or jengel@hilcorp.com or Paul Mazzolini at 777-8369. _ Joe En Drilling Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska - MPU C-47: 8-1/2" x 9-7/8" Plug Operational Procedure 7.19.2017 Current Status: • 9-5/8" Casing Shoe: 6,590' MD / 4,886' TVD • 8-1/2" x 9-7/8" Hole TD: 10,293' MD / 7,163' TVD • Formations Depths: o Kuparuk C: 10,224' MD / 7,153' TVD o HRZ:9,280-9,499' MD • 7" Casing stuck at 9,510' MD / ^'6,890' TVD, Across HRZ • Unable to circulate, rotate or reciprocate o Suspect HRZ has collapsed, packing off the annulus • MW in hole: 10.5 ppg LSND • Offset Kup C Pore Pressure, MP C-4: 6.5 ppg EMW Prep Work: • Inform AOGCC of current well ops, and upcoming BOPE Test due date (7/18/2017) • PU 4" DP, if possible • Obtain 7" E -slips to set casing and remove joint through Stack • Contact E -line and source CIBP, pert guns, cement retainer • Notify Halliburton for upcoming cement • Notify Baker for upcoming casing cut and spear assembly Procedure: 1. RIH with E -line and set CIBP, at 9,250' MD a. Last circulation depth was 9,380' MD, at 6 bpm with full returns on 7/14 b. Top of HRZ is 9,280' MD c. To give best chance of success of circulation through annulus and minimize risk of annulus collapsing, set CIBP 30' above top HRZ 2. Set 7" Emergency slips to remove casing joint -- a. Monitor annulus for 3 hrs, minimum before setting e -slips. 3. Notify AOGCC & Test BOPE 4. RIH with E -line and perforate above CIBP a. CIBP set at ^'9,250' MD 5. Establish circulation through annulus a. Start at low flow rates, documenting pump pressure and increase rates to 6-8 bpm b. If unable to circulation through annulus, RIH and perforate at shallower depth 6. RIH with Cement retainer on 4" DP, and set retainer at 100' above CIBP at 9,150' MD, a. If perforations had to be performed shallower to establish circulation, ensure cement retainer setting depth has been adjusted. b. Tag retainer and Pressure test t/ 3000 psi 7. Establish circulation through 9-7/8" x 7" annulus a. Start at low flow rates, documenting pump pressure and increase rates to 6-8 bpm 8. Squeeze cement into 9-7/8" x 7" annulus to isolate Kuparuk C formation a. 15.8# Class G Cement b. 500' MD of annular volume+ 7" casing volume between CIBP and Retainer c. 9-7/8" x 7" Annular Capacity: .04713 bbl/ft i. Use 30%OH Excess d. 7" 26# Capacity: .038 bbl/ft e. 30.6 bbls (1.3 bbl OH Excess) + 3.8 bbl 7" casing volume = 34.4 bbl f. Casing volume may change if retainer is set more than 100' MD above CIBP 9. Unsting from cement retainer and Pump 100' of cement on top of retainer a. 3.8 bbl 7" Casing Volume 10. POOH above cement, circulate hole clean and cement stinger clean a. Circulate with water at high flow rate to remove cement rings b. Pump Nerf ball to clean stinger 11. POOH with cement stinger 12. PU CIBP, RIH and set CIBP at — 7100' a. Confirm set & cut depth with DD to ensure sufficient depth to kickoff without interference of casing stub. Depth may change due to directional plan 13. RIH and cut 7" casing at — 7000' MD a. Use Baker Knives on 4" DP b. Cut twice to ensure ability to pull casing free c. 7000' MD cut depth gives 410' OH below surface casing 14. Change Rams to 7" solid rams and test 15. POOH, LD 7" cut casing a. Engage 7" casing with spear if needed 16. PU cement stinger on 4" DP, Pump Kickoff plug from 7100' MD t. — 200' MD into surface casing shoe a. Total cement volume will be pumped in two plugs, to ensure plug does not fall b. 7" 26# Capacity: .038 bbl / ft c. 9-7/8" OH Capacity: .094 bbl/ft i. Use 30% OH Excess d. 9-5/8" Capacity: .075 bbl / ft e. Pump 10 bbl Visc pill ahead of first plug to ensure plug does not fall 17. POOH above cement, circulate hole clean and cement stinger clean a. Circulate with water at high flow rate to remove cement rings b. Pump Nerf ball to clean stinger 18. WOC and tag TOC 19. PT cement plug to 3,OOOpsi 20. Displace well to seawater 21. POOH & LD cement Stinger 22. MU tubing handling equipment 23. RIH with 3-1/2 kill string to ±3,000' MD, Land Hanger 24. Freeze protect well to 2,000' TVD 25. ND BOPE, NU Tree, Set BPV. Test Same. 26. RDMO A separate sundry will be submitted for the re drill of MPU C-47. K 110—p ANA , LIA: KB Elev Above Sea Level: 41.7'/ GL Hec: 15.2' 16 9-5/8' ,5901V 186' T SCHEMATIC Milne Point Unit Well: MPC -47 PTD: 217-077 API: 50-029-23577-00-00 /� Top 7" 7015' MD / ;,185' TVD IFWFI RY DETAIL No. I Kern Top MD 1 CIBP 9,250 2 Cement Retainer 9,160 3 Composite Plug 7,108 OPEN HOLE / PROPOSED CEMENT DETAIL Conductor Driven CASING DETAIL 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16"Conductor 164/A-106B/Weld N/A Surface 151' N/A 9-5/8" Surface 40/L-80/DWC/C 8.75" Surface 6,590' 00758 7" Intermediate 26/L-80/Hyd 563 6.151" 7,015' 9,510' 0.0383 TUBING DETAIL 3-1/2" Tubing 9.3/L-80/8RND 1 2.922" Surface 1:3,000 0.008 /� Top 7" 7015' MD / ;,185' TVD IFWFI RY DETAIL No. I Kern Top MD 1 CIBP 9,250 2 Cement Retainer 9,160 3 Composite Plug 7,108 OPEN HOLE / PROPOSED CEMENT DETAIL Conductor Driven 12-1/4" 1st stage 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg 9-7/8" x 7" Squeeze 384.9 bbl 15.8 Class G Above Cmt Retainer 3.3 bbl 15.8 Class G Kick Off Plug 64 bbl 15.8 Class G Bottom 7" 10 MD / 6,890' TVD (< L4,e C- 8-1/2" x 9-7/8" 10,293' MD / 7,162' TVD PERFORATION DETAIL No. etm MD Top MD 1 9,215 9,215 GENERAL WELL INFO WELL INCLINATION DETAIL PBTD=6,390'MD/t4,745'TVD KOP @ 326' TD = 10'293 MD / 7,162'TVD API: 50-029-23577-00-00 Max Deviation: 850 Drilled and Cased by Innovation —July 14, 2017 Max Hole Angle = 85 deg. @ 10,293 MD Updated by JPE 7/19/17 Schwartz Guy L (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Monday, July 31, 2017 5:06 PM To: Schwartz, Guy L (DOA) Cc: Bettis, Patricia K (DOA); Paul Mazzolini; Cody Dinger Subject: RE: C-47 redrill (PTD 217-077) Thanks, Guy. As of now the plan is to keep the same BHL as originally permitted. If it does change, we will submit a new PTD. Once our rig schedule after Endicott is confirmed, we will submit the 10-404 for C-47 if necessary. Please let me know if you have any questions. Joe From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, July 31, 2017 3:53 PM To: Joe Engel <jengel@hilcorp.com> Cc: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: C-47 redrill (PTD 217-077) Joe, To clarify are you planning to redrill to the same BHL when you return? If it is more than 500 ft away you will need a new PTD application. Also, if the well is not reentered within 60 days you will need to submit a 10-404 report as per 20 AAC 25.072. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-7937226 ( or (Guv schwartz@alaska aovi. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS am 7 c s4 ,y 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Operations shutdown ✓ Performed: Suspend r Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill LI Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Name: Development ❑✓ Stratigraphic ❑ Exploratory E]N�+ Service ❑ 217-077 EC E 1 V E D 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-029-23577-70-00 SEP 2 0 2017 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 047434 MPU C-47 PB1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): ROP/DGR ADR Geo -Pilot Al -Bit Gamma/EWR-Phase4/ADR MD/TVD Milne Point Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,293 feet Plugs measured 6,385 feet true vertical 7,162 feet Junk measured WA feet Effective Depth measured 6,385' feet Packer measured N/A feet true vertical 4,745' feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 151' 16" 151' 151' Surface 6,590' 9-5/8" 6,590' 4,886' 5750 3090 Intermediate 165' 7" 165' 165' 7240 5410 Production Liner Perforation depth Measured depth 9,210-9,215 feet True Vertical depth 6,702-6,704 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 3,007' 2,430' Packers and SSSV (type, measured and true vertical depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: I N/A Subsequent to operation: N/A 14. Attachments (required per 20 AAC 25.070, 25.071, 825.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑✓ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby Certify that the foregoing Is true and Correct t0 the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 3t-7- Authorized Name: Paul Mazzolini Contact Name: Joe Engel Authorized Title: Drilling Manager Contact Email:ienpelJhilCor J.COm .�— sok PAUL /r►�F2Zot-!Nf Authodzed Signature: Date: Contact Phone: 777-8395 Form 10-404 Revised 4/2017 j . z 5--11 ,��1/l RSDMS %-� SEP 2 5 2017 Submit Original Only n Hilmcp Alaska, LLC KE Elev Above Sea Level: 41.7'/ GL Elev: 15.2' SCHEMATIC Milne Point Unit Well: MPC -47 PTD: 217-077 API: 50-029-23577-00-00 9-5/8" 6,590 MD 4,886' TVD Top 7" 7,015' MD / j 5,185' TVD JEWELRY DETAIL No. I Item Top MD CASING DETAIL 7,108 2 Cement Retainer 9,160 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16" Conductor 164/A-1068/Weld N/A Surface 151' N/A 9-5/8" Surface 40/L-80/DWC/C 8.75" Surface 6,590' 0.0758 7" Fish Intermediate 26/L-80/Hyd 563 6.151" 7,015' 9,510' 0.0383 7" Intermediate 26/L-80/HTTC 6.151" Surface 165' 0.0383 TUBING DETAIL 3-1/2" Tubing 9.3/L-80/8RND 1 2.922" 1 Surface 1 3,007' 1 0.008 9-5/8" 6,590 MD 4,886' TVD Top 7" 7,015' MD / j 5,185' TVD JEWELRY DETAIL No. I Item Top MD 1 Composite Plug 7,108 2 Cement Retainer 9,160 3 CIBP 9,250 OPEN HOLE / PROPOSED CEMENT DETAIL Conductor Driven 12-1/4" 1st stage 305 bbls Lead 11.7 ppg; 45.7 bbls Tail 14.5 ppg 12-1/4" 2nd stage 229 bbls Lead 11.1 ppg, 37 bbls Tail 14.5 ppg Above Composite Plug 1" Plug 32.9 bbls, 2"d Plug 32 bbls (15.8 Class G) Above Cmt Retainer 3.3 bbl 15.8 Class G Squeeze Below Retainer 38.2 bbl 15.8 Class G PERFORATION DETAIL No. Btm MD Top MD 1 9,215 9,210 TOC 8,404' MD 2 3 Bottom 7" 9,510 MD / 6,890' TVD 88-_1/2" x 9-7/8" 10,293' MD / 7,162' TVD GENERAL WELL INFO WELL INCLINATION DETAIL FPBTD=6,385'MD/4,745'TVD liAPI: 50-029-23577-00-00 KOP @ 26.89' = 10,293'MD/7,162'TVD Drilled and Cased by Innovation —July 14,2017Maz Hole Angle=82.8 deg.@10,293 MD x Deviation: 83° Updated by JPE 7/19/17 n Well Name: MP C-47 Field: Milne Point County/State: , Alaska (LAT/LONG): ovation (RKB): 26.89 API #: Spud Date: 6/28/2017 Job Name: 1710174D MPC -47 Drilling Contractor Innovation AFE #: 1710174D Hilcorp Energy Company Composite Report AFE $: , ACtiVI Date... 6,/25i2017 Ops Summar Continue R/D svc lines throughout rig. Secure stairways- Remove cuttings boxes and containment. Install cross beams in cellar for mob. Peak trucking on location @ 21:40 hrs.;Demob pipeshed, gen module, pits and catwalk. Stage on location. Demob sub off well C-46.;Walk sub in line with well row. Install Mob down row and spot sub.;Spin sub and walk wheels and tow bar. Install Bowbox and take measurements for Bowline modification. Build Bowline. well over well C-47. Verify sub is clr over conductor. 6/26/2017 Notification sent via email for diverter test to AOGCC 0 05:51 him 6/26/17. Spot catwalk, Pipeshed, Pits, & Gen mod. Continue working on Bow line & Flow box modifications. Release trucks at 12:00. Work on both centrifuges (found feed tubes in poor condition).;Shim sub with 1.125 strips. Hook up interconnects. Trouble shoot MP#1 Drive .Open up MP#1&2 and replace valves and seats as needed. Continue working on Bow line & Flow box modifcations.;Cont Bowbox/Bowline modifications. R/U pits. Service rig and ready handling equipment. C/O saver new DS -50 thread. RKB / GL = 26.89', RKBANellhead = 25.96'.; Load, strap and tally 210 total jts 5", DS -50. Work on pre -rig acceptance checklist. sub w/ Troubleshoot TDS enable function. Electrician found loose connection on fiber optic com Iine.;Continue working on gowbox and Bowline modifications (1° Cont load 5" DP.;Continue working on rig acceptance checklist. Put drop F/ Bowbox -T/ corner, 1.6° drop F/ corner- T/ shakers). Cont C/O saver sub. steam throughout rig.;N/U diverter stack. Install knife valve, N/U diverter line. Plumb in jet lines and drains. Plumb in Bowline innemonnecl.;Hauled 520 bbls 6/27/2017 H20 from Pad for total = 520 bbis Rig Accepted at 0600: Continue to Ni diverter system BOPS. Function test same. GOOD. Move water around pits and check lines. Good.;Build high vis & Test hopper and charge pumps. Good. Perform PMs on MP #1&2.;Perform state whiteness diverter test and rig inspection with MR Matt Herrera & pill Laubenstein. All tests passed. Annular closed in 12 sec & Knife valve opened in 4 sec.;Test gas alarms.;State did request the certification showing the math for the N2 Back up system sized for our accumulator. We sent in and added to our O drive paperwork.;Attempl to set wear bushing. Unable to get WB past bag. After function test there is a piece of rubber hanging in the slack. Remove Flow riser to inspect annular.;Dress annular and inspect. Remove loose of annular. Send in pies to town. Annular looks ok to run.;Work on TO leak. Open top panel and remove manifold to get to leak, tighten 11 plugs on chunk hydraulic manifold, re -assemble same, function lest system, no Ieaks.;Finish plumbing jet into Bow box. Finish installing cellar drain pan.;lnstall 12 3/8" wear bushing, Pi Drift and P/U 210 joints 5" DS -50 drill pipe racking 105 st is in derrick. Load 8.7+ ppg spud mud into pits. Note: tag bttm @ 45'.;Drift and P/U 17 its 5" HWDP and jars racking in derrick.;MIU top drive on single. Fill diverter stack and lines w/ mud, good. Test mud pumps and surface lines to 3000 psi, good. Pump 700 gpm, Bow box works well w/ fluid 3" from top Bowline.;NVU conductor cleanout BHA, 12 1/4" VAREL RS616G1HX PDC bit, mud motor, 12 1/8" stab, 101/2" IBS, XO= 36.11'. MIU 1 std 5" HWDP and lop drive, break circulation, tag @ 45'. 6/282017 Drill out conductor F/ 45'T/ 160'. 360 GPM, 280 psi, 30 RPM. Circ clean before shutting pumps down 30 min. Working flow line jets & running through bleeder while making connections.;POOH & Stand back HWDP. P/U 2 NMFDC & RIH.;DnII out conductor F1160' T/ 17T. Drill ahead F/ 177'T/288'. @ 360 GPM, 30 RPM, 100-150 FPH. Bow line & Running 500 GPM on bleeder while making connections.;Pump out slow letting the hole cleanup F/ 288' T/ 215'. POOH & stand Working jets back HWDP & Drill collars.;M/U BHA #1, 12.25 PDC Motor BHA. Carry scribe through MWD & UBHO. Check UBHO with Halliburton Gyro. Good. Down load MWD, RAJ Gyro & Hang shieve in derrick.;TIH to 216', wash down to 288' pumping 350 gpm, 350 psi.;Rotary drill 12 1/4" hole 11288' to 309 400 gpm, 720 psi, 40 rpm, 1.5k tq. Note: Run Gyro every stand drilled.;Directional drill @ KOP, 70 deg per DO f/ 3091399', 399', Rack 1 std back, MN single HWDP w/ jars, Gyro survey.;Directional drill f/ 399'to 961'(562') AROP 112 FPH (232 FPH on blm) GPM 480, 1300 PSI WOB 5-8k , 70 RPM, 3.61K TO MW 9.1/ Vis 200, ECD 9.7 PU/SO/ROT 69/69/69 Final gyro @ 728'/1st MWD survey @ 78V:Directional drill f/ 961' to 1763'(802') AROP 133.6 FPH (200 FPH on btm) GPM 583, 1700 PSI WOB 5-10k. 70 RPM, 5K TO MW 9.1/210 Vis, ECD 9.9 PU/SO/ROT 81/73/76.;Pump 30 bbl hi vis sweeps @ 967' and 1480' w/ 200% increase at shakers, mostly clay. Note: RID and release gyro @ 1300' 3.61 slide hrs, 2.72 rotate hrs. Currently 11.75' above the line, 8.04' dght.;Daily losses to formation= 0 bible for total= 0 bbls;Hauled 515 bbls cutting to G&I for total = 515 bbls Hauled 0 bible H2O from 6 mile lake for total = 0 bbl 6/29/2017 Directional drill 12 1/4" hole F/ 1763' T/ 2530'(767') AROP 128 FPH (250 FPH on btm) GPM 475- 550, 1750 PSI WOB 1-6k, 70 RPM, 5K TO MW 9.2/150 Vis, ECD 9.9 PU/SO/ROT 130/87/77.;Sweeps @ 2090' 100 % Increase, Dropped vis from 200+ to 120- 150, 500' after permafrost @ 2509. Screen up from 80s to 100s @ 2000' due to sand content 1%. Perform screen test with new screens.;Directional drill F/ 2530'T/ 3285'(755') AROP 125 FPH (250FPH on him) GPM 525- 580, 1750 PSI WOB 6-10k, 80 RPM, 8K TO MW 9.2/150 Vis, ECD 9.9 PU/SO/ROT 130/87/77.;Directional drill F/ 3285' T/ 4145'(860') AROP 143 FPH (246 FPH on btm) GPM 530, 1750 PSI WOB 6-10k, 70 RPM, 8-9kK TO MW 9.4/110 Vis, ECD 10 PU/SO/ROT 142/85/106.;Pump 25 bbl hi vis sweep @ 3520', sweep back 1000 stks early, 50% increase in cuttings.;Directional drill F/ 4145' T/ 4867'(722') AROP 120 FPH (200 FPH on bim) GPM 530, 1800 PSI WOB 6-14k , 80 RPM, 11-13kK TO MW 9.2/110 Vis, ECD 10.3 PU/SO/ROT 158/91/117.;Pump 25 bbl hi vis sweeps @ 4170' and 4725', sweeps back 1000 stks early, 50% increase in cuttings on tat sweep, 50% increase on 2nd Dump and dilute to help maintain mud wl.;Currently.41' below the line, 2.05' right 10.9 rotate bra, 3.37 slide hm.;Daily, losses to formation= 0 bbls for total= 0 bbls;Hauled1254 bbls cutting to G&I for total = 1769 bbls Hauled 390 bbls H2O from 6 mile lake for total = 390 bbl 6/30/2017 Directional drill 12 1/4" surface hole F/ 4867' T/5612 '(745') AROP 124 FPH (200 FPH on btm) GPM 550, 2150 PSI WOB 4-12k, 80 RPM, 13-16K TO MW 9.2/110 Vis, ECD 10.3 PU/SO/ROT 180/96/130.;Hold back ROP to 150-200 due to G&I Backing up. Add dilution mud to lower ECDs. Pump sweeps @4725'. 5300', 5880', sweeps back 800 stks late, 20-50% increase.;Directional drill F/5612' T/ 6089'(447') AROP 79.5 FPH (110 FPH on btm) GPM 550, 2150 PSI WOB 10-20k , 80 RPM, 15-18kK TO MW 9.2/110 Vis, ECD 10.1 PU/SO/ROT 195196/133.;Directional drill F/ 6089'T/ 6600 @ TD'(511') AROP 93 FPH (156 FPH on btm) GPM 550, 2150 PSI WOB 12-14k, 80 RPM, 18-19K TO MW 9.5/110 Vis, ECD 10.5 PU/SO/ROT 20011001136.;TD surface section 200' past Schrader bluff formation per Hilcorp Geo in heavy clay interval. 1.75 slide hrs, 10.92 rotate hrs. 13.67 above the line, 4.8T left. Verify drill pipe count.;Pump 30 bbl hi vis sweep, Circulate and condition for casing 550 gpm, 2100 psi, 80 rpm, lower YP from 47 to 19 and vis to 60 over 3+ circulations. Sweep back 1000 silks early, 10% increase.;Flowcheck wall, static. Pump out of hole 500 gpm, 1500 psi f/ 6600' to 6062' w/25k overpull, backream to 6040', continue to pump out f/ 6049to 5616'.;Daily losses to formation= 0 bbls for total= 0 bbls;Hauled 1254 bbls cuffing to G&[ for total = 3023 bbls Hauled 780 bbls H2O from 6 mile lake for total = 1170 bbl Hauled 280 bbls H2O from B-Pad for total = 2560 bbl 7/1/2017 Pump Out of the hole F/ 5616' T/ 3930'. 500 GPM 10-15 K over Pulls. Pulling slow getting heavy mud back. Connections are very tight. Having to take the time to break out slow.;Back ream slow F/ 3930' T/ 3650'& let well clean up. Getting One sand and silt over shakers & 10 PPG mud in returns. Connections are very light. Having to take the time to break out slow.;Pump Out of the hole F/ 3650' T/2600'. 500 GPM Over Pulls. 2780' 40K.;Pump Out of the hole F/ 2600' T2050' 500 GPM Over Pulls. Pull slow F/ 2050' T/ 1900' Circ bim up before getting to permafrost. Getting fine sand and silt across shakers. Small chunks of coal.;Pull on elevators F/ 1 900'T/ 1700'. Pulling 25K over. Started swabbing.;Continue to Pump Out of the hole F/ 1700'T/1500'. 500 GPM. Pulling good.;Continue to Pump Out of the hole F/ 1500'T/709'@ HWDP pumping 500 GPM, Pulling good.;POOH on elevators F/ 709', UD 6 jm HWDP ( note: replace HW it qi 1 w/ jt if 12 due to nick on tool face) rack 6 stds HWDP w/ jam in derrick. Note: Strip tool jts packed w/ clay Throughout the trip.;UD 2 Flex collars, UBHO. Strip clay from BHA, download MWD and UD directional tools, drain motor, UD motor and bit. Grade= 2/3/CT/S/X/I/NOrrD. String stab slight leading edge wear, both in gauge.;Clear and clean rig floor, load out tools from pipeshed. Pull 12 3/8" wear bushing.;R/U 9 5/8" handling equipment, R/U volant tool, torque to 39 ft/lbs, hold pjsm with HES, Weatherford, rig crew.;Ensure no debris, P/U, Baker lock and M/U 9 5/8" shoe track, shoe it w/ 2 centralizers 10' from ea, end ever stop collars, 1 centralizer mid tube over stop collar on 2 FC jts.;Ensure proper float operation, Bakerloc and NYU BA if w/ centralizer mid tube over stop collar, P/U and RIH w/ 9 5/8" DWC/C, L-80 40# casing per tally, use BOL 2000 pipe dope.;Utilize dog collar clamp on tat 5 its ran, torque casing to optimum 32300 0/[bs. RIH @ moderate speed, Fill on the fly and every 5 jm ran, RIH to 784' (19 jts ran );Daily losses to formation= 0 bbis for lots[= 0 bbls Hauled 450 bb[s H2O from L-Pad lake for total = 450 bbl;Hauled 523 bbls cutting to G&I for total = 3546 bbls Hauled 300 bb[s H2O from 6 mile lake for total = 1470 bbl 7122017 Run 9 5/8 409 Casing F/ 908' T/ 3090'. Tq Connections to 32000#. Fill on the fly and top off every 5 joints with CRT. Well not loosing on the trip. Break circ every 10 joinls.;Had to Rot past ledge at 1193'. 10 RPM 9K tq @ 4 bpm. Went right pasl.;Circ & condition mud staging pumps up to 6 bpm. ICP 130 FCP 65. Getting 9.7 PPG mud back. Circ two bim up.9.4 in and out. UP/DN 141/95.;Conlinue to Run 95B 40# Casing F/ 3090' T/5000'. Tq Connections to 320009. Fill on the fly and top off every 5joints with CRT. Well not loosing on the trip. Break circ every 10 joints.;Cim & condition mud staging pumps up to 6 bpm, ICP 200 psi 9.6+/ FCP 170 psi CBU until9.4+ m and out. UP/DN 200/110.;Continue to Run 9 518 40# Casing F/ 5000' T/6512''. Tq Connections to 32000#. Fill on the fly and top off every 5 joints with CRT. Break circ every 10 joints. Correct displacement on trip in.;Wash last 2 its down pumping 2 bpm, 180 psi to 6590' on depth, 160 its ran, 7 its left out. UP/DN 3001130.;Circulate and condition for cement job, reciprocate slow 20', rotate 2 rpm, 25k tq, stage pump up slow from 2 bpm, 3 bpm 180 psi, 4 bpm 200 psi, 5 bpm 210 psi, 6 bpm FCP 170 psi. No losses.;PJSM for pumping 1st stage cement job. Shut down, close upper and lower IBOP, R/U cement line and velves.;Continue to circulate, reciprocate and rotate, stage to 5 bpm, 260 psi, shut down pump, R/U cement line, pump 5 bbls water. PT lines to 1000 psi low/ 4000 psi high, good.;Mix and pump 60 bbis 10.5 ppg tuned spacer 3 bpm, 50 psi, note: add red dye to first 10 bbls pumped. shut down, drop bypass plug. 01:22 start batching lead cement.;Pump 307.9 bbls 11.7 ppg exlenda cern lead cement ( 700 sx, 224 bbls mix water, 2.248 YP ) 5 bpm, 420 psi, 142 bbis away slow pump to 2 bpm 100 psi for 20 bbis wl bypass plug passes stage tool.;Pump 60.7 bible 15.8 ppg swift cem tail cement ( 295 sx, 35 bbis mix water, 1.156 YP ) 3.5 bpm, 400 psi. Shut down, drop wiper dart, pump 20 bbls water 3.5 bpm, 115 psi. Swap to rig pump.;Displace with 277.6 bbls 9.4+ ppg mud pumping 4 bpm 70 psi, 1600 stks slow pump to 2 bpm 30 psi for 20 bbls until wiper dart passes ESC tool. 200 bbls pump caught pressure 250 psi.;Swap to cementers, pump 80 bbis water 5 bpm, 585 ps with pressure climbing to 795 psi. Swap to rig. Note: unable to rotate and reciprocate when pumping water, park casing on depth.;Displace with 112.1 bbls 9.4+ ppg mud pumping 4 bpm 680 psi, FCP 940 psi, bump plug on calculated stm. Pressure up 500 psi over FCP @ 1500 psi, and hold. CIP @ 05:32.;Bleed off pressure Rost held. Pressure up to 2850 psi and open ESC tool.;Pump 3 bpm, 270 psi thru ESC @ 2007', 18.6 bbls away see spacer with red dye @ returns, start pumping black water to annulus wl trip tank pump, see cement @ returns 45.88 bbls away.;Spacer and 67 bbls good cement returned to surface. Total estimated losses 62 bbis throughout cement job.;Daily losses to formation= 0 bbls for total= 0 bbis Hauled 0 bbis H2O from L-Pad lake for total = 450 bbl;Hauled 114 bbls cuffing to G&I for total = 3660 bbls Hauled 600 bbis H2O from 6 mile lake for total = 2070 bbl 7/3/2017 Circ out cmt from Es cmt tool @ 2007' after opening tool. 3 bpm, for first him up. Got back mud push, 67 bbl cmt and 40 bbl water. Stage up pumps to 6 bpm & circ clean.;Shul down & Flush all surface equipment with black wmter.;Continue to circulate through stage tool @ 6 bpm while waiting on cmt. MW 9.4 in and ouL;PJSM second stage cmt tool. Break out Volant tool and re-engage before second stage cmt job.;Pump second stage curt job as follow 5 bbl fresh water, 60 bbl 10.5 ppg Tuned spacer, 258.7 bbl Lead cmt, 335 SX @ 10.7 ppg, Perm L Cmt. Pump 36.2 bbl Tail 15.8 PPG, Drop Plug Displace with 20 bbls;Halliburton Displace with 20 bbl H2O, Rig pump 132 bbl mud & bump on calculated strokes. Final lift pressure 630 psi, Pressure up and close cut tool @ 1200 psi. Pressure up to 2000 psi & Hold good.;Bleed down and check flow. Good. CIP @ 15:36. Got back 60 bbl mud push, 185 bbl good cmt to surface. 9 bbl total losses calculated for second stage cmt job.;R/D Volant tool and Weatherford equipment. Drain stack and flush all surface equipment with black water. Blow down cmt lines, Remove Diverter line, Riser, Pick stack & prep to set slips.;Center up 9 5/8" casing, set E-slips per wellhead rep with 275k on slips. Welder cut casing, UD cut P. Continue to clean in mud pi1s.;Set stack down and Range up. Install riser, C/O casing elevators to 5" drill pipe elevators. WU accumulator hyd lines to stack. MN flush tool on it of DP, pump and flush stack. UD flush lool.;N/D stack diverter, break flange bolts, rack back BOP, remove diverter tee from cellar. Vac out cellar box.;Cut off and dress 9 5/8" casing stub ( total cut it 31.27') install 7" x 11" 5m multi bowl and flange up same. Install packing per wellhead rep, test void to 500 /3780 psi 5 min ea. good test.;N/U 11 x 13 5/8" DSA, set BOP stack and flange up to DSA, install kill and choke lines, turn buckles, riser, drip pan and hole fill Iine.;Open BOP doors and inspect ram cavities, button up same. Install 1502 outlets on annulus. Install mouse hole.;R/U test equipment with 5" test it. ready for State witness BOP test. Load pits with 290 bbis 9.5 _SND mud.;lnspect and C/O saver sub;Daily losses to formation= 72.1 bbls for total= 72.1 bbis Hauled 1200 bbis H2O from L-Pad lake for total = 1800 bbl;Hauled 2162 bbis cuffing to G&I for total = 3660 bbis Hauled 0 bbis H2O from 6 mile lake for total = 5822 bbl Hauled 0 bbls H2O from B-Pad for total = 2560 bbl 7/42017 Change out saver sub on Top Drive.;KU 5" Test Joint. Set test plug. Fill/Purge BOPE.;Shell Test ROPE. Test Annular, UPR/LWR VBR,s, Blind Rams, Choke Manifold, Choke/Kill Valves, 5" Floor Valves, Hyd IBOP, Manual IBOP, to 250/3500 psi. 5 min ea.;(1 failure due to air. Bleed down and recycle valves. Test Good.) Perform Draw Down Test: Start 3150 psi, After close 1700 psi, 200 psi build @ 21 sec. Full Recovery 68 seconds. 6 N2 @ 2325 psi ave.;Test PVT and Gas detection System. Test witnessed by AOGCC Rep Adam Earl.;Rig down test equipment. Set 10" ID Wear bushing.;Sewice rig, perform derrick inspection, load tools to rig floor.;P/U Clean Out BHA with VM-1 RR Tricone Bit Wrio jets, 1.5 deg bend Malar. 11 its HWDP/Jar= 405.10';Single in hole picking up 40 jts 5" NC-50 DP from 405'to 1660'.;Hang blocks, slip and out 95' drilling line. Re-calibrate block position and test same.;Single in w/ DS50 DP from 1660' fo 1940', wash down and tag plug just above ESC;Drill cmt f/ 2002' to 2007', Drill out plug and ESC f/ 2007' pumping 400 gpm, 450 psi, 40 rpm, wob 25k, cleanup same, make dry pass, clean. P/U/SO/ROT 83/66/75;Single in w/ 5" DS50 DP f/ 2010' to 3799, TIH w/ sids 5" DP to 6441', correct displacement on trip in. 68 its total DS50;CBU, Circulate and condition thick mud @ returns pumping 350 gpm, 700 psi,;RtU pump in sub wl circ hose, line up and flood choke and kill line, close upper VBR, press up and test 9 5/8" casing to 3000 psi U 30 min charted, 60 psi pressure drop;Check surface equipment, bleed off pressure, re-lest to 3000 psi for 30 min, charted, good. Bleed oft pressure, open VBR. 5 th is pumped, 5 bbls bled oft.;Wash down f/ 6441'to 6448'tag TOC, drill cement and FE. Drill cement from 6441'to Baffle adaptor @ 6461', Drill baffle adaptor @ 6461';;Daily losses to formation= 0 bbls for total= 72.1 bbls Hauled 150 bbis H2O from L-Pad lake for total = 1950 bbl;Hauled 114 bbis cutting to G&I for total = 5936 bbis Hauled 0 bbis H2O from 6 mile lake for total = 2070 bbl 7/5/2017 Continue Drill cement and FE from 6461' to 6600'. Drill 20' new formation to 6620';Displaced well to 9.5 _SND Mud System.;Pull into shoe, RU and Perform FIT to 13.5 ppg EMW using 9 5 ppg MW. Apply 1024 psi. 3 bible pumped. Bleed 2 1/4 bbls back. R/D test equipment.;Monitor static well. POOH from 6566 U4960'. (L/D single @ 6472' to rotate breaks, UD Jt @ 6000' w/bad hard band and replace w/1 st it UD) Pump Slug @ 4960'. POOH to Surface. UD Bit/MTR;CIean and clear rig floor. Prep to PU Geo Pilot/Under Reamer BHA.;PU RSS w/ UR BHA #3 w/ 8.5" SFE46D PDC bit, download MWD, shallow hole pulse test. Finish WU BHA w/ rip tide UR, RIH w/ 3 side 5" HWDP, jars, 1 it 5" HWDP, well commander, 2 stats 5" HWDP= 515.82';Drift and PN 9 its 5" NC50 DP RIH f/ 515' to 770', RIH w/ stds f/ 770' to 1509, WU top drive, pump 500 gpm, 1100 psi, break in geo pilot bearings.;Continue to RIH f/ 1500' to 4000', NU TD, fill pipe, continue RIH to 6551' above shoe. UD std # 42 due to worn hard bands. Correct displacement on TIH;Fill pipe, Wash and ream to bottom @ 6620' pumping 500 gpm, 1450 psi, 30 rpm 14.5k tq. Get SPRs PU/SO/ROT 200/102/137;Ddll 8 12" hole f/ 6620' to 6800' putting UR 99 past 9 5/8" shoe. AROP 45 GPM 500, 1450 PSI WOB 10k. 70 RPM, 15.2K TO MW 9.5/53 Vis, ECD 10.3 PL/SO/ROT 192/96/133;Currently 13.26' above the line, 4.68' Ieft;;Daily losses to formation= 0 bible for total= 72.1 bbis Hauled 0 bbls H2O from L-Pad lake for total = 1950 bbl;Hauled 829 bbls cutting to G&I for total = 6765 bbis Hauled 450 bbls H2O from 6 mile lake for total = 2520 bbl , ball, pull Vbit depth of 6726', open Reamer & observe 100 psi pressure drop, ream down t/6732'. 500 gpm, 1430 psi, 120 rpm, 16.8 Tq. PU to 6726' and :rve 7K over pull and verity reamer open.;Continue to ream down to 6799' up to 12K WOB, PUW 215K, SOW 97K, RWT 136K;Drill ahead f/6799'to 1'. 550 GPM, 1670-1800 PSI, 120 RPM, 16K Tq,18 WOB, 12K DWOB, 10.3 ECD. (Observed Pressure drop to 1440 psi @ 6829'. Return flow stabil and 0 tools all function properly. S;(Observed Pressure drop to 1440 psi @ 6829'. Return flow stabil and MWD tools all function properly. Suspect reamer opened.);POOH 1/68631/6829'. Begin BR up to 6789'. Ream full stand back to 6863'. 550 GPM, 1350 PSI, 100 RPM, 16K Tq, 5K WOB.;Lost hi line :r @ 6289' prior to connection. Switch to rig power, drill 2' and lost power again. Production give ok to go back on high Line.;Drill 9 7/8" hole F/ 686371 (283') AROP 38 FPH (44 FPH on btm) 1600, 1780 PSI WOB 24k, 140 RPM, 16.5K TO 9.5/53 Vis, ECD 10.5 10/ROT 240/90/139 )B 20K;Ddll 9 7/8" hole F/ 7146'T/ 7475'(329') AROP 54.8 FPH (73 FPH on btm) 1600, 1780 PSI WOB 20k, 140 RPM, 17-18K TO 9.5/50 Vis, ECD 10.44 18K;Drill 9 7/8" hole F/ 7475'T/ 7806' (331') AROP 55.1 FPH (72 FPH on bum) )0, 1850 PSI WOB 20-22k, 160 RPM, 18-19K TO /52 Vis, ECD 10.5 ROT 262/91/143 19K;Pump 35 bbl hi vis sweep @ 7560', sweep back on time w/100% increase ty 8.05' above the line, 1.01' Iefl.;;Daily losses to formation= 0 We for total= 72.1 bbis 0 bbls H2O from L -Pad lake for total = 1950 bbl;Hauled 285 bbis cutting to G&I for total = 7050 We 450 bbis H2O from 6 mile lake for total = 2970 bbl Drill 9 7/8" hole F/ 7805' T/ 8120' (315') AROP 53FPH ( 67 FPH on btm) GPM 600, 1890 PSI WOB 20k. 160 RPM, 18-19K TO MW 9.5/52 Vis, ECD 10.4 PU/SO/ROT 265/95/147 DWOB 15K;Pump hi visc nut plug sweep @ 8125'. 200 % increase cuttings at shakers. Running 2% lube. Both centrifuges on Iine.;Drill 9 7/8" hole F/ 8120' T/ 8501' (381') AROP 64 FPH (77 FPH on btm) GPM 600, 1920 PSI WOB 20-25k , 160 RPM, 18-20K TO MW 9.5/52 Vis, ECD 10.4 DWOB 15K;Stan turning azimuth from 838V w/ 70% @ 80L TF.;Drill 9 7/8" hole F/ 8501'T/ 8873' (372') AROP 62 FPH ( 73 FPH on btm) GPM 540, 1750 PSI WOB 20-25k, 120 RPM, 19-201( TO MW in/out 10.2/9.7 Vis 50, ECD 11 PU/SO/ROT 241/118/159 DWOB 20K;Pump 30 bbl hi vis nut plug sweep @ 862T, sweep back on time w/ 10% increase.;At 8800' increase MW before drilling into HRZ @ 9054' f/ 9.5 ppg to 10.5 ppg adding 12 ppg LSND mud w/ black product from vac trucks to system over 2 circulations until 10.3+ ppg in/outDrill 9 7/8" hole F/ 8873' T/ 9002' (129') AROP 64.5 FPH ( 73.5 FPH on btm) GPM 550, 1750 PSI WOB 20-25k, 120-140 RPM, 18-20K TO MW in/out 10.3+ Vis 47, ECD 11.2 PU/SO/ROT 2451114/157 DWOB 20K;Add barite to finish increasing MW f/ 10.3+ ppg to 10.5 ppg in/out before drilling past 9002' (50' above HRZ) pumping 600 gpm, 2200 psi, rotating and work pipe.;Get new parameters w/10.5 ppg MW /8 ppb black product /2% Iubes;Drill 9 7/8" hole F/ 9002' T/ 9100' (98') AROP 39.2 FPH (49 FPH on btm) GPM 500, 1750 PSI WOB 15-20k , 120-140 RPM, 19-20K TO MW in/out 10.5 Vis 49, ECD 11.3 B 12K;Continue w/ build and turn. 100% deflection, RSS giving avg of 4.71 deg / 100' output Encounter severe slip stick entering HRZ @ 9054' ally 3.24' above the line, 0.67' right;;Daily losses to formation= 0 bible for total= 72.1 bbis d 0 bbis H2O from L -Pad lake for total = 1950 bbl;Hauled 456 bible cuffing to G&I for total = 7506 bbis d 600 bbis H2O from 6 mile lake for total = 3570 bbl Drill 9 718" hole F/ 9100' T/ 9230' (130') AROP 37 FPH (43 FPH on btm) GPM 500, 1750 PSI WOB 15-20k, 120-160 RPM, 15-23K TQ MW in/out 10.5 Vis 49, ECD 11.3 PU/SO/ROT 242/114/156 DWOB 12-15K;Pump sweep @ 9195';Lost swab on MP# 2. PU off boltm, reduce pump to 300 gpm, Circulate out sweep with MP 1 while replace swab on MP 2.;Service Rig and Continue to circulate while change out Piston Wear plate on pump #2.300 gpm/715 psi.;Drill 9 7/8" hole F/ 9230' T/ 9408' (178) AROP 27 FPH (47.5 FPH on him) GPM 525, 1875 PSI WOB 10-25k, 130-170 RPM, 15-23K TQ MW in/out 10.5 Vis 49, ECD 11.3 PU/SO/ROT 242/114/156 DWOB 15-20K;Last survey 9349', flow and 15'right of plan. Assembly not putting out the planned 6° doglegs. Drilling through the HRZ, having frequent periods of law ROP due to high stick slip and;erratic torque which is not helping build rates. Projecting ahead with 4.75° doglegs, we can achieve the inclination required for 7" casing point but will be around 200' off to the right of plan.;Drill 9 7/8" hole F/ 9408' T/ 9563'(155') AROP 25.8 FPH ( 31.9 FPH on him) GPM 500, 1900 PSI WOB 15-251k , 130 RPM, 17-20K TQ err MW in/out 10.45 Vis 51, ECD 11.2 PU/SO/ROT 242/112/161 DWOB 13-18K;9445' pump 30 bbl hi vis sweep w/ walnut. 100% increase @ sweep retums.;Drill 9 7/8" hole F/ 9563' T/ 9725' (162) AROP 27 FPH (36 FPH on btm) GPM 550, 2100 PSI WOB 15-25k, 120 RPM, 18-20K TQ MW in/out 10.4+ Vis 50, ECD 11.3 SPU/SO/ROT 2571113/163 DWOB 18-20K;Very slow drilling f/ 9590' to 9617' ROP dropped it 25 fph to 7 fph or less, suspect balled bit, Pump 30 bbl hi vis sweep w130 ppb walnut, as soon as sweep out bit ROP increased to 35-45 FPH ;Build rates drop off with the slow ROP. See sections of 4-7'/100' build rates when getting a consistent ROP but not often enough to achieve average desired target output.;Currently 3.42' below the line, 45.43'right.;;Daily lasses to formation= 0 bbis for total= 72.1 bbis Hauled 0 bbls H2O from L-Pad lake for total = 1950 bbl;Hauled 606 bbis cuffing to G&I for total = 8122 We Hauled 600 bbis H2O from 6 mile lake for total = 4170 bbl Grill 9 7/8" hole F/ 9725'T/ 9955'(230r) AROP 38 FPH (46 FPH on btm) GPM 550, 2424 PSI WOB 18-27k, 110-170 RPM, 13-25K TQ MW inlout 10.4+ Vis 50, ECD 11.3 PU/SO/ROT 264/112/156 DWOB 18-20K;Pump 30 bbl low wt/visc nut plug sweep, back on time with 50% increase in cuttings. See 200 psi drop after sweep. Make constant parameter adjustments to maintain -50 ROP.,Drill 9 7/8" hole F/ 9955' T/ 10146' (191') AROP 32 FPH ( 37.5 FPH on bm) GPM 550, 2450 PSI WOB 20-27k, 120-170 RPM, 15-25K TQ MW inlout 10.4+ Vis 50, ECD 11.4 PU/SO/ROT 290/98/157 DWOB 18-20K;Drill 9 7/8" hole F/ 10146' T/ 10293'@ TO (147') AROP 49 FPH (59 FPH on bm) GPM 550, 2450 PSI WOB 25k, 160 RPM, 18-21K TQ MW in/out 10.5 Vis 50, ECD 11.4 PU/SO/ROT 286198/160 DWOB 18-23K;Pump 30 bbl to vis sweep w/ walnut @ 10198', sweep back on time w/ no increase. Note: drilling break @ 10240'f/ 60 to 200 fph. TO in Kuparuk C sand per Geo @ 10293';45.08' below the line, 255.92' right;Pump 35 bbl hi vis sweep 600 gpm, 2500 psi, rotate 120 rpm, working pipe. Inc MW f/ 10.5 ppg to 10.8 ppg in/out adding 290 bbls 12 ppg spike fluid. Sweep back on time, 10% increase. Max gas @ BU 314;Finish weight up to 11 ppg inlout using barite.;Cont to circulate- work pipe while Mixing liner running pill, 130 bbis of 11 ppg , 12 ppb black product and graphite w/, 4% lube to cover 1372' of OH to 8921' @ 100'+ above HRZ. PU/SO/ROT 273/1091161;Get new SPRs, flow check well, static. POOH 5 ads on elevators 500 fph if 10293' to 9979', TIH 500 fph to btim with no ssues.;;Daily losses to formation= 0 bbis for total= 72.1 bbis iauled 0 bbis H2O from L-Pad lake for total = 1950 bbl;Hauled 627 bbls cutting to G&I for total = 8749 bbls iauled 600 bbls H2O from 6 mile lake for total = 4770 bbl 3reak Circ @ 500 gpm/1900 psi. Pump 130 bbis of Pill, Chase with 132.8 bbis Mud, follow with 20 bbis slug, chase slug with 7 bbis Mud. DUW 264KISOW 117K w/pump. 2771C/117K no pump.;TOH on elevators f/10293'to 8000' UD 5" DP @ 500 fph/8 fpm (2293') as per Engineer Swab/Surge rrip Schedule;TOH F/8000'to 7000' UD 5" dp @ 1000 fph/16.7 fpm as per Swab/Surge Trip Schedule I-OH F/7000' to 6800' UD 5" dp @ 1500 fph/25 fpm;Circulate 1 hole volume from 6800' @ 600 GPW2150 psi. Pump Slug;TOH F/6800' to 6000' UD 5" dp @ 1500 fph/25 fpm as per Swab/Surge Trip Schedule;TOH F/6000'to 5000' UD 5" dp @ 2000 fph/33 fpm as per Swab/Surge Trip Schedufe;TOH F/5009to 1000' UD 5" dp @ 2500 fph/41.7 fpm as per Swab/Surge Trip Schedule;TOH F/4000'to HWDP' UD 5" dp @ 3000 fph/50 fpm as per Swab/Surge Trip Schedule Jote: last 20 jts over torqued to 601k, have to warm up tool its to breakout. :orrect displacement on trip outflow check well, static. TIH with 6 side excess 5" DP in Derrick from 515' to 89V @ 50 fpm.;TOH F/ 890' to HWDP' UD 5" ip @ 3000 fph/50 fpm as per Swab/Surge Trip Schedule;UD HWDP, Well Commander, Jars and Ripe Tide Under Reamer. Down Load MWD, UD emaining BHA. Bit Graded: 1,1,WT,A,X,I,ERTD .oad out drill pipe and BHA f/ pipe shed.;Note: recovered 7 1/2" wide x 12" long piece of curved metal, resembling pari of ES cementer shift sleeve wedged m lower stab of geo-pilot.;Clear and clean rig floor, pull 10" ID wear bushing.;Close blind ram, C/O upper VBR to 7" casing rams.;;Daily losses to formation= I bible for total= 72.1 bbis iauled 0 bible H2O from L-Pad lake for total = 1950 bbl;Hauled 119 bbis cutting to G&I for total = 8868 bbis iauled 300 bbis H2O from 6 mile lake for total = 5070 bbl 7/11/2017 Continue with changing to 7" Pipe Rams. Rig up test equipment. Test 7" Solid body rams to 250/3500 psi. Rig down Test equipment.;Service Rig;Rig up to run 7" 26#, L-80, 563 Hyd Casing. MU WOT Volant w/ Cement Swivel/Bail Extensions. Rig up power tangs ect.;PU Landing joint, MU Fluted Mandrel Casing Hanger. Drift run casing hanger. Adjust TD Lube oil pump PSI. PJSM on running casing.;P/U Shoe track assy. With thread lock. Flash light Jts verify no debris. Fill Pipe, Check Floats, Floats good.;Run 7" 26# 563 Hyd Casing to 4000' @ 3000 fph/50 fpm as per Swab/Surge Trip Schedule;Run 7" Casing from 4000 to 6000' @ 2000 fph/33 fpm as per Swab/Surge Trip Schedule;Run 7" Casing from 6000 to 6600' (9 518" Csg Shoe)@ 1500fph/25 fpm as per Swab/Surge Trip Schedule;@ the 9 5/8" Shoe, Break circulation and CBU staging up to 8 bpm. 2 bpm 1226 psi, 3 bpm 1275 psi, 4 bpm / 320 psi, 5 bpm / 360 psi, 6 bpm / 400 psi, 7 bpm/450 psi, 8 bpm/500 psi. Full returns;Run T' Casing from 6800 to 7000' @ 1500 fph/25 fpm as per Swab/Surge Trip Schedule Run 7" Casing from 7000 to 8000' @ 1000 fph/16.7 fpm as per Swab/Surge Trip Schedule;Run T' Casing from 8000 to 8845' @ 500 fph/8.3 fpm as per Swab/Surge Trip Schedule. Clean trip to 8845' MD. Proper displacement.;@ 8845', Break circulation staging pump up slowly to 5 BPM / 535 psi while reciprocating pipe. Had full returns for 12 min @ 5 BPM before psi drop and diminishing returns.;Reduce pump rate staging down from 5 bpm to 1 bpm / 220 psi (ICP was 295 psi) attempting to establish circulation. Had slight returns that were intermittent. 91 bbis loss to formation;234k Up, 125k Dn- Wts clean with no indications of differential sticking. Attempt to obtain rpm parameters. Stalled @ 13k but could establish slight intermittent 1-2 rpm when working pipe.;Unable to establish notable returns. Discuss options with drilling team. Decision made to POOH and attempt to establish circulation every Sits. Static losses @ 0 BPH.;POOH laying down casing from 8845'- T/ 7997' MD. Attempt to establish circulation every 200' while pulling out of hole at 500 fph.;Hauled 114 bible cutting to G&I for total = 8868 bbls Hauled 150 bible H2O from 6 mile lake for total = 5220 bbis Hauled 0 bible H2O from L-Pad for total = 1950 bbls;Hauled 0 bbls H2O from B-Pad for total = 2560 bbis MUM IQ.... 01 hhI1 11 formal on for Intel - 161 hhl, 7/121'2017 Cont POOH laying down casing from 7997' - T/ 7810" MD. No isu ies laying down casing.;Break circ @ 1 bpm/155 psi, no returns. 1.5 bpm/165 psi w/slight returns, staging pump up to 2 bpm/210 psi. Work pipe, attempt to establish returns, pump on up stroke, no pump on down stroke.;Start lowering MW from 11.0 to 10.5 ppg w/25 ppb LCM BG. No sucess establishing sufficent returns. Loss rate @ 150 BPH while circulate/Hole static with pump off.;Established slightly better returns w/slight displacement returns on down stroke with no pump.;POOH laying down additional 5jts casing from 7810'to 7600';Bring on pump @ 1 bpm/210 psi staging up to 2.5 bpm/255 psi. See 30 % returns w/initial -105 bph loss rate. Use higher pump rate on up stroke and 1 bpm as working rate for down stroke.;lncrease pump rate .5 bpm in 30 min intervals as loss rate decreased and return flow increased. Staged up to 3.5 bph w/14 bph loss rate. Increased pump to 4 bpm w/30 bph lass rate.;Remain @ 3.5 bph with loss rate diminsh U 30 bph to 0 bph, w/ 10.5 mw in and 10.6 out. continue bring 10.5 mw to surface @ 3.5 bph/250 psi.See 10.5 MW out @ 868 bbis pumped. 345 bible over calculated;RIH w/ 7", 26#, L-80, Hydril 563 casing F/ 7600' T/ 842T MD. Broke circulation @ 8021' MD staging up to 3.5 1255 psi (full returns).;Attempt to circulate @ 8427' MD. Psi up to 600 psi with no circulation. bleed off and psi up to 700 psi w/ same results several times. Troubleshoot surface equipment (good).;Pull 2 its and L/D F/ 8427' - T/ 8340' MD. Psi up to 1000 psi and work pipe to clear obstruction in casing string. Re-establish circulation stage up to 3.5 BPM / 282 psi w/ no lasses. Circ 30 bbls;Wash do csg F/ 8340' - T/ 9380' MD. 2 BPM / 330 psi / 22%flow. 121k dn, 244k up. Consistently saw 150-200 over psi when breaking circulation each if then pressure would fall back to normal.;Over pressures seemed to be time sensitive. The longer the pumps were down, the more pressure it took to re-establish circulation. Tagged @ 9365' w/ 9k dn. Stuck @ 9365' MD.;Packed off @ 700 psi. Bleed psi off and break free. Stick pipe while simultaneously packing off @ 700 psi. Bleed psi off, rotate @ 1-2 rpm w/ 14k tq.;Free string and re-establish circulation w/ rot. Stage up pumps to 2 BPM w/ 320 psi. 35% returns.;Pump @ 2 BPM, 320 psi w/ 15% flow w/ 35% returns while reciprocating pipe @ 6 fpm. 121k dn, 2441k up. Condition hole to re-establish full returns. Pump 25 bbls 11#, 40 ppb LCM pill.;Hauled 62 bbis cuttings to G&I for total = 8930 bbis Hauled 300 bbls H2O from 6 mile lake for total = 5520 bbis Hauled 0 bbis H2O from L-Pad for total = 1950 bbls;Hauled 0 bbis H2O from B-Pad for total = 2560 bible Daily losses to formation 426 bbls for total = 498 bbis 7/132017 Continue establish returns @ 9365', Stage pump f/2 bpm to 4 bpm as return flow increases and loss rate decrease. Had innitial 46 bph loss rate @ 4 bpm. Remain @ 4 bpm up stroke and 2 bpm down stmke.;Obtain 2nd loss rate @ 4bpm w/39 bph loss rate. 10.5 ppg to surface at 17400 stks. Pumping 4 bpm W/7.9 bph loss rate. Pumped total of 1,075 bible to achieve full returns with 10.5 ppg in/out.;Wash down w/casing from 9380'. Work through bridge and pack offs @ 9390' pumping 3.5 bpm/310 psi. PUW 255/SOW 120K W/Pump. Break circulation on up stroke. @ 9525, Encounter 500 to 700 ps PUW 296K. At;@ 9525, see pack off to 700 psi, fight pack off issues with no success. Bleed to zero, pressure back up to 700-800 on casing several times, with no bleed off while working pipe.;POOH laying down casing 09525 to 9380' attempting to re establish circulation on each joint UD. Pipe stuck @ 9354' w/no circulation. Work pipe w max straight pull 475K,;Pressure up casing 800.1500 psi w/attempting to work pipe free. Begin to stage pump up to 2000 psi, see fluid movement @ 1800 psi, continue work pipe and see consistent pump psi drop.;Park @ neutral wt, stage pump to 4 bpm /450 psi, straight pull to 465K and free pipe.;Circulate and condition hole reciprocating pipe F/ 9387' - T/ 9346' MD. Rot @ 3-6 rpm, 20k tq, Initial circulating rate staged up to 3.5 BPM, 390 psi W/ 50% returns. Staged up to 6 BPM, 415 psi.;Losses consistently diminished as we staged up to 6 BPM. Pump 25 bbis 50 ppb LCM pill while staging pumps up. Had full returns just prior to LCM pill clearing shoe.;CBU after establishing full returns. Saw moderate amounts of sand @ shakers wl no significant shale cuttings observed.;Wash and Ream casing down F/ 9387'- T/ 9536' MD. At connections, Hold 180 psi on backside while making up its via annular to stabilize shales and loss zone. Saw full returns after each connection.;Wash do @ 300 fph, 6 BPM, 390 psi w/ 47% flow. 3-6 rpm w/ 20k tq. Saw 3-8k bobbles past 9520' MD. Work pipe down 4-6 feet increments before moving forward when in ratty hole.;Stalled, packed off and took wt @ 9536' MD. 8- 10k tag. Stuck casing @ 9536 w/ diminished returns (85% losses). Work tight hole F/ 9536'- T/ 9509' MD.;Work pipe staging up to 480k max up w/ and without pumps and rotary (20k tq).;Ramp pumps up (1-6 BPM) and bleed off while holding tq and up wt @ 480k. Hold 470-480k up and work rotation oscilating pipe w/ max tq 25k wl and without pumps. Maintain slight returns when pumping;1830 max psi @ 6 BPM pump rate. 3 BPM, 1715 psi w/13% returns.;Hauled 67 bible cuttings to G&I for total = 8997 bbis Hauled 300 bbis H2O from 6 mile lake for total = 5820 bbls Hauled 0 bbls H2O from L-Pad for total = 1950 bbls;Hauled 0 bbis H2O from B-Pad for total = 2560 bbls Daily losses to formation 296 bbis for total = 794 bbis 7/14/2017 Continue work stuck pipe @ 9510' MD. Max straight pull 480k. Max tq 30k. 2 BPM, 1675 psi. 10% returns. Attempt all possible parameters w/ no progress. Pump 25 bbl (50ppb) LCM pill-no change.;Continue work stuck pipe @ 9510' (no progress). Lost all circulation. Inject @ 6 BPM, 1850 psi when attempting to surge pumps and work free.;Perform full derrick inspection (good). Grease TDS, Blocks, Crown and Drawworks.;Conlinue working stuck pipe @ 9510' MD. 480k max pull, 30k max tq while oscilating. No circulation. Attempt to circulate with pump rates ranging .5 to 12 BPM w/ max injection psi 2450 psi (no go).;No progress from 9510' MD.;N/D flow riser and unflange adapter flange from top of annular. R/U airslips below table on top of annular. Set slips wl 162k string wt. Install safety clamp. Attempt to breakout CRT (no success);CRT stuck in joint of casing. R/U to UD CRT w/joint of casing. P/Jand reset airslips w/ 165k string wt. Close annular w/ reduced psi @ 730 psi. Re-install safety clamp.;R/U power tongs w/ double snub lines and breakout jt. UDjt with CRT.;Hauled 0 bbis cuttings to G&I for total = 8997 bbls Hauled 450 bible H2O from 6 mile lake for total = 6270 bbis Hauled 150 bbis H2O from L-Pad lake for total = 2100;Hauled 0 bible H2O from B-Pad for total = 2560 bbls belly losses to formation 1511 Ithis for total = 2305 bbl 7/15/2017 M/U xo pup (HTTC pin x Hydril box). WU 10' Hydril pup jt. P/U string and release air slips. N/U flow riser.;Clean and Paint rig. Perform PM on rig equipment while wailing on wireline services.;R/U Pollard E -line. RIH w/ 7" "K-1" CIBP (BOT) to tag depth of 9404' (soft tag - 50 fibs) on .25" E -line. 2100# up, 400# dn. Pick up and place CIBP on depth @ 9250' MD w/ 2100# line tension.;Set CIBP and observe 600# drop on line tension indicating CIBP set on depth as designed. P/U 20' and slack back off tagging CIBP on depth.;POOH w/ E -line. R/D Pollard E -line and stage equipment on Iocation.;N/D flow riser and set air slips on top of annular w/ 185k string wt. B/O xo and pup jt, UD same. MN 7" cutoff it to protect collar during drill pipe trips. Install containment for Flow box.;C/O DS -50 saver sub to HT -38 saver sub. Service TDS.;PJSM, M/U 6-1/8"BHI STX-1Milltooth (3x15's), bit sub (ported float installed) and xo sub (5.3'total length). Single in hole wl4", HT -38, 14#, 5-135 drill pipe to 3402' MD (108 its). 2.33" drift;Hauled 57 bbls cuffing to G&I for total= 9054 bbls Hauled 150 bbls H2O from 6 mile lake for total= 6420 bbls Hauled 300 bbls H2O from L -Pad lake for total = 2400 bbls;Hauled 0 bbis from B -Pad for total = 2560 bbls Daily losses to formation 100 bbls for total = 2405 bbls 7/16/2017 Continue to single in hole picking up 4" DP from 3402'to 6286' (200jts total);Slip and cut 188' Drill Iine.;Service Rig;POOH and set back 4" DP from 6286' to surface. Prep to PU 4" OP.;Single in hole picking up remaing 100 its 4" DP;POOH, set back 50 stands 4" OP. B/O bit, bit sub, and xo. UD same.;R/D 7" cutoff trip nipple with containment. M/U 7" pup jts and R/U test equipment. Test 7" casing to CIBP @ 9250' MD. 3100 psi w/ 15 min hold (good). R/D test equipmenl.;WD air slips from top of annular, Remove choke and kill lines. Break wellhead Ranges. Lift stack. Set "C" 22 E -slips w/ 150k string wt. Rough out 7". Remove and UD cutoff it 15.52'.;Dress 7" esq. Attempt to set packoff (no go). Remove and inspect bowl (goad). Redress packoff w/ dove tail seal removed. Set stack. MAl packoff on running tool and set from floor (good). RILDS.;N/U BOP stack, choke and kill lines, tighten Ranges and install riser.;C/O upper rams from 7" to VBR's (2-7/8" x 5-1/2"). Inspect ram body. Charge Koomey.;lnstall test plug w/ 4" test it. Flood stack, choke manifold and test equipment. Test BOP equipment 250/3500 w/ 5 min hold on each. Chart and record same. AOGCC rep Lou Laubenstein waived witness;Hauled 0 bbls cutting to G&I for total = 9054 bbls Hauled 150 bbls H2O from 6 mile lake for total = 6570 bbls Hauled 0 bbls H2O from L -Pad for total = 2400 bbls;Hauled 0 bbls H2O from B -Pad for total = 2560 bbls Udy s in formation 0 bbis for total = 2405 bbis 7/17/2017 Continue Test BOP equipment 250/3500 w/ 5 min hold on each. Chart and record same. AOGCC rep Lou Laubenstein waived witness. No Failures. Test Gas alarms and PVT Systems. Perform Accumulator Test.;Blow Down and rig down test equipment. PU landing it w/Pack off running tool. Pull Pack Off. Close in Well and test Flange breaks to 3500 PSi.;Service Rig;R/U Pollard, RIH with E -line. Could not get to 9250'. Put guns on depth @ 9215' btm shot and 9210'top shot. Fire guns with good indication of detonation. POOH w/E-Line. Set E -Line aside.;Close Blind Rams and establish circulation through parts @ 9210', laking returns out annulus valve to cellar box. Stage pump f/1 bpm/310 psi to 8 bpm/690 psi. Pumped 43 bbls total.;Rig down PESI while rig up return line from annulus to choke Iine.;CBU x2 staging pump to 5 bpm, taking returns through choke. Stage up pumps to 7 BPM, 605 psi ICP 1505 FCP w/ 9.5 MW IN , 9.6 MW OUT. 6-15 units BGG. Initial loss rate 70 BPH @ 6 BPM T/ 0 Iosses.;Started seeing pit gain as MW out was getting closer to targeted 9.5 ppg MW. Shut down and monitor well via Trip Tank w/ 9.6 MW . Flow @ 60 BPH and falling off to 12 BPH before continuing operations;Well was ballooning. annulus @ 360 psi, casing @ 80 psi. Monitored flow per minute with reducing rate and vol @ trip tank#1 taking returns through choke. Bleed down casing to 0 psi, Csg @ 6 psL;Open Blinds-monitorwell (static)Cont monitor 7'h9-5/8" annulus w/down trending flow to trip tank. Shut blinds and establish circulation through parts (good). Open well backup and monitor (static).;PJSM, NVU X-1" Mech. 3BB - 7" cmt retainer on Snap latch setting tool. Verify setting tool in properly located for running in hole. RIH on 4" DP out of derrick T/ 8187' @ 100 fpm as per BOT;Monitor trip displacement on pill pit #2 and monitor flowback from annulus on trip tank#1 (5 BPH) and continuing to trend down.;Hauled 461 bbls cuttings to G&1 for total = 9515 bbls Hauled 150 bbis H2O from 6 mile lake for total = 6720 bbls Hauled 600 bbls H2O from L -Pad for total = 3000 bbls;Hauled 0 bbls H2O from B -Pad for total = 2560 bbls Daily losses to formation 267 bbls for total = 2672 bbis .5-1 gallon hydraulic spill from water truck. MP Environmental notified. 7/18/2017 RIH on 4" DP F/ 8187' T/ 9134'. Close in well & establish up to 4 bpm @ 880 psi. Took 1000 psi to break circ @ 1 bpm. Set cm retainer @ 9160' as per baker. Snap in and out good.;Set down 30k on amt retainer. Test back can retainer to 3000 psi for 5 min. Goad. Establish circ through curt retainer taking returns through the annulus to the choke and stage up pumps to 5 bpm.;Circ & condition while waiting for Halliburton to rig up @ 5 bpm, 915 psi.;PJSM, Line up to Haliburton & pump 5 bbl water to test lines. test lines to 3500. Good. Swap to rig & continue to circ while waiting on Halliburton to batch up.;Line up and pump 15 bbl water, 38.2 bbl 15.8 cmt, 186 sx, Chase with 5 bbl water, Lineup to rig and displace with 90 bbl 9.5 mud, with FCP @ 670.( Caught pressure @ 20 bbl away);P/U & unsling from retainer. Saw pressure drop. Pump 2 bbl leaving 1.3 bbl in the pipe. R/D circ lines. Pull 5 stands dry. Drop wiper ball & circ two btm up. No curt in returns.;CIP @ 13:43. Est TOC @ 8404' MD Annulus shut in with 60 psi after unstinging from retainer. Showing .8bbl over on G/L after displacing.;Service rig.;POOH F/ 8820'T/ surface. UD running tool.;PJSM, M41 T' Python composite plug as per BOT rep. RIH on 4" DP @ 100 fpm running speed from surface to 7117' MD.;132k UP, 76k DN. P/U to 7110' (btm of plug). Drop 1-7/16" phenolic ball do dp. Pump do @ 3 bpm, 303 psi. Reduce rate @ 700 stks to 2 BPM, 220 psi.;Ball on seat @ 909 stks (1195 calc stks). Psi up to 2000 psi, set plug. P/U to 151 k shear off "Python" plug,;Psi drop to 0 psi, wt indicator showed drop from 151 k to 84k static. P/U 20' and slack back off with light tag (31K) on depth @ 7108' MD (top of p[ug).;Pump 20 bbl dtyjob. POOH racking back 4" dp F/ 7108' - T/ 2331' MD. Hole took proper displacement.;Continue POOH laying down 4" dp (74 its) F/ 2331' - T/ surface. B/O and Clean, UD running tool.;Bring Baker tools to floor. M/U 5.5" body cutters w/2-1/4" blades (8.538" max OD), spiral 6" OD stab, xo (total BHA length= 8.73). RIH on 4" DP F/ surface - T/ 5976' MD.;Hauled 351 bbls cuttings for total= 9866 bbls Hauled 0 bbls H2O from 6 mile lake for total = 6720 bbls Hauled 600 bbls H2O from L -Pad for total = 3600 bbls;Hauled 0 bbls H2O from B -Pad for total = 2560 bbls Daily losses 0 bbls to formation for total = 2672 bbls 7/19/2017 RIH on 4" dp with Baker Knives F/ 5984' T/ 6994. Set knives at 7015'. Middle of 7" Joint. Take parameters as per baker. ROT 80 rpm, & stage up pumps to 990 psi. Saw pressure dump to 550 psi.;Slack off and mill. Shut down pump & pick up off the casing stump. Bring on pump with no rotary & slack off. Saw pressure dump to at set down. Good indication of out. Also Flowing out annulus more.;Shut annular and break circ @ 1 bpm @ 120 psi. Full returns out annulus. Shut down monitor annulus flow. Slowing down from 10 bpm to 3 bpm. Fluid dropping in the casing. U tubing.;POOH F/ 7015'T/ Surface and L/D Knives. Clean and clear the rig floor. Monitor annulus. Flowing 10 bph. Let fluid drop in the casing and flow slowed to .5 bpm in i hr.;Close blinds and change top rams to 7". Set dummy pack off & test plug. Test 7" rams and choke line to 250/3500 psi. RID testing equipment.;NVU baker spear & spear casing stump. Work wt up to 365K. We got movement at 300 but slips were sliding on the casing and we were unable to go back down. Pulled casing stump up 2'.;Break circ in to cellar up to 4 bpm. No help. Shut down and consult drilling engineer. RID spear. Decided to MMU cutters and RIH to 50' in the shoe and out 7".;M/U 5.5" body cutlers w/ 2-1/4" blades (8.538" Max OD), Spiral Stabilizer w/ 6" OD, XO (Total BHA length = 8.73') and RIH on 4" DP out of derrick to cut depth of 6540' MD.;Obtam parameters - 80 rpm, 6.3k tq, 1.7 BPM 1325 psi, 4.3 BPM / 850 psi. Cut 7" casing @ 6540' MD. 80 rpm's w/ 4.3 bpm flow.;7 mins into cutting operations, significant psi drop from 1000 psi to 490 psi, Tq dropped from 6.3k to 5.6k.;Felt pipe sever and notable bump on rig floor. P/U 5' and observe cutters engage free pipe w/ psi increase and slight increase in up wt. Shutdown monitor well (static).;POOH F/ 6540'- T/ surface. B/O and UD cutter assy. Good indicators on cutter blades of cut on casing. 500' midnight depth. BOP drill while tripping @ 23:00 hrs (38 sec to secure well).;P/U working single, lWU spear w/ 6.220" grapple, packoff and 8-1/4" stop ring. Drain stack and annulus. RIH and engage TOP @ wellhead. P/U with good latch on fish.;PIU to 215K, Saw bobble and wt indicator drop to 168k. Pulled free pipe to surface with 175k up. Monitor well via trip tank. Separate "E" slips and remove same from cutoff jt.;Bring casing equipment to rig floor. R/U Weatherford casing. Monitor well via trip tank (static).;PJSM, Attempt to breakout cutoff w/ spear assy. Unable to break casing connection using power tongs and rig tongs together @ 30k tq. Heat connection with hammer (no go).;PJSM, Hot work permit. Close annular, cover rotary table with fire blanket, maintain continuous atmospheric monitoring. Welder heat connection. Break with power tongs. UD spear assy w/ cutoff jt.;Monitor well (static). Continue pulling 7" HTTC casing F/ 6540'- T/ 5884' MD. Continue heating connections to breakout.;Hauled 114 bbls cuffings to G&I for total = 9980 bbls Hauled 150 bbls H2O from 6 mile lake for total = 6870 bbls Hauled 0 bbis H2O from L-Pad lake for total = 3600 bbls;Hauled 0 bbls H2O from B-Pad for total = 2560 bbls Daily losses 0 bbls to formation for total = 2672 bbls 7/20/2017 Continue POOH w/T' casing F/ 5884' - T/ surface. Heat every connection to breakout and Iaydown.;Clean and clear rig floor. R/D Weatherford casing equipment. Set 10" ID wear bushing.;Rig service. Grease traveling equipment.;Mob fishing tools to floor. Verify measurements with printed BHA (good). R/U 4" handling equipment.;P/U 7" cutoffjl w/ spear assy. Breakout spear assy and laydown 7" cutoff jt. M/U BOT ITCO-type spear w/ 6.220' grapple (re- run), inspect same (good). PIU remaining BHA.;BHA as follows - Spear,bumpers, oil jars, xo, 6 Ps 6" spiral DC's, xo, accelerators, bottleneck XO (total length BHA = 234.22').;RIH F/ 234'- T/ 6525' MD. Obtain Parameters @ 6525' MD, 1301k up, 83k dn.;S/O engage TOF on depth @ 6540'. NO GO @ 6550' MD (10'swallow). Tag w/ 4k, P/U to 1501c Set do 201k to cock jars, P/U 200k and bleed off jars to seat grapple (fish on).;Fire jars staging up from 2501k up to 275k up. Stage up from 275k to 325k post firing jars each time with straight pull. Fired jars a total of 7 times.;Saw movement on 7th fire with straight pull of 310k before breaking over and falling back to 1501k. SIO and re-tag on depth. PIU w/ 145-150k up wt (7" fish calculated wt 11,200 Ibs).;POOH F/ 7016- T/ 737' MD racking back all 4" dp. Hole took proper displacement.;L/D BOT fishing assy F/ 73T - T/ 503' MD. Bottleneck XO, DC's, XO,all jars & accelerators.;R/U Weatherford Casing equipment. L/D T' cutoff jt w/ spear, C/O elevators, ready TIW. Continue Laying down 7" casing F/ 503'+/- to 175' MD. Heat each connection to breakout ;Hauled 0 bbls cuttings to G&I for total = 9980 bbis Hauled 150 bbls H2O from 6 mile lake for total = 7020 bbls Hauled 0 bbis H2O from L-Pad lake for total = 3600 bbls;Hauled 0 bbls H2O from B-Pad lake for total = 2560 bbls Daily losses 0 bbis to formation for total = 2672 bbls 7/21/2017 Continue to Pull 7" 563 Heating up each connection with torch to break. F/ 400' To surface. L/D cut off joint. 33.35 cut. L/D Fishing equipment.;Service rig.;Change top rams from 7" to 2 7/8 X 5 112 VBRs. Test to 250/3500 psi with 3.5 & 4" Test joint. Good.;R/U 2 718 handling equipment. INU cmt stinger & PIU 16 Joints of 2 718 tubing to 499'. Change handling equipment to 4" & RIH T/ 6590'. Take parameters at shoe.;RIH F/ 6590' - T/ 7108' MD tag on depth w/ 4k. PIU off tag to 7105' MD. 122k up, 80k dn.;R/U pump in assy w/ cmt line. Circulate and condition hole @ 7105' MD. 4 BPM, 300 psi, 38%flow. Pumped 3x string vol.;PJSM wl cmtrs, wet lines, PT lines 1000/3000 (good). Batch up @ 20:10 hrs. Pump 1st cmt plug as follows - 27 bbis H2O, 32.9 bbis 15.8 ppg cmt, 4 bbis H2O then turnover to rig. Pumped cmt @ 3.7 BPM.;Cmtrs driver side pump had erratic psi and delivery. Shut down @ 1.2 bbls into cmt job and changed over to passenger side pump. Continued pumping as per detail with no other issues.;Displace W/ rig - 62 bbls, 9.6 LSND mud 4.5 bpm, FCP 400 psi. Caught cmt @ 21.5 bbls into displacement. CIP @ 21:00 hrs. Est TOC @ 6698' MD (no pipe in hole). (9.4 bbls lost during disp).;R/D cmt line and L/D single with pump in assy. POOH F/ 7105' - T/ 6570' MD @ 20 fpm. Slightly wet connections every stand. Tried pulling slovver @ 15 fpm w/ no change. No issues pulling oul.;Drop wiper ball and circulate end string clean @ 11.7 BPM, 1360 psi, 59% flow. No traces cement back to surface. Circulate a total of 1.5x surface to surface. Pump dry job.;POOH F/ 6570r- T/ 4480' racking back 4" dp. Hole showed proper displacement;Continue POOH F/ 4480' - T/ 500' with 4" DP. Monitor well (slatic).;C/O handling equipment. POOH F/ 500'- T/ surface w/ 2-7/8" cmt stinger. Clean and inspect (good).;RIH F/ surface - T/ 500' MD with 2-7/8" cmt stinger. WU XO and C/O handling equipment to 4'.;Continue RIH F/ 500' (cmt stinger) TI 5220' MD with 4" HT-38, 14p, 5-135 drill pipe.;Hauled 389 bbls cuttings to G&1 for total= 10369 bbls Hauled 0 bbls H2O from 6 mile lake for total = 7020 bbis Hauled 0 bbls H2O from L-Pad for total = 3600 bbls;Hauled 0 bbis from B-Pad for total = 2560 bbis Daily losses 9.4 bbls to formation for total = 2682 bbis 722/2017 RIH F/ 5220' T/ 6599. Establish parameters @ shoe. Wash down @ 3 bpm & Tag cmt @ 6754'.;L/D one single. R/U side entry sub & cmt hose @ 5750'. Circ & condition @ 4 bpm @ 350 psi while conducting cmt PJSM.;Line up Halliburton & pump 5 bbl water. Test lines to 3000 psi. Good. Batch up 15.8 cmt & Pump 22 bbl water ahead, 32 bbl 15.8 cmt & 4 bbl water to chase.;Displace with rig @ 5 bpm 61 bbl. R/D circ hose & POOH @ 15 FPM. Pulling wet. POOH T/ 6090'. CIP @ 9:45.;Pump down wiper ball & Circ & condition @ 500 GPM @ 1250 psi. Saw trace cmt back at btm up. Circ clean. Pump 10 bbl 11.7 Dry job.;POOH F/ 6090'T/ Surface and clean 2 7/8 cmt stinger.;RIH with 2 7/8 & 4" Dp T/ 5974'.;Cut and slip drilling line (106'). Re-calibrate floor and crown saver.;RIH F/ 5974'- T/ 6225' MD. Kelly up and wash do F/ 6225'- T/ 6286' MD. 112k up, 78k do, 84 gpm, 120 psi. Saw slight increase in pump psi (10-20) and slight drag (3-4k) (possible green cmt).;Saw 250 pressure spike after making connection while washing down. Broke over and fell back to 120-140 psi, NO TAG.;P/U T/ 6284' MD. CBU @ 540 gpm, 1545 psi, 15% flow, 5 rpm, 5.1 k tq. Saw wt increase @ btms up 9.6 to 9.9. Appeared to be stringer cmt in contaminated mud.;Continue washing down F/ 6284' - T/ tag depth of 6385' MD @ 84 gpm, 110 psi. Tag w/ Sk set do (2x). TOC @ 6385' MD.;P/U and CBU 2x @ 6375' MD. 540 gpm, 1545 psi, 5 rpm, 5.lk tq.;POOH F/ 6375'- T/ 6220' MD. RIU to lest casing. Test 9-5/8" casing w/ cmt plug @ 6385' MD. Test to 3000w/ 30 min hold (test good). Chartand record. 5.5 bbls pumped, 5.5 bbls bled back.;RIH F/6220'- T/ 6345' MD. Displace well -Pump 32 bbls 8.5 ppg, 141 vis spacer pill, Chase w/8.5+ ppg seawater @ 9 BPM, 1400 psi. Circulated a total of 627 bbis seawater.;Momtor well (static). POOH laying down 4" dp F/ 6345' - T/ 5093' MD. RIH w/ excess 4" out of derrick F/ 5093'- T/ 6202' MD. POOH laying down 4" F/ 6202'- T/ 2891' MD.;Hauled 900 bbis cutting to G&I for total= 11269 bbis Hauled 150 bbis H2O from 6 on lake for total = 7170 bbls Hauled 300 bbis H2O from L-Pad lake for total = 3900 bbls;Hauled 0 bbis H2O from &Pad lake for total = 2560 bbls 712312017 Lay down 4" DP from 2891' to 500'.;C1O handling equipment to 2=7/8". POOH laying down 2 7/8" dp F/ 500' to surface.;Sewice rig, perform derrick inspection, R/D 2 7/8" handling equipment, clean and clear rig floor.;Pull wear bushing. R/U for 7" casing. Run mule shoe and 3 joints of HTTC 26 Ib L80 7" casing to 136'. MU landing joint, pup, and hanger and land same at 165.26. Install pack off.;Change handling equipment from 7" to 3 1/2". Run mule shoe+ 103 joints of 3-1/2", EUE 8rd, 9.3 It, tubing. WU hanger and landing joint and land same. RILDS. 58k up, 51k dn.;Set TWC. Flush and blow down all surface equipment in sub. N/D stack, choke, kill and fill up lines. Set back on stump and secure. WD DSA. Continue cleaning phs.;N/U dry hole tree. Test void 500/5000 with 5/10 min hold (good). Test tree 500/5000 w/ 5 min hold on each (good). R/D test equipment. Remove T WC. Secure weII.;R/U to freeze protect well w/ LRS in morning. Clear 4" handling equipment and associated subs from floor.;C/O saver sub to DS -50. Continue cleaning mud pits and flush surface equipment. Blow down and drain same. C/O valves in pits as needed. Tear down MP's and inspect valve and seats.;Make parts list and schematic for additional vac system. Clean and prep pipeshed. Load and tally 215 jts DS -50 drill pipe for C-45 surface.;Hauled 946 bbls cuttings to G&I for total = 12215 bbis Hauled 0 bbls H2O from 6 mile lake for total = 7170 bbls Hauled 0 bbls H2O from L -Pad lake for total = 3900 bbls;Hauled 0 bbls H2O from B -Pad lake for total = 2560 bbls Oath, to&.. 0 bbis to formation for total = 2682 bbls 7/24/2017 R/U LRS and freeze protect well w/ 150 bbls diesel (2000'+/-). Pump dawn OA taking returns back thru ting @ 3.5 BPM, 250 psi. U-tube diesel 2 Ins. R/D lines and clean out cellar box.;Set BPV and secure well. Adjust skate motor mount. Perform PM's on TDS. Continue cleaning throughout rig w/ misc painting projects. C/O hopper 3" butterfly hopper valve.;lnspect TDS. C/O dies on grabber. Inspect and tighten grating bolts throughout rig as needed. Adjust drag chain tension. Begin install of electrical panel plugin board for break shack and envirovac;lnstall baffle plate in pit #1, remove and inspect dresser sleeve on mix pump, charge pump suction and associated lines. Re plumb gun line in pill pit #1. Install gauges for hydraulics on rig floor.;Cont welding projects in mud pits (security notified of non permit confined permit), trough, possum belly dump and install dresser sleeve on charge pumps. Clean and clear rig floor on excess equip.;lnstall additional bolts for spinner stop blocks. Continue load and tally total of 215 its DS -50 drill pipe in shed. Continue cleaning and paintings projects throughout rig.;Continue painting radiator lines in gen rm. Touch up paint previous welding projects throughout rig. Pressure wash exterior of rig. Continue load and tally drill pipe in shed.;Hauled 432 bbls cuttings to G&I for total = 12647 bible Hauled a total of 7170 bbls H2O from 6 mile lake Hauled a total of 2560 bbls H2O from B -Pad lake Hauled a total of 7170 bbls H2O from L -Pad Iake;Total losses to well 2682 bbls LSND mud. 7/25/2017 Wait on ASR to finish up on C-46. Pressure wash cattle chute area, paint as needed. Install new gauges on hydraulic system on rig floor. C/O centrifuge #2 feed pump shaft seals. C/O ODS cathead chain ;Assist welder on penetrations for electrical receptacles. Re -plumb pill pit #2 gun line. ASR RDMO C-46.;ASR continues to RDMO C-46, Well support tie in C-46 and prep for wire line. Perform derrick inspection, bridal up. Continue painting on rig, welder install chains on hopper room loading dock.;Finish electrical panel modifications.;Well support continues to tie in C-46 and prep for wire line. PJSM, scope down derrick, re -assemble both mud pumps. Continue to paint around rig. Rig released from C-47 @ 06:00.;Hauled 0 bible cuttings to G&I for total = 12647 bbls Hauled a total of 7170 bible H2O from 6 mile lake Hauled a total of 2560 bbls H2O from B -Pad lake Hauled a total of 7170 b Is H20 from L -Pad lake Total losses to well2682 Me LSND mud Schwartz, Guy L (DOA) From: Joe Engel <jengel@hilcorp.com> Sent: Saturday, July 15, 2017 4:31 PM To: Quick, Michael J (DOA) Cc: Schwartz, Guy L (DOA); Paul Mazzolini; James Lott - (C); Regg, James B (DOA); Cody Dinger; Foerster, Catherine P (DOA) Subject: Re: MPC -47 (PTD # 217-077) Update Thank you, Mike. I will keep you updated. Have a good weekend. -Joe On Jul 15, 2017, at 4:17 PM, Quick, Michael J (DOA) <michael.quick@alaska.gov<mailto:michael.quick@alaska.gov>> wrote: Joe You have verbal approval to proceed with the plan you submitted. Please keep me updated with your progress. Mike On Jul 15, 2017, at 12:52 PM, Joe Engel <jengel@hilcorp.com<mailto:jengel@hilcorp.com>> wrote: We were unable to free our 7" casing on MP C-47. Please find attached the procedure and 403 form for isolating the Kuparuk C and plugging the current wellbore for redrill for your approval. I will submit the hard copy next week, as per your instructions. Please let me know if you have any questions. Thank you for your time. Joe From: Quick, Michael 1 (DOA) [mailto:michael.quick@alaska.gov] Sent: Friday, July 14, 2017 8:56 PM To: Joe Engel <jengel@hilcorp.com<mailto:jengel@hilcorp.com>> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov<mailto:guy.schwartz@alaska.gov>>; Paul Mazzolini <pmazzolini@hilcorp.com<mailto:pmazzolini@hilcorp.com>>; james.regg@alaska.gov<mailto:james.regg@alaska.gov>; James Lott - (C) <jlott@hilcorp.com<mailto:jlott@hilcorp.com>> Subject: Re: MPC -47 (PTD # 217-077) Update Joe Both options for you plan forward appear to be acceptable. We will need a 403 and procedure submitted electronically to me, and I can get you verbal approval if everything is in order. We would then need the sundry submitted in hard copy next week. You can submit the sundry to me when you know which option you will use, or you can submit both options and send me a email once you have determined which option it will be. You can call to discuss if things change. Mike On Jul 14, 2017, at 5:11 PM, Joe Engel <jengel@hilcorp.com<mailto:jengel@hilcorp.com>> wrote: Guy/Mike — I wanted to give you an update on MPC -47. We TD'd 8-1/2" x 9-7/8" Hole at 10,293' MD in the Kuparuk C (top of Kuparuk C is 10,224' MD). Current MW in hole is between 10.5 —11.0 ppg. Kup C PP at nearby offset well is 6.5 ppg EMW. While RIH with 7" casing, we have encountered hole stability issues across the HRZ and have become stuck at — 9,510' MD. The decision has been made to abandon the hole section (with the decision to sidetrack to be determined next week). This presents two abandonment scenarios: where we are able to free the casing and remove it from the wellbore and where we are not. We would like to isolate the Kuparuk sands in the manner listed below, depending on the scenario, in preparation for a potential redrill of the well. Option 1: 7" Casing pulled from OH, Abandoned OH 1. RIH with cement stinger t/ top of HRZ (9,299' MD) a. Farthest depth to be confident of free pipe movement 2. Pump Kuparuk C Abandonment Plug, 500' MD a. 61.5 bbl (1.3 OH Excess) 3. Pull above plug, Circulate hole clean and WOC for sufficient compressive strength 4. Tag Kup C Abandonment Plug 5. POOH t. — 7000' MD 6. Pump Kickoff plug —200' into surface casing shoe a. 49 bbl OH volume, 15 bbl CH volume, 64 bbl total b. 1.3 OH Excess 7. Pull above plug, circulate hole clean and WIC for sufficient compressive strength 8. Tag Kickoff Plug Option 2: 7" Casing remains stuck at 9510' MD 1. RIH with E -line and set CIBP, at depth determined by casing stretch calculation to ensure we are free and can establish circulation 2. RIH with E -line and perforate, at depth determined by casing stretch calculation to ensure we are free and can establish circulation 3. RIH with Cement retainer on 4" DP, and set retainer at 100' above CIBP, Pressure test 4. Establish circulation and squeeze cement into the 9-7/8" x 7" annulus a. 500' MD of annular volume + 7" casing volume between CIBP and Retainer b. 30.6 bbls (1.3 bbl OH Excess) + 4 bbl 7" casing volume 5. Unsting from cement retainer and Pump 100' of cement on top of retainer 6. POOH, PU CIBP, RIH and set CIBP at "' 7100' 7. RIH and cut 7" casing at — 7000' MD 8. Pump Kickoff plug from 7100' MD t. "' 200' MD into surface casing shoe Please let us know if this change in plan is acceptable to the AOGCC, and if you would like a sundry submitted. Please call with any questions. Thank you for your time. Joe Joe Engel I Drilling Engineer I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 1 Anchorage I AK 199503 Office: 907.777.8395 1 Cell: 805.235.6265 <HEC MPU C-47 Intermediate Plug Procedure.pdf> <MPC -47 10-403 Plug for Redrill _7.15.17.xls> THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR BILL WALKER Paul Mazzolini Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-47 Hilcorp Alaska, LLC Permit to Drill Number: 217-077 Surface Location: 722' FSL, 2307' FEL, SEC. 10, TI 3N, R10E, UM, AK Bottomhole Location: 1943' FSL, 224' FEL, SEC. 3, T13N, R10E, UM, AK Dear Mr. Mazzolini: Enclosed is the approved application for 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, 0 Daniel T. Seamount, Jr. Commissioner sfi DATED this day of June, 2017. I STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISoiON PERMIT TO DRILL •' 7C nn MAY 18 2017 A OG CC 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas LJLV Service- WAG LJ Service - Disp ❑ 1c. Specify if well is proposed for: ❑❑ Drill ❑l - Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑✓ ' Service - Winj ❑ Single Zone Q - Coalbed Gas ❑ Gas Hydrates Redrill❑ Reentry Exploratory -Oil ❑ Development - Gas ❑ Service -Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas 2. Operator Name: 5. Bond: Blanket Li • Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 - MPU C-47 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 13,509' - TVD: 7,256' • Milne Point Field ` Kuparuk River Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 722' FSL, 2307' FEL Sec 10, T13N, R10E, UM, AK ADL047434 (SHL, BHQ IADLO47433 (TPH) 8. DNR Approval Number: 13. Approximate Spud Date: Top of Productive Horizon: 310' FNL, 2182' FWL, Sec 11, T13N, R10E, UM, AK LONS 84-123 6/17/2017 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1943' FSL, 224' FEL, Sec 3, T13N, R10E, Um, AK ADL047433 - 2560 / ADL047434 - 2560 5310' to nearest unit boundary 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 41.7 15. Distance to Nearest Well Open Surface: x-558156 y- 6029004 Zone -4 GL / BF Elevation above MSL (ft): 15.2 to Same Pool: 1500' to MPC -04 16. Deviated wells: Kickoff depth: 326 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.0351) Maximum Hole Angle: 94.3 degrees - Downhole: 2974• 00 Surface:• 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) i6" 16 164# A-1068 Weld 151' Surface Surface 151' 151' Driven L - 305 bbls 11.7# 1 T - 45.7 bbls 14.5# 12-1/4" 9-5/8" 40# L-80 DWC/C 6,600' Surface Surface 6,600' 4.899' L-229 bble 11.1#1T-37 bli 14.5# 7" 26# L-80 HTTC 2,000' Surface Surface 2,000' 1,725 2,000' 1,725' 10,200' 7,110' 34 bbls 15.8 ppg e -1/2"x 9.88" 7" 26# L-80 Hyd 563 8,200' 6-1 /8" 4-112" 13.5# L-80 VAM HTTC 3,509' 10,000' 7,076' 13,509' 7,256' Cementless Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 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 ❑1 20. Attachments: Property Plat BOP Sketch B Drilling Program V Time v. Depth Plot Time e Shallow Hazard Analysise AAC 25.050 requirements Diverter Sketch Seabed Report Fluid Program 20 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: Jae Engel Authorized Name: Paul Mazzolmi Contact Email: 'erl el a hilcor .com Authorized Title: Drilling Manager Contact Phone: 777-8395 fotL F�vL MA22 Authorized Signature: l Commission Use Only Permitto Drill API Number: __Ta ermit Approval See cover letter for other Number: p2I ^ Q �g 50- 01 _ 1AK -GG—OQ Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales Other: 0Q ,r /12 N P �5.� Samples sures: Yes No Mud log req'd: Yella N2 5L X) � IY 'F^ ' O HzS measures: Yes No,❑/ Directional svy sures: Ye[yJ N� rf Spacing exception req'd: Yes ❑ No LYJ Inclination -only svy req'd: Ye❑ N Gi S� Post initial injection MIT req'd: Ye❑ NO APPROVED BY /� 1 // Approved by: COMMISSIONER THE COMMISSION Date: G ?'I -57W117"'— J - J I " r t Submit Form and Form 10-401 Revised 5/2017 �Tr ,11 j1v dto 4�Onthe fro a date of approval per 20 AAC 25.005(g) Attachments in Duplicate K Hilmrp Alaska, LI.0 5/18/2017 Joe Engel Drilling Engineer Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Application for Permit to Drill MPC -47 Dear Commissioner, Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8395 Email jengel@hilcorp.com RECEIVED MAY 18 2017 A►CGCC Hilcorp Alaska, LLC hereby submits for review and approval for a Permit to Drill an onshore production well at Milne Point'C' Pad, well slot 47. Drilling operations are intended to commence approximately June 171h, 2017. / MPU C-047 is planned to be a grassroots oil production well, targeting the Kuparuk River Pool. The directional plan is a three string, lateral well, with the kick off point at ±326' MD/TVD. Maximum hole angle is 94.3 degrees at ±11,809' MD. The 12-1/4" surface hole will TD below the Schrader Bluff OA sand, ±6,600' MD / 4,898' TVD, and then 9-5/8" casing will be set and cemented to surface via a two stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, a Temp log will be run between 6 —18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC. The intermediate section will be drilled with an 8-1/2" x 9-7/8" rotary steerable BHA with under reamer to TD in the Kuparuk C at ±840 inclination at ±10,200'MD / 7,110' TVD. This hole will be subsequently cased with 7" 26# L-80 casing string to surface and cemented to 500' above the uppermost hydrocarbon bearing zone via a single stage cement job. The 6-1/8" production section will then be drilled while geosteering, staying in reservoir, to TD at ±13,509' MD / 7,256' TVD and completed as a producer in the Kuparuk_C_reservoir with completed with a 4-1/2" 13.5# L-80 slotted liner. Production tubing will be 2-7/8" 12.6# L-80. Please find attached the Form 10-401, Application For Permit to Drill per 20 AAC 25.005 (a) and the drilling program for MPC -47, which includes information required by 20 AAC 25.005 (c). If you have any questions, or require further information, please do not hesitate to contact myself (Joe Engel) at 777- 8395 or jengel@hilcorp.com or Paul Mazzolini at 777-8369. Sincerely, ,( i� 0 Joe Engel Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC Milne Point Unit (MPU) C-047 Drilling Program Version 0 May 18, 2017 Milne Point C-047 Drilling Procedure Hilcorp e�`.PM Table of Contents 1.0 Well Summary ............................ 2.0 Management of Change Information............................................................................................................3 3.0 Tubular Program: ............................................................ ..... **** ... ** ...... -*- ....... **'**'*** 4.0 Drill Pipe Information: ......................................................................... ............ 5.0 Casing Inspection............................................................................................................................................4 6.0 Internal Reporting Requirements.................................................................................................................5 7.0 Planned Wellbore Schematic.........................................................................................................................6 7 """""""""""""' 8.0 Drilling /Completion Summar 9.0 Mandatory Regulatory Compliance / Notifications...................................................................................8 10.0 R/U and Preparatory Work.........................................................................................................................10 11.0 N/U 13-5/8" 5M Diverter System.................................................................................................................10 12.0 Drill 12-1/4" Hole Section............................................................................................................................12 15 13.0 Run 9-5/8" Surface Casing........................................................................................................................... 19 14.0 Cement 9-5/8" Surface Casing..................................................................................................................... 15.0 BOP N/U and Test........................................................................................................................................23 16.0 Drill 8.5" x 9.88" Intermediate Hole Section..............................................................................................24 28 17.0 Run 7" Intermediate Casing........................................................................................................................ 18.0 Cement 7" Intermediate Casing.......................................................................................................... .......31 19.0 Drill 6-1/8" Production Hole Section..........................................................................................................33 20.0 Run 4-1/2" Slotted Liner..............................................................................................................................36 21.0 Set 4-1/2" Production Liner Hanger...........................................................................................................39 41 22.0 Cleanout Run &Displacement (Contingency)........................................................................................... 41 23.0 Run 2-7/8" Completion Tubing................................................................................................................... 24.0 Post Rig Completion Work..........................................................................................................................42 25.0 Innovation Rig Diverter Configuration......................................................................................................43 26.0 Innovation Rig BOP Schematic...................................................................................................................44 27.0 Wellhead Schematic.....................................................................................................................................45 28.0 Days Vs Depth...............................................................................................................................................46 29.0 Formation Description - MP C Pad Data Sheet........................................................................................47 30.0 Anticipated Drilling Hazards.......................................................................................................................48 31.0 Innovation Rig Layout.................................................................................................................................50 32.0 FIT Procedure...............................................................................................................................................51 33.0 Innovation Choke Manifold Schematic......................................................................................................52 34.0 Casing Design Information..........................................................................................................................53 35.0 8-1/2" x 9.88" Hole Section MASP..............................................................................................................54 36.0 6-1/8" Hole Section MASP...........................................................................................................................55 37.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................................56 57 38.0 Surface Plat (As Built) (NAD 27)................................................................................................................ 39.0 Offset MW vs TVD Chart............................................................................................................................58 40.0 Drill Pipe Information..................................................................................................................................59 Milne Point Unit ure Drilling Procedure Hilcorp 1.0 Well Summary Well MPU C-047 Pad Milne Point "C" Pad Planned Completion Type 4-1/2" Slotted Liner Target Reservoir(s) Ku aruk C Planned Well TD, MD / TVD 13,509' MD / 7,256' TVD PBTD, MD / TVD Surface Location (Governmental) 13,499 MD / 7,256' TVD 722' FSL, 2,307' FEL Sec 10, TI 3N, RI OE, UM, AK Surface Location (NAD 27 — Zone 4) X=558,156.85 Y=6,029,004.74 Surface Location (NAD 83) Top of Productive Horizon (Governmental) 3 10'FNL, 2182' FWL, Sec 11, TON, R10E, UM, AK TPH Location (NAD 27) X=562,604.59, Y=6,033,287.77 TPH Location (NAD 83) BHL (Governmental) 1943' FSL, 224' FEL, Sec 3, TON, R10E, UM, AK BHL (NAD 27) X=560,177.81, Y=6,035,520.13 BHL (NAD 83 AFE Number 1710174 AFE Drilling Das 24 Days AFE Completion Das 5 Days AFE Drillinjr, Amount $5,138,413 AFE Completion Amount $1,704,156 AFE Facility Amount $350,000 Maximum Anticipated Pressure (Surface) 1666 psi Maximum Anticipated Pressure (Downhole/Reservoir) 2974 psi 5" 19.5# S-135 DS -50 (Weatherford Rental) Work String 4" 14# S-135 HT -38 Weatherford Rental KB Elevation above MSL: 26.5 ft + 15.2 ft = 41.7 ft GL Elevation above MSL: 15.2 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilco c Eves' mnprp 2.0 Management of Change Information H Hilco>p Alaska, LLC Ht1c rp Changes to Approved Permit to Drill Date: 05-09-2017 Subject: Changes to Approved Permit to Drill for MPU C-047 File #: MPU C-047 Drilling and Completion Program Any modifications to MPU C-047 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be communicated to the BLM and AOGCC. Approval: Drilling Manager Prepared Drilling Engineer Date Page 3 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E.c C.P-y 3.0 Tubular Program: Hole Section OD in ID (in) Drift in ODML .. Connt40 Grade si k -Ib 916 Cond 16" 14" 8.835" 8.75" 10.235" A -106B L-80 Weld DWC/C 5,750 3,090 8-1/2" 7" 6.276" 6.151" 7.656" L-80 HTTC & H563 7,240 5,410 604 6-1/8" 4-1/2" 3.849 3.75 4.93 13.5 L-80 HTCC 9020 8540 307 4.0 Drill Pipe Information: Surface & 5" 4.276" 1 3,25" 1 6.625" 1 19.5 5-135 GPDS50 36,100 43,100 5 60 r.,rar P i;are & NC50 6-1/8" 4 3.34" 2 5625" 1 4 875" 1 14 S-135 HT -38 12 200 17,700 649 5.0 Casing Inspection All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure HilCuEn� co,o 6.0 Internal Reporting Requirements 6.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry tab. • 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. 6.2 Afternoon Updates • Submit a short operations update each work day to Pmazzolini@hilcorp com , ienizel@hileorp.com and cdinger@hilcorp.com 6.3 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. 6.4 EHS Incident Reporting • Health and safety: Notify EHS field coordinator. • Environmental: Drilling Environmental coordinator • Notify Drlg Manager & Drlg Engineer • Submit Hilcorp Incident report to contacts above within 24 Ins 6.5 Casing Tally • Send final "As -Run" Casing tally to,iengel c@hilcorp.com and cdineer(&,hilcorp.com 6.6 Casing and Cmt report • Send casing and cement report for each string of casing to *engel@hilcorp.com.and and cdinjzer@hileorp.com 6.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Paul Mazzolini 907.777.8369 907.317.1275 pmazzolini@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 Ikeller@hilcorp.com Completion Engineer Paul Chan 907.777.8333 907.444.2881 Dchan@hilcorp.com Geologist Matt Brown 907.777.8448 713.458.8667 mbrown@hilcorp.com Reservoir Engineer Anthony McConkey 907.777.8460 970.529.6199 amcconkev@hilcorp.com Drlg Environmental Coord Keegan Fleming 907.777.8477 1 907-350-9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 1 907.382.4336 caiones@hilcorp.com EHS Field Coordinator Jimmy Watson 907.777.8450 907.744.7376 iiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinaer hilcor2x Page 5 Version 1 May 2017 n Hilcorp Encw cmmpany 7.0 Planned Wellbore Schematic HAN. SCHEMATIC KB Ejgj AbM Sea LewE 41.7*/GL F,)#y:152' 1 16^• 3 • 4 Milne Point Unit C-47 Drilling Procedure Milne Point Unit Well: MPC -47 PTD: TBD API: TBD : 5 t20 6 c 6,600' AID 8 -.-.---."___------------------ _-.-.....----- --------------- .--- .._---- _.._..-..----..-.--.----------------. JEWELRY DETAIL CASING DETAIL hem Tap MD WftlD I DD 1 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 16' Conduaot 164/A-IWB NE N/A Surtace 151' N/A 93/8' Surface 40/L-SO/DWC/C 8.75" Surface I 6,5OD' 0.0758 r Imarmediate 26/1_-W/H C I 6.151" I Surface I3,000 60383 r imermediete 26A-W/H 563 1 6.151" 1 3,0017 I 10,207 x0383 4112' Slotted Dner 135#/L-80/VAM HI IL I 3.958 I ±10,000 13,509' 0.00152 1 4 Ijr x 7' Uw Top Packer (HRD-E ZKP) 10,Ot%Y TUBING DETAIL 1 Shoe 113,507' 2-J r Tubing I 12.6 -80 x 1 3.833" 1 Surtace 210,000' 0.0058 : 5 t20 6 c 6,600' AID 8 -.-.---."___------------------ _-.-.....----- --------------- .--- .._---- _.._..-..----..-.--.----------------. JEWELRY DETAIL No. hem Tap MD WftlD I DD 1 Tubing Hanger 2L5.2' - 2 Stage Tool- Halliburton ES Cementer 21,900' - - 3 GLM A32 -7/8'x1" TBD - - 4 M GL#22-71Wx1" TBD 5 GLM1Cd 2-78'x3" MD 6 GLM#42-7/8'x3" TBD 7 GLM #52-7Wx3' TBD 8 GUVI #6 2-71Wx I- TBD 9 GLM #J 2-78'x1' TBD 10 GLM#82-7/8'x I' TBD - - 11 I GLM #9 2-7/8' x I- TBD 12 1 Sliding Sleeve 2-J8' TBD - 13 Packer r x 2-7/r 29,910 14 1 2-718' WLEG 210,OOD' 15 1 4 Ijr x 7' Uw Top Packer (HRD-E ZKP) 10,Ot%Y 16 1 Shoe 113,507' 9 10 TOC 9,700' AID 11 OPEN HOLE/ PROPOSED CEMENT DETAIL ConduLtor Given IF.EV4'Iu sWe 3050015 Lead 11.7 RM 45.7= Tail 24.5 P29 12-1/6"2ndstage 229 pp)Slead 11.129, 37W&Tai114.588g 9.88"x8.5' 3 =15.889 li ..13 n �T • 1 16 p t/ 11• - NII :, ':A -„S __.. 41/2„ 7^ 13,509' 4ID 10,200' AH) GENERALWELL INFO WELL INCLINATION DETAIL PBTD= t13,509'LMDIt7X6'1VD API: TBD KOP IP326' TD=13,509'.MD/ 7,256'n-1) Onlled and Cased by Innovation -Date TBD Max HoleAngle-94.30 deg.011,W9'MD Max Devizam 94-W Upoateo by OD 517/17 Page 6 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp Fne Cmnpany 8.0 Drilling / Completion Summary MPU C-047 is a grassroots oil production well, targeting the Kuparuk River Pool, located on Milne Point `C -Pad'. The directional plan is a three string, lateral well, with the kick off point at ±326' MD/TVD. Maximum hole angle is 94.3 degrees at±11,809' MD. Drilling operations are expected to commence approximately June 17'', 2017. Surface casing will be run to 6,600' MD / 4,898' TVD and cemented to surface via atwo stage primary cement job. Cement returns to surface will confirm TOC at surface. If cmt returns to s ace Temp log will be run between 6 —18 Ins after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC. Intermediate casing_will be run to ±10,200' MD / 7,110' TVD, landed in the Kuparuk C at ±840 inc and cemented via a single stage cement job bringing cement to 500' MD (minimum) above top of the Kuparuk C, ± 9,700' MD. /Production liner will be 4.5" 13.54 L-80 slotted liner, and production tubing will be 2-7/8" 12.6# L-80. All waste & mud generated during drilling operations will be hauled to the Milne Point G&I facility located on `B" pad. J General sequence of operations: 1. MOB Innovation to well site 2. N/U 13-5/8"annular and 16" diverter line. ✓D 3. Drill 12-1/4" hole to TD of surface hole section 4. Run and Cement 9-5/8" surface casing. 5. N/D diverter, N/U & test 13-5/8" x 5M BOPE. 6. Drill 8-1/2" hole to TD. 7. Run and cement 7" intermediate casing. 8. Drill 6-1/8" hole to TD. 9. Run 4-1/2" slotted production. 10. Run 2-7/8" production tubing 11. N/D BOP, N/U Tree, RDMO Reservoir Evaluation Plan: 1. Surface Hole: No mud logging. LWD: GR + Res / 2. Intermediate Hole: No mud logging, On site geologist. LWD: GR +Res 3. Production Hole: No mud logging. On site geologist & Geo Steer. LWD: G + R�e�ss 4. Cased Hole Logs: GR/CCL Post Rig �L _9L- to Page 7 Version I May 2017 47 Milne Point Unit ure Drilling Procedure Hilcorp Energy Company 9.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. 4 5 • BOPs shall be tested at (2) week intervals during the drilling and completion of MPU C-047. Ensure to provide AOGCC 24 his notice prior to testing BOPs. SDP • The initial test of BOP equipment will be to 250/3001rpsi & subsequent tests of the BOP equipment will be to 250��s,i 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, Notify AOGCC and 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". • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • There are no variance requests at this time. Page 8 Version 1 May zUl i Milne Point Unit C-47 Drilling Procedure Hilcorp Eve C P -Y Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi)_ 12-1/4" • 13-5/8" 5M diverter (Hydril MSP) 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 o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets Initial Test: 250/3000 (Annular 2500 psi) 8-1/2" & 6-1/8" 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line • 3-1/8" x 5M Kill line • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Subsequent Tests: 250/3000 (Annular 2500 psi) 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.regg@alaska.gov Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: g_tty schwartzna alaska gov Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria.loepp@alaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http-//doa alaska¢ov/ogc/forms/'lestWitnessNoti£hhnl Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 9 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E.c Company 10.0 R/U and Preparatory Work 10.1 Drive 16" conductor. ✓ 10.2 Dig out and set impermeable cellar inside existing culvert. 10.3 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 10.4 Install Seaboard slip-on 13-5/8" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 10.5 Insure (2) 3" threaded nipples are installed on opposite sides of the conductor with ball valves on each nipple. These will be used to take cement returns to the cellar during the surface cmt job, and also to wash out the diverter and hanger in preparation for running the pack -off. 10.6 Level pad and ensure enough room for layout of rig footprint and R/U. 10.7 MIRU Innovation Rig. J 10.8 Mud loggers WILL NOT be used on C-047. 10.9 Mix spud mud for 12-1/4" surface hole section. Keep mud cool. 10.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 10.11 Install 5" liners in mud pumps. • White Star Quattro 1300 Hp mud pumps are rated at 4097 psi, 368 gpm @ 140 spm @ 96.5% volumetric efficiency. 11.0 N/U 13-5/8" 5M Diverter System 11.1 N/U 13-5/8" CTI BOP stack in diverter configuration (Diverter Schematic in Sec 21 of program). • N/U 20" SOW • N/U 13 5/8", 5M diverter "T". • 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 Page 10 Version 1 May 2017 H Hilcorp E.B Company 11.2 Milne Point Unit C-47 Drilling Procedure • Place drip berm at the end of diverter line. `k' A7 of Function test diverter. Ensure that the knife gate andular are operated on the same circuit so that knife gate opens prior to annular closure. 11.3 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. 11.4 Rig & Diverter Orientation (Drawing not to scale): I r� ■ ,B � I I I , ■ I I ■ 3 I I I ■ �} I I , ■ I I ■ „ I 1 z. ■ I I ■ .z 1 zs■ 1 I■ �� I sX 21 ■ I u■ I I I . >s 46 Il ,B 4 1 13 5 ■ =B C-47 39 1 47 1 I B ■ I �■ 1: � I I 1 ° ■ I I I I 75' Radius Clear of Ignition Sources I 61 I0 I 0=0L_ J o I I I m —Diverter Line I 1 ❑ 1 \ 1 � c-rno Page 11 Version 1 May 2017 Milne Point Unit C-47 n Drilling Procedure Hilc T F.nerey Cmn 12.0 Drill 12-1/4" Hole Section 12.1 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 so that wireline orientation is possible if necessary. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. ✓ • Drill pipe will be 5" 19.5# 5-135 NC50 & DS50 • Run a solid float in the surface hole section. 12.2 5" drill pipe, 5" HWDP, and Jars will come from Weatherford. 12.3 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. 12.4 Drill 12-1/4" hole section to section TD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. We want to be approx. 200' through the base of the permafrost. Permafrost base is estimated at 1900' TVD • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • 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 450-600 gpm. Monitor shakers closely to ensure shaker screen and return lines can handle the flow rate • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Slow in/out of slips and while tripping to keep keep swab and surge pressures low • Make wiper trips if necessary. • Adjust MW and viscosity as necessary to maintain hole stability. • Take MWD surveys every stand drilled (-60' intervals). • No gas hydrates have been encountered on C Pad wells, however be prepared if hydrates are seen: • 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 Page 12 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp F.neegy CompauY prevent mud from belching over the bell nipple. Consider adding mud products such as Lecithin to allow the gas to break out. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling, packing off or running gravels • Do not stop to circulate on wiper trips with bit across a slide interval, especially not in an area where DLS is > 4. • Do not slide for 100' MD above the base of the permafrost or 100' below the base. We want to leave this transition as undisturbed as possible. • Ensure TD of the hole section is — 100' MD below Schrader Bluff Sands, confirm with Geologist 12.5 12-1/4" hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite 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. ✓ • PVT System: An electronic PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, and Toolpusher office. Ensure proper pits are in the `Active' at all times. • Hydrates: Hydrates have not been encountered on any `C' pad wells to date. Be prepared if any are seen and don't stop to circulate out gas. Control drill when hydrates encountered. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 45 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 13 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure HilcoT rncrgy con.vmy System Type: 8.8 - 9.5 ppg Pre -Hydrated Aquagel/freshwater spud mud ✓ Pro ernes: Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL Section i viscosity Plastic Viscos' Yield Point Ali FL TerriD PH Surface 8.8-9 75-175 20-40 25-45 <10 <70°F 8.5-9.0 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 . OpH) BARAZAN D+ as needed BAROID 41 as required for 8.8 — 9.5 ppg PAC -L /DEXTRID LT if required for <10 FL ALDACIDE G 0.1 ppb 12.6 At TD; pump sweeps, circulate 2-3 BU at high flow rates and rpm — racking back I stand per BU and alternating reciprocation depths to minimize risk of troughing and dropping inclination. Pump out of the hole holding TF highside/ Pull slow if hole starts unloading MPB-33 LL: Drop vise to — 50 cp and MW of 9.4 at TD before coming out of the hole. Resulted in smooth BROOH and casing run 12.7 If hole conditions will not allow the BHA to be pulled out on elevators, prior to initiating backreaming, try to orient motor to high side and attempt to pump out to avoid damaging the wellbore. 12.8 Should backreaming be absolutely necessary to get out of the hole: • Prior to initiating backreaming, ensure at least 2-3 B/U have been circulated to get hole as clean as possible. • Pump at full drill rate (450 — 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, packing off or running gravels • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 12.9 TOH with the drilling assembly, handle BHA as appropriate. 12.10 No open hole logging program planned. Page 14 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp z St.*,� 13.0 Run 9-5/8" Surface Casing C e, 13.1 The plan is to set slips for the 9-5/8" casing to facilitate good circulation during the cement job. 13.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" DWC/C x HT -38 XO on rig floor and M/IJ to FOSV —readily available. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Consider RAJ 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. 13.3 P/U shoe joint, visually verify no debris inside joint. 13.4 Continue M/U & thread locking shoe track assembly consisting of: • (1) Shoe joint w/ float shoe bucked on (thread locked). Install (2) centralizers on shoe joint over stop collars 10' from each end. (1) Joint with float collar bucked on pin end & thread locked. Install (1) centralizer mid tube over a stop collar. • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle WN • (1) Joint with Halliburton bypass baffle adapter bucked on pin & threadlocked. Install (1) centralizer mid tube over a stop collar. Page 15 Version 1 May 201 / Milne Point Unit C-47 Drilling Procedure Hilcorp E C.Y 13.5 Ensure proper operation of float equipment while picking up. Ensure to record S/N's of all float equipment and stage tool components. Float equipment and Stage tool equipment drawings: A Oeeaea Leno rype H ES Cementer ,an No. iO No. losing Sleeve vo. Shear Pins Dpening Sleeve No. Shear Pins ES Cementer Depth ^Retermrce Casag sales %U1.1 Seton 5 B Ma,. m arter anllwa C Mae. -T.1 05 D Opensg Seat 10 E T�� Seat 10 Plug Set larap[SlI RenNn(Olea Part No. Eill Gernatar SO No. SMnOrrOy Closing Plug OD Opening Plug DD C OD Shut -Off Plug Do - 7 -7 Bypass Plug td LISEd) oD 13.6 Continue running 9-5/8" surface casing • Fill casing while running in the hole every joint and top off every 5, using fill up line on rig floor or CRT. Circ through shoe track. Page 16 Version 1 May 2017 larap[SlI RenNn(Olea Eill Gernatar SMnOrrOy e Ad.Pta 11y�PuetAq C M V+as Mlle Hort Caen Flea Shoe 13.6 Continue running 9-5/8" surface casing • Fill casing while running in the hole every joint and top off every 5, using fill up line on rig floor or CRT. Circ through shoe track. Page 16 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E Enc —P -Y • Install (1) centralizer every other joint for the first 15 joints. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • M/U DWC/C connections as per recommended torque ratings below. • 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. 9-5/81140# L-80 DWC Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 29,800 ft -lbs 34,800 ft -lbs 13.7 Install the Halliburton Type H ES -II Stage tool so that it is positioned at 1900' MD / 1868' TVD. This will position the stage collar comfortably below the permafrost. • Install centralizers over couplings on 3 joints below and above stage tool. • Do not place tongs on ES cementer, this can cause damage to the tool. • Ensure tool is pinned with 6 opening shear pins. There are 6 holes, the tool is normally sent with only 4 pins installed. This will allow the tool to open at 3300 psi. 13.8 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 13.9 Slow in and out of slips. 13.10 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. 13.11 Lower casing to setting depth. Confirm measurements. 13.12 Have slips staged in the cellar, along with necessary equipment for the operation. 13.13 R/U circulating equipment and circulate B/U. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. 13.14 Hold casing string and reciprocate casing if possible while conditioning mud. Page 17 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp Encs Company 13.15 Casing Specifications: Connection Type: Size(O.D.): DWC/C Casing 9-5/8 in standard Weight (Wall): 40.00 Ib/ft (0.395 in) Material L-80 Grade 80,000 Minimum Yield Strength (psi) 95,000 Minimum Ultimate Strength (psi) 5,300 Pipe Dimensions 9.625 Nominal Pipe Body O.D. (in) 8.835 Nominal Pipe Body I.D.(in) 0.395 Nominal Wall Thickness (in) 40.00 Nominal Weight (Ibslft) 38.97 Plain End Weight (lbs/ft) 11.454 Nominal Pipe Body Area (sq in) Weight (Wall): 40.00 Ib/ft (0.395 in) Grade: L-80 -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston. TX 77041 Phone: 713-479-3200 Fax 713479-3234 E-mail: VAMUSA les® muse mm Page 18 Version 1 May 2017 Pipe Body Performance Properties 916,000 Minimum Pipe Body Yield Strength (lbs) 3,090 Minimum Collapse Pressure (psi) 5,750 Minimum Internal Yield Pressure (psi) 5,300 Hydrostatic Test Pressure (psi) Connection Dimensions 10.625 Connection O.D. (in) 8.835 Connection I.D. (in) 8.750 Connection Drift Diameter (in) 4.81 Make-up Loss (in) 11.454 Critical Area (sq in) 100.0 Joint Efficiency (%) Connection Performance Propertles 916,000 Joint Strength (lbs) 16,360 Reference String Length (ft) 1.4 Design Factor 947,000 API Joint Strength (lbs) 916.000 Structural Compression Rating (lbs) 3.090 API Collapse Pressure Rating (psi) 5.750 API Internal Pressure Resistance (psi) 19.0 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 29,800 Minimum Final Torque (ft -lbs) 34.800 Maximum Final Torque (ft -lbs) 39,800 Connection Yield Torque (ft -lbs) Grade: L-80 -USA VAM USA 4424 W. Sam Houston Pkwy. Suite 150 Houston. TX 77041 Phone: 713-479-3200 Fax 713479-3234 E-mail: VAMUSA les® muse mm Page 18 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp Energy Campa"y 14.0 Cement 9-5/8" Surface Casing 14.1 Hold a pre job safety meeting over the upcoming cmt 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 cmt unit at acceptable rates. • Discuss how to handle cmt returns at surface. Ensure vac trucks are on standby and ready to assist • Pre determine which pump 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 cement 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 iron used to route slurry to rig floor 14.2 Document efficiency of all possible displacement pumps prior to cement job. 14.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cmt pump or treating iron will not be pumped downhole. 14.4 R/TJ cementing head (if not already done so). Company rep to witness top and bottom plugs have been loaded correctly. 14.5 Fill surface lines with water and pressure test. 14.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 14.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the 1St stage, confirm actual cement volumes with cementer after TD is reached. / 14.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & tail slurry, and TOC will be brought to the stage tool. / n_cW.. �,.d 1st Ctn nn Tn4al ('ement Volume: Page 19 Version 1 May 201 SS`I LSD{lnl6LGU 1 Calculation Vol (bbl) Vol (ft3) Section m 12-1/4" OH x 9-5/8" Casing (6100'- 1900') x.0558 bpf x 1.3 = 305 1715 J Total Lead 1715 12-1/4" OH x 9-5/8" Casing e (6600'- 6100') x.0558 bpf x 1.3 = 37 204 12-1/4" Rat Hole (6610'- 66001 x.145 bpf X 1.3 = 1.9 10.67 9-5/8" Shoe Track 90' x .0758 bpf = 6.8 38.2 Total Tail 45.7 256.67 Page 19 Version 1 May 201 SS`I Milne Point Unit C-47 Drilling Procedure Hilcorp Cement Slurry Design (Pt stage cement jobs): Lead Slurry Tail Slum System Type 1/II Type 1/11 11.7 Ib/gal 14.5 Ib/gal Density 2.5069 ft3/sk 1.39 ft3/sk yi eld 14.35 gal/sk 6.8 gal/sk Mixed Water 14.9 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the casing collar depths in mind. If the hole gets "sticky", position casing string at desired depth and continue with cement job. 14.10 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits. HEC Rep to witness. 14.11 Ensure rig pump is used to displace cmt. Displacement calcs have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the shutoff plug must be bumped. 14.12 Displacement calculation: wt`s (6600' — 90') x .0758 bpf = 493.5 bbl total (with 80 bbls spotted across the stage tool to ensure proper operation once open) 14.13 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 the any cement seen at surface. 14.14 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of the shoe track volume, —3.4 bbls before consulting with drilling engineer. 14.15 If the plug is not bumped, consult the drilling engineer. Ensure the free falls stage tool opening plug is available if needed. This is the backup option to open the stage tool if the plugs are not bumped. 14.16 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 20 Version 1 May 2017 Milne Point Unit C-47 N Drilling Procedure Hilcorp e�.V cry 14.17 cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. GS (� oo I''`D vPE'" to 3300 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. 14.18 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have sacks of sugar available and vac trucks ready to assist. Ensure to flush out any rig components used to route cement. Second Stage Surface Cement Job: 14.19 Prepare for the 2"d stage as necessary. Circulate until 1 stage reaches sufficient compressive strength. Hold pre job safety meeting. 14.20 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 14.21 Fill surface lines with water and pressure test. 14.22 Pump remaining 60 bbls 10.5 ppg tuned spacer. 14.23 Mix and pump cement per below recipe for the 2nd stage. 14.24 Cement volume based on annular volume + open hole excess (200% for lead and 30% 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. F�r;..,atad Ind Ctnoe Tatal Cement Volume: Cement Slurry veslgn (Lnu stage Section Calculati=1.3,= bl) Vol (ft3) System 16" Conductor x 9-5/8" Casing (140') x .1289 101.3 v 12-1/4" OH x 9-5/8" Casing (1400' - 140') x .051 1.39 ft3/sk 1185 J Total Lead 1287 12-1/4" OH x 9-5/8" Casing (1900'- 1400') x.05 208 F' Total Tail 1 208 Cement Slurry veslgn (Lnu stage cement Juin: Lead Slurry Tail Slurry System Permafrost L Type 1/11 Density 11.1 Ib/gal 14.5 Ib/gal Yield 4.3279 ft3/sk 1.39 ft3/sk Mixed Water 21.405 gal/sk 6.8 gal/sk Page 21 Version 1 May 2017 I Milne Point Unit C-47 Drilling Procedure Hilcom 14.27 Displacement Calculation: 1900' x.0758 bpf = 144 bbls mud K� 14.28 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 some sacks of sugar available to retard setting of cement. 14.29 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. 14.30 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. Set slips and back out and cut joint. 14.31 Flush out wellhead with FW and BOP stack thoroughly to ensure cement, mud and cuttings are removed. 14.32 M/U pack -off running tool and pack -off to bottom of Landing joint. Set casing slips packoff. Run in lock downs and inject plastic packing element. Pressure test t/ 2450 psi. 14.33 Lay down landing joint and pack -off running tool. Ensure to report the following on Wel1Ez: • 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 • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid • If losses are seen during cement job, note at operation during the cement job they were observed and where the cement was • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped &bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface &volume • Note time cement in place • Note calculated top of cement • 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 iengelna,hilcorp.com and � a to t onnc to the AC Page 22 Version 1 May 2017 Milne Point Unit C-47 H Drilling Procedure Hilcorp B�cmwy 15.0 BOP N/U and Test 15.1 N/D the diverter T, 16" knife gate, 16" diverter line & N/U 11" x 13-5/8" 5M casing spool. 15.2 N/U 13-5/8" x 5M CTI BOP as follows: • BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / 13- 5/8" x 5M mud cross / 13-5/8" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in lbottom cavity. VBRs �r • Single ram should be dressed with 2-7/8" x 5" P l� • N/U bell nipple, install flowline. V • Install (1) manual valve & HCR valve on kill side of mud cross. (manual valve closest to 4 mud cross). • Install (1) manual valve & HCR valve on choke side of mud cross. (manual valve closest to mud cross) 15.3 Run 5" BOP test assembly, land out test plug (if not installed previously). • Test BOP to 250/ i for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Confirm test nreI Js with PTD • Ensure to leave `B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. • We will need to test on the following sizes: 5" (for 5" DP) 15.4 R/D BOP test assembly. 15.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 15.6 Mix 10.0 ppg Baradrill-N fluid for production hole 15.7 Set 10" ID wearbushing in wellhead. 15.8 Keep 5" liners in mud pumps. Page 23 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilco] 16.0 Drill 8.5" x 9.88" Intermediate Hole Section ,/ 16.1 P/U Clean out BHA for drilling out stage collar and shoe track • Used 8-1/2" Bit and HWDP 16.2 Single in the hole w/ 8-1/2" clean out assembly on 5" DP from pipe shed to stage tool. 16.3 Note depth stage tool is tagged on AM report. Drill out stage tool as follows: • Do not exceed 75 rev/min rotation speed. A good range is 40 to 75 rpm. • Drilling with minimal WOB is recommended, 2-5 K# is enough. • Apply weight and allow it to drill off before applying more. After drilling out, chase any remaining debris to bottom with the drill bit. 16.4 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 7'V � �16 5 R/U and test casing to 2900 psi / 30 min. Ensure to record volume / pressure and plot on FIT eA k graph. AOGCC reg is 50% of burst =T750 / 2 = 2875 psi. Test pressure for the well is 2900 psi. 16.6 Drill out shoe track and 20' of new formation. 16.7 CBU displace hole to 9.5 ppg LSND for FIT. OWFF and pull into casing shoe 16.8 Conduct FIT to 12.5 ppg EMW. If 12.5 ppg EMW is not obtained call and discuss with Drilling Engineer. C1z.S-i6 0 4� o n = 1.4-- 16.9 POOH and LD cleanout BHA h« 16.10 P/U 8.5" x 9.88" Rotary Steerable Directional Assembly w/ i lnder Reamer • 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 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 pipe will be 5" 19.59 S-135, NC50 & DS50. • Install ported float in the BHA. Page 24 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E.w C—P-Y 16.11 8.5" x 9.88" hole section mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1) ppg above highest anticipated MW. • 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. • Run the centrifuge continuously while drilling the production hole, this will help with solids removal and minimize sand content and LGS to maintain fluid properties and quality of the mud system. • Canrig 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: 9.5 —11.6 ppg KCl Inhibited WBM i Pro erfies: •- Concentration 0.94 bbl 22 ppb D Plus rBarazan 1.25 ppb (as req'd forYP) Density Plastic Yield Point LGS MBT HPHT pH Depths 0.2 ppb Vlscosit As req'd for MW <b% <20 <11.0 9-10 6600' —10200' .5 —11.6 15-25 15-20 _a:. Q., �AAILNI aysrem rvmivt%auv--. .. •- Concentration 0.94 bbl 22 ppb D Plus rBarazan 1.25 ppb (as req'd forYP) 1.0 ppb T 3.0 ppb Barotrol Plus 5.0 ppb BDF-515 4.0 ppb Caustic Soda 0.2 ppb Baroid 41 As req'd for MW Aldacide G 1 0.25 ppb Page 25 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E� Cmpmy 16.12 RIH w/ 8.5" x 9.88" directional assembly on 5" DP from the derrick. Shallow test MWD to confirm tool communication Slow string speed when tripping through the stage collar 16.13 Drill 8.5" x 9.88" hole section to section TD per Geologist and Drilling Engineer in Kup C. • Pump at 600 gpm (200ft/min Annular Velocities) • Once — 100' of new hole is drilled and under reamer has cleared the casing shoe, circulate hole clean, drop ball and open under reamer, indications will be pumps pressure and turbine RPM. • 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. • Pump high vis sweeps to aid in hole cleaning. • Take MWD surveys every stand +/- 60'. Surveys can be taken more frequently if deemed necessary. • Monitor hole cleaning indicators, PUW, Pump pressure and ECD, Make wiper trips as necessary. • Perform wiper trip 200' before penetrating HRZ • Before drilling into HRZ, weight up t/ 10.4 ppg and increase KCl t/ 6% • Once below the HRZ, keep drilling ECDs below Ippg over static MW • Closely monitor PWD information while drilling to minimize ECD, especially important when drilling the Miluveach and Kingak Formations. • Keep swab and surge pressures low when tripping, especially important when tripping through the Miluveach and Kingak Formations. • Slow and smooth pulling in and out of slips on each connection. • Slowing ramp pumps on/off on each connection • 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. 16.14 At TD; pump low vis sweeps, CBU at full rate and RPM least 3 times at maximum circulation and rotation. Alternate reciprocation depths while CBU to reduce risk of troughing and dropping inclination, this is especially important as we will be landed and high inclination. Under reamer will be open during CBU, to maximize flow and hole cleaning. 16.15 Once hole is cleaned up, drop ball and close under reamer. Indications will be pump pressure and turbine rpm change. 16.16 Weight up at TD for shale stability while TOOH, ±10.8 ppg 16.17 If backreaming is necessary: • Circulate at max rate while maintaining drilling ECD's (flow will be less due to 10.8 ppg MW) Page 26 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp Energy Company 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 and circ at least a b/u once at the shoe. 16.18 TOH with the drilling assy, L/D or handle BHA as appropriate. 16.19 No open hole wire line logs are planned. sow Ps� 16.20 Change top rams to 7" for casing run. Test 250/b"<psi. Chart test. Page 27 Version 1 May 2Ul Milne Point Unit C-47 Drilling Procedure Hilcorp Emw camp� 17.0 Run 7" Intermediate Casing 17.1 R/U 7" casing running equipment. • Ensure 7" Hydril 563 & HTTC x NC50 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. • R/U CRT w/ cement swivel. 17.2 WU & threadlock shoe track assy consisting of: • (1) Float shoe joint w/ float shoe bucked on. Install (2) solid body centralizers over a stop ring at 10' from each end. • (1) Baker locked joint. Install (1) solid body centralizer mid joint over a stop ring • (1) Float collar joint w/ float collar bucked on pin end. Install (1) solid body centralizer mid tube over a stop ring. • Ensure proper operation of float shoe and float collar. 17.3 Run 7" 26# L-80 563/HTTC casing. i • Fill casing while running using CRT or fill up line. • Use "BOL 2000" for 563 & "BOL 4010NM" for HTTC thread compound. Dope pin end only w/ paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Install centralizers on every joint to 500' above Kup C. No centralizers required above that. 17.4 RIH following casing running schedule, keeping surge below max drilling ECD EMW 17.5 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 17.6 Slow in and out of slips. 17.7 Casing will be set on depth with slips. 17.8 Lower string to shoe depth. We will plan to set slips in the wellhead to facilitate rotation during the cement job. Confirm measurements indicate that a collar is not across the landing ring in the wellhead for setting slips. 17.9 Circulation and condition mud for cement job through CRT. Reduce YP to < 20 to help ensure success of cement job. 17.10 After circulating, set string at setting depth. Page 28 Version 1 May 2U1 I Milne Point Unit C-47 Drilling Procedure Hilcorp 7" Casing Torque Values OD Weight Wall Th. 7 in. 26.00 Iblft 0.362 in. Nominal OD MUT (Min) MUT (Opt) MUT (Max) Max Operating Connection ft -lb ft -lb ft -lb Torque, ft -lb HTTC 22950 244450 25950 35000 Hydril563 7800 9400 13700 33000 OD Weight Wall Th. 7 in. 26.00 Iblft 0.362 in. Nominal OD 7.000 in. Nominal ID 6.276 in. Nominal Cross Section Area 7.549 sgin. Grade Type API 5CT Min. Yield Strength 80 ksi Max. Yield Strength 95 ksi Min. Ultimate Tensile Strength 95 ksi Tensile Yield Strength 604 klb Internal Yield Pressure 7240 psi C011anse Pressure 5410 Int le Yield Strength )ression Resistance rression with Sealability rat Yield Pressure nal Pressure Resistance Bending Capacity Bending with Sealability (CAL IV) Load on Coupling Face Connection �' Data 5 t Grade API Drift Connection LBO 1 6.151 in. VAMO HTTC 604 klb 604 klb 483 klb 7240 psi 5410 psi 21 °noon 50 0/100 ft 296 klb Connection Type Connection OD (nom) Connection ID (nom) Make-up Loss Coupling Length Critical Cross Section Tension Efficiency Compression Efficiency Compression Efficiency with Sealability Pressure Efficiency I Pressure Efficiency Min. Make-up torque Opti_ Make-up torque Max. Make-up torque Maximum Torque with Sealability Max. Torsional Value page 229 Version 1 May 2017 Premium T&( 7.552 in. 6.212 in. 4.562 in. 10.282 in. 7.549 sgin. 100 % of pipe 100 %of pipe 80 % of pipe 100 % of pipe too %of pipe 22950 11.1b 24450 ft lb 25950 ft.lb 35000 f[Ab 41500 ft.lb Milne Point Unit C-41 Drilling Procedure H11COLp E.� C.Pmr -' TenarisHydril Size: 7.000 in. Wall: 0.362 in. Connection: Wedge 563T`^ Casing Weight: 26.00 lbs/ft Casing/Tubing: CAS Grade: L80.1 Coupling option: REGULAR Min. Wall Thickness: 87.5 % PIPE BODY DATA GEOMETR" MAKE-UP TOKQUL* Minimum 7800 ft -lbs Optimum 9400 ft -lbs Nasi mum 13700 ft -lbs OPERATIONAL LIMIT TO k.. -. Operating Torque 33000 ft -lbs Yield Torque 39000 ft-lbS BUCK -011 T�;J V Qijl ' t z3nn fr-Ihs Ma�imun 15000 ft -lbs Page 30 Version 1 May 2017 Standard Drift Naminai OD 7.000 in. Nominal Weight 26.00 Ib&ift Diameter 6.151 in. Special Drift Nominal ID 6.276 in. Well Thickness 0.362 in. Diameter N/A Plain End Weight 25.69 Wfit PERFORMANCE Body Yield 604 x 1000 lbs Internal Yield 7240 psi SMYS 80000 psi Strength Collapse 5410 psi WEDGE 563— CASING CONNECTION DATA GEOMETRY OD 7.656 in. Z::Ccnnecticn =UnneLbonn. Coupling Length 9.250 in.in. PERFORMANCE 604 x 1000 Imernal Pressure 7240 psi Tension Efficiency 100 % lam Yield Strength lbs Capacity Compression Compression 604 x 100D Bending 52 °1100 ft Efficiency 100 % Strength Ise ERemal Pressure 5410 psi Capacity MAKE-UP TOKQUL* Minimum 7800 ft -lbs Optimum 9400 ft -lbs Nasi mum 13700 ft -lbs OPERATIONAL LIMIT TO k.. -. Operating Torque 33000 ft -lbs Yield Torque 39000 ft-lbS BUCK -011 T�;J V Qijl ' t z3nn fr-Ihs Ma�imun 15000 ft -lbs Page 30 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hil00rp B=V COMPOY 18.0 Cement 7" Intermediate Casing 18.1 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. • How to handle cement returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cement operation. • Document efficiency of all possible displacement pumps prior to cement job. 18.2 7" cement job will be a single stage, single slurry job. 18.3 RU Cement lines to cement swivel on CRT. Plugs will be dropped manually. CRT will be used to rotate and reciprocate during cement job. 18.4 Pump 5 bbls fresh water. Pressure test surface cement lines to 4000 psi. 18.5 Pump remaining 40 bbls 10.5 ppg spacer. 18.6 Drop bottom plug, Mix and pump slurry per below calculations, 25% OH excess volume Section: Calculation: Vol (ft3) 9.88" OH x 7" Casing: (10,200'— 9,700') x 0.04723 bpf x 1.25 =65.73 13.44$ ft3 8.5" (pilot hole) Rat Hole: 10' x.0701 x 1.25 =5 7" Shoe Track: 90' x .038 bpf =19.3 Total Volume•34190 Slurry Information Cement Slul System Sm4ftCEM' Sys Density 15.8 Ib/gal Yield 1.16 ft3/sk Mixed I 5.04 gal/sk Water Page 31 Version 1 May 2017 l63 sn IN Milne Point Unit C-47 Drilling Procedure Hilcorp EnmW C.P-Y 18.8 After pumping cement, drop top plug and displace cement with drilling mud. Use rig pumps for displacement. Ensure to have a good baseline measurement for pump displacement ahead of time. Displacement calcs: • 10,110' x.038 bpf = 384.2 bbls. 18.9 Monitor returns closely while displacing cement. Ensure pits are strapped every 10 bbls of displacement and communicated with Co Rep. If losses are seen, reduce pump rate. 18.10 Do not over displace by more than 1/2 shoe track volume. Total volume in shoe track is 3.5 bbls 18.11 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. • If this is the case, monitor the pressure on the casing and do not let it exceed 500 psi over the final pump pressure. 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 • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight &type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped &bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • 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(@hilcorp.com and cdin er@hilcorp com This will be included with the EOW documentation that goes to the AOGCC. 18.12 R/D cementing equipment. Flush out wellhead with FW. 18.13 Observe 9-5/8" x 7" Annulus for minimum 3 hours for no pressure or flow. Cc 18.14 ND, Set slips on 7" casing. Set Packof£ RILDS. NU. Test void to 250/4000 psi for 10 min. 18.15 After sufficient wait time, R/U and run a (RT from shoe t/ 8000' to locate TOC Page 32 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcnorp E Cam � v r 19.0 Drill 6-1/8" Production Hole Section 19.1 P/U 6-1/8" RSS 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. • Workstring will be 4" 14# S-135 HT -38 • Install ported float above motor. 19.4 6-1/8" hole 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. • 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 viscosifrer additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use water or low vis sweeps. • 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. Page 33 Version 1 May 2017 FA Milne Point=C-47Drilling Pr Hilcorp GveW COMP Y System Type: 9.5-10.5 ppg Baradrill N `7 Pro erties: entration Water bbl KCL b Section it ., Viscosit Plastic Viscos Yield Point Total Solids MBT H 8.5-9.0 6-1 /8" 9.5-10. 75-175 15-25 15-25 <10%< _ BARACARB 25 19.5 19.6 Product entration Water bbl KCL b NaC1 75BARACARB b KOH pb N -VIS 1.5 ppb N-DRIL HT PLUS Fppb 5 BARACARB 25 BARACARB 50 BARACOR 700 pbBARASCAV D pbX-CIDE 207 ppb TIH w/ 6-1/8" directional assembly on 4" DP to above TOC. Shallow test MWD and LWD on trip in. Note depth of TOC on moming report. Circulate bottoms up. 19.7 R/U and test casing to a6vu psi / 30 min. Ensure to record volume / pressure and plot on FIT graph. AOGCC regulation is o urs . 19.8 Drill out shoe track and 20' of new formation. p 19.9 CBU and condition mud for FIT. �Port'� 19.10 Conduct FIT to 12.5 ppg EMW. D 19.11 Drill 6-1/8" hole section to section TD per Geologist and Drilling Engineer. • Pump at 150-250 gpm (Target 200 ft/min AV) • RPM: 120 — for hole cleaning in horizontal sections • Geosteer in reservoir as per geologist and Halliburton Geosteer Tech. • 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. Page 34 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E.m C2,T • Pump water or other low vis sweeps to aid in hole cleaning. • Keep swab and surge pressures low when tripping. • Make wiper trips if necessary. • Take MWD surveys every stand drilled. 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. 19.12 At TD; pump hi -vis sweeps, CBU at least 3 times at maximum circulation and rotation, and pull a wiper trip back to the window. If backreaming is necessary: • Circulate at full drill rate (150-250 gpm). • 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 and circ at least a b/u once at the shoe. 19.13 Displace to KW completion brine 19.14 TOOH with the drilling assembly. Once inside casing, Rabbit DP on remaining drillpipe on TOOH that will be used to run 4.5" liner— Confirm diameter drift with Baker for setting liner hanger. 19.15 L/D 6-1/8" BHA 19.16 No additional logs are planned for the 6-1/8" hole section. Page 35 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp 20.0 Run 4-1/2" Slotted Liner 20.1 Ensure rams have been tested on 4-1/2" test joint prior to running liner. 20.2 Ensure wear bushing is installed in wellhead. 20.3 R/U 4-1/2" casing running equipment. • Ensure 4-1/2" HTTC x HT -38 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. 20.4 Run 4-1/2" slotted liner per completion tally. • Use "API Modified" or "BOL 4010 NM" thread compound. Dope pin end only w/ paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 4-1/2" VAM HTTC M/U torques Casing OD Minimum Maximum Yield Torque 4.J z 9,3 5 0 ft -lbs 14,40U ft -lbs o Page 36 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure HiIaTc..»a., r.n,.nwn.. %s m on: 05lun. 20151 lean-Guluau nr Besse DATA ARE INFORMATIVE ONLY. BASED ON SI -PD 101156 OD Weight 4 1/2 In. I 13.50 Ib/ft ID Cross Section Area Yield Strength Yield Strength ultimate Tensile Strength lie Yield Strength Yield Pressure Wall Th 0.290 In. 3.920 in. 3.836 sgin. API 5CT 80 ksi 95 ksi 95 list 307 k@ 307 Ilia 9,020 psi a knows VAM° like VAM Tensile Meld Strength 307 klb Compression Resistance 307 Ilia Compression with Sealability 246 Iib Internal Yield Pressure 9,020 psi Elde"I Pressure Resistance 8,540 psi Max. Bending 77 °/100R Max. Bending with SeslabllitY 33 °/100R Max. LnaO on Cou lin Face 158 Ilia eswwgl_7�-/ Connection Data Sheet Grade L80 In OD (nom) 5n ID (nom) Loss Length ross Section Pressure API Drift I Connection 3.795 in. VAN® HTTC 4.930 in. 3.849 in. 4.380 in. 9.917 in. 3.836 sqm. 100 % of 100 % Of with Sealability 80 %of mry 100 % Do you need help on this pmduRl - Remember no one knows VAM° like VAM Min. Make-up torque 6,910 R.Ib 8,130 R.Ib Opti. Make-up torque 9,350 R•Ib Max. Make-up torque Max. Torque with Sealability 12,350 R.Ib Max. Torsional Value 34 400 ft.lb Do you need help on this pmduRl - Remember no one knows VAM° like VAM .nada@vamflerdservke.rom ukDvam0eldserNre.[am raMa@vamfle105ervke.Com LakuDvemfiepservlre.mm use DvamfleMservice.rwn dvaeiDvamfielOservke.mm o gepo"yomflexxoryke.rom mexlroDvamRNdserHce.00m nlgMe@vamflwOservke.mm susfmlb@vamfleldservke.mm brsVk@vamflwdse l... eM.1.0vemnermhey"o.rom Wer 240 VAMP Spealaxrtf avallabm worldwide 24/7 for Rig SRe Asslstdnoe ON¢/ ConnKLgn Dd:d SaeeL' 9/e _'knIr .1 w Ww �dmSPrvIttS.COm 20.6 Ensure to run enough liner to provide for approx 150' overlap inside 7" casing. Ensure hanger/pkr will not be set in a 7" connection and t5e—packer should be above the 7" float collar. 20.7 Before picking up Baker ZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 20.8 M/U Baker ZXP liner top packer. 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. 20.9 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 20.10 RIH w/ liner on DP no faster than 1-2 min / stand. Watch displacement carefully and avoid V/ surging the hole. Slow down running speed if necessary. Page 37 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure 20.11 Fill DP with Top drive every 10 stands oras appropriate. Slotted liner should fill while RIH. 20.12 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth + S/O depth every 5 stands. Record torque value if it becomes necessary to rotate the string to bottom. 20.13 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 20.14 If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 20.15 RIH to TD. Page 38 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp 21.0 Set 4-1/2" Production Liner Hanger 21.1 Drop Ball. Pressure up as required by Baker procedure to set the liner hanger (20% above nominal setting pressure. 2500 psi is nominal setting pressure. Pressure up to 3000 psi to confirm hanger setting. 21.2 Slack off total liner weight plus 20k to confirm hanger set. 21.3 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner. 21.4 Bleed pressure to zero to check float equipment. 21.5 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve. 21.6 Rotate slowly and slack off 50k downhole to set the ZXPNliner toTnarker• 21.7 P/U to P/U weight plus 1 ft. µ t 7-- yoper�E 2 21.8 Close annular and test 4" DP x 7" annulus to 1500 psi / 10 min to test liner top packer. 21.9 Bleed off pressure, open up annular. 21.10 Pressure up to 500 psi down DP and pickup to remove the RS packoff bushing from the RS nipple. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops off rapidly, indicating pack -off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 21.11 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 21.12 Pick up to the high -rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re -tag the liner top, and circulate the well clean. 21.13 Watch for cement returns and record the estimated volume. Rotate & circulate to clear curt from DP. 4Vu Ce-h...;X 21.14 POOH, verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 21.15 If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure Page 39 Version 1 May 2017 J Milne Point Unit C-47 Drilling Procedure Hilcorp F.W Compmy and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 21.16 NOTE: Some hole conditions may require movement of the drillpipe to "work" the torque down to the setting tool. 21.17 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set -down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. 21.18 Pick up above SBE, Circulate BU at high rate to clean up wellbore. Ensure wellbore is clean at the production packer set depth. 21.19 POOH and LD running tool 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 • Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight &type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement, actual displacement volume, whether plug bumped &bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure • Note if pre flush or cement returns at surface & volume • Note time cement in place • Note calculated top of cement • 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 ieneelkhilcorp.com pchanna hilcoM.com. and cdingerLaMilcorR.com. This will be included with the EOW documentation that goes to the AOGCC. Page 40 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp F -m Company 22.0 Cleanout Run & Displacement (Contingency) 22.1 If well conditions warrant, a clean out run will be performed prior to running completion tubing 22.2 M/U casing clean out assembly complete with casing scraper assemblies for each size casing in the hole. 6.125" Casing scraper for 7" 26# casing. 4" DP to surface. 22.3 TIH & clean out well to top of SBE (+/- 10,000' MD). • Circulate as needed on trip in if string begins to take weight. • Circulate hi -vis sweeps as necessary to carry debris out of wellbore. 22.4 TOH w/ clean out assy. LDDP on the trip out. Note any abnormal wear on the clean out assy. ✓ kaNrZ J�<< �✓ 23.0 Run 2-7/8" Completion Tubing JAN-�N ,„. 23.1 R/U and run 2-7/8" tubing assy with GLM, sliding sleeve, nipple profile, production packer and WLEG. • Ensure appropriate well control crossovers on rig floor and ready. • Monitor displacement from wellbore while RIH. 23.3 Run 2-7/8" tubing to position WLEG below liner hanger/liner top packer. Record PU and SO weights. 23.4 RIH with completion to top of liner hanger/liner top packer. SO past liner top packer and space out WLEG —1 — 2 joints below liner top. ✓ 23.5 Makeup the tubing hanger and landing joint. 23.6 Reverse circulate the well with 310 bbl brine w/ corrosion inhibitor at 3 BPM. 23.7 Land hanger. RILDs and test hanger. Make note of actual weight on hanger on morning rpt 23.8 Perform a low pressure tubing test to 500 psi. C /1C vx-e Pi'-,,) ) 23.9 With annulus open, pressure up on tubing to close Autofill sub. Confirm Autofill sub is closed. Page 41 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp 23.10 Continue pressurizing the tubing to 3500 psi and set the packer. Test the tubing to 3500 psi for 30 minutes. Bleed off the tubing pressure to 1500 —1700 psi. Test the annulus to 3,700 psi for 30 min. Record and notate all pressure tests on chart. 23.11 Bleed off the tubing pressure to zero and shear the DCR valve in GLM #1.�`� 23.12 Set TWC and test to 1000 psi. ND BOPE and NU adapter flange and tree. Test to 5000 psi. 23.13 RU lubricator and pull TWC. RU hot oil pump and freeze protect the tubing and IA to 2500' MD with + 90 bbl of diesel. Allow freeze protect to U-tube. 23.14 Install BPV and test to 1000 psi. Secure the tree and cellar. V 23.15 RDMO Innovation 24.0 Post Rig Completion Work 24.1 Pull BPV. RU slickline. Pull shear valve and replace with dummy. Drift tubing to maximum deviation. RMDO. 24.2 RU Hot Oiler. Pressure test all lines to 5000 psi. 24.3 Pressure up on tubing to 4700 psi and hold for 10 minutes to expend Mirage 24.4 RU Slickline. 24.5 Run gas lift valves. 24.6 RD SL 24.7 Install BPV Page 42 Version 1 May qui i Milne Point Unit C-47 H Drilling Procedure Hileorp Ev C011WY 25.0 Innovation Rig Diverter Configuration 3-118' Kill 13-51E Technolo9l iUol Technology .519'5M Control chnology Double Ram 118' Choke Line ---�-18' Diverter Line Page 43 Version 1 May zu I i EMilne Point Unit C-47 Drilling Procedure Hilcorp E.c C.Y 26.0 Innovation Rig BOP Schematic 0 -----13-5/8" 5M Control Technology Annular BOP • Technology Double Ram T o -----�13-518" 5M Control ® Technology Single Ram 3-5/8"x 5M -11" x 5M 9-518" DBL D Seal 2-1/16"x SM 13-5/8" x 5M Casing Hanger S-22\ 13-518" NOM `2-1116" 5M t2O" 9-5/8" BTC Btm x x 10.5" -4 SA Pin Top W/ Primary Seal Casing " Casing Page 44 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure HilDorp F.nelgy Compmy 27.0 Wellhead Schematic HILCORP ALASKA, LLC MO -390 90.6 EST 154.1 EST 63.5 EST Page 45 0 3-1/8 5- 41,3 EST 3-1/8 5M A 3-1/8 5M HEAD 'v Y ADAPTER. TUBING SM–E-2CLN 11 5M X 3-1/8 5M (SPECIAL) WITH TWO (2) 3/8 CL 3-1/8 SM 6.1 EST 11 5M TUBING HANGER, SM–E-2CL 11 X 3-1/2 EU 8R0 BOX TOP - X 3-1/2 OD API MOD BOX BTM WITH TWO (2) 3/8 LP PORTS Si EST 11 5M 2-1/16 5M CASING HANGER. SMB -22 26.0N L-80 OWC/X BOX �4 25.8 8.500 EST STUB ACME-2G–LH PIN TOP W/SEAL ASSEMBLY 2-1/16 SM 9-5/8 DOL IPS } 13-5/8 5M 2-1/16 5M CASING HANGER. S-22 20.5 13-5/8 X 9-5/8 - EST 9-5/8 CASING MOM 7 CASING TUBING 5.000 PSI WELLHEAD ASSEMBL —� 2-%�8" 13-3/8 X 9-5/8 X 7 X 3-1/ ON THIS DRAWING ARE REST R IC TEO CONFIDENTIAL DOCUMENT US ••"` 1_10 "11 3 1 ND CAN VARY yGNIHCANIFLY ^' duwiw w4. W MATERIAL LENGTHS. IMPLIED. P-21576 STACKUP HEIpIT IS SHOULD BE CONSIDERED APOSES ONLY. Version 1 May 2017 A Milne Point Unit C-47 14 Drilling Procedure Hileorp Enema C.P-Y 28.0 Days Vs Depth MPC -47 Days vs. Depth Days 0 5 10 15 20 25 30 N 66 a 6000 .c y Q Q1 a 8000 v a, 2 10000 12000 � 2tl Page 46 Version 1 May 2017 35 Milne Point Unit C-47 Drilling Procedure MITT1-sM. Cmnpmy 29.0 Formation Description — MP C Pad Data Sheet C Naa.y AYy klarvW a]00 ss4 Raspecaty47Wto ABW R(Gal} FIAC71S PRO DU CTION"OLE, I E 5 5,000' L S. PLAN TO LIMIT HOLE INCLINATIONA EES AND DOG LEGS TOIt OOFT. NOLESMOOTHNESSSe ee 1f PORTANT. Seabee (Colville) Interval: PrMoniinaaN/ i1siMEMisd Nllsunsand ury with EMs a Salts. slWearM ouasiwulseanw dcoal. TlY seaEee is gxit gs"d P" +Yhdl.ail reachi.q lEe lata TIGHTIPACKING OFF INTERMEDIATE CASING; Ezp«t ROM Paneb'atim TNes- C-43: 7-518"CASING STOPPED AT 9.113 14755 ND), UNABLE TO RUN DEEPER, HAD TO PULL. POOR HOLE CLEANING, INSUFFICIENT CIRCULATING. MADE HOLE OPENER RUN AND E 6,000' RERAN CASING. HRZ: tigNY Raboactiw iAro. very aarM G2AAwsaMalmeN M951M15 erefWexperrsFVd mrKa Feepspe ssile bPa aluN. 019NMc. 9eM Iolace tMck RFT CWi1 fi V Tull(WrdarMWlxar poaMW NtopWHRZ 115-tO Epol wwicnwn c�uM wCn LCY lname�c .. TOP lin V a'd 10%Tuffs (-v'Ic3W 68W Ie o1) RESERVOIR OVER -PRESSURE RESULTING M90' Kalubik Shale: GOM 109 mvka MN19N ICaH V .2-67a- Silt wBdnlawir Kaluck and KLpY11L-D- IN WELL FLOWS AFTER PENETRATING 6570' 69•caWla avNprsssMrM due to Nph lnl«ta•n-� KALUBIK KUPARUK "D" & KUPARUK: IG70. fe NR V west imotMKtQiNefandsf irgy_ALnrWELL PROBLEM YOI..rvOI WRY. MIO WEAMi COYMEHi Kalubik V Presser. proses flats MI. DO ICWwr 69Y). w.a KALUSIK SILTS, SEE OVER-PRES$IAtE 51A1Ni`iRT. Cm OEM 7M(WI) R,LLMY' BN A110] 6T60'w 1 Kuparuk Interval: R` `a FLDWw4 num(M31 t01P-C w11't. rNAT CFIATFD C -i CS2 061 OEM MSOITOYI MOPMUN 1341111 "D" Shale TIY V SEW N ase top K.PN EY6lront Ntl is CSa OEM MOs(T ) gIPYNM MAIII. Lowvn OWEEP 6900' Iucwn as tlr'Cap RorA KUPARUKGVER. C31 FLMACM OWT 1.70) INP -D- 9Arl0A T.I.KUO•Ma,Y IC41) C PRESSUREIAAYOCCURINTHED-SHALE STWIAWL.e 11 a PPP 6910' Gas FLOW=ss 11Y0 STAM11NPMVK 1031111 (cot) LCU C SAND: 6w,mLors. airs. u WMd. C.r GCY ".10M I KUP-O- mines OIL BEARING TARGET FOR EASTERN C -PAD. cJ9 sL ROW UK Tfnauli) KUPARIsA1 lt] BMLLIIFAD 1Ty C's, MVM "LOW, ?wall KOPARUK � 7,000' B LCU: Low«CrMauwn tlrscadomily G12A TL" 1131110M51 .SK I'll's KU aruk OW 1 B SHALE OR LAMINATED ZONE: CaeA avow MaIMs11 KAk3K. 11.21x1 P LvnrYlad Zore Eeprm ENO'nLN. c.l2A [L>A cIOwFD YM6E RVKYO Dli LwER ]D60' Fne to llMQlm QiVl iirs3aE«Mirg C.0 FLOW SWI1M211 KVP-O' sAl laf RZ fIEIATEO IC41) ..1sal"WlBId"P HydIMMASIon Cao FLOW AlI09 I ..... Iu$ A3 IsSA M .1 -MINI Ter B slide is YarY I'LOWwT. WOE 9 Kn unstada la CN MIM andl«EdixWd]I C1 FLOW 616511.%rvw KUPAR4K 90197 FLOWED.."WOR WAS ddnin9 (C-26Lt). RM 9ACK TO To. GCI' 7060 A3: nn 9mtn sYdstur, caoriarirl0 IC41) VPWNd. r"hansty I`W ps"Wissisift. SERIOUS POTENTIAL FOR LOST RETURNS WHILE 17- PA PMSMA .10 to 100 and RUNNING. CIRCULATING AND CEMENTING PRODUCTION 711D, A2 PWnleabiliy. HYtlraFarEal Oearin9_ CASING (ESPECIALLY IF SURFACE CASING IS SHALLOW (C-01) 8Alt SBriW mA3 SET} ALSO BE PRE PARE D FOR POSSIBLE "BRE ATHING" FOLLOWING THE CEMENTING JOB. C-01.-02.-05.-06.-07, 7155' Al EAST, files Veined""1,. -08, A4, -17. -19, -22. -26, -23. -28, a9, -06. -IM (Col) Miluveach Mlluveach ShaleS: Prrdrnirumty -- 'KUPARUK FO TIO Shale sits sluts. 6d.nd 3o0ADon WIOw--� KtparWl Al. (C.tina Seat SAM K'garlM �r . -PRESSURE MAP 2006 Kin ak CORPIeES. Poe N1). Stntial Tar lost � Y"V 9 rMens wNN turvirg, crcliaEng « ` S We TJD <eRYnE119 FaYn9. / '•-� Kingak: MSTEr akW xrNlltNN bbdrda al P2 LVl &ALI TM s9ITM`M, TM KGnpak is known to IMOOnr r / 0622' T28 unatEle 1M lalger 0 is left open to drilling 8670' T+A fluids. in tlDt ang)es abav 45 dep�s a88VON1 mud w.wd is nRuind SM W. 1 Ba River u1sibaEwt In addition lwle staGl®tion ./ 9 mud product am r«onmended r«welh:� Sand exposing lM nn,,ul. See R«armrrldea PrxYces. 691r SAGRIVERSAND: 9larkr as116mtr.91M200rllaO. .93Scagly pats'" PAterdial hydrocarbon MIHN –_- C-23 tw iftdU Sag Ri—Sats. ' Shublik SHUSUIc hrbulN.a Di1l.Npr. dOix a ii sr, i sidNne). ISIMSPtlMM, alias.. sMamera ando0O MnSil ultda6Drr. e� �A >l 1 l W aW W depart an Weed en sEYdi eO9e1 altd "IW CS3 Pr.W .GNMSilly. IYIKVs�dammdrmM V- \ .. _r sie)PrbWrw NylSE arrd aeoOrldarylYRa lln Nl0FIS10Yy \ _ SamMarytYHa mry W%WsAxdeMnOWI.sllssilSAA K r C41 Ir- Frb Ys mtMmWdle wedlost tlreYYbn Mets OiaOT.. }�. ants C31 (19961 ddYdmdr Se9R aMd __� _ v -. 1 _,.^! Page 47 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp soero �vmr 30.0 Anticipated Drilling Hazards Surface 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 Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section efficiently — control ROP and avoid loading the hole with gas. Minimize gas belching by reducing flow rate if necessary. 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 DRILTREAT 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 adjacent wells in the vicinity. 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 btwn surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No 112S events have been documented on drill wells on this pad. Page 48 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E.W CO -PM 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 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Intermediate & Production Hole Sections: 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 with AV of 200 ft/min. 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 are no known faults in either hole section. H2S: Treat every hole section as though it has the potential for H2S. No 1-12S events have been documented on drill wells on "C" pad. The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic 112S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event 1-12S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures expected while drilling this well. Page 49 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp 31.0 Innovation Rig Layout May LUt i Page 50 Version I Milne Point Unit C-47 Drilling Procedure Hilcorp Energy Cmnpany 32.0 FIT Procedure Formation Integrity 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. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount t of kick tolerance in case well control measures are required. _ ��-P"`�� b' L"a Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 51 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure H — Hilcorp E C n ne�gy mnP Y 33.0 Innovation Choke Manifold Schematic Page 52 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp I F. -P Y 34.0 Casing Design Information Calculation & Casing Design Factors Milne Point Unit DATE: 5.18.2817 WELL: MPU C-47 DESIGN BY: Joe Engel Crite Hole Size 12-14" Hole Size 8ITx9.88" Hole Size 6 -19 - Mud Density: 9.5 Mud Density: 10.8 Mud Density: 9.8 Drilling Mode MASP(8.5' x 9.88'): 2915 psi (see attached MASP determination & calculation) Production Mode MASP: 2974 psi (see attached MASP determination & calculation) Collapse Calculation: Section Calculation 1, 2, 3 Max MW gradient external stress and the casing evacuated For the internal stress Page 53 Version 1 May 2017 Milne Point Unit ure Drilling Proced47 ure Hilcorp E..W CmnPa^Y 35.0 8-1/2" x 9.88" Hole Section MASP - ------ ---------- Maximum Anticipated Surface Pressure Calculation 8-1/2" x 9.88" Intermediate Hole Section A_iicorp MPU C-047 Milne Point MD ND Planned Top: 6600 4899 Planned TD: 10200 7110 Anticipated Formations and rressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Top Kuparuk D Shaie 6,98177— 3560 9.8 0.510 Top Kuparuk C Sand 7,111 1 3627 Oil I 9.8 0.510 offset Well Mud Densities Tnn f-nfnl Bottom (TVD) Date Well mrv,ansc 10.70 .-11..-, 8,886 -- 12.50 6,900 10.50 6,401 W7,4082001 =C-28A 11.00 6,821 10.50 6,450 10.30 6,830 Assumptions: 1. Fracture gradient at shoe is estimated at 0.7 psi / ft based on field test data. 2. Maximum planned mud density for the 8-1/2" x 9.88" hole section is 11.0 ppg. 3. Calculations assume Kuparuk reservior contains 100% gas (worst case). 4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface: 9-5/8" Shoe 6600' MD / 4899' ND 4899 (ft) x 0.7(psi/ft)= 3429 psi 3429 (psi) - [0.1(psi/ft)*4898(ft)]= F2939 psi Drilling Mode MASP MASP from pore pressure (wellbore completely evacuated to gas) 7110(ft) x 0.51(psi/ft)= 3626 psi 3626 (psi) - [0.1(psi/ft)*7110(ft)]= 2915 psi I Summary: 1. MASP while drilling 8-1/2" Intermediate hole is governed by the wellbore completely evacuated togas from Ithe Kuparuk Reservior Page 54 Version 1 May 2017 Milne Point Unit ure Drilling Proced4477 ure Hilcorp Energy C.P.Y 36.0 6-1/8" Hole Section MASP Maximum Anticipated Surface Pressure Calculation in 6.125" Production Hole Section '.Hilcorp MPU C-047 Milne Point MD ND Planned Top: 10200 7110 Planned TD: 13509 7256 Anticipated Formations ano rrressures: ND Est Pressure Oil/Gas/Wet PPG Grad Formation Top KuparukCSand 7,111 3627 Oil 9.8 O.SiO offset Well Mud Densities 11m1 on+tnm fNnl Date Wei C -15A IVIVY IGlirjc 10.70 -1 l" 8,886 8,972 2016 C-43 12.50 6,900 7,547 2004 C - 28A 10.50 6,401 7,339 2006 C-40 11.00 6,821 7,408 2001 C-12 10.50 6,450 7,578 1985 C-11 10.30 6,830 7,526 1985 Assumptions: 1. Fracture gradient at shoe is estimated at 0.7 psi / ft based on field test data. 2. Maximum planned mud density forthe 6-1/8" hole section is 10.0 ppg. 3. Calculations assume the Kuparuk reservior contains 100% gas (worst case). I4. Calculations assume worst case event is complete evacuation of wellbore to gas. Fracture Pressure at 7" shoe considering a full column of gas from shoe to surface: 7110 (ft) x 0.7(psi/ft)= 4977 4977 (psi) - [0.1(psi/ft)`7110(ft)]= 4266 psi Drilling Mode MASP 5l MASP from pore pressure (wellbore completely evacuated togas),-- . 7256(ft) x 0.51(psi/ft)= 3700 psi j 3700 (psi) - [0.1(psi/ft)'7256(ft)]= Summary: -,— ,1. MASP while drilling 6-1/8" Intermediate hole is governed by Ithe Kuparuk. completely evacuated to gas from Page 55 Version I May 201 "/ Milne Point Unit C-47 0 Drilling Procedure Hilcorp E� C.wy 37.0 Spider Plot (NAD 27) (Governmental Sections) i LeOery • MPU C47_SHL ONer Surface Hiles (SHL) X MPU C47 TPM ' Otl'er Batt°m Hiles tHHL) _ _ _ OMer Well Paths + MPU C47_BHL O Di aM Gas una 8°wdary = Pad F.OWI t Milne Point Unit MPC -47 Well 11, e°d.° e"O°° Sec tt ADL047437 _eC.., 0 500 1,000 === Feet Page 56 Version 1 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E..W Company 38 0 Qnrfare Plat (As Built) (NAD 27) Page 57 Version I May 2017 PLANT GEODETIC + M 2iD0 13 , SECTION TMS I � w I ■ 19 I C-PAO C-PAO F I r,, POSITION(DMS) POSI710N(O.DG) AVEL PA OFFSETS _ ■ q S B -PAD Ill - •. Na757.87 I A - AD p i.... ■ 1] 2■ I I I :7: 24 ■ I I ■ 42 :4 E I 1 e - N - 25 ■ I I I "r I 9 ■ ■ ' , 26 0 21 r 2.339' EEL 23■ I I I I I I ■ 11 I VICINITY MAP N70.4902494' Nr Sa I I I 46 N: '° ■ I .5 II I ■ 2130 2E N LEGEND ° 9 a ■ 14 AS-3UILT CONDUCTOR 47 ■ EKNOD CCNOUORI 722' EG 2.307 FEL I I 61 ■ I I ■ 15 I I I I I I I s ■ I I I I NOTES IN 22. L 9JRVEV DATE MARDI 12. 2017 rl aZ FERCK 05 PUMP 2. REENCE PHEID BOM17-01 PCS. 14-21 LI O I I 1 ALASKA STATE PCODRCNRES ARE ALkJ A ZOVE I 3- LAKE ° I I I ALA o IQ1 L J o I a MOOETIC 4JCRONATES ARE NAD 27. ©^,�, I .. PAC FACTOR IS0 M:A 9 COfiTROL IS EASED C,1. IIUE�IIIW^�nMlll ONTACALE .AL I 5. HClJ2 EN AND AND C -L MDNJMENIS C -I AND C-2 I 6. E ATONS APE BASE) ON BP% MINE PT DAVM tM.S Lj + M w"L' GRAPHIC SCALE 0 1I] 25DLrIJ ]o] u N FEET I mZE - 250 ft. LOCATED N@IN pn" ACTO 2C- 1D T 13 K.. R. 10 E. UM AT MERMIAN. AK. vvftrvcicN Hilcorp Alaska c MA MPU C -PAD bell M. e17 Mx y1 "a WELLS C-44, C-45. C-46 AS -BUILT WELL LOCATIONS g+ r ac I, 1•-n6• Page 57 Version I May 2017 PLANT GEODETIC GEODETIC TOP OF SECTION CELLER BO% WELL A.S.P. COORDINATES COORDINATES POSITION(DMS) POSI710N(O.DG) AVEL PA OFFSETS RIIA ELEV. NO. N: 6029204.76 Na757.87 N70'29"25.4623° N70.4904062' 15.0 923' FS 15.22 C -4c' E:.158093 `.18 E:600.35 W149'3130.3608" WT 49.5251002' 2.339' EEL 8929147.50 N: 1697.85 N 0'2924.8978 N70.4902494' 14.8 888 5 14.79 C-45 N: E: 599.98 W'149'31'29.8454" w49.5249571' 2.351' FEL E556111.14 N:6029004 , 74 N:1547.94 N70'29'23.4902' N70.4898594' 15.2 722' EG 2.307 FEL 15J5 C-47 E: 558156.85 E: 599.43 VI149'31'28-5331" W149.524 92 Page 57 Version I May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E.e C2,7 39.0 Offset MW vs TVD Chart 0 2000 f gi 4000 5000 F717,57111 9000 10000 11000 12000 g 9 10 11 12 Mud Density (Ppg) Page 58 Version 1 13 14 May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E Com E. Pv Y 40.0 Drill Pipe Information 5" 19.59 S-135 NC -50 1W Weatherford 5" 19.50 Ib/ft S-135 W/ INC 50 6-518" OD x 3.1/4" ID Tool Joint 500204050016200 ONS RILL PIPE SPECEper Outside Diameter e 5-135 n NC 50 Interchanh MAdjustp.d 5' XH & 4-1/2" IF e IEU Nominal Weight Foot 19.50 lbs Weight With Tool Joint per Foot 23.08 lbs TOOL JOINT DATA Outside Diameter 6-518" Inside Diameter 3-114' API Drift 3-1/8' Rabbit OD, Suggested 3-1116" Minimum Make -u Tor ue 25 900 ftlbs Maximum Recommend Make -u Tor ue 26 800 ft -lbs Torsional Yield Strength 51,700 ft -lbs Tensile Strength 1,269 000 IbS TUBE DATA New Premium Outside Diameter 5.000" 4.855" Inside Diameter 4.276" 4276' Wall Thickness 0.362' 0290' Cross Sectional Area 5.275 s in 4.154 s in Maximum Hook Loadfiensile Stren th Slip Crushin /Slip Type (SDXL) Burst Pressure 712 000 lbs 572,100 lbs 17,700 si 560 800 lbs 453,500 lbs 16 100 si Colla se Pressure 15,700 si 10 D00 si Torsional Yield Strength 74,100 ft -lbs 58,100 ft -lbs Ca aci 4V! Tool Joint 0726 US allft 0.726 US aLYt Dis lacement 4Y1 Tool Joint 0.353 US al/ft 0.322 US allft Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss, damage or injury resulting from the use of the information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. Page 59 Version I May 2017 B Hilcorp 5" 19.5# S-135 DS -50 NW Grant Prideco ...,.py.amm«�n.m a«m:.,oa„aramm Drill Pipe Configuration f 1 Pit. Body 00-n`5.WD Pipe Body Wall lEkeness ., 0.362 Pipe Body Grade 3-135 Dn8 RP Length Itnoe2 Connection GPD35o Tod J.in OD 8.025 Tod Joint ID Im 3 250 Pin Torg 0 Box Tong 12 Drill Pipe Performance Milne Point Unit C-47 Drilling Procedure Drill Pipe Performance Sheet 80 % Inspec4on Class Nominal Wapt4 O.Wowon 110.50 nll P.pe App.xwule Lengthnm 31.6 SnmwhE n 3l32Rafsed Elevator Shoulder Information Tool Joim SMYS ro 1211000 UPW T 1W EWx Uput OD (DTE( .?5.125 Fnedm, Fa 1.0 xem: r«e w.. rvr*:we m.mv.ne. Drill-Pbe Len001 Pa 502 Perfofinence of Dnp Pion with Roe Body at FBest res l— --Nominal 60% Inspection Class ... ""'«°"'m' rw �« Ip�«al MUTeem Pee d4imm-tl WeQlt te.m 24.11 2310 ..n Tatoe .e:I non Fluid D'is 13cemenl ia.m, C.37 0.30 Tatman ONy p 500.800 Fluid Dis lacament anenl o oro vtmmYm uur 43.100 m^atwtmae3g,8W to3m Fluid Capacft te.m 1 0.70 0.72 Flndd . 0.0180 0.0167 O.D172 ..^umsan 36,100 Talion Orly 0 550,000 Drift Sce .13.125 cmmemwmnz32.tm 1467.400 Im-. a�sm m,n.w,a"sue m.m. mv:proem.:..ran.vv.v.m xn.vnm:.v.:„r: a.. rose. roar.�n ma.^«..nmmvvmz.mme, «pemv.amm Connection Performance GPDS50 ( 6.625.1 OD x 32.50 .1 ID ) 120.000 m a .1.em w.�« Tm,I«.anw«, nmw.emm.wn Tool Joint Dimensions o mn a^mavn mu rem .sh Balamed m m 8.435 mt4n Ma Tamoe 43.100 Ten Linilad 1.018.900 Ium .m nco mrsltnt 5.830 IIIME.. Mahe-uo Torwre 36.100 1.202.500 1,250,WC 1.l MmamVtinOL-iyryey"uC«Wm.M. N.S%. rinlmm TeN.bnl N m c.wm«m rot 593 .trJr . n•c nm:.�•wa« Pipe Body Slip Crushing Capacity ,TV Ppesod7Cordll;• ( tm en:T�+z.:xs3 onx .w.v — rtm..4.om 5 O OD 0.362.) Wall S-135) Pipe Bodv Performance Pee Body[ortlprmon( 5(m OD 0.3621m Wall S-135) Toot Jun Torsional SeengN Hemi ]1.Bm API Przmitan eWss TW Jun Tens, e 3 ngtn Iron "M.w0 Elevator Shoulder Information 580.800 Pipe Tpraorvl3VenpTv:`]4,100 w Smoo01E0ge Height 58,150 T oraimW TBallo 3'32 Raised 1-24 — Boz OD &812 .w:; 9.350 Elevator Capacity mu 1.658.1100 Assumed Elevator Bore D I n Pipe Body Slip Crushing Capacity ,TV Ppesod7Cordll;• ( tm en:T�+z.:xs3 onx .w.v — rtm..4.om 5 O OD 0.362.) Wall S-135) Pipe Bodv Performance Pee Body[ortlprmon( 5(m OD 0.3621m Wall S-135) we: uvTme amm .woe=w new Page 60 Version I May 2017 Nominal m%mzpemon Class API Przmitan eWss Ripa Ta Ie SUenDM ..)712,100 560.800 580.800 Pipe Tpraorvl3VenpTv:`]4,100 w 58,150 58,150 T oraimW TBallo 0.07 1-24 1.24 BD%Pipe Torsional SUeNth .w:; 9.350 46550 46,5m VAN 15.838 15,038 C.I.P. ipv;. 15.872 10,020 10020 Pye co im 5.000 4.819 0 Wali Thipaness tm 0382 0.200 0.200 N.Ri 113 nm .270 4.278 4.276 C,oss3ecwral AnsauPpe Body Im•z5.275 4ANI 4A54 Cress Brea O IML 19.835 1831418.5N Crosz Seevxul Area or I Guinn a.WYLa Im•x• 14.380 m•a, .'ma 14.380 ex'rw 14.350 A— we: uvTme amm .woe=w new Page 60 Version I May 2017 Milne Point Unit C-47 Drilling Procedure Hilcorp E.nW C.pW 4" 14# S-135 HT -38 400204138036211 1W Weatherford 4" 14.00 Ib/ft Internal Coating S-135 w/ HT 38 4-718" OD x 2.9/16" ID w/ X 7000 Hard Banding Tool Joint DRILL PIPE SPECIFICATIONS Grade S-135 Connection HT 38 Interchangeable With 2-7116" upset Type IU Internal Coating TK 34 XT Nominal Weight per Foot 14.00 lbs Adjusted Weight With Toot Joint per Foot 15.65 Itis TOOL JOINT DATA Outside Diameter 4-718" Inside Diameter 2-9116" API Drift 2-7116" Rabbit OD, Suggested 2-318" Hard Band X 7000 Minimum Make-up Torque 12,200 ft -lbs Maximum Recommend Make-up Torque 17,700 ft -lbs Torsional Yield Strength 29,500 ft -lbs Tensile Strength 649,200 lbs TUBE DATA New Premium Outside Diameter 4.000" 3.868" Inside Diameter 3.340" 3.340" _ Wall Thickness _ 0.330" 0264' Cross Sectional Area 3.805 sq in 2.989 sq In Maximum Hook Loadrrensile Strength 513,600 Itis 403,500 Itis SII Cmshin SDXL 431,900 Itis 3413001bs Burst Pressure 19,500 psi 18,400 psi Collapse Pressure 20,1100psl 13 800 si Torsbnal Yleltl Stren ih 41 900 ft4bs 32 800 ft -lbs Ca ci W/Tool Jomt 0.442 US aVR 0.442 US allR , Dis lacement W! Tool Joint 0.240 US alfft 0.223 US aVR_ Excessive heat or pulling when tube is torqued can cause the maximum pull to decrease. Where possible all figures are obtained from OEM data source. NOTE: Weatherford in no way assumes responsibility or liability for any loss, damage or Injury resulting from the use of the Information listed above. All applications are for guidelines and the data described are at the user's own risk and are the user's responsibility. Page 61 Version I May 2017 Hilcorp Alaska, LLC Milne Point M Pt C Pad Plan: MPU C-47 MPU C-47 Plan: MPU C-47 wp06 Standard Proposal Report 05 May, 2017 HALLIBURTON Sperry Drilling Services HALLIBURTON EM Sperry Drilling M Pt C Pad Well: Project: Milne Point Site: M Pt C Pad Well: Plan: MPU C-47 Wellbore: MPU C-47 Design: MPU C-47 Wp06 WELL DETAILS: Plan: MPU C47 Ground Leal: 15.28 +N/ -S +Er -W Northing Easting 0.00 0Ag 6029004.74 558158.85 BPRF 2250 W 0 3000 0 r as 3750 D m r j 4500 � - SBOA 2 5250 195p6�0 145682 MO. 850,04 Hilmrp Alaska, LLC SURVEY PROGRAM REFERENCE INFORMATION Method'. Minimum Curvature Co-ordinate (N/E) Reference: Well Plan: MPU C47, Tore Noun Error System: ISCWSA Yes Version: Vertical(TVD) Reference: As-BuiO@4170usft [CaWl-lation Scan Method: Closest Approach 3D 7" X812' Measured Depth Reference: As-Built@4170usft Error Surface: Elliptical Conicarning Method Error Ratio SunmyPlan Calculation Method: Minimum Curvature 70° 29' 23,490 N 149.31' 20.533 W 7110,63 WELL DETAILS: Plan: MPU C47 Ground Leal: 15.28 +N/ -S +Er -W Northing Easting 0.00 0Ag 6029004.74 558158.85 BPRF 2250 W 0 3000 0 r as 3750 D m r j 4500 � - SBOA 2 5250 195p6�0 145682 MO. 850,04 V4 011 SURVEY PROGRAM TVD TKLGM Date: 2 01612-1 3T00.00:00 Wiidated: Yes Version: Size LatlBude Longitude 7" X812' Depth Fmm Depth To SunmyPlan Tool 70° 29' 23,490 N 149.31' 20.533 W 7110,63 26.50 1300 00 MPU C47 wars SRG-SS 7256.70 1300.00 660D.00 MPU C47 wines MWD+IFR2+MS+sag 6600.00 1D200.00 MPU Cd7 wp06 MWD+IFR2+MS+sa1 TVDPath WDss Path MDPath 10200.00 13509.04 MPU C47 wp06 MWD+IFR2+MS+sa1 192225 BPRF 4441.70 4400.00 5937.38 SBOA 6391.70 nials, .1 CM1 6591.70 6550.00 9049.40 THRZ 684170 6800.00 9444.08 TKLGM 6981.70 6940.00 9721.93 TKUO 7111.70 7070.00 10210.67 TKUC WELL DETAILS: Plan: MPU C47 Ground Leal: 15.28 +N/ -S +Er -W Northing Easting 0.00 0Ag 6029004.74 558158.85 BPRF 2250 W 0 3000 0 r as 3750 D m r j 4500 � - SBOA 2 5250 5 MO 3265M0 r�j1p0•.. 326 .1N0 .go1\po 626�� _O\1pj1�.,626Ito' 0 0 "A.57 _ 1000 gubOa 51100 1117 A1. 40 710 0 M10115011- - - - 2n.u, 819 195p6�0 145682 MO. 850,04 V4 011 SURVEY PROGRAM TVD TKLGM Date: 2 01612-1 3T00.00:00 Wiidated: Yes Version: Size LatlBude Longitude 7" X812' Depth Fmm Depth To SunmyPlan Tool 70° 29' 23,490 N 149.31' 20.533 W 7110,63 26.50 1300 00 MPU C47 wars SRG-SS 7256.70 1300.00 660D.00 MPU C47 wines MWD+IFR2+MS+sag 6600.00 1D200.00 MPU Cd7 wp06 MWD+IFR2+MS+sa1 TVDPath WDss Path MDPath 10200.00 13509.04 MPU C47 wp06 MWD+IFR2+MS+sa1 5 MO 3265M0 r�j1p0•.. 326 .1N0 .go1\po 626�� _O\1pj1�.,626Ito' 0 0 "A.57 _ 1000 gubOa 51100 1117 A1. 40 710 0 M10115011- - - - 2n.u, 819 5500 g6„ __ - __. ........ 6106'___. .. _. %00 6521. MO• S40 9 5/8" X 12 1/4'I. _ _ _�'rBSPC 50" ow 6116D 16 0 659326 M O .9061. 56905 'POP g,,60r1 9212191a10 Sa�Ort 61°1106 SMO 11663 1 . 10199. laeim9 nd Or G� 6 �gm - a o 0 'ul Nul- CM 1 Floating Target wp05 412" X 612p1 195p6�0 145682 MO. 850,04 V4 011 5500 g6„ __ - __. ........ 6106'___. .. _. %00 6521. MO• S40 9 5/8" X 12 1/4'I. _ _ _�'rBSPC 50" ow 6116D 16 0 659326 M O .9061. 56905 'POP g,,60r1 9212191a10 Sa�Ort 61°1106 SMO 11663 1 . 10199. laeim9 nd Or G� 6 �gm - a o 0 'ul Nul- CM 1 Floating Target wp05 412" X 612p1 850,04 THRZ TVD TKLGM TKUD Size TKUC 7" X812' MO j255T Z.10 . 135 'do cap _MPU�d7_wpA¢ " Ma AT *9p5 G Cpl MpOA, WMFc.sT W MpCGO I Ai'4Pp5 Grob Gp11 MPCAT Wp65 aA1 ,0 GpMPGAI WY•' GMpGl'T M �C(A,nOr�rwLL a�2 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 Vertical Section at 310.00° (1500 usfUin) CASING DETAILS TVD MD Name Size 4898.83 6500.00 95/8"X121/4" 95/6 7110,63 10200.00 7' X 812" 7 7256.70 13509.04 412" X 612" 4-12 FORMATION TOP DETAILS TVDPath WDss Path MDPath Formation 1671.70 1630.00 192225 BPRF 4441.70 4400.00 5937.38 SBOA 6391.70 6350.00 8758.15 CM1 6591.70 6550.00 9049.40 THRZ 684170 6800.00 9444.08 TKLGM 6981.70 6940.00 9721.93 TKUO 7111.70 7070.00 10210.67 TKUC MO j255T Z.10 . 135 'do cap _MPU�d7_wpA¢ " Ma AT *9p5 G Cpl MpOA, WMFc.sT W MpCGO I Ai'4Pp5 Grob Gp11 MPCAT Wp65 aA1 ,0 GpMPGAI WY•' GMpGl'T M �C(A,nOr�rwLL a�2 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 Vertical Section at 310.00° (1500 usfUin) NALLIBURTON Spumy 131llung 6650 3 O On 3800 L+ L 0 3325 475 0 Project: Milne Point MPC -47 x906 CP7 WELL DEI'AOS: Flan: MPU C-47 +N/ -S +&-W 0.00 0.00 oreund Ua el: 15.20 Northing Easnng ®6thude lungirude 6029004]4 558156.85 70°2923490N 149°31'28.533W Site: Well: Wellbore: M Pt C Pad Plan: MPU C-47 MPU C47 1 P 47 xP05 CM REFERENCE INFORMATION Plan: MPU C47 wpG6 Be®n Cxo-Sleerin8_ _ _ _ _ -MFC 7x905 CPI _ Cgbp inete (WE) Reference: Well Plan' MPU C-47, Tme Nodh 7"X812"__________ End Dir : 10199.94'Mg7110.63'TVD Vertical IND) Reference: Aa-Built®4t]0usn Measured Depth Reference: M-Built®4'V0us11 MUD Stas Dir6.1°/100': 9212.W 1V[D.(698s'WD Celculatbn Method Minimum Curvature -- MLGM CASING DETAILS 750 TVD TVDSS MD Sim Name Fnd Dir %51.76'MD,6593.25'7rVD - 6500 4898.83 4857.13 6600.00 9-5/8 9 5/8" X 12 1/4" 7110.63 7068.93 10200.00 7 7" X81/2" 7256.70 7215.00 13509.04 4-1/2 41/2"X612" -1425 -950 -475 0 MPU C47 xpW 412"X612' _ _ _ _ _ - - MPCd7 xP06 CPI I ToW Depth : 13509.04' MD, 7256.7 TVD _ MPC47 w 06 CN MPC -47 x906 CP7 MPCJ7 x905 CPS MPC47 wy05 CP4 - 1 P 47 xP05 CM NiPC-47 up05 CP2 Be®n Cxo-Sleerin8_ _ _ _ _ -MFC 7x905 CPI _ ___ -TKUC 7"X812"__________ End Dir : 10199.94'Mg7110.63'TVD 9000 MUD Stas Dir6.1°/100': 9212.W 1V[D.(698s'WD -- MLGM 750 Floating Target xp05 - - - - - _-- Fnd Dir %51.76'MD,6593.25'7rVD - 6500 Stan Dir 69109: M65.2T MD, 6185.669VD n CMI 9 SB" X 12 I/4" SBOA BPRF_ y2 But Dir: 145682' Ate, 1350.6' TVD S.D,5'/109 1226.5T1D,1177.41TVD 2 - - - - - - - - -Build Dir 5°/100': 926.5' MD, 914.52TVD - - _- - Build Dir4°/100': 6265' MD, 625.2=D Build Dir 3°/100':3265MD, 326.51 475 950 1425 1900 2375 2850 3325 3800 4275 4750 5225 West( -)/East(+) (950 wf /in) HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Pad Well: Plan: MPU C47 Wellbore: MPU C-47 Design: MPU C-47 wp06 Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU C47 TVD Reference: As -Built @ 41.70usft MD Reference: ASBuilt @ 41.70usft 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: HAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone D4 Using geodetic scale factor Site M Pt C Pad, TR -13-10 Site Position: Northing: 6,027,347.71 usft Latitude: 70° 29'7.200 N From: Map Easting: 558,058.04usft Longitude: 149°31'31.821W Position Uncertainty: 0.00 usft Slot Radius: 0.. Grid Convergence: 0.45 ' Well Plan: MPU C47 Well Position +NIS 0.00 usft Northing: 6,029,004.74 usft Latitude: 70° 29'23.490 N +E/ -W 0.00 usft Easting: 558,156.85 usft Longitude: 149° 31'28.533 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 15.20 usft Wellbore MPU C47 Magnetics Model Name Sample Date Declination Dip Angle Field Strength P) (°) (nT) BGGM2016 6/15/2014 19.45 81.09 57,608 Design MPU C47 wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 26.50 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) C) 26.50 0.00 0.00 310.00 5/52017 6:34:46PM Page 2 COMPASS 5000.1 Build 81 Halliburton H A LL I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US +CANADA Local Co-ordinate Reference: Well Plan: MPU C47 Company: Hilcorp Alaska, LLC TVD Reference: As -Built @ 41.70usft Project: Milne Point MD Reference: As -Built @ 41.70usft Site: M Pt C Pad North Reference: True Well: Plan: MPU C47 Survey Calculation Method: Minimum Curvature Wellbore: MPU C47 Depth Inclination Design: MPU C47 wp06 System +NIS Pian Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NIS +EI -W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) ('I100usft) (°1100usft) (°/100usft) (°) 26.50 0.00 0.00 26.50 -15.20 0.00 0.00 0.00 0.00 0.00 0.00 326.50 0.00 0.00 326.50 284.80 0.00 0.00 0.00 0.00 0 00 0.00 626.50 9.00 49.50 625.27 583.57 15.27 17.88 3.00 3.00 0.00 49.50 926.50 21.00 49.50 914.52 872.82 65.61 76.81 4.00 4.00 0.00 0.00 1,226.50 36.00 49.50 1,177.41 1,135.71 158.31 185.35 5.00 5.00 0.00 0.00 1,456.82 46.38 57.13 1,350.60 1,308.90 247.81 307.25 5.00 4.51 3.31 28.79 8,465.27 46.38 57.13 6,185.66 6,143.96 3,001.26 4,568.60 0.00 0.00 0.00 0.00 9,051.76 49.00 9.00 6,593.25 6,551.55 3,345.97 4,788.48 6.00 0.45 -8.21 -102.77 9,212.19 49.00 9.00 6,698.50 6,656.80 3,465.55 4,807.42 0.00 0.00 0.00 0.00 10,199.94 84.26 313.99 7,110.63 7,068.93 4,248.48 4,481.58 6.10 3.57 -5.57 59.87 10,219.07 84.26 313.99 7,112.54 7,070.84 4,261.71 4,467.88 0.00 0.00 0.00 0.00 10,231.46 85.00 314.00 7,113.70 7,072.00 4,270.27 4,459.01 6.00 6.00 0.10 0.97 10,308.04 88.01 313.41 7,118.37 7,076.67 4,323.08 4,403.76 4.00 3.93 -0.77 -11.07 10,559.59 88.01 313.41 7,127.12 7,085.42 4,495.85 4,221.13 0.00 0.00 0.00 0.00 10,581.01 88.50 313.00 7,127.77 7,086.07 4,510.51 4,205.53 3.00 2.30 -1.92 -39.84 10,731.01 88.50 313.00 7,131.70 7,090.00 4,612.77 4,095.86 0.00 0.00 0.00 0.00 10,762.68 87.87 313.00 7,132.70 7,091.00 4,634.36 4,072.71 2.00 -2.00 0.00 179.87 11,031.21 87.87 313.00 7,142.70 7,101.00 4,817.38 3,876.46 0.00 0.00 0.00 0.00 11,075.02 89.62 313.00 7,143.66 7,101.96 4,847.24 3,844.44 4.00 4.00 -0.01 -0.13 11,231.22 89.62 313.00 7,144.70 7,103.00 4,953.77 3,730.19 0.00 0.00 0.00 0.00 11,283.49 91.71 313.00 7,144.09 7,102.39 4,989.41 3,691.97 4.00 4.00 0.01 0.08 11,531.34 91.71 313.00 7,136.70 7,095.00 5,158.37 3,510.79 0.00 0.00 0.00 0.00 11,580.67 94.30 313.00 7,134.11 7.092.41 5,191.96 3,474.76 5.26 5.26 0.00 0.00 11,809.33 94.30 313.00 7,116.95 7,075.25 5,347.47 3,308.00 0.00 0.00 0.00 0.00 11,957.69 86.50 313.00 7,115.91 7.07421 5,448.57 3,199.58 5.26 -5.26 0.00 -180.00 12,232.69 86.50 313.00 7,132.70 7,091.00 5,635.77 2,998.83 0.00 0.00 a(lo 0.00 12,371.88 79.54 313.00 7,149.60 7,107.80 5,729.93 2,897.86 5.00 -5.00 0.00 180.00 12,376.08 79.54 313.00 7,150.37 7,108.67 5,732.75 2,894.83 0.00 0.00 0.00 0.00 12,528.07 87.14 313.00 7,167.98 7.12628 5,835.63 2,784.51 5.00 5.00 0.00 0.00 12,803.07 87.14 313.00 7,181.70 7.140.00 6,022.95 2,583.64 0.00 0.00 0.00 0.00 13,009.61 76.18 313.00 7,211.62 7,169.92 6,162.11 2,434.41 5.31 5.31 0.00 -179.99 13,059.36 76.18 313.00 7,223.50 7.181.80 6,195.05 2,399.08 0.00 0.00 0.00 0.00 13,309.04 89.43 313.00 7,254.71 7,213.01 6,363.62 2,218.31 5.31 5.31 0.00 0.01 13,509.04 89.43 313.00 7,256.70 7,215.00 6,500.01 2,072.04 0.00 0.00 0.00 0.00 5/52017 6.34:46PM Page 3 COMPASS 5000.1 Build 81 Planned Survey Halliburton HA LL I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US +CANADA Local Co-ordinate Reference: Well Plan: MPU C-07 Company: Hilcorp Alaska, LLC TVD Reference: As -Built @ 41.70usft Project: Milne Point MD Reference: As -Built C 41.70usft Site: M Pt C Pad North Reference: True Well: Plan: MPU C47 Survey Calculation Method: Minimum Curvature Wellbore: MPU C47 Depth Inclination Design: MPU C-47 wp06 Depth TVDss Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +EI -W Northing Easting DLS Vert Section (usft) (1) V) (usft) usft (usft) (usft) (waft) (usft) -15.20 26.50 0.00 0.00 26.50 -15.20 0.00 0.00 6,029,004.74 558,156.85 0.00 0.00 100.00 0.00 0.00 100.00 58.30 0.00 0.00 6,029,004.74 558,156.85 0.00 0.00 200.00 0.00 0.00 200.00 158.30 0.00 0.00 6,029,004.74 558,156.85 0.00 0.00 300.00 0.00 0.00 300.00 258.30 0.00 0.00 6,029,004.74 558,156.85 0.00 0.00 326.50 0.00 0.00 326.50 284.80 0.00 0.00 6,029,004.74 558,156.85 0.00 0.00 Build Dir 3°1100' : 326.5' MD, 726.5'TVD 400.00 2.21 49.50 399.98 358.28 0.92 1.08 6,029,005.67 558,157.92 3.00 -0.23 500.00 5.21 49.50 499.76 458.06 5.11 5.99 6,029,009.90 558,162.80 3.00 -1.30 600.00 8.21 49.50 599.07 557.37 12.70 14.87 6,029,017.55 558,171.61 3.00 -3.23 626.50 9.00 49.50 625.27 583.57 15.27 17.88 6,029,020.15 558,174.61 3.00 -3.88 Build Dir4°1100' :626.5' MD, 625.2TTVD 700.00 11.94 49.50 697.54 655.84 23.94 28.04 6,029,028.90 558,184.69 4.00 .6.09 800.00 15.94 49.50 794.57 752.87 39.59 46.35 6,029,044.68 558,202.88 4.00 -10.06 900.00 19.94 49.50 889.69 847.99 59.59 69.77 6,029,064.86 558,226.14 4.00 -15.14 926.50 21.00 49.50 914.52 872.82 65.61 76.81 6,029,070.94 558,233.14 4.00 -16.67 Build Dir 5°1100' : 926.5' MD, 914.52'TVD 1,000.00 24.68 49.50 982.24 940.54 84.13 98.50 6,029,089.63 558,254.68 5.00 -21.38 1,100.00 29.68 49.50 1,071.18 1,029.48 113.78 133.22 6,029,119.55 558,289.16 5.00 -28.92 1,200.00 34.68 49.50 1,155.79 1,114.09 148.35 173.70 6,029,154.43 558,329.37 5.00 -37.70 1,226.50 36.00 49.50 1,177.41 1,135.71 158.31 185.35 6,029,164.48 558,340.94 5.00 40.23 Start Dir 6.1100' : 1226.5'MD, 1177.41'TVD 1,300.00 39.26 52.30 1,235.62 1,193.92 186.57 220.19 6,029,193.01 558,375.55 5.00 -48.75 1,400.00 43.77 55.53 1,310.48 1,268.78 225.52 273.77 6,029,232.37 558,428.82 5.00 -64.76 1,456.82 46.38 57.13 1,350.61 1,308.91 247.81 307.26 6,029,254.92 558,462.13 5.00 -76.08 End Dir :1456.87 MD, 1350.6' TVD 1,500.00 46.38 57.13 1,380.40 1,338.70 264.78 333.51 6,029,272.09 558,488.25 0.00 -85.29 1,600.00 46.38 57.13 1,449.38 1,407.68 304.07 394.31 6,029,311.85 558,548.74 0.00 -106.61 1,700.00 46.38 57.13 1,518.37 1,476.67 343.35 455.12 6,029,351.61 558,609.22 0.00 -127.94 1,800.00 46.38 57.13 1,587.36 1,545.66 382.64 515.92 6,029,391.37 558,669.71 0.00 -149.26 1,900.00 46.38 57.13 1,656.35 1,614.65 421.93 576.72 6,029,431.12 558,730.20 0.00 -170.59 1,922.25 46.38 57.13 1,671.70 1,630.00 430.67 590.25 6,029,439.97 558,743.66 0.00 -175.33 BPRF 2,000.00 46.38 57.13 1,725.34 1,683.64 461.22 637.53 6,029,470.88 558,790.69 0.00 -191.91 2,100.00 46.38 57.13 1,794.33 1,752.63 500.50 698.33 6,029,510.64 558,851.18 0.00 -213.23 2,200.00 46.38 57.13 1,863.32 1,821.62 539.79 759.13 6,029,550.40 558,911.67 0.00 -234.56 2,300.00 46.38 57.13 1,932.31 1,890.61 579.08 819.94 6,029,590.16 558,972.15 0.00 -255.88 2,400.00 46.38 57.13 2,001.30 1,959.60 618.37 880.74 6,029,629.92 559,032.64 0.00 -277.21 2,500.00 46.38 57.13 2,070.29 2,028.59 657.65 941.54 6,029,669.67 559,093.13 0.00 -298.53 2,600.00 46.38 57.13 2,139.27 2,097.57 696.94 1,002.34 6,029,709.43 559,153.62 0.00 -019.86 2,700.00 46.38 57.13 2,208.26 2,166.56 736.23 1,063.15 6,029,749.19 559,214.11 0.00 -341.18 2,800.00 46.38 57.13 2,277.25 2,235.55 775.52 1,123.95 6,029,788.95 559,274.59 0.00 -362.50 2,900.00 46.38 57.13 2,346.24 2,304.54 814.80 1,184.75 6,029,828.71 559,335.08 0.00 -383.83 3,000.00 46.38 57.13 2,415.23 2,373.53 854.09 1,245.56 6,029,868.46 559,395.57 0.00 405.15 3,100.00 46.38 57.13 2,484.22 2,442.52 893.38 1,306.36 6,029,908.22 559,456.06 0.00 -026.48 3,200.00 46.38 57.13 2,553.21 2,511.51 932.67 1,367.16 6,029,947.98 559,516.55 0.00 -447.80 5/52017 6:34:46PM Page 4 COMPASS 5000.1 Build 81 Halliburton H A LL I B U R TO N Standard Proposal Report Database: Sperry EDM - NORTH US +CANADA Local Co-ordinate Reference: Well Plan: MPU C47 Company: Hilcorp Alaska, LLC 971.95 ND Reference: As -Built @ 41.70usft Project: Milne Point 469.12 MD Reference: As -Built @ 41.70usft Site: M Pt C Pad 2,691.19 North Reference: True Well: Plan: MPU C47 559,637.52 Survey Calculation Method: Minimum Curvature Wellbore: MPU C47 57.13 2,760.18 Design: MPU C47 wp06 1,549.57 6,030,067.25 559,698.01 Planned Survey -511.77 3,600.00 46.38 57.13 Measured 2,829.16 Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +E/ -W Northing Easting DLS Vert Section (usft) O (_) (usft) usft (usft) (usft) (usft) (usft) 2,580.60 3,300.00 46.38 57.13 2,622.20 2,580.50 971.95 1,427.97 6,029,987.74 559,577.03 0.00 469.12 3,400.00 46.38 57.13 2,691.19 2,649.49 1,011.24 1,488.77 6,030,027.50 559,637.52 0.00 490.45 3,500.00 46.38 57.13 2,760.18 2,718.48 1,050.53 1,549.57 6,030,067.25 559,698.01 0.00 -511.77 3,600.00 46.38 57.13 2,829.16 2,787.46 1,089.82 1,610.37 6,030,107.01 559,758.50 0.00 -533.10 3,700.00 46.38 57.13 2,898.15 2,856.45 1,129.10 1,671.18 6,030,146.77 559,818.99 0.00 -554.42 3,800.00 46.38 57.13 2,967.14 2,925.44 1,168.39 1,731.98 6,030,186.53 559,879.47 0.00 -575.75 3,900.00 46.38 57.13 3,036.13 2,994.43 1,207.68 1,792.78 6,030,226.29 559,939.96 0.00 -597.07 4,000.00 46.38 57.13 3,105.12 3,063.42 1,246.97 1,853.59 6,030,266.05 560,000.45 0.00 -618.39 4,100.00 46.38 57.13 3,174.11 3,132.41 1,286.26 1,914.39 6,030,305.80 560,060.94 0.00 -639.72 4,200.00 46.38 57.13 3,243.10 3,201.40 1,325.54 1,975.19 6,030,345.56 560,121.43 0.00 -661.04 4,300.00 46.38 57.13 3,312.09 3,270.39 1,364.83 2,036.00 6,030,385.32 560,181.91 0.00 -682.37 4,400.00 46.38 57.13 3,381.08 3,339.38 1,404.12 2,096.80 6,030,425.08 560,242.40 0.00 -703.69 4,500.00 46.38 57.13 3,450.07 3,408.37 1,443.41 2,157.60 6,030,464.84 560,302.89 0.00 -725.02 4,600.00 46.38 57.13 3,519.05 3,477.35 1,482.69 2,218.40 6,030,504.59 560,363.38 0.00 -746.34 4,700.00 46.38 57.13 3,588.04 3,546.34 1,521.98 2,279.21 6,030,544.35 560,423.87 0.00 -767.66 4,800.00 46.38 57.13 3,657.03 3,615.33 1,561.27 2,340.01 6,030,584.11 560,484.35 0.00 -788.99 4,900.00 46.38 57.13 3,726.02 3,684.32 1,600.56 2,400.81 6,030,623.87 560,544.84 0.00 -810.31 5,000.00 46.38 57.13 3,795.01 3,753.31 1,639.84 2,461.62 6,030,663.63 560,605.33 0.00 -831.64 5,100.00 46.38 57.13 3,864.00 3,822.30 1,679.13 2,522.42 6,030,703.38 560,665.82 0.00 -852.96 5,200.00 46.38 57.13 3,932.99 3,891.29 1,718.42 2,583.22 6,030,743.14 560,726.31 0.00 -874.28 5,300.00 46.38 57.13 4,001.98 3,960.28 1,757.71 2,644.03 6,030,782.90 560,786.79 0.00 -895.61 5,400.00 46.38 57.13 4,070.97 4,029.27 1,796.99 2,704.83 6,030,822.66 560,847.28 0.00 -916.93 5,500.00 46.38 57.13 4,139.96 4,098.26 1,836.28 2,765.63 6,030,862.42 560,907.77 0.00 -938.26 5,600.00 46.38 57.13 4,208.94 4,167.24 1,875.57 2,826.43 6,030,902.18 560,968.26 0.00 -959.58 5,700.00 46.38 57.13 4,277.93 4,236.23 1,914.86 2,887.24 6,030,941.93 561,028.75 0.00 -980.91 5,800.00 46.38 57.13 4,346.92 4,305.22 1,954.14 2,948.04 6,030,981.69 561,089.23 0.00 -1,002.23 5,900.00 46.38 57.13 4,415.91 4,374.21 1,993.43 3,008.84 6,031,021.45 561,149.72 0.00 -1,023.55 5,937.38 46.38 57.13 4,441.70 4,400.00 2,008.12 3,031.57 6,031,036.31 561,172.33 0.00 -1,031.53 SBOA 6,000.00 46.38 57.13 4,484.90 4,443.20 2,032.72 3,069.65 6,031,061.21 561,210.21 0.00 -1,044.88 6,100.00 46.38 57.13 4,553.89 4,512.19 2,072.01 3,130.45 6,031,100.97 561,270.70 0.00 -1,066.20 6,200.00 46.38 57.13 4,622.88 4,581.18 2,111.30 3,191.25 6,031,140.72 561,331.19 0.00 -1,087.53 6,300.00 46.38 57.13 4,691.87 4,650.17 2,150.58 3,252.05 6,031,180.48 561,391.67 0.00 -1,108.85 6,400.00 46.38 57.13 4,760.86 4,719.16 2,189.87 3,312.B6 6,031,220.24 561,452.16 0.00 -1,130.17 6,500.00 46.38 57.13 4,829.85 4,788.15 2,229.16 3,373.66 6,031,260.00 561,512.65 0.00 -1,151.50 6,600.00 46.38 57.13 4,898.83 4,857.13 2,268.45 3,434.46 6,031,299.76 561,573.14 0.00 -1,172.82 9 518" X 121/4" 6,700.00 46.38 57.13 4,967.82 4,926.12 2,307.73 3,495.27 6,031,339.51 561,633.63 0.00 -1,194.15 6,800.00 46.38 57.13 5,036.81 4,995.11 2,347.02 3,556.07 6,031,379.27 561,694.11 0.00 -1,215.47 6,900.00 46.38 57.13 5,105.80 5,064.10 2,386.31 3,616.87 6,031,419.03 561,754.60 0.00 -1,236.80 7,000.00 46.38 57.13 5,174.79 5,133.09 2,425.60 3,677.68 6,031,458.79 561,815.09 0.00 -1,258.12 7,100.00 46.38 57.13 5,243.78 5,202.08 2,464.88 3,738.48 6,031,498.55 561,875.58 0.00 -1,279.44 7,200.00 46.38 57.13 5,312.77 5,271.07 2,504.17 3,799.28 6,031,538.31 561,936.07 0.00 -1,300.77 7,300.00 46.38 57.13 5,381.76 5,340.06 2,543.46 3,860.08 6,031,578.06 561,996.55 0.00 -1,322.09 7,400.00 46.38 57.13 5,450.75 5,409.05 2,582.75 3,920.89 6,031,617.82 562,057.04 0.00 -1,343.42 5/52017 6:34:46PM Page 5 COMPASS 5000.1 Build 81 HALLIBURTON Halliburton Standard Proposal Report Database: Company: Project: Site: Well: Waltham: Design: Sperry EDM - NORTH US Hilcurp Alaska, LLC Milne Point M Pt C Pad Plan: MPU C-47 MPU C-47 MPU C-47 wp06 +CANADA Local Coordinate Reference: Well Plan: MPU C-47 TVD Reference: As -Built @ 41.70usft MD Reference: As -Built @ 41.70usft North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NIS +F/ -W Northing Easting DIS Vert Section (usft) (•) (•) (usft) usft (usft) (usft) (usft) (usft) 5,478.04 7,500.00 46.38 57.13 5,519.74 5,478.04 2,622.03 3,981.69 6,031,657.58 562,117.53 0.00 -1,364.74 7,600.00 46.38 57.13 5,588.72 5,547.02 2,661.32 4,042.49 6,031,697.34 562,178.02 0.00 -1,38607 7,700.00 46.38 57.13 5,657.71 5,616.01 2,700.61 4,103.30 6,031,737.10 562,238.51 0.00 -1,407.39 7,800.00 46.38 57.13 5,726.70 5,685.00 2,739.90 4,164.10 6,031,776.85 562,299.00 0.00 -1,428.71 7,900.00 46.38 57.13 5,795.69 5,753.99 2,779.18 4,224.90 6,031,816.61 562,359.48 0.00 -1,450.04 8,000.00 46.38 57.13 5,864.68 5,822.98 2,818.47 4,285.71 6,031,856.37 562,419.97 0.00 -1,471.36 8,100.00 46.38 57.13 5,933.67 5,891.97 2,857.76 4,346.51 6,031,896.13 562,480.46 0.00 -1,492.69 8,200.00 46.38 57.13 6,002.66 5,960.96 2,897.05 4407.31 6,031,935.89 562,540.95 0.00 -1,514.01 8,300.00 46.38 57.13 6,071.65 6,029.95 2,936.33 4,468.11 6,031,975.64 562,601.44 0.00 -1,535.33 8,400.00 46.38 57.13 6,140.64 6,098.94 2,975.62 4,528.92 6,032,015.40 562,661.92 0.00 -1,556.66 8,465.27 46.38 57.13 6,185.67 6,143.97 3,001.27 4,568.60 6,032,041.35 562,701.40 0.00 -1,570.56 Start Dir 6°1100' : 9465.27' MD, 6185.66'IVD 8,500.00 45.95 54.30 6,209.72 6,168.02 3,015.37 4,589.30 6,032,055.62 562,721.99 6.00 -1,577.36 8,600.00 45.13 45.97 6,279.83 6,238.13 3,061.01 4,644.01 6,032,101.68 562,776.34 6.00 -1,589.94 8,700.00 44.92 37.49 6,350.57 6,308.87 3,113.70 4,691.02 6,032,154.73 562,822.93 6.00 -1,592.09 8,758.15 45.09 32.56 6,391.70 6,350.00 3,147.35 4,714.61 6,032,188.56 562,846.25 6.00 -1;588.52 CM1 8,800.00 45.34 29.04 6,421.19 6,379.49 3,172.85 4,729.81 6,032,214.18 562,861.25 6.00 -1,583.77 8,900.00 46.37 20.80 6,490.90 6,449.20 3,237.84 4,759.96 6,032,279.39 562,890.88 6.00 -1,565.10 9,000.00 47.97 12.91 6,558.94 6,517.24 3,307.93 4,781.13 6,032,349.64 562,911.50 6.00 -1,536.26 9,049.40 48.95 9.18 6,591.70 6,550.00 3,344.21 4,788.20 6,032,385.97 562,918.29 6.00 -1,518.36 THRZ 9,051.76 49.00 9.00 6,593.25 6,551.55 3,345.97 4,788.48 6,032,387.73 562,918.56 5.99 -1,517.44 End Dir :9061.76' MD, 6593.25' TVD 9,100.00 49.00 9.00 6,624.90 6,583.20 3,381.93 4,794.18 6,032,423.73 562,923.97 0.00 -1,498.69 9,200.00 49.00 9.00 6,690.51 6,648.81 3,456.47 4,805.98 6,032,498.36 562,935.19 0.00 -1,459.82 9,212.19 49.00 9.00 6,698.50 6,656.80 3,465.56 4,807.42 6,032,507.45 562,936.56 0.00 -1,455.08 Start Dir 6.1°1100' : 9212.19' MD, 6698.5'rVD 9,300.00 51.03 2.53 6,754.96 6,713.26 3,532.43 4,814.11 6,032,574.37 562,942.73 6.10 -1,417.22 9,400.00 53.74 355.63 6,816.04 6,774.34 3,611.54 4,812.75 6,032,653.46 562,940.75 6.10 -1,365.33 9,444.08 55.06 352.75 6,841.70 6,800.00 3,647.20 4,809.12 6,032,689.08 562,936.84 6.10 -1,339.63 TKLGM 9,500.00 56.83 349.22 6,873.02 6,831.32 3,692.94 4,801.85 6,032,734.76 562,929.21 6.10 -1,304.65 9,600.00 60.22 343.27 6,925.26 6,883.56 3,775.69 4,781.51 6,032,817.34 562,908.23 6.10 -1,235.89 9,700.00 63.85 337.73 6,972.18 6,930.48 3,858.86 4,751.98 6,032,900.27 562,878.06 6.10 -1,159.80 9,721.93 64.68 336.56 6,981.70 6,940.00 3,877.06 4,744.31 6,032,918.42 562,870.24 6.10 -1,142.22 TKUD 9,800.00 67.69 332.53 7,013.23 6,971.53 3,941.51 4,713.60 6,032,982.62 562,839.03 6.10 -1,077.27 9,900.00 71.68 327.61 7,047.96 7,006.26 4,022.71 4,666.79 6,033,063.44 562,791.58 6.10 -989.22 10,000.00 75.80 322.92 7,075.96 7,034.26 4,101.54 4,612.08 6,033,141.82 562,736.27 6.10 -896.64 10,100.00 80.00 318.39 7,096.94 7,055.24 4,177.09 4,550.09 6,033,216.89 562,673.70 6.10 -800.59 10,199.94 84.26 313.99 7,110.63 7,068.93 4,248.49 4,481.58 6,033,287.73 562,604.64 6.10 -702.22 End Dir : 10199.94' MD, 7110.63' TVD 10,200.00 84.26 313.99 7,110.63 7,068.93 4,248.53 4,481.54 6,033,287.77 562,604.59 0.00 -702.16 Begin GooSteering-7" X8112" 5/52017 6:34:46PM Page 6 COMPASS 5000.1 Build 81 HALLIBURTON Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 10,210.67 TKUC 10,219.07 10,231.46 10,300.00 10,308.04 10,400.00 10,500.00 10,559.59 10,581.01 10,600.00 10,700.00 10,731.01 10,762.68 10,800.00 10,900.00 11,000.00 11,031.21 11,075.02 11,100.00 11,200.00 11,231.22 11,283.49 11,300.00 11,400.00 11,500.00 11,531.34 11,580.67 11,600.00 11,700.00 11,800.00 11,809.33 11,900.00 11,957.69 12,000.00 12,100.00 12,200.00 12,232.69 12,300.00 12,371.88 12,376.08 12,400.00 12,500.00 12,528.07 12,600.00 Halliburton Standard Proposal Report Sperry EDM - NORTH US +CANADA 313.99 Local Co-ordinate Reference: Well Plan: MPU C47 Hilcorp Alaska, LLC 4,467.88 6,033,300.85 TVD Reference: As -Built @ 41.70usft Milne Point 85.00 314.00 MD Reference: As -Built @ 41.70usft M Pt C Pad 4,459.01 6,033,309.34 North Reference: True Plan: MPU C47 87.69 313.47 Survey Calculation Method: Minimum Curvature MPU C47 4,409.59 6,033,356.23 562,532.12 4.00 MPU C-47 wp06 88.01 313.41 7,118.37 7,076.67 4,323.08 4,403.76 6,033,361.71 562,526.24 4.00 -594.65 Vertical 313.41 Map Map Inclination Azimuth Depth TVDss +NIS +EI -W Northing listing (1) (1) (usft) usft .(usft) (usft) (usft) (usft) 84.26 313,99 7,111.70 7,070.00 4,255.90 4,473.90 6,033,295.09 562,596.90 53.2017 6:34:46PM DLS Vert Section 7,070.00 0.00 -691.56 84.26 313.99 7,112.54 7,070.84 4,261.71 4,467.88 6,033,300.85 562,590.84 0.00 683.22 85.00 314.00 7,113.70 7,072.00 4,270.27 4,459.01 6,033,309.34 562,581.90 6.00 670.92 87.69 313.47 7,118.07 7,076.37 4,317.56 4,409.59 6,033,356.23 562,532.12 4.00 602.67 88.01 313.41 7,118.37 7,076.67 4,323.08 4,403.76 6,033,361.71 562,526.24 4.00 -594.65 88.01 313.41 7,121.57 7,079.87 4,386.24 4,337.00 6,033,424.34 562,458.99 0.00 -502.91 88.01 313.41 7,125.05 7,083.35 4,454.92 4,264.40 6,033,492.45 562,385.87 0.00 403.15 88.01 313.41 7,127.12 7,085.42 4,495.85 4,221.13 6,033,533.03 562,342.29 0.00 -343.70 88.50 313.00 7,127.77 7,086.07 4,510.51 4,205.53 6,033,547.57 562,326.57 3.00 -322.32 88.50 313.00 7,128.27 7,086.57 4,523.45 4,191.65 6,033,560.40 562,312.59 0.00 -303.37 88.50 313.00 7,130.89 7,089.19 4,591.63 4,118.54 6,033,628.00 562,238.96 0.00 -203,54 88.50 313.00 7,131.70 7,090.00 4,612.77 4,095.86 6,033,648.96 562,216.12 0.00 -172.58 87.87 313.00 7,132.70 7,091.00 4,634.36 4,072.71 6,033,670.36 562,192.81 2.00 -140.97 87.87 313.00 7,134.09 7,092.39 4,659.80 4,045.44 6,033,695.58 562,165.34 0.00 -103.73 87.87 313.00 7,137.82 7,096.12 4,727.95 3,972.36 6,033,763.16 562,091.73 0.00 -3.93 87.87 313.00 7,141.54 7,099.84 4,796.10 3,899.27 6,033,830.73 562,018.12 0.00 95.86 87.87 313.00 7,142.70 7,101.00 4,817.38 3,876.46 6,033,851.82 561,995.15 0.00 127.00 89.62 313.00 7,143.66 7,101.96 4,847.24 3,844.44 6,033,881.43 561,962.89 4.00 170.74 89.62 313.00 7,143.83 7,102.13 4,864.28 3,826.16 6,033,898.33 561,944.49 0.00 195.69 89.62 313.00 7,144.49 7,102.79 4,932.48 3,753.03 6,033,965.94 561,870.83 0.00 295.55 89.62 313.00 7,144.70 7,103.00 4,953.77 3,730.19 6,033,987.05 561,847.83 0.00 326.73 91.71 313.00 7,144.09 7,102.39 4,989.41 3,691.97 6,034,022.39 561,809.34 4.00 378.91 91.71 313.00 7,143.60 7,101.90 5,000.66 3,679.90 6,034,033.55 561,797.18 0.00 395.40 91.71 313.00 7,140.62 7,098.92 5,068.83 3,606.80 6,034,101.14 561,723.55 0.00 495.22 91.71 313.00 7,137.63 7,095.93 5,137.00 3,533.70 6,034,168.73 561,649.92 0.00 595.03 91.71 313.00 7,136.70 7,095.00 5,158.37 3,510.79 6,034,189.91 561,626.85 0.00 626.32 94.30 313.00 7,134.11 7,092.41 5,191.96 3,474.76 6,034,223.21 561,590.57 5.26 675.50 94.30 313.00 7,132.66 7,090.96 5,205.11 3,460.66 6,034,236.25 561,576.37 0.00 694.76 94.30 313.00 7,125.16 7,083.46 5,273.12 3,387.73 6,034,303.68 561,502.92 0.00 794.34 94.30 313.00 7,117.65 7,075.95 5,341.12 3,314.81 6,034,371.11 561,429.47 0.00 893.92 94.30 313.00 7,116.95 7,075.25 5,347.47 3,308.00 6,034,377.40 561,422.61 0.00 903.21 89.53 313.00 7,113.92 7,072.22 5,409.25 3,241.75 6,034,438.66 561,355.88 5.26 993.68 86.50 313.00 7,115.91 7,074.21 5,448.57 3,199.58 6,034,477.64 561,313.42 5.26 1,051.25 86.50 313.00 7,118.49 7,076.79 5,477.37 3,168.70 6,034,506.20 561,282.31 0.00 1,093.42 86.50 313.00 7,124.60 7,082.90 5,545.44 3,095.70 6,034,573.69 561,208.79 0.00 1,193.10 86.50 313.00 7,130.70 7,089.00 5,613.52 3,022.70 6,034,641.18 561,135.27 0.00 1,292.78 86.50 313.00 7,132.70 7,091.00 5,635.77 2,998.83 6,034,663.25 561,111.23 0.00 1,325.36 83.13 313.00 7,138.78 7,097.08 5,681.48 2,949.82 6,034,708.57 561,061.86 5.00 1,392.29 79.54 313.00 7,149.60 7,107.90 5,729.93 2,897.86 6,034,756.61 561,009.53 5.00 1,463.24 79.54 313.00 7,150.37 7,108.67 5,732.75 2,894.83 6,034,759.41 561,006.48 0.00 1,467.37 80.74 313.00 7,154.46 7,112.76 5,748.82 2,877.60 6,034,775.34 560,989.13 5.00 1,490.90 85.74 313.00 7,166.24 7,124.54 5,816.53 2,805.00 6,034,842.47 560,916.00 5.00 1,590.04 87.14 313.00 7,167.98 7,126.28 5,835.63 2,784.51 6,034,861.41 560,895.37 5.00 1,618.01 87.14 313.00 7,171.57 7,129.87 5,884.63 2,731.97 6,034,909.99 560,842.45 0.00 Page 7 1,689.76 COMPASS 5000.1 Build 81 Halliburton HA LL I B U R TO N Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: Sperry EDM - NORTH US +CANADA Hilcorp Alaska, LLC Milne Point M Pt C Pad Plan: MPU C-47 MPU C-47 MPU C-47 wp08 Local Co-ordinate Reference: Well Plan: MPU C47 TVD Reference: As -Built @ 41.70usft MD Reference: As -Built @ 41.70usft North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) V) (^) (usft) usft (usft) (usft) (usft) (usft) 7,134.86 12,700.00 87.14 313.00 7,176.56 7,134.86 5,952.74 2,658.92 6,034,977.52 560,768.88 0.00 1,789.50 12,800.00 87.14 313.00 7,181.55 7,139.85 6,020.86 2,585.88 6,035,045.06 560,695.32 0.00 1,889.24 12,803.07 87.14 313.00 7,181.70 7,140.00 6,022.95 2,583.64 6,035,047.13 560,693.06 0.00 1,892.29 12,900.00 82.00 313.00 7,190.87 7,149.17 6,088.74 2,513.09 6,035,112.36 560,622.00 5.31 1,988.63 13,000.00 76.69 313.00 7,209.36 7,167.66 6,155.74 2,441.24 6,035,178.79 560,549.64 5.31 2,086.73 13,009.61 76.18 313.00 7,211.62 7,169.92 6,162.11 2,434.41 6,035,185.10 560,542.76 5.31 2,096.06 13,059.36 76.18 313.00 7,223.50 7,181.80 6,195.05 2,399.08 6,035,217.77 560,507.18 0.00 2,144.30 13,100.00 78.33 313.00 7,232.47 7,190.77 6,222.08 2,370.09 6,035,244.57 560,477.98 5.31 2,183.89 13,200.00 83.64 313.00 7,248.12 7,206.42 6,289.42 2,297.88 6,035,311.33 560,405.25 5.31 2,282.48 13,300.00 88.95 313.00 7,254.58 7,212.88 6,357.45 2,224.92 6,035,378.78 560,331.77 5.31 2,382.10 13,309.04 89.43 313.00 7,254.71 7,213.01 6,363.62 2,218.31 6,035,384.90 560,325.11 5.31 2,391.13 13,400.00 89.43 313.00 7,255.62 7,213.92 6,425.65 2,151.79 6,035,446.40 560,258.12 0.00 2,481.96 13,500.00 89.43 313.00 7,256.61 7,214.91 6,493.84 2,078.66 6,035,514.01 560,184.46 0.00 2,581.82 13,509.04 89.43 313.00 7,256.70 7,215.00 6,500.00 2,072.05 6,035,520.13 560,177.81 0.00 2,590.84 Total Depth : 13509.04' MD, 7256.7' TVD -41/2" % 6 112" 5/5!2017 6:34:46PM Page 8 COMPASS 5000.1 Build 81 H ALL I B U R TO N Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt C Pad Well: Plan: MPU C47 Wellbore: MPU C47 Design: MPU C47 wp06 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU C47 As -Built Q 41.70usft As -Built ® 41.70usft True Minimum Curvature Targets Vertical Vertical Dip Depth Depth Depth SS Target Name (usft) (usft( Name Lithology 8,758.15 -hit/miss target Dip Angle Dip Dir. TVD -NIS +EI -W Northing Easting - Shape (°) (°) (usft) (usft) (usft) (usft) (usft) MPC47 wpO5 CP4 0.00 0.00 7,144.70 4,953.77 3,730.19 6,033,987.05 561,847.83 - plan hits target center TKUC 1,922.25 1,671.70 BPRF Point MPC47 wp06 CP7 0.00 0.00 7,132.70 5,635.77 2,998.83 6,034,663.25 561,111.23 - plan hits target center - Point MPC47 wp05 CPS 0.00 0.00 7,136.70 5,158.37 3,510.79 6,034,189.91 561,626.85 - plan hits target center Paint MPC47 wp05 CPI 0.00 0.00 7,113.70 4,270.27 4,459.01 6,033,309.34 562,581.90 - plan hits target center - Point MPC47wpO6CPll 0.00 0.00 7,256.70 6,500.01 2,072.04 6,035,520.13 560,177.80 - plan misses target center by 0.01 usft at 13509.04usft MD (7256.70 TVD, 6500.00 N, 2072.05 E) - Point MPC47 wp06 CP9 0.00 0.00 7,181.70 6,022.95 2,583.64 6,035,047.13 560,693.06 - plan hits target center - Point Floating Target wp05 0.00 0.00 6,698.50 3,465.55 4,807.42 6,032,507.45 562,936.56 - plan hits target center Point 'MPC47 wpO5 CP3 0.00 0.00 7,142.70 4,817.38 3,876.46 6,033,851.82 561,995.15 - plan hits target center - Point MPC47 wp05 CP2 0.00 0.00 7,131.70 4,612.77 4,095.86 6,033,648.96 562,216.12 - plan hits target center -Point Casing Points — —- --- Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 6,600.00 4,898.83 95/8"X121/4" 9-5/8 12-12 10,200.00 7,110.63 7" X81/2" 7 8-12 13,509.04 7,256.70 412"X612" 4-1/2 6-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft( Name Lithology 8,758.15 6,391.70 CMI 5,937.38 4,441.70 SBOA 9,721.93 6,981.70 TKUD 9,049.40 6,591.70 THRZ 9,444.08 6,841.70 TKLGM 10,210.67 7,111.70 TKUC 1,922.25 1,671.70 BPRF 5/52017 6.34:46PM Page 9 COMPASS 5000.1 Build 81 HALLIBURTON Database: Sperry EDM - NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: MPtC Pad Well: Plan: MPU C47 Wellbore: MPU C-47 Design: MPU C-47 wp06 Plan Annotations Measured Vertical Depth Depth (usft) (usft) 326.50 326.50 626.50 625.27 926.50 914.52 1,226.50 1,177.41 1,456.82 1,350.61 8,465.27 6,185.67 9,051.76 6,593.25 9,212.19 6,698.50 10,199.94 7,110.63 10,200.00 7,110.63 13,509.04 7,256.70 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: MPU C-47 As -Built @ 41.70usft As -Built @ 41.70usft True Minimum Curvature Local Coordinates +NIS +E/ -W lush) (usft) Comment 0.00 0.00 Build Dir 3-/100': 326.5' MD, 326.5'TVD 15.27 17.88 Build Dir 4-/100': 626.5' MD, 625.27'7VD 65.61 76.81 Build Dir 5-/100': 926.5' MD, 914.52'TVD 158.31 185.35 Start Dir 5°/100': 1226.VMD, 1177.4l'TVD 247.81 307.26 End Dir : 1456.82' MD, 1350.6' TVD 3,001.27 4,568.60 Start Dir 6'1100': 8465.27' MD, 6185.66 -TVD 3,345.97 4,788.48 End Dir : 9051.76' MD, 6593.25' TVD 3,465.56 4,807.42 Start Dir 6.1°/100':9212.19' MD, 6698.5'TVD 4,248.49 4,481.58 End Dir : 10199.94' MD, 7110.63' TVD 4,248.53 4,481.54 Begin Geo-Steenng 6,500.01 2,072.05 Total Depth : 13509.04' MD, 7256.7' TVD Halliburton Standard Proposal Report 5/52017 5:34:46PM Page 10 COMPASS 5000.1 Build 81 Hilcorp Alaska, LLC Milne Point M Pt C Pad Plan: MPU C-47 MPU C-47 50029xxxxx00 MPU C-47 vil Sperry Drilling Services Clearance Summary Anticollision Report 05 May, 2017 Closest Approach 30 Proximity Scan on Current Survey Data INoRN Reference) Reference D,hu,r: M PI C Ped - Plan: MPU C47 - MPU Od7 - MPU C47 wp06 Well Coordination: 6,029,004.74 N. 558,156.85 E 170° 29 23.49" N,149.31' 28.53" WI Datum Height: As -Built @ 41.70usft Scan Range: 0.00 to 13,509.04 unk Measured Depth. Scan Ratlius Is 1,54835 mN. Clearance Factor cutoff Is failing". Max Ellipse SepareUon Is Unllmltetl GecdeOc Scale Factor Applied genion: 5000.1 Build 61 Scan Type: GL09AL FILTER APPLIED. All wellpaths within 2/100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services REFERENCE INFCRMATI�i WFLL nEfMS'. lil- ICA] W19P(N411L'tN1IX ) Nede 2me 01 NALLIBURTON Project: Milne Point .. I.IM x.w1.11 wN wo: Mw c,o. T^. xa�u -", s^'^"0h' -.elii cm,w free 1520 "I .Fr -w nx,loo, EwOM uoim I.,u,de,s Site: MPt C Pad eM...lr onm^e Well: Plan: MPU C-07 M 0.1 P.Fnz.: .ail uN OW 0. W29 34 539/56.63 fi°29UdmN 1J9°31'2BSI3W Wellbore: MPU C47 200'HOOn000.r rebrenc. sURJEV PROGRAM GLOBPI FlLTER APPIIED:Nw.LTo Plan : MPU C-07 wP06 1350eein asas M To 1350eW Em Plots D. 201412-13TO3:OO:W V.oil.'. Tes Version: oeau Flom o.M, To li.r�rml.x rool Cnswc nUr S Wddef/S.F. '.50 13ol MW C4]wpCB SRGa8 1]0.00 6800M MPU CA7 xyA M D+lFR2NM5+..0 ryn WEISS MD siu N.m[ 15000 1020.0 MPU C-0]xyC6 MWO'IFR2.MS.sa9 4898.83 4857.13 66W.00 ?5M 9WX121/4' 102000 13503.4 MPU C<]xp[e MNMIFR+W-., '/1]063 ]06893 1020,00 ] ]'X812' 7256 70 72150 /150904 YIR J Vl'%612' 150.00 , --- 0120.00 T 0 MPG39 MPG2&1 NIP In 1 P@L 90,00 � MPC, I MPC 06 m y 6000 � P0.16 U C -0U '1 I � 4000 .. - m PC -41 I y MPC,, U 0.00 7500 0250 9000 9750 10500 11250 12000 12]50 13500 1/250 0 750 1500 2250 3000 3750 4500 5250 6000 8750 Measured Depth (1500 usft/in) .50 4.50- 3.00 a.o0 Collision Risk Procedures R m n .50 1.50- -Collision Avoidance Req. N,,Go Zone - Stop Drilling 0.00 5,100 8000 6600 7200 7800 8400 9000 9600 10200 10800 11400 0 600 1200 1000 2400 3000 3600 4200 4800 Measured Depth Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU C-47 - MPU C-47 wp06 Closed AppmacF 3D PmXlmlty Sean on Current Survey Data (North Reference) Reference Design: MPt C Pad - Plan: MPU C47 -MPU C47 -MPU C47 wPU6 Sun Range: 0.00 to 13,509.04 usR. Measured Depth. Sun Radius Ie 1,54835 peg. Clearance Factor cutoff is Unlimited. Max Ellipse Separadon is Unpinned Measured Minimum @4eaeared Ellipse ®Measured Clearance Summary Baud an Was Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Nam. - Design (usig 1 -ft) (..ft) (usR) Uaff EX MP18-01 MP18-01-MP18-01-MP18-01 MP1s-01-MP1s-01-MP10-01 MP10-01-MP16-01-MP1a01 M Pt C Pad MPC -0I -MPC -0I -MPC -01 1,330.35 299.43 1,330.35 277.17 1,230.38 13.450 Centre Distance Pass- WC-0I-MPC-0I-MPC01 1,3sDOD 299,70 1,350.00 2812 1,253.38 13.227 Ellipse Separation Pass - mnC l-MPC-0I-MPO01 1,40DOD 303.90 1,400.00 260.31 1,29D.55 12.804 Cbararce Factor Pass - MPC -02- MPC -02- MPC -02 2,100.00 232.71 21100.00 206.53 2,130.14 8.687 Ellipse Separation Pau- MPC-02-MPC-02-MPCO2 2,130.37 232.43 2,130.37 206.73 2,158.37 9.043 Centre Dean. Pass- MPC-02-MPD-02-MPCO2 4,475.00 921.37 4,47500 707.06 4,403.66 4299 Clearance Factor Pass- MPC -04 -MPC -04 -MPC 1,015.6D 629.66 1,015.60 61644 933,77 47.660 Centre Nannies Pass - MPC -04 -MPC -o4 -MPC -04 1,125.00 631.16 1,125.00 615.46 1,014.68 40.216 Ellipse Separation Pass - MPC -04 -MPC -04 -MPC -04 12,45DOD 1370.57 12,450.00 95226 9.40D.00 3.276 Clearance Factor Pass - MPC-05-MPG05-MPC-05 303.14 179.20 363.14 174.79 374,78 39.932 Cenbs Dolan. Penn - MPC -05 -MPC -05 -MPC -05 475.OD 180.10 475.00 174.30 488.66 31.065 Ellipse Separation Pass - MPC -GS -MPC-05-MPC05 925.00 225.95 92500 214.48 928.02 19.710 Class. Factor Pass- MPC -05 -MPC -05A -MPO -05A 363.14 179.20 363.14 174.79 374,78 39.932 Centre D6tance PasS- MPC-QS -MPC-0SA-MPC-05A 475.00 180.10 47500 174.30 408.66 31065 Ellipse Separation Pass - MPC -05 -MPC -05A -MPC -OSA 92500 225.95 925.00 214.48 920.D2 19.710 Cleamme Factor Pass - MPC -06 -MPC -06 -MPC -Ge 354.21 56.00 354.21 54.39 354.05 13.315 Cents Distance Pass - MPC -0e -MPC -0e -MPC -0S 425.OD 59.29 425.00 54.05 43570 11.297 Ellipse Separation Pass - MPC46-MPC-06-MPC-06 65o0D 71.64 650.00 63,70 659.50 9,020 Class. Facbr Pass- MPC -08 -MPC -08 -MPC -0O 585.81 55.88 505.81 4889 594.43 ]997 Centre Dieasnu Pass- MPC-06-MPOOB-MPCU8 600AD 55.94 600.00 4878 60823 7.815 Ellipse Separation Pass - MPC -09 -MPC -0O -MPC -0O 675.00 59.06 675.00 50.93 600.40 7.265 Ckarance Factor Pass - MPC -IO -MPC -I0 -MPC -1D 896.27 159.20 896.27 147.51 897,68 13.613 Centre Distance Pass - MPO -to -MPC -10 -MPC -10 925.00 159.50 92500 147.30 92477 13074 Ellipse Separation Pass - 05 May, 2017 - 18,39 Page 2 o17 COMPASS HALLIBURTON Hilcorp Alaska, LLC Milne Point Anticollision Report for Plan: MPU C-47 - MPU C-47 wp06 Closest Approach 3D Proximity Scan on Durant Survey Data (North Reference) Reference Desiam M Pt C Pad - Plan: MPU C47 -MPV Cdr -MPU C47 sauce Scan Range: 0.00 to 13,509.04 ueR. Measured Depth. Scan Radius is 1,549.25usR. Clearanw Factor cuMRis Unlimited. Max Ellipse Separation Is Unlimaed Measured Minimum @Measured Ellipse @Meaaured Clearance Summer, Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (..it) (..it) (Usti) (Usti) -it MPC-Ia-MPGIO-MPG10 1,075.00 174.20 1,075.00 15929 1,081.87 11.632 Clearance Factor Pass - MPC -II -MPC -II -MPC -11 1'309.08 19860 1,309.08 175.50 1,255.49 9.016 Centra Dktarce Pass - MPC -II -MPC -II -MPC -11 1.325.00 190.90 1,32500 176.55 1.26820 8.898 Ellipse Separation Pass - Mil -MPC -II -MPC -11 1,375.00 203.70 1.375.00 10060 1,307.50 8.788 Clearance Factor Pass - MPC -I2 -MPC -I2 -MPO -12 1,350.00 271.39 1,350.00 255.79 1,412.96 17.404 Clearance Factor Pass- MPC-I2-MPPI2-MPC-12 1,355.01 27197 1,355.01 255.78 1.417,67 17.406 Ellipse Separation Pass- MPC-I2-MFC-I2A-MPC-12A 1,350.07 271.39 1.35000 255.79 1,41296 17.404 Ckamnce Factor Pass - ail 2-MPC-I2A-MPC-12A 1,555.01 271.37 1.35501 255]8 1.417.67 17.406 Ellipse Separation Pasa- MPC-I2-MPC-I2APB1-MPC-I2APB1 1,35000 271.39 1.350.00 25539 1,412.96 17.404 Clearance Factor Pasa- MPG-I2-MPC-12 Pal -MPGI2APB1 1,355.01 271.37 1.355.01 25536 1.417.67 17.406 Ellipse Separation Pau - MPC -I3 -MPC -I3 -MPC -13 1,244.32 9687 1,244.32 6873 1,202.06 4.315 Centre Distance Pass - MPC -I3 -MFG -I3 -MPC -13 1,25000 8893 1.250.00 6662 1.206.60 4.200 Ellipse Separation Pass - hil3-MPC-I3-MPC-13 1,27500 8903 1,275.00 68.09 1,22841 4251 Clea2nce Factor Pass- MPC -I4 -MPC -I4 -MPC -14 11158.12 24.51 1.1511.12 7.50 1,115.10 1.441 Clearance Factor Pass - MPC -I5 -MPC -I5 -MPC -15 1062.47 134.50 1.062.47 119.64 1.049.21 9055 Centre Distance Pass - MPC-IS-MPC-I5-MPG15 1075.00 104.fi3 1.075.00 119.50 1.060.23 6.899 Ellipse Separation Pace - MPC-I5-MPC-I5-MPG15 1,150.00 141.54 1,15000 124.80 1,124.74 8459 Clearance Factor Pass- MPC-I5-MPG15A-MPC-15A 1,06247 134.50 1.062.47 119.64 1,047.55 9,055 Centre Distance Pass - MPG1S-MPC-I5A-MPG15A 1,075.00 134.63 1.075.00 119.50 1,058.57 8,899 Ellipse Separation Pass - MPC-I5-MPG15A-MPC-15A 1.150.00 141.54 1.15000 12480 1,12308 8.459 Cleamnce Factor Pass- MPC -I6 -MPC -I6 -Ml 699.50 261.75 699.50 252.79 691.36 29.208 Centre Distance Pass - MPC -I6 -MPC -I6 -Ml n5.00 261.87 725.00 252.57 713.29 28.166 Ellipse Separation Pass - MPC-I6-MPG16-Al 1.300.00 385.13 1,300.00 36480 1,168.76 18,945 Clearance Factor Pass - MPCBO-MPG20-Ml 1,23930 28.64 123970 8.96 1,191.39 1455 Cleamnce Factor Pass - MPC -25 -Plan MPC-25B-MPG25B wpO2 26289 439.53 26289 43]33 27133 200.014 Centra Distance Pass - MPC -25 -Plan MPC-25B-MPG25B wp02 025.00 44o.oe 825.00 43367 787.62 68.629 Ellipse Separation Pass- MPG25-Plan MPO-258-MPG25B wp02 13.509.04 1,429.70 13,509.04 1'102.08 13,037.8 5374 Clearance Factor Pass- MPC-26-MPC-28-MPG28 73939 114.77 73939 106.94 739.34 14.659 Centre Distance Pass - MPC -26 -MPC -25 -MPC -28 775.00 115.09 775.00 106.03 773.26 13.921 Ellipse Separation Pass - MPC -28 -MPC -28 -MPC -28 925.00 127,82 925.00 117.54 913.28 12436 Clearance Factor Pass - MPC -26 -MPC -20A -MPC -28A 738.79 11437 739.79 107.05 74302 14.866 Centre Distance Pass - 05 May, 2017 - 18:39 Page 3of7 COMPASS HALLIBURTON Hili orp Alaska, LLC Milne Point Anticollision Report for Plan: MPU C-47 - MPU C-47 wp06 Closest Approach 30 PmxImlty Scan on Current Survey Data (North Reference Reference Design: M Pt C Pad -Plan: MPU C47 - MPU C47 -MPU C47 -196 Sun Range: 069 to 13,509.04 usft. MeaeureE Depth. Scan Radius is 1,516.25 usft. Closter- Factor cutoff N Unlir led. Max Ellipse Separation is Unlimitetl Site Name Measured Depth Minimum @Measured Distance Depth Ellipse Separation sliklearattered Depth Clearance Summary Based on Factor Minimum Separation Warning ComWnse. Well Name - Wellbore Nam. - Deal,n (usft) (usft) (usft) (usft) usft MPC-20-MPG20A-MPG2BA MPC -28 -MPC -28A -MPC -20A MPC36-MPG36-MPG36 MPC-W-MPG36-MPG36 MPC36-MPC-35-MPG36 775.00 925.00 100.00 200.00 1150.00 11509 127.02 240.24 240.52 342.07 775al) 925.00 100.00 200.00 1,150.00 106.93 117.65 239.06 23867 331.20 776.94 916.96 95.20 19376 1,03135 14.100 Ellipse Separation 12.570 Clearance Factor 204094 Centre Distance 130.014 Ellipse Separation 31.478 Caamnce Fehr Pass - Pass - Pass- pass - Pass- Mn39-MPC-39-MPCa9 MPC39-MPC-39-MPG39 MPC39-MPG39-MPG39 MPC40-MPG40-MPC40 MPC40-MPG40-MPC-40 MPG40- MPC40- MPC -4O 79129 8W.00 875.00 46287 47500 525.00 76.10 76.14 80.41 25.37 25.42 28.94 791.29 80000 87500 462.87 475.01 525.00 69.85 6981 73.34 21.20 21.24 22.41 79233 000.85 87197 467.48 479.50 528.85 12.18 Centre Distance 12.026 EMicen Separation 11364 Clearance Factor 6.205 Centre Distance 6.088 Ellipse Separation 5.943 Clearance Factor Pass - Free - Pass- Pass - Pass - Pass- MPC41-MPC4I-MPG41 MPC41-MPC4I-MPC41 MPC41-MPC4I-MPC41 MPC41-MPC41 L1-MPC41L1 MPC41-MPG41 L1-MPC41 L1 MPC41-MPC41 LI-MPC41 L1 26.50 75.00 425.00 26.50 75.W 425.00 29.65 2974 30.49 29.65 29.74 38.49 26.50 75.00 42501 26.50 75.00 42500 28.57 28.49 3529 28.57 28.49 35.39 29.7 78.37 426.67 29.97 78.37 426.67 27.455 Centre Distar-e 23826 Ellipse Separation 12.024 Clearance Factor 27.455 Centre Distance 23.026 Ellipse Separellon 12,429 Clearance Factor Pass- Pass - Pass- Pass - Pass- PasS- MPC41-di L2-MPC41 L2 MPC41-MPC41 L2-MPC41L2 MPC41-MPC41 L2 -MPC -41 L2 MPC41-MPC4I PSI -MPC41PB1 MPC41-MPC41 Pal -MPC41 Pal MPC41 - MPC41 Pal -MPC41 Pal 26.50 7500 425.00 26.0 75.00 400.00 2965 29.74 38.49 29.65 29,74 3548 26.50 75.01 425.UD 25.50 75.00 40000 20.57 2049 35.39 28.57 28.49 33.20 29.97 7837 42867 29.87 75.37 402.07 27.455 Centre Distance 23,826 Ellipse Separation 12.429 Cannelton Factor 27.455 Centre Distance 23.826 Ellipse Separation 11,096 Clearance Factor Pass- Pass - Plea - Pass - Pass - Pass- MPC41-MPG41 PB2 -MPC41 PB2 MPCdt-MPC41 P82-MPC41 P132 MPC41-MPC41 PB2 -MPC41 PB2 Plan: MPC SKupamklSag- KupaNklSag River - MP Plan: MPC35 KupamWSag- Kupanrk/Sag River - MP Plan: MPC -35 Kupamk5ag- KWaruk599 River -MP 26.50 7500 425.W 94111 975.00 1,250.00 29.65 29.74 38.49 248.24 248.58 290.86 20.50 7500 425.00 941.11 975.00 1,25000 28.57 2849 3529 239.67 239.52 277.17 29.97 7837 426.67 936.43 967.71 1,20460 9.455 Centre Distance 23.826 EIIip5e6eparetion 12➢24 Clearance Factor 20.964 Centre Distance 27.424 Ellipse Separation 21.2M Clearance Fodor Pasa- Pass - Paes- Pass - pose - Pass- Plan : MPU C45 -MPU C45(Hey You) - MPU C45w 1,15960 90.65 1,1556D 77.78 1,13]6 7.048 Caamnce Factor Pass - a5 May, 2017 - 18:39 Page 4017 COMPASS HALLIBURTON Anticollision Report for Plan: MPU C-47 - MPU C-47 wp06 Hilcorp Alaska, LLC Milne Point Closest Approach 3D Proximity Sean on Current Survey Data (North Reference) Reference Design: M Pt C Pad - Plan: MPU C47 -MPU C47 -MPU C47 ends Scan Ranga: 0.00 1013,509.00 uak. Measured Depth. Scan Radius to 1,Ws.25 usa. Clearance Fee., cutoff Is Unlimited Max Ellipse Saparatlon Is Unlimited Measured Minimum gw...ured Ellipse @Mmsured Chrome. Summary Based on f Site Name Depth Dlatance Depth SeparatiSeparation Warning Depth Pa., Minimum g Comparison Well Name - Wellbore Name - Deals. (Usln (eft) (usfu (..ft) usf Pian: MPU C46 -MPU C46 -MPU C46 ep05 87369 192.62 673.69 18366 06/66 21052 Centre Distance Pass - Plan. MPU C46 -MPU C46 -MPU C48 w,05 90000 193.02 900.00 18349 68849 20.263 Ellipse Separation Pass - Plan: MPU C46 -MPU C46 -MPU C46 erOS 1,150.00 226.00 1,150.00 212.37 1,113.86 16.578 Clearance Factor Pass - SYN6V to0)Orogram From To Sum,/Plan Survey Tool (uek) (u50) 26.50 1,30000 MPUC47%oW SRG 5 1,30000 6,60060 MPU C47 ep06 MW)+IFR2+MS+sag 6,6woo 10,200.00 MPU C47 ep06 MWD+IFR2+M6+sag 10.20000 13,509.09 MPU G47 W06 MWD+IFR2+MS+sag Ellipse error terms are cerrehated across survey foal lien points. Calculated ellipses McaPorale surface armor. Separation is me actual distance between ellips0ids- DisMnce Bameen .noes is the straight line cudan. between w Ifthore.nims. Clearance Facto= Dishan. Saloom, PraMas I (Distance Between Profiles - Ellipse Separation). All sM6on coordinates were rakulated using the Minimum Curvature method. OS May, 2017 - 16:39 Page 5017 COMPASS Hilcorp Alaska, LLC HALLIBURTON Milne Point Anticollision Report for Plan: MPU C-47 - MPU C-47 wp06 Direcfion and Coon inates are rektive to Toe Nardi Reference. Vertical Depths are relative to As-Built@41]OUS11, Northing and Easting are relative to Plan: MPU C-47. Coordinate System Is US State Plane 1927 (Exact solution), Alaska Zone 04. Central Medtlien Is -15gW Gritl Convegen¢ a15Utfara is: 0.45'. 0.5 May, 2017 - 18:39 Pape 6 f7 Ladder Plot IAPC41,MPC-411.2,MPC4112W MPC 1,MPG41PB1,MPC41 PB1W — MPC4I,MPC 1,MPC41W I�HS� .1l fl MPG0I,MPC0I,101"C01V1 C MPCI0, MPG' 0, MPC10V1 '350-- WP 14,MPC14,10KA4V1 MPC-M,MPC 9,MP&39V3 O MPGI2,MP012,MPG12W a MPCI2,MPC-12A,MPGI2AW C MPG12, hfo 1l APB1, MPGlMPB1W 0 PGO6,M6,MPGO6V1 MPGO @ goo- MPPI3,MPC-13,MPC13V4 �- I 025,P1an MPC-25B,MPC25Bvg02V13 P V) MPCO8,MP"alAPfA8V1 N MPc-15'WG15,MPC15V1 G IAPGIS,MPGiSA,MPCISAW 0) U Pbn:MPC35Ktpaok6ag, KUlsarUYSag FAer,MPG35 1 O MPG05,NPC05,MPG05V1 N MPC05,MPC05A,MPCO5AVI VI C U MPG04,MPC04,MPG MPC26,MPG28,MPC28V1 MP G28, MPG28A, MPP28A V6 0 I MPG16,MPC16,MPP16V1 0 2500 5000 7500 10000 12500 Plan:MPUC-45,MPUC45(1-IayVou),MPUC45.pO6W Measured Depth (2500usfUn) MPC ,MPC40,10PC GV19 Plan IJIFUC-4fi MP MPU"" 0.5 May, 2017 - 18:39 Pape 6 f7 I�HS� .1l fl � LOMPA55 HALLIBURTON Anticollision Report for Plan: MPU C-47 - MPU C-47 wp06 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor Hilcorp Alaska, LLC Milne Point ' VB2,MPG41PB2V2 'G41L2, MPC41l2 VO ' 1PB1,MPG41P81V0 'G41,MPC41V0 1G01,MPG01 V1 PG10,MPG1oV1 PC-UV1 PG39,MPG39V3 PG12,MPG12V9 PG12A,MPC-IMV3 PC-1MPBI.WC-IMPB1 V6 PGo6,MPGo6V1 PC -13 MPC -13V4 pan MPG25B,MPC2 Bvp02V13 PGo8,MPC-08VI PG15,MPG15V7 PG15A,MPG15AVo C35 Kuparuk6ag,Kupauk6ag R w MPG35 1V PC-05,MPGo5V1 PG05A,MP"5AV1 PG04,MPC-04V1 PG28,MPG26V1 PG28A,hPG28AV6 PG16,MPG16V1 G45,MPUC45(HeyVou),MPUG45v 06V0 MPC40,MPG4oV19 MwuredDepy1f50DmV1) Plen'MPUG46,MPUG46,MPUC svpo5V0 05 M Y' W17 - 18:39 Page Tal r COMPASS I ... MPC4I,MF MPG4I.MF MPC41,M1 n MPGo1,Ml IS - - ' MPG10,M ',.,. MPC -14,M MPC -39,M 50 MPC -12,M MPG12,M MPG12.M 25 MPC06,M 1 MPG13,M 1 { MPG25,P 00 _.. _.I � I 11 r _- MPG08,M MPG15,M 75 1 WC -15,M PlanAW MPC05,M MPC05,M W ision Avoe nce Req MPC -04,M N Go Zone -Slop Dillln MPC -28,M 25 MPG28,M MPG16,M Plan:MPU 00 .em ocm vcn wn me 7500 8750 10000 11250 1]me 13750 15000 MPC-0o� Hilcorp Alaska, LLC Milne Point ' VB2,MPG41PB2V2 'G41L2, MPC41l2 VO ' 1PB1,MPG41P81V0 'G41,MPC41V0 1G01,MPG01 V1 PG10,MPG1oV1 PC-UV1 PG39,MPG39V3 PG12,MPG12V9 PG12A,MPC-IMV3 PC-1MPBI.WC-IMPB1 V6 PGo6,MPGo6V1 PC -13 MPC -13V4 pan MPG25B,MPC2 Bvp02V13 PGo8,MPC-08VI PG15,MPG15V7 PG15A,MPG15AVo C35 Kuparuk6ag,Kupauk6ag R w MPG35 1V PC-05,MPGo5V1 PG05A,MP"5AV1 PG04,MPC-04V1 PG28,MPG26V1 PG28A,hPG28AV6 PG16,MPG16V1 G45,MPUC45(HeyVou),MPUG45v 06V0 MPC40,MPG4oV19 MwuredDepy1f50DmV1) Plen'MPUG46,MPUG46,MPUC svpo5V0 05 M Y' W17 - 18:39 Page Tal r COMPASS TRANSMITTAL LETTER CHECKLIST WELL NAME: m? (J G— 4 7 - PTD: A I � — 60 - /Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: til �tLF �di/1� POOL: lr! �11� ���rl� gsw W� Rlw4x oi) 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 it). 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 cau t and IV 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 JPer Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 da s after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 10 ___ _ Well Name: MILNE PT UNIT C-47 Program DEV Well bore seg ❑ PTD#2170770 Company HILCORP ALASKA LLC Initial Classrrype DEV / PEN.D GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0304. 1.A),Q.2.A-D) _ _ _ _ _ _ _ _ _ . NA Yes '1 Permit fee attached _. .... NA 12 2 Lease number appropriate. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ... Yes ADL0047434, Surf Loc & TD;_ ADL0047433, Top Prod Interv.. _ 3 Unique well name and number _ .. _ _ ... ... _ _ Yes MPU C-47 '4 Well located in. a. defined pool _ _ .. . . . ................... . Yes MILNE POINT, KUPARUK RIVER OIL - 525100, governed by Conservation Order No. 4320.... Can permit be approved before 15 -day wart ................. .... ...... 5 Well located proper distance from drilling unit boundary. _ _ _ _ _ _ _ _ _ .. Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries..... 14 6 Well located proper distance from other wells _ _ ... _ _ Yes _ CO 432D has no inlerwell spacing_ restrictions........... 7 Sufficient acreage. available in drilling unit_ _ _ Yes NA. 8 If. deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ _ .. _ _ _ Yes Pre -produced injector: duration of pre -production less than 3 months (Forservice well oNy) .. NA. 9 Operator only affected party.... _ _ _ Yes Wellbore. will be. more than 500' from an external property line where ownership or landownership changes. Geologic Date: Engineering Date Public Date Commissioner: Commissioner: Co missioner 10 Operator has.appropriate bond in force _ _ _ _ _ _ _ _ ... Yes _ _ _ 1-12S measures required....... Appr Date 11 Permit. can be issued without conservation order _ _ _ _ ...... _ _ Yes .................... .. _ _ _ _ Appr Date 12 Permit can be issued without administrative approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ hole will be drilled using 9.5 to 10.5 ppg mud. PKB 5/25/2017 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .NA .... ..... ...... . . . . . . ..... ...... .... .... 13 Can permit be approved before 15 -day wart ................. .... ...... Yes _ _ Onshore development well to be drilled. 14 Well located within area and strata authorized by Injection Order# (put. 10# in.comments) (For NA... 15 All wells. within 114. mite area_of review identified (For service well only). _ _ _ _ _ _ _ ... NA. 16 Pre -produced injector: duration of pre -production less than 3 months (Forservice well oNy) .. NA. 18 Conductor string. provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 16" conductor set. at 151 ft.. ............. Engineering 19 Surface casing. protects all known USDWs ... ............ _ _ _ _ NA No aquifers.,. permafrost area. 20 CMT vol adequatelo carculate.on conductor & surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _____ Yes using 2_stage cement job ES at 1900 ft. (SchraderBLuff will be covered with surface casing) 21 CMT vol adequate to tie-in long string to surf csg______ _ _ _ _ _ _ _ _ _ _ __ _ ___ _ _ No _ 7" intermediate casing will be. cemented to 500 ft above Kup C 22 CMT will cover all known productive horizons. _ _ _ .... _ _ _ _ . Yes Using. slotted liner over the production lateral (horizontal) 23 Casing designs adequate for C, T, B&. permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ____ Yes BTC supplied... 24 Adequate tankage. or reserve pit _ _ _ _ _ _ _ - - - - - - - _ _ _ _ Yes Rig has steel pits.. All waste to approved disposal well..B pad_ 25 If a re -drill, has. a 10-403 for abandonment been approved ...................... NA _ grassroots well _ _ _ _ _ _ _ _ .... 26 Adequate wellbore separation proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes .. No issues with collision . Ladder plot provided.. 27 If diverter required, does it meet regulations _ _ _ _ _ _ .Yes _ _ Innovation rig has 16" diverter. _ Using BOPE_ annular for bag. Appr Date 28 Drilling fluid program schematic & equip list adequate_ _ ......... . . . . . Yes _ _ _ Max formation pressure = 3700 psi . GLS 5/31/2017 1129 BOPEs,_do they meet regulation ... _ _ _ _ _ _ Yes _ Innovation rig has 13 5/8 5000 psi BOPE . .... .. 130 BOPE.press rating appropriate; test to (put ping in comments)_ _ _ _ _ _ _ _ _ _ _ .... Yes MASP= 2974 psi _Will lest BOPE to 3500 psi (annular to 2500 psi) 31 Choke manifold complies w/API. RP -53 (May 84) .......... . . . . . . . ...... . . . . . Yes 32 .Work will occur without operation shutdown . . . . . . . ............. . . . . . . Yes . .... No sundry needed for completion operations.... slotted liner..... _ 33 Is presence of H2S gas. probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ ....... Yes _ _ H2S on pad.. Rig has sensors and alarms 34 Mechanical_ condition of wells within AOR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ NA Geologic Date: Engineering Date Public Date Commissioner: Commissioner: Co missioner 35 Permit can be issued w/o hydrogen sulfide measures ....... ... . .. . ......... . No... _ _ _ _ 1-12S measures required....... Geology 36 Data.presented on potential overpressure zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes ..... Estimated reservoir pressureis 9.8 ppg. EMW: will be drilled. using 8,8 to 11.6 ppg. mud, Production Appr Date 37 Seismic. analysis of shallow gas zones _ _ _ _ _ _ _ _ _ _ _ _ _ . NA _ _ hole will be drilled using 9.5 to 10.5 ppg mud. PKB 5/25/2017 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .NA .... ..... ...... . . . . . . ..... ...... .... .... 39 Contact name/phone for weekly_ progress reports [exploratory only] _ _ _ _ _ _ _ _ _ .. NA _ _ _ Onshore development well to be drilled. Geologic Date: Engineering Date Public Date Commissioner: Commissioner: Co missioner
