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216-027
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241030 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-26 50283202010000 224098 10/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/14/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 10/12/2024 AK E-LINE Perf GP-ST-18742-33 50733203060000 177032 10/9/2024 AK E-LINE LeakDetect/Packer IRU 11-06 50283201300000 208184 10/4/2024 AK E-LINE Plug/Perf MPU B-28 50029235660000 216027 10/4/2024 READ CaliperSurvey MPU F-13 50029225490000 195027 10/15/2024 READ CaliperSurvey MPU L-36 50029227940000 197148 10/17/2024 READ CaliperSurvey MRU G-01RD 50733200370100 191139 10/10/2024 AK E-LINE Hoist NCIU A-21 50883201990000 224086 10/8/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/1/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/11/2024 AK E-LINE Perf PBU 06-18B 50029207670200 223071 10/2/2024 HALLIBURTON RBT PBU 14-32B 50029209990200 224073 10/13/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON WSTT PBU NK-26A 50029224400100 218009 10/14/2024 HALLIBURTON PPROF PCU 02A 50283200220100 224110 9/30/2024 AK E-LINE CBL PCU 02A 50283200220100 224110 10/4/2024 AK E-LINE Perf SDI 3-25B 50029221250200 203021 10/17/2024 AK E-LINE Patch Please include current contact information if different from above. T39726 T39727 T39728 T39732 T39733 T39734 T39735 T39736 T39737 T39738 T39739 T39739 T39740 T39741 T39742 T39742 T39743 T39744 T39744 T39745 MPU B-28 50029235660000 216027 10/4/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.01 13:27:33 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/04/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-13 50283201870000 222117 9/26/2024 AK E-LINE Perf END 2-72 50029237810000 224016 8/26/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON RBT MPI 2-16 50029218850000 188134 9/9/2024 AK E-LINE Perf MPI 2-16 50029218850000 188134 9/20/2024 AK E-LINE Perf MPU B-16 50029213840000 185149 9/28/2024 READ CaliperSurvey MPU B-24 50029226420000 196009 8/20/2024 HALLIBURTON PERF MPU B-28 50029235660000 216027 9/28/2024 HALLIBURTON TUBINGCUT MPU I-01 50029220650000 190090 8/17/2024 HALLIBURTON PERF MPU R-103 50029237990000 224114 9/20/2024 AK E-LINE Hoist MRU M-02 50733203890000 187061 9/23/2024 AK E-LINE Perf PBU 02-21B 50029207810200 211033 9/30/2024 HALLIBURTON RBT PBU L2-10 50029217460000 187085 8/23/2024 HALLIBURTON RBT PBU L-212 50029232520000 205030 9/24/2024 HALLIBURTON IPROF PBU L-254 50029237520000 223030 9/20/2024 HALLIBURTON IPROF PBU P1-17 50029223580000 193051 9/7/2024 HALLIBURTON RBT PBU S-09A 50029207710100 214097 8/21/2024 HALLIBURTON RBT PBU Z-235 50029237600000 223055 9/19/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39619 T39620 T39620 T39620 T39621 T39621 T39622 T39623 T39624 T39625 T39626 T39627 T39628 T39629 T39630 T39631 T39632 T39633 T39634 MPU B-28 50029235660000 216027 9/28/2024 HALLIBURTON TUBINGCUT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.04 15:10:24 -08'00' 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: R & R Rev. Circ Jet Pum 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 11,000 feet N/A feet true vertical 4,341 feet N/A feet Effective Depth measured 10,995 feet feet true vertical 4,341 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6 / L-80 / TXP-BTC 4,125' 3,852' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / 13Cr-80 / JFE Bear 4,844' 4,298' Tripoint Ret. Tripoint Perm BOT SLZXP LTP Packers and SSSV (type, measured and true vertical depth)(3) Tendaka Swell N/A See Above N/A 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: 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: N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 324-189 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 473 Gas-Mcf 2,220 2,952 2,257251 143 1581,260 169 24 Plugs Junk measured Length measured true vertical Packer MDSize N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047437 & ADL0047438 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT B-28 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-027 50-029-23566-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC 20" 9-5/8" 7" 113' 5,687' 11,000' 2,880' 5,721'Surface Tieback 4-1/2"Liner 5,437' Casing Conductor 5,570' 2,835' Burst N/A Collapse N/A 3,090psi 4,790psi TVD 113' 113' 4,436' 4,745, 4,875, 5,563, 6,167, 6,238 & 6,878 4,250. 4,311, 4,433, 4.433, 4,423 & 4,422 7,500psi 5,750psi 6,890psi 8,430psi4,341' measured PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.10.22 11:01:12 - 08'00' Taylor Wellman (2143) By Grace Christianson at 3:12 pm, Oct 22, 2024 RBDMS JSB 103124 WCB 2-10-2025 DSR-10/23/24 _____________________________________________________________________________________ Revised By: TDF 10/22/2024 SCHEMATIC Milne Point Unit Well: MPU B-28 Last Completed: 10/5/2024 PTD: 216-027 TD =11,000’ (MD) / TD =4,341’(TVD) 20” Orig. KB Elev.:57.2’/ GL Elev.: 23.5’ RKB – THF: 30.55’ (Doyon 14) 7 109-5/8” 1 2 4 8 See Screen/ Solid Liner Detail PBTD =10,995’ (MD) / PBTD =4,341’(TVD) 9-5/8” ‘ES’ Cementer @ 2,126’ 4-1/2” Shoe @ 11,000’ 9 11 12 13 4-1/2” 7” 5 3 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 113’ N/A 9-5/8" Surface 40 / L-80 / TC II 8.835 Surface 5,721’ 0.0758 7” Tieback 26 / L-80 / TXP 6.151 Surface 5,570’ 0.0368 4-1/2” Liner (250ђ Screens) 12.6 / L-80 / H521 3.958 5,563’ 11,000’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP-BTC 3.958 Surface 4,125’ 0.0087 4-1/2" Tubing 12.6 / 13Cr-80 / JFE Bear 3.958 4,125’ 4,844’ 0.0087 OPEN HOLE / CEMENT DETAIL 42" ~29 bbls (6 Yards dumped down backside) 12-1/4" 333 bbls in 12-1/4” Hole Cement to Surface 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 221’ Max Hole Angle = 94.5 deg. @ 8,502’ MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23566-00-00 Drilled and Cased by Doyon 14 - 3/25/2016 Install 7” Tieback and Tubing by Doyon 14 – 8/27/2022 4-1/2” Jet Pump Completion by ASR – 11/17/2023 4-1/2” Jet Pump Completion by ASR – 10/5/2024 4-1/2” SOLID LINER DETAIL Jts Top (MD) Btm (MD) 31 5,585’ 6,934’ 2 7,433’ 7,516’ 2 8,385’ 8,468’ 3 8,676’ 8,799’ SWELL PACKER DETAIL Top (MD) Btm (MD) 6,175’ 6,186’ 6,238’ 6,249’ 6,878’ 6,888’ JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 4,652’ 4-1/2” Sliding Sleeve, 3.813" X, Open Down, Port Covered for I-Wire 3.813 2 4,719’ Gauge Carrier, Baker Zenith ( Nickel Coated) 3.953 3 4,745’ 7'' x 4-1/2" 13 CR Tripoint Retrievable packer 3.920 4 4,810’ 4-1/2” XN-Nipple w/ 3.813" No-Go w/ RHC-M Plug installed 3.813 5 4,830’ 4-1/2” Non- Sealing Overshot – Bottom @ 4,844’4.892 6 4,875’ Tripoint 7'' x 4-1/2" Perm. packer 7 4,937’ 4-1/2” XN-Nipple w/ 3.725" No-Go w/ 2.313” X-Nipple Reducer installed 8 5,541’ 4-1/2” Mule Shoe – Bottom @ 5,581’ Lower Completion 9 5,563’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.200” 10 5,562’ 7” Tieback Assy. (8.25” OD No-Go @ 5,561’) 6.151” 11 See Below 5-1/2” 17# Tendeka Swell Packers 4.982” 12 10,963’ 4-1/2” Drillable Packoff Sub 2.400” 13 10,995’ WIV Valve LTC BxB (1.5” Ball on Seat/Closed) - 4-1/2” SCREENS LINER DETAIL Jts Top (MD) Btm (MD) 12 6,934’ 7,433’ 21 7,516’ 8,385’ 5 8,468’ 8,676’ 52 8,799’ 10,961’ Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 ASR#1 & SL 50-029-23566-00-00 216-027 10/3/2024 10/7/2024 No operations to report. PU/MU Packer, check all shear screws (Loose). MU and test DHG system - good. Install CC Clamps first 10JT, every other following. RIH w/ 4-1/2",12.6#,13Cr-80 JFE-Bear completion at 60fpm - 15 Joints - Utilizing GBR Torque-turn. Install 4- 1/2",12.6#,9Cr, TXP Box x JFE-Bear Pin Crossover. Continue RIH w/ 4-1/2",12.6#,L-80, TXP-BTC TBG, pumping 1x displacement to formation. T/ 4,815' PUW=56k, SOW=45k. Slack off on TBG stump 4,843' MD and attempt to shear bolts w/ -5, -10, -15, - 30, -40k. Unsuccessful. Confer w/ OE. LD Joint#121 to Skate, install Kelly hose. PU Joint #121. Bring pumps on (conventional) above stump 2.5bpm @ 75psi. Attempt to fluff/swallow stump 8-10x working back up to -40k. PSI never increased. LD JT#121 and BO Kelly. LD 2 Joints, PU/MU space-out pups. Install Joint #119 and Hanger. Feed TEC through and test - Good. Shut Annular and test DHG - Good. Bring pumps on Reverse Circulating - 2.5bpm at 40psi. Pump total of 85bbls 8.4# 1% KCI w/ 1% CI. Open Annular and test DHG - good. Land hanger, RILDS - Good. RIH w/ 4-1/2" GR, latch and pull RHC-M at 4,799' SLM - 4,810' MD (11' correction). RIH w/ 3.78" Cent, 2' Stem, 3.80" cent, S.Bailer (zero at BTM Cent.). S/D at 4,825' SLM - 4,836' MD - and 4,832' SLM - 4,843' MD. BTM Cent has brass markings from shear bolts in Overshot. Depths correlate w/ shear pins in Overshot. 10/5/2024 - Saturday WELL S/I ON ARRIVAL. PULLED BALL & ROD FROM RHC PLUG BODY @4,810' MD. PULLED RHC PLUG FROM 4,810' MD 10/8/2024 - Tuesday 10/6/2024 - Sunday Ensure SSD is closed. Reset RHC-M, Drop B&R, set packer to 3,500psi, and test TBG 30min. Test IA to 3,000psi for 30min - Good. Set BPV/CTS, RDMO. Release rig 18:00 10/6/2024 10/7/2024 - Monday 10/4/2024 - Friday Continue POOH w/ 4-1/2",12.6#,L, TXP-SR completion maintaining 2x displacement and 10bbls/hr. F/3,153' T/ 19.97' cut joint. 40 arm caliper run inconclusive from junk in wellbore. Run 7" BLB and 6.10" G.Ring to TBG stub at 4,832' SLM. BLB has fiberous rope-like chunks, schmoo, ploymer. Run 6.125" Junk Basket to stub at 4,832' SLM - minimal returns. Fluid level 300'. Log 7" CSG w/ 40 arm caliper from TBG stub at 4,832' SLM to surface. - Good data. RD Slickline and ASR tongs. 10/2/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/3/2024 - Thursday MIRU ASR-1. Accept rig at 10:00 10-3-2024.Test BOPE 250/2500psi - Good. Witness waived by AOGCC. Pull CTS/BPV. MU landing joint to hanger. Pull Hanger w/ 57k, free travel 55k. Pump 20bbls. BO/LD hanger/landing joint. POOH w/ 4- 1/2",12.6#,L, TXP-SR completion maintaining 2x displacement F/ TBG cut at ~4,847' - T/ 3,319'. TEC Spooler freezing up, troubleshoot. Service Tongs / rack. Swap fluid in spooler line oiler to 5606A and apply heat, spooler operational. Land hanger, RILDS - Good. Pull Hanger w/ 57k, free travel 55k. Pump 20bbls. BO/LD hanger/landing joint. POOH w/ 4- 1/2",12.6#,L, TXP-SR completion maintaining 2x displacement F/ TBG cut at ~4,847' - T/ 3,319 - RIH w/ 4-1/2",12.6#,13Cr-80 JFE-Bear completion at 60fpm - 15 Joints - Utilizing GBR Torque-turn. Install 4- 1/2",12.6#,9Cr, TXP Box x JFE-Bear Pin Crossover. Continue RIH w/ 4-1/2",12.6#,L-80, TXP-BTC TBG, pumping 1x displacement to formation. Log 7" CSG w/ 40 arm caliper from TBG stub at 4,832' SLM to surface. - Good data 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: R & R Rev. Circ Jet Pump 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,000' N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Tieback 4,790psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE POINT SCHRADER BLUFF OIL N/A 4,341' 10,995' 4,341' 1,241 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT B-28 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 5/1/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047437 / ADL0047438 216-027 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23566-00-00 Hilcorp Alaska LLC C.O. 477.05 Length Size Proposed Pools: 113' 113' 12.6 / Cr13 / JFE Bear TVD Burst 5,581' 8,430psi MD N/A 6,890psi 5,750psi 6,890psi 4,436' 2,835' 4,434' 5,721' 2,912' 113' 20" 9-5/8" 7-5/8' 5,687' 7-5/8'2,659' 2,880' 5,571' See Schematic 5,437' See Schematic 4-1/2" 4,341'4-1/2" BOT SLZXP LTP & (3) Tendaka Swell Pkrs and N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 5,563 MD/ 4,433 TVD, 6,175 MD/ 4,423, 6,238 MD/ 4,423 TVD & 6,878 MD/ 4,422 TVD and N/A 11,000' Perforation Depth MD (ft): No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.01 08:50:23 - 08'00' Taylor Wellman (2143) By Grace Christianson at 8:26 am, Apr 30, 2024 * BOPE test to 2500 psi. * Caliper log to AOGCC upon completion. * SSVs on tubing and IA with high and low pilot trips configured as described. 1,241 10-404 MGR02MAY24 SFD 5/2/2024 DSR-4/30/24JLC 5/3/2024 Well: MPB-28 RWO PTD: 216-027 API: 50-029-23566-00-00 Well Name:MPU B-28 API Number:50-029-23566-00-00 Current Status:Jet Pump Producer Rig:ASR #1 Estimated Start Date:May 1, 2024 Estimated Duration:4 days Reg.Approval Reqd? Yes Date Reg. Approval Recvd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:216-027 First Call Engineer:Scott Pessetto 801-822-2203 Second Call Engineer:Brian Glasheen 907-545-1144 AFE Number: Current Bottom Hole Pressure:1,668 psi @ 4266 TVD DHG reading 1/20/24 Maximum Expected BHP:1,668 psi @ 4266 TVD 7.52 PPGE Max. Anticipated Surface Pressure:1,241 psi Gas Column Gradient (0.1 psi/ft) Min ID:2.313 @ 4936 XN Nipple w/ Nipple Reducer Brief Well Summary MPB-28 was drilled and completed in 2016 as a gas lift producer. In 2022 MPB-28 was converted to a jet pump completion to increase drawdown on the reservoir. During the recompletion to jet pump in 2022 the 7-5/8 tieback liner was pulled and a new 7 tieback liner was installed. Poor 2023 jet pump performance indicated the tubing had developed a hole(s) in the low velocity area below the jet pump. The holes were confirmed by a caliper log. A workover was completed in November 2023 to replace the bad tubing with 13Cr tubing. During the November 2023 workover two bad joints of pipe were rerun into the well. The tubing was patched, passed an MIT- T, and the well is now online. To prepare for the eventual failure of the patch and allow a quick workover to repair the leak, this 10-403 is being submitted before a failure has occurred. It is proposed to stack a packer as the impact to drawdown is minimal and reduces risk in milling the permanent packer. Objective 1.Pull 4-1/2 reverse circulation jet pump completion. 2.Run new 4-1/2 reverse circulation jet pump completion with corrosion resistant tubing tail. Notes on Well Condition New 7 casing installed 8/26/2022 o MIT-IA to 3,000 psi 11/18/2023 o 11-16-23 caliper max penetration 37%, max metal loss 8.6% MIT-OA to 1,500 psi passed on 9/28/2023 Tripoint permanent packer 4,874 MD 13Cr tubing below the 3.813 sliding sleeve 4,753 MD Tubing holes between 4,538-4,622 MD Planned SSV Pilot Settings o Power fluid SSV high pressure trip will not exceed 3,000 psi o Power fluid SSV low pressure trip will be set to 50 percent of header pressure o Production SSV high pressure trip not to exceed 650 psi o Production SSV low pressure trip not to be below 75 psi Procedure: Slickline (Non-Sundried Work) 1. MIRU SL. Pressure test PCE to 250 low / 2,500 psi high. 2. Pull upper patch packer, 3x snap latch tubing joints, and lower patch. Confirm sufficient lubricator length prior to pulling. 3. Patch assembly lengths: a. Upper NS packer, patch assembly #5 @ 4,519 MD (29.44 OAL, 2 pins @ 1600# release) b. Snap latch tubing joint, assembly #4 @ 4547 MD (23.94 OAL, 4 pins @ 3200# release) c. Snap latch tubing joint, assembly #3 @ 4570 MD (23.79 OAL, 6 pins @ 4800# release) d. Snap latch tubing joint, assembly #2 @ 4593 MD (23.06 OAL, 8 pins @ 6400# release) Well: MPB-28 RWO PTD: 216-027 API: 50-029-23566-00-00 e. Lower NS packer, assembly #1 4. Pull 3.813 reducer sleeve from 3.813 sliding sleeve. 5. Pull nipple reducer from 3.75 XN nipple. 6. RDMO E-Line (Non-Sundried Work) 1. MIRU E-line. Pressure test PCE to 250 low / 2,500 psi high. 2. Pickup mechanical cutter and CCL 3. Perform cut mid-joint in first full joint above packer.~4,847 RKB using 2023 ASR tubing tally. a. Cut to leave enough room to allow overshot to swallow tubing by 10. 4. RDMO. Brief RWO Procedure (Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If required, kill well w/ 8.4 ppg source water prior to setting CTS plug. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 4-1/2 test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure off casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well w/ 8.4 ppg source water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2023 workover was 59k lbs on ASR1. b. Tubing was cut pre-rig. 6. Confirm hanger free, lay down tubing hanger. 7. POOH and lay down the 4-1/2 tubing. a. Dispose of tubing. b. Save jewelry for inspection and reuse on a future well. c. Rig up spooler for TEC wire. d. 65 cannon clamps used on TEC wire in 2023. 8.Rig up slickline for memory caliper of the 7 casing per CO 808 requirement. 9. Pick up new 4-1/2 jet pump completion with non-sealing chrome overshot and RIH to 50 above tubing stub at ~4,847 RKB. a. Confirm overshot is pinned to correct shear weight. b. Clamp gauge wire every other joint. c. Test gauge every 2,000. Caliper log to AOGCC: melvin.rixse@alaska.gov Well: MPB-28 RWO PTD: 216-027 API: 50-029-23566-00-00 Nom. (OD)Length Item Lb/ft Material Notes 4-1/2"~25 4-1/2 Non-Sealing Overshot 13Cr 12.6 13Cr ~4,847 4-1/2"10 4-1/2" Pup 12.6 9Cr 5.03"2 3.813" X Nipple - RHC Installed 9Cr ~4812, 62° 4-1/2"10 4-1/2" Pup 12.6 9Cr 4-1/2"41 4-1/2" jts 13Cr 4-1/2"10 4-1/2" Pup 12.6 9Cr 6"5 7" x 4-1/2" Retrievable Packer 9Cr 4-1/2"10 4-1/2" Pup 12.6 9Cr 4-1/2"10 4-1/2" pup 12.6 9Cr 4-1/2"6 Gauge Carrier, Baker Zenith Ni 4-1/2"10 4-1/2" pup 12.6 9Cr 4-1/2"41 4-1/2" jts 12.6 13Cr 4-1/2"10 4-1/2" TXP Pup Jt 12.6 9Cr 5.6"2 4-1/2" Sliding Sleeve, 3.813" X, open down, port covered for I wire 9Cr ~4670, 55° 4-1/2"10 4-1/2" TXP Pup Jt 12.6 9Cr 4-1/2"500 4-1/2" jts 12.6 13Cr 4-1/2"4130 4-1/2" TXP 12.6 L-80 4-1/2"10 Space out pup 12.6 L-80 30 Tbg hanger, Seaboard, TC-1A L-80 10. Pump 15 barrels of 1% KCL with 1% by volume corrosion inhibitor (CI) down the IA, taking returns up the tubing, followed by 82 barrels of KWF. a. This is to inhibit the casing from below the sliding sleeve to the top of the liner top packer. 11. Prepare to set 4-1/2 casing overshot. 12. Lower completion until overshot swallows stub. Observe shear of overshot on stub. 13. Space out to land hanger with stub swallowed. 14. Land hanger. a. Take extra care to not damage gauge wire while landing hanger. b. Note pickup and slack off weight prior to landing hanger. 15. RILDS. Lay down landing joint. 16. Consult with Milne Wells group on plan to freeze protect after RDMO. 17. Drop ball and rod and pump to seat in X nipple below the packer. Set the packer per vendor setting procedure. 18. Pressure test the tubing to 3,000 psi, charted for 30 minutes. 19. Pressure test the IA to 3,000 psi, charted for 30 minutes. a. B-pad power fluid pressure is 2,600 psi. 20. Set CTS. 21. RDMO ASR. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. 5. Pull CTS. - mgr - mgr Well: MPB-28 RWO PTD: 216-027 API: 50-029-23566-00-00 6. RD crane. Move 500 bbl returns tank and rig mats to next well location. 7. Replace gauge(s) if removed. 8. Turn well over to production. RU well house and flowlines for a Jet Pump completion. Slickline 1. Spot Slickline unit and RU. 2. Pressure test lubricator to 250 psi low and 2,500 psi high. 3. Pull ball and rod. 4. Pull RHC profile. 5. Shift sliding sleeve open 6. Set 13C jet pump in sliding sleeve. Attachments: 1. Well Schematic Current 2. Well schematic Proposed 3. BOP Drawing _____________________________________________________________________________________ Revised By: TDF 1/29/2024 SCHEMATIC Milne Point Unit Well: MPU B-28 Last Completed: 11/17/2023 PTD: 216-027 TD =11,000 (MD) / TD =4,341(TVD) 20 Orig. KB Elev.:57.2/ GL Elev.:23.5 RKB THF: 30.55 (Doyon 14) 4 79-5/8 1 2 3 5 See Screen/ Solid Liner Detail PBTD =10,995 (MD) / PBTD =4,341(TVD) 9-5/8 ES Cementer @ 2,126 4-1/2 Shoe @ 11,000 6 8 9 10 4-1/2 7 Bad Pipe: 4,538 to 4,622 Patch: Top @ 4,518 & Btm @ 4,641 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 113 N/A 9-5/8" Surface 40 / L-80 / TC II 8.835 Surface 5,721 0.0758 7 Tieback 26 / L-80 / TXP 6.151 Surface 5,570 0.0368 4-1/2 Liner (250 Screens) 12.6 / L-80 / H521 3.958 5,563 11,000 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / Cr13 / JFE Bear 3.958 Surface 5,581 0.0087 OPEN HOLE / CEMENT DETAIL 42" ~29 bbls (6 Yards dumped down backside) 12-1/4" 333 bbls in 12-1/4 Hole Cement to Surface 8-1/2 Cementless Screens Liner in 8-1/2 hole WELL INCLINATION DETAIL KOP @ 221 Max Hole Angle = 94.5 deg. @ 8,502 MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23566-00-00 Drilled and Cased by Doyon 14 - 3/25/2016 Install 7 Tieback and Tubing by Doyon 14 8/27/2022 4-1/2 Jet Pump Completion by ASR 11/17/2023 4-1/2 SOLID LINER DETAIL Jts Top (MD) Btm (MD) 31 5,585 6,934 2 7,433 7,516 2 8,385 8,468 3 8,676 8,799 SWELL PACKER DETAIL Top (MD) Btm (MD) 6,175 6,186 6,238 6,249 6,878 6,888 JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 4,753 Sliding Sleeve opens down, 3.813" X,2-7/8 Sleeve Reducer installed 2 4,814 Zenith Gauge Carrier, Nickel Coated 3 4,875 Tripoint 7'' x 4-1/2" Perm. packer 4 4,937 4-1/2 XN-Nipple w/ 3.725" No-Go w/ 2.313 X-Nipple Reducer installed 5 5,541 4-1/2 Mule Shoe Bottom @ 5,581 Lower Completion 6 5,563 BOT SLZXP Liner Top Packer w/BD Slips 7 x 9-5/8 6.200 7 5,562 7 Tieback Assy. (8.25 OD No-Go @ 5,561) 6.151 8 See Below 5-1/2 17# Tendeka Swell Packers 4.982 9 10,963 4-1/2 Drillable Packoff Sub 2.400 10 10,995 WIV Valve LTC BxB (1.5 Ball on Seat/Closed) - 4-1/2 SCREENS LINER DETAIL Jts Top (MD) Btm (MD) 12 6,934 7,433 21 7,516 8,385 5 8,468 8,676 52 8,799 10,961 _____________________________________________________________________________________ Revised By: TDF 3/28/2024 PROPOSED Milne Point Unit Well: MPU B-28 Last Completed: 11/17/2023 PTD: 216-027 TD =11,000 (MD) / TD =4,341(TVD) 20 Orig. KB Elev.:57.2/ GL Elev.:23.5 RKB THF: 30.55 (Doyon 14) 7 109-5/8 1 2 4 8 See Screen/ Solid Liner Detail PBTD =10,995 (MD) / PBTD =4,341(TVD) 9-5/8 ES Cementer @ 2,126 4-1/2 Shoe @ 11,000 9 11 12 13 4-1/2 7 5 3 6 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 113 N/A 9-5/8" Surface 40 / L-80 / TC II 8.835 Surface 5,721 0.0758 7 Tieback 26 / L-80 / TXP 6.151 Surface 5,570 0.0368 4-1/2 Liner (250 Screens) 12.6 / L-80 / H521 3.958 5,563 11,000 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / Cr13 / JFE Bear 3.958 Surface ±4,847 0.0087 4-1/2" Tubing 12.6 / Cr13 / JFE Bear 3.958 ±4,8475,581 0.0087 OPEN HOLE / CEMENT DETAIL 42" ~29 bbls (6 Yards dumped down backside) 12-1/4" 333 bbls in 12-1/4 Hole Cement to Surface 8-1/2 Cementless Screens Liner in 8-1/2 hole WELL INCLINATION DETAIL KOP @ 221 Max Hole Angle = 94.5 deg. @ 8,502 MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23566-00-00 Drilled and Cased by Doyon 14 - 3/25/2016 Install 7 Tieback and Tubing by Doyon 14 8/27/2022 4-1/2 Jet Pump Completion by ASR 11/17/2023 4-1/2 SOLID LINER DETAIL Jts Top (MD) Btm (MD) 31 5,585 6,934 2 7,433 7,516 2 8,385 8,468 3 8,676 8,799 SWELL PACKER DETAIL Top (MD) Btm (MD) 6,175 6,186 6,238 6,249 6,878 6,888 JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 ±4,670 4-1/2 Sliding Sleeve, 3.813" X, Open Down, Port Covered for I-Wire 2 ±X,XXX Gauge Carrier, Baker Zenith 3 ±X,XXX 7'' x 4-1/2" Retrievable packer 4 ±4,812 4-1/2 XN-Nipple w/ 3.725" No-Go w/ RHC Plug installed 5 ±X,XXX 4-1/2 Non- Sealing Bottom @ ±4,847 6 4,875 Tripoint 7'' x 4-1/2" Perm. packer 7 4,937 4-1/2 XN-Nipple w/ 3.725" No-Go w/ 2.313 X-Nipple Reducer installed 8 5,541 4-1/2 Mule Shoe Bottom @ 5,581 Lower Completion 9 5,563 BOT SLZXP Liner Top Packer w/BD Slips 7 x 9-5/8 6.200 10 5,562 7 Tieback Assy. (8.25 OD No-Go @ 5,561) 6.151 11 See Below 5-1/2 17# Tendeka Swell Packers 4.982 12 10,963 4-1/2 Drillable Packoff Sub 2.400 13 10,995 WIV Valve LTC BxB (1.5 Ball on Seat/Closed) - 4-1/2 SCREENS LINER DETAIL Jts Top (MD) Btm (MD) 12 6,934 7,433 21 7,516 8,385 5 8,468 8,676 52 8,799 10,961 Milne Point ASR Rig 1 BOPE 2023 11 BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 5-1/2 Fixed Rams Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/16/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 1-27 50029216930000 187009 2/6/2024 YELLOW JACKET PERF KU 13-06A 50133207160000 223112 2/7/2024 YELLOW JACKET GPT MPU G-18 50029231940000 204020 2/8/2024 READ Caliper Survey MPU B-28 50029235660000 216027 1/15/2024 YELLOW JACKET PATCH PBU PAVE 1-1 50029237670000 223094 1/5/2024 YELLOW JACKET CBL SRU 241-33B 50133206960000 221053 2/8/2024 YELLOW JACKET GPT Please include current contact information if different from above. T38513 T38514 T38515 T38516 T38517 T38518 2/21/2024 YELLOW MPU B-28 50029235660000 216027 1/15/2024 JACKET PATCH Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.21 09:17:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/8/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-08 50133203040000 177029 10/11/2023 AK E-LINE TUBING CUT KBU 14-6Y 50133205720000 207149 10/24/2023 AK E-Line PLUG/PERF MPU B-28 50029235660000 216027 1/10/2024 HALLIBURTON MFC40 MPU F-65 50029227520000 197049 1/19/2024 HALLIBURTON MFC40 MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag Please include current contact information if different from above. T38488 T38489 T38490 T38491 T38492 T38493 2/8/2024 MPU B-28 50029235660000 216027 1/10/2024 HALLIBURTON MFC40 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.08 10:05:37 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/3/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240103 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-28 50029235660000 216027 12/27/2023 READ Leak Detection Survey MPU F-65 50029227520000 197049 12/15/2023 READ Caliper Survey PBU W-202 50029234340000 210133 12/5/2023 READ Production Profile Please include current contact information if different from above. T38251 T38252 T38253 1/3/2024 Leak Detection MPU B-28 50029235660000 216027 12/27/2023 READ Survey Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.03 13:52:25 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231221 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-28 50029235660000 216027 12/6/2023 HALLIBURTON PATCH MPU F-10A 50029226790100 223027 12/7/2023 HALLIBURTON PLUG MPU F-10A 50029226790100 223027 12/7/2023 HALLIBURTON TUBING-PUNCH NCIU A-12B 50883200320200 223053 12/1/2023 HALLIBURTON RBT NCIU A-18 50883201890000 223033 12/4/2023 HALLIBURTON RBT PBU 01-28B 50029215970200 223089 12/13/2023 HALLIBURTON RBT Please include current contact information if different from above. T38238 T38239 T38239 T38240 T38241 T38242 12/22/2023 MPU B-28 50029235660000 216027 12/6/2023 HALLIBURTON PATCH Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.22 09:09:45 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231128 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-13 50133205250000 203138 11/13/2023 HALLIBURTON RMT3D MPU B-28 50029235660000 216027 11/20/2023 HALLIBURTON LDL MPU B-28 50029235660000 216027 11/21/2023 HALLIBURTON MFC MPU C-20 50029219140000 189015 11/21/2023 HALLIBURTON LDL NS-24 50029231110000 202164 11/20/2023 READ LeakPointSurvey PBU 13-20 50029207050000 182009 11/16/2023 HALLIBURTON WFL-TMD3D PBU L-216 50029232060000 204065 7/20/2023 PROBE MSIL (CBL) PBU S-09A 50029207710100 214097 7/7/2023 PROBE MSIL (CBL) PBU S-32A 50029220990100 212082 7/13/2023 PROBE MSIL (CBL) PBU S-124 50029233230000 206136 7/15/2023 PROBE MSIL (CBL) Please include current contact information if different from above. T38150 T38151 T38151 T38152 T38153 T38154 T38155 T38156 T38157 T38158 11/29/2023 MPU B-28 50029235660000 216027 11/20/2023 HALLIBURTON LDL MPU B-28 50029235660000 216027 11/21/2023 HALLIBURTON MFC Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.29 11:22:45 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231121 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-28 50029235660000 216027 11/16/2023 READ Caliper Survey PBU GNI-04 50029233670000 207117 6/13/2023 HALLIBURTON Press-Temp Please include current contact information if different from above. T38143 T38144 11/21/2023 MPU B-28 50029235660000 216027 11/16/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 12:11:15 -09'00' 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 Install Patch 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 11,000 feet N/A feet true vertical 4,341 feet N/A feet Effective Depth measured 10,995 feet feet true vertical 4,341 feet 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 / Cr13 / JFE Bear 5,581' 4,435' BOT SLZXP LTP Packers and SSSV (type, measured and true vertical depth)(3) Tendaka Swell N/A See Above N/A 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: 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: 5,563, 6,167, 6,238 & 6,878 4,433, 4.433, 4,423 & 4,422 Tieback 2,912' 4,434' 6,890psi 4,790psi2,659' 7" Burst N/A Collapse N/A measuredPlugs 7,500psi 5,750psi 6,890psi 8,430psi 5,570' 2,835' 3,090psi 4,790psi 5,437' Casing Conductor 4,341'11,000' 2,880' 5,721'Surface Tieback Liner 20" 9-5/8" 7" 113' 5,687' TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-027 50-029-23566-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047437 & ADL0047438 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT B-28 Junk measured Length measured true vertical Packer MD 113' 0 Size 113' 4,436' 0 15200 Water-BblOil-Bbl Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureGas-Mcf Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. scott.pessetto@hilcorp.com 907-564-4373 N/A Scott Pessetto N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 343 1,384 2,317388 165 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 10:57 am, Jan 31, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.01.30 13:30:01 - 09'00' Taylor Wellman (2143) RBDMS JSB 020824 DSR-1/31/24 _____________________________________________________________________________________ Revised By: TDF 1/29/2024 SCHEMATIC Milne Point Unit Well: MPU B-28 Last Completed: 11/17/2023 PTD: 216-027 TD =11,000’ (MD) / TD =4,341’(TVD) 20” Orig. KB Elev.: 57.2’/ GL Elev.: 23.5’ RKB – THF: 30.55’ (Doyon 14) 4 79-5/8” 1 2 3 5 See Screen/ Solid Liner Detail PBTD =10,995’ (MD) / PBTD =4,341’(TVD) 9-5/8” ‘ES’ Cementer @ 2,126’ 4-1/2” Shoe @ 11,000’ 6 8 9 10 4-1/2” 7” Bad Pipe: 4,538’ to 4,622’ Patch: Top @ 4,518 & Btm @ 4,641’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 113’ N/A 9-5/8" Surface 40 / L-80 / TC II 8.835 Surface 5,721’ 0.0758 7” Tieback 26 / L-80 / TXP 6.151 Surface 5,570’ 0.0368 4-1/2” Liner (250ђ Screens) 12.6 / L-80 / H521 3.958 5,563’ 11,000’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / Cr13 / JFE Bear 3.958 Surface 5,581’ 0.0087 OPEN HOLE / CEMENT DETAIL 42" ~29 bbls (6 Yards dumped down backside) 12-1/4" 333 bbls in 12-1/4” Hole Cement to Surface 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 221’ Max Hole Angle = 94.5 deg. @ 8,502’ MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23566-00-00 Drilled and Cased by Doyon 14 - 3/25/2016 Install 7” Tieback and Tubing by Doyon 14 – 8/27/2022 4-1/2” Jet Pump Completion by ASR – 11/17/2023 4-1/2” SOLID LINER DETAIL Jts Top (MD) Btm (MD) 31 5,585’ 6,934’ 2 7,433’ 7,516’ 2 8,385’ 8,468’ 3 8,676’ 8,799’ SWELL PACKER DETAIL Top (MD) Btm (MD) 6,175’ 6,186’ 6,238’ 6,249’ 6,878’ 6,888’ JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 4,753’ Sliding Sleeve opens down, 3.813" X,2-7/8” Sleeve Reducer installed 2 4,814’ Zenith Gauge Carrier, Nickel Coated 3 4,875’ Tripoint 7'' x 4-1/2" Perm. packer 4 4,937’ 4-1/2” XN-Nipple w/ 3.725" No-Go w/ 2.313” X-Nipple Reducer installed 5 5,541’ 4-1/2” Mule Shoe – Bottom @ 5,581’ Lower Completion 6 5,563’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.200” 7 5,562’ 7” Tieback Assy. (8.25” OD No-Go @ 5,561’) 6.151” 8 See Below 5-1/2” 17# Tendeka Swell Packers 4.982” 9 10,963’ 4-1/2” Drillable Packoff Sub 2.400” 10 10,995’ WIV Valve LTC BxB (1.5” Ball on Seat/Closed) - 4-1/2” SCREENS LINER DETAIL Jts Top (MD) Btm (MD) 12 6,934’ 7,433’ 21 7,516’ 8,385’ 5 8,468’ 8,676’ 52 8,799’ 10,961’ Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 Slickline 50-029-23566-00-00 216-027 12/2/2023 1/20/2024 No operations to report. PT PCE 300L/3500H. RAN 4-1/2" GR(steel), 3.70" DMY PACKER DRIFT w/ DMY PTSA STINGER, DRIFTED CLEAN TO 4900' SLM. BRUSHED w/ 4-1/2'' BLB, 3.70' G-RING, BRUSHED XN- NIP @ 4910' MD. SET 4-1/2'' NIPPLE REDUCER (secdary lockdown, control, lih 37'' (2.31'' i.d.) IN 3.725'' XN-NIP @ 4910' MD. 12/2/2023 - Saturday No operations to report. 12/5/2023 - Tuesday 12/3/2023 - Sunday Work continued from 12/2/2023. SET 2.31'' XX-PLUG (control, on seat, 23'' lih, 4 x 1/8'' ports) IN 4-1/2'' NIP-REDUCER @ 4910' MD. BRING ON POWER FLUID & CIRC OUT WELL. PERFORMED PASSING CMIT-TxIA. RAN 2-7/8'' GR w/ EQ-PRONG (dogless) & EQUALIZED 2.31'' XX-PLUG IN 4-1/2'' NIP-REDUCER @ 4910' MD. PULLED 2-7/8" XX-PLUG FROM NIP REDUCER @ 4,910' MD. RAN 42BO SHIFTING TOOL(90's facing down) TO SLIDING SLEEVE @ 4,702' MD TO VERIFY SLEEVE IS OPEN(no issues). SET 3.813" X-LOCK w/ FLOW SLEEVE IN SLIDING SLEEVE @ 4,702' MD. RAN 4-1/2" CHECK SET TO FLOW SLEEVE @ 4,702' MD(sheared). WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS. 12/4/2023 - Monday 12/1/2023 - Friday No operations to report. 11/29/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/30/2023 - Thursday MPU Well Support,tied well into process post-RWO. Surface lines PT'd and wellhead serviced. Turned over to I&E group. Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 ASR 50-029-23566-00-00 216-027 12/2/2023 1/20/2024 WELL SHUT-IN ON ARRIVAL. RIG-UP .125 CARBON WIRE. TS - 1.75" RS, 10' x 1-1/2" ROLLER STEM (2.0" whls), KJT 5' x 1-1/2" ROLLER STEM (2.0" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD, RIG-UP POWER FLUID. PT PCE 350L / 3500H (Good). PULL 2-7/8" JETPUMP (ratio: 12B) FROM XD-SS AT 4,702' MD(recovered a dime size rock in the throat, nozzle plugged). PUMP 100bbls POWER FLUID DOWN TUBING. BRUSH 2-7/8" FLOWSLEEVE AT 4,702' MD W/ 2-7/8" BRUSH. SET 2-7/8" JETPUMP (ratio: 12B) IN XD-SS AT 4,702' MD. WELL FLOWING ON DEPARTURE, PAD OP NOTIFIED. No operations to report. 12/9/2023 - Saturday WELL FLOWING ON ARRIVAL. RIG-UP .125 CARBON WIRE. TS = 1.75 RS, 10' x 1-1/2" ROLLER STEM (2.0" whls), KJT 5' x 1-7/8" ROLLER STEM (2.0" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). PULL 2-7/8" JETPUMP (ratio: 12B) FROM XD-SS AT 4,702' MD. SET 2-7/8" JETPUMP (ratio: 12B) IN XD-SS AT 4,702' MD. WELL FLOWING ON DEPARTURE, PAD OP NOTIFIED. 12/12/2023 - Tuesday 12/10/2023 - Sunday No operations to report. 12/11/2023 - Monday 12/8/2023 - Friday No operations to report. 12/6/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I UPON ARRIVAL. PICK UP LUBRICATOR. STAB ON; PT LOW 250PSI; HIGH 2500PSI. PT GOODL OPEN SWAB 23 TURNS; RIH; CCL TO COE 41.7 AND CCL TO BOTTOM 46.6'. SET NORTHERN SOLUTIONS LOWER PATCH AT COE 4,630' (OAL=34.6', Min ID 2.365"). RDMO HES. 12/7/2023 - Thursday WELL SHUT-IN ON ARRIVAL. RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 5' x 2-5/8" ROLLER STEM (3.50" whls), KJT LSS. STACK RISER ALONGSIDE WELLHOUSE, STACK PATCH SECTIONS IN WELLHOUSE. PICK-UP LUBRICATOR, STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). SET NS 2-7/8" SPACER PIPE W/ SNAPLATCH ASSY IN LOWER ANCHOR AT 4,592' SLM (oal - 36'). SET NS UPPER PACKER, 2-7/8" SPACER PIPE W/ SNAPLATCH ASSY IN SNAP LATCH RECPT AT 4,556' SLM (oal - 36'). TOP OF PATCH AT 4,516' SLM / 4,524' MD. SET 2-7/8" XX PLUG IN FLOW SLEEVE AT 4,702' MD. LRS PERFORMED PASSING MIT- TO 3000psi (See log).. EQUALISE AND PULL 2-7/8" XX PLUG FROM FLOW SLEEVE AT 4,702' MD. SET 2-7/8" JETPUMP (ratio:12B) IN FLOW SLEEVE AT 4,702' MD. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 ASR 50-029-23566-00-00 216-027 12/2/2023 1/20/2024 WELL CIRCULATING ON ARRIVAL. BEGIN R/U .125 CARBON, 1-1/2'' RS, QC, 10' X 1-1/2'' RS (1.96'' wheels), QC, KJ, 5' X 1-1/2'' RS (1.96'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. SET 2-1/2 XX-PLUG IN FLOW SLEEVE @ 4744' SLM / 4702' MD. RAN 2.125'' CENT., PONYTAIL, FOUND HOLES @ 4602' SLM & 4583' SLM. RAN 4-1/2 D&D HOLEFINDER, SET @ 4509' SLM, PRESSURE UP ON TUBING TO 700 PSI, IA STAYED @ 150 PSI, GOOD TEST. WELL CIRCULATING ON DEPARTURE. No operations to report. 12/23/2023 - Saturday WELL FLOWING ON ARRIVAL. BEGIN R/U .125 CARBON, 1-1/2'' RS, QC, 10' X 1-1/2'' RS (1.96'' wheels), QC, KJ, 1-1/2'' RS (1.96'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. PULL 3'' JET PUMP @ 4744' SLM / 4702' MD. SET 2-1/2 XX-PLUG SET IN X-NIPPLE @ 4928' SLM / 4910' MD. CIRCULATE FOR 1hr, PRESSURE UP ON IA & TUBING, GOOD TEST. SET 2-1/2 XX-PLUG SET IN FLOW SLEEVE @ 4744' SLM / 4702' MD. RAN 4-1/2 D&D HOLEFINDER, SET @ 4509' SLM (failed test), SET @ 4000' SLM (failed test), SET @ 3500' SLM (passing test). PULL 2-1/2 XX-PLUG SET IN FLOW SLEEVE @ 4744' SLM / 4702' MD. WELL CIRCULATING ON DEPARTURE. 12/26/2023 - Tuesday 12/24/2023 - Sunday No operations to report. 12/25/2023 - Monday 12/22/2023 - Friday No operations to report. 12/20/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/21/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 ASR 50-029-23566-00-00 216-027 12/2/2023 1/20/2024 No operations to report. No operations to report. 12/30/2023 - Saturday No operations to report. 1/2/2024 - Tuesday 12/31/2023 - Sunday No operations to report. 1/1/2024 - Monday 12/29/2023 - Friday RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 10' x 2-5/8" ROLLER STEM (3.50" whls), 2-1/8" OJ, 2-1/2" LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). JAR FOR 2 HOURS ON LOWER PATCH ASSEMBLY AT 4,587' SLM (left on flow slv at 4,704' slm). LAY DOWN LUBRICATOR, HILCORP CRANE PICKED RISER AND LUBRICATOR. PULL LOWER PATCH ASSEMBLY FROM ON TOP OF FLOW SLEEVE AT4,704' SLM (see log). WELL CIRCULATING ON DEPARTURE, PAD OP NOTIFIED. 12/27/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL CIRCULATING ON ARRIVAL. BEGIN R/U .125 CARBON, 1-1/2'' RES, QC, 10' X 1-1/2'' RS (1.96'' wheels), QC, KJ, 5' X 1-1/2'' RS (1.96'' wheels), QC, KJ, LSS, CHECK ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. RUN READ LDL, LOG FROM 4740' SLM TO 0' SLM. PULL UPPER PACKER & SPACER PIPE @ 4510' SLM. PULL SPACER PIPE @ 4552' SLM. LATCH LOWER PACKER & SPACER PIPE @ 4587' SLM, JAR @ 1900# FOR 1 HOUR, NO MOVEMENT. WELL CIRCULATING ON DEPARTURE. 12/28/2023 - Thursday WELL SHUT-IN ON ARRIVAL. RIG-UP .125 CARBON. TS = 1.75" RS, 5' x 2-5/8" ROLLERS STEM (3.50" whls), 3' x 3.0" STEM, 5' x 2- 5/8" ROLLER STEM (3.50" whls), 2-1/8" OJ, 2-1/2" LSS. M/U S-BOX, STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). JAR FOR 1 HOUR ON LOWER PATCH ASSEMBLY AT 4,587' SLM(no movement). Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 Fullbore 50-029-23566-00-00 216-027 12/2/2023 1/20/2024 No operations to report. No operations to report. 1/6/2024 - Saturday No operations to report. 1/9/2024 - Tuesday 1/7/2024 - Sunday No operations to report. 1/8/2024 - Monday 1/5/2024 - Friday T/I/O=220/100/100 Freeze Protect Pumped 125 bbls diesel down IA. U-Tube to TBG for 1.5 hours. Pumped 3 bbls 60/40 down prod lat and 3 bbls 60/40 down PFL. Final Whps= 150/150/100 1/3/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/4/2024 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 E & S Line 50-029-23566-00-00 216-027 12/2/2023 1/20/2024 1/12/2024 - Friday No operations to report. 1/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL. MAKEUP TOOLS, STAB ON & PRESSURE TEST TO 3,000 PSI (pass). DRIFT TO SSD W/ 3.73" CENT, 5' x 1- 3/4", 3.79" GAUGE RING, SD @4,716' SLM (4,702' MD). RAN KJ, BLB, 3.79" GAUGE RING & BRUSHED FOR PATCH FROM 4,500' - 4,700' SLM. LOG W/ HES 40 ARM CALIPER FROM 4,717' SLM (4,702' MD) TO SURFACE @50'/MIN. WELL LEFT S/I ON DEPARTURE. 1/11/2024 - Thursday No operations to report. Work continues from 1/15/2024. SET PATCH ASSY #4 TOP @ 4547' MD. (23.94' OAL, 4 PINS @ 3200# RELEASE) SET PATCH ASSY #5 TOP @ 4519' MD. (29.44' OAL, 2 PINS @ 1600# RELEASE). MIT-T TO 2500 PSI - PASSED. ATTEMPT TO MIT- IA - FAIL. PULLED TEST TOOL FROM PATCH ASSY #5 @4,519' MD. JAR ON PATCH ASSY #5 @4519' MD FOR 1 HOUR. LAY DOWN FOR WIND - GUSTING OVER 38 MPH. No operations to report. 1/13/2024 - Saturday WELL SI ON ARRIVAL INTITAL T/I/O = 0/250/0. PICK UP LUBE, STAB ON. PT 300/3000 PSI. TAG SLIDING SLEEVE REDUCER NIP AT 4750 EOT AND 4718 CCL DEPTH CORRECTED TO WORKOVER TALLY, W/ NS PATCH, SET NORTHERN SOLUTIONS PATCh PACKER AT 4635 FT. CCL - MID ELEMENT = 27.0 FT, CCL STOP = 4608 FT, 700 / 620 LB LINE TENSION BEFORE/AFTER, NO PRESSURE CHANGE. SET DOWN ON PATCH AFTER SETTING, HAD TO WORK LINE 500 LB OVER TO GET FREE AND POOH. GOOD INDICATION OF SETTING. FINAL T/I/O = 0/250/0. PATCH IN PROGRESS, ELINE COMPLETE, READY FOR SLICKLINE. WELL S/I ON ARRIVAL. PT 250/ 2500. SET PATCH ASSY #2 TOP @ 4593' MD. (23.06' OAL, 8 PINS @ 6400# RELEASE). SET PATCH ASSY #3 TOP @ 4570' MD. (23.79' OAL, 6 PINS @ 4800# RELEASE). 1/16/2024 - Tuesday 1/14/2024 - Sunday No operations to report. 1/15/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 E & S Line 50-029-23566-00-00 216-027 12/2/2023 1/20/2024 No operations to report. WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-1/2'' RS, 10' X 1-1/2'' RS (1.96'' wheels), QC, KJ, 5' X 1-/2'' RS (1.96'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. RAN 2.125'' CENT, 3' X 1- 1/2'' STEM, BOW SPRING CENT., 2-1/2 GR (steel), X-PRONG, LATCH & PULL XX-PLUG @ 4927' SLM / 4913' MD. RAN 2-7/8 JET PUMP (ratio:12, screen, oal= 55''), SET IN REDUCER SLEEVE IN SS @ 4742' SLM / 4744' MD. NEEDS TO BE SENT TO FIRE HALL TO BE REDRESSED. WELL FLOWING ON DEPARTURE. 1/20/2024 - Saturday No operations to report. 1/23/2024 - Tuesday 1/21/2024 - Sunday No operations to report. 1/22/2024 - Monday 1/19/2024 - Friday RAN 2" LIB TO 4900' SLM (4910' MD GET INPRESSION OF TOP OF LOCK). ATTEMPT TO PULL PLUG FROM NIPPLE . REDUCER @ 4910' MD ( UNABLE TO LATCH). RUN 1.25" LIB TO XX PLUG @ 4910' MD ( INCONCLUSSIVE MARKS OF WHY UNABLE TO LATCH PLUG). WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS. 1/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MAKEUP TOOLS, STAB ON & PRESSURE TEST TO 3,000 PSI (pass). PULLED UPPER PATCH ASSY #5 @ 4519' MD. PULLED 2-7/8" XX PLUG FROM XD SSD @ 4702' MD.SET UPPER PATCH ASSY #5 @ 4519' MD. (29.44' OAL, 2 PINS @ 1600# RELEASE). 1/18/2024 - Thursday SET 2-7/8" XX PLUG IN XD SSD @ 4702' MD. MIT-T 2500 PSI (PASSED). MIT-IA 2500 PSI (PASSED). PULLED 2-7/8" XX PLUG FROM XD SSD @ 4702' MD. ATTEMPT TO EQUALIZE & PULL PLUG @4,910' MD - UNABLE TO LATCH. RAN KJ, 1.90" CENT, 10' x 1-1/2" PUMP BLR W/ MSBB, SD @4,899' SLM (4,910' MD), RECOVERED 2/3 O-RING FROM TEST TOOL. RAN KJ, 1.90" CENT, 10' x 1-3/4" PUMP BLR W/ SNOKEL BTM TO XX PLUG @ 4910' MD (no recovery). RAN 2-7/8 GR w/EQ PRONG, UNABLE TO LATCH. RAN 2-7/8 GR, UNABLE TO LATCH. 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: P & R Rev. Circ Jet Pump 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 11,000 feet N/A feet true vertical 4,341 feet N/A feet Effective Depth measured 10,995 feet feet true vertical 4,341 feet 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 / Cr13 / JFE Bear 5,581' 4,435' BOT SLZXP LTP Packers and SSSV (type, measured and true vertical depth)(3) Tendaka Swell N/A See Above N/A 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: 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: N/A Scott Pessetto 323-544 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. scott.pessetto@hilcorp.com 907-564-4373 113' 0 Size 113' 4,436' 0 15200 Water-BblOil-Bbl 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 0500154 Junk measured Length measured true vertical Packer MD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-027 50-029-23566-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047437 & ADL0047438 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT B-28 5,437' Casing Conductor 4,341'11,000' 2,880' 5,721'Surface Tieback Liner 20" 9-5/8" 7" 113' 5,687' TVD 7,500psi 5,750psi 6,890psi 8,430psi 5,570' 2,835' 3,090psi 4,790psi 5,563, 6,167, 6,238 & 6,878 4,433, 4.433, 4,423 & 4,422 Tieback 2,912' 4,434' 6,890psi 4,790psi2,659' 7" Burst N/A Collapse N/A measuredPlugs PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 10:54 am, Jan 31, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.01.30 13:03:19 - 09'00' Taylor Wellman (2143) RBDMS JSB 020824 DSR-1/31/24WCB 2-13-2025 _____________________________________________________________________________________ Revised By: TDF 1/29/2024 SCHEMATIC Milne Point Unit Well: MPU B-28 Last Completed: 11/17/2023 PTD: 216-027 TD =11,000’ (MD) / TD =4,341’(TVD) 20” Orig. KB Elev.: 57.2’/ GL Elev.: 23.5’ RKB – THF: 30.55’ (Doyon 14) 4 79-5/8” 1 2 3 5 See Screen/ Solid Liner Detail PBTD =10,995’ (MD) / PBTD =4,341’(TVD) 9-5/8” ‘ES’ Cementer @ 2,126’ 4-1/2” Shoe @ 11,000’ 6 8 9 10 4-1/2” 7” Bad Pipe: 4,538’ to 4,622’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 113’ N/A 9-5/8" Surface 40 / L-80 / TC II 8.835 Surface 5,721’ 0.0758 7” Tieback 26 / L-80 / TXP 6.151 Surface 5,570’ 0.0368 4-1/2” Liner (250ђ Screens) 12.6 / L-80 / H521 3.958 5,563’ 11,000’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / Cr13 / JFE Bear 3.958 Surface 5,581’ 0.0087 OPEN HOLE / CEMENT DETAIL 42" ~29 bbls (6 Yards dumped down backside) 12-1/4" 333 bbls in 12-1/4” Hole Cement to Surface 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 221’ Max Hole Angle = 94.5 deg. @ 8,502’ MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23566-00-00 Drilled and Cased by Doyon 14 - 3/25/2016 Install 7” Tieback and Tubing by Doyon 14 – 8/27/2022 4-1/2” Jet Pump Completion by ASR – 11/17/2023 4-1/2” SOLID LINER DETAIL Jts Top (MD) Btm (MD) 31 5,585’ 6,934’ 2 7,433’ 7,516’ 2 8,385’ 8,468’ 3 8,676’ 8,799’ SWELL PACKER DETAIL Top (MD) Btm (MD) 6,175’ 6,186’ 6,238’ 6,249’ 6,878’ 6,888’ JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 4,753’ Sliding Sleeve opens down, 3.813" X Profile 2 4,814’ Zenith Gauge Carrier, Nickel Coated 3 4,875’ Tripoint 7'' x 4-1/2" Perm. packer 4 4,937’ 4-1/2” XN-Nipple w/ 3.725" No-Go 5 5,541’ 4-1/2” Mule Shoe – Bottom @ 5,581’ Lower Completion 6 5,563’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.200” 7 5,562’ 7” Tieback Assy. (8.25” OD No-Go @ 5,561’) 6.151” 8 See Below 5-1/2” 17# Tendeka Swell Packers 4.982” 9 10,963’ 4-1/2” Drillable Packoff Sub 2.400” 10 10,995’ WIV Valve LTC BxB (1.5” Ball on Seat/Closed) - 4-1/2” SCREENS LINER DETAIL Jts Top (MD) Btm (MD) 12 6,934’ 7,433’ 21 7,516’ 8,385’ 5 8,468’ 8,676’ 52 8,799’ 10,961’ Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 ASR 50-029-23566-00-00 216-027 11/13/2023 11/20/2023 Pull completion PKR free. Pump 150 bbls of 8.4 ppg source water dw TBG returning to IA. Monitor well (static). POOH w/ 4- 1/2" Jet pump completion, Cont. to POOH No operations to report. 11/11/2023 - Saturday MIRU. Perform shell test & chase leaks. After successful shell test start BOPE test. Test BOPE as per approved sundry T/ 250 psi low & 2500 psi high for 5/5 charted mins. AOGCC waived witness to testing. 11/14/2023 - Tuesday 11/12/2023 - Sunday No operations to report. 11/13/2023 - Monday 11/10/2023 - Friday No operations to report. 11/8/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 11/9/2023 - Thursday No operations to report. Test BOPE as per approved sundry T/ 250 psi low & 2500 psi high for 5/5 charted mins. AOGCC waived witness to testing Well Name Rig API Number Well Permit Number Start Date End Date MP B-28 ASR #1 / SL 50-029-23566-00-00 216-027 11/13/2023 11/20/2023 No operations to report. Past 24 hrs: Pressure up TBG to set PKR. Have communication to IA. Trouble shoot. TBG & IA combo MIT to 3,000 PSI F/ 30 charted mins. (Good test) Set BPV. RDMO. SIMOPS: Nipple down the tree and nipple up the BOP stack on E-37. Install well house and cap, install heater in the wellhouse. Rig released from B-28 @ 0600 HRS. 11/18/2023 - Saturday Slickline: WELL S/I ON ARRIVAL. PULL BALL & ROD @ 4917' SLM. RAN HES LDL. LOG FROM 4912' SLM / 4200' SLM. PULL 4-1/2 RHC @ 4926' SLM / 4936' MD. WELL S/I ON DEPARTURE. 11/21/2023 - Tuesday 11/19/2023 - Sunday Slickline: PULL BALL & ROD @ 4895' SLM. LRS FREEZE PROTECT TBG 40 BBLS OF 60/ 40 MEOH. SET BALL & ROD @ 4895' SLM. RUN TANDOM 4-1/2" 42 BO'S & CYCLE SSD THEN LEAVE CLOSED @4,722' SLM (4,702' MD). LRS ATTEMPT MIT-IA. TBG TRACKING IA. RAN 4-1/2" D&D HOLE FINDER. SET @4,772' SLM, 4,737' SLM, 4,682' SLM, ALL FAIL W/ IA . COMMUNICATION. PUH & SET @3,683' SLM, PASS W/ TBG @1,000 PSI & IA @250 PSI. RAN 4-1/2" D&D HOLE FINDER, SET @4,728' SLM, 4,681' SLM, 4,576' SLM ALL FAIL W/ IA COMMUNICATION. PUH & SET @4,472' SLM, & 4,372' SLM, PASS W/ TBG @1,000 PSI & IA @250 PSI. PULL BALL & ROD @4,893' SLM. LRS FREEZE PROTECT IA W/ 44 BBLS. SET BALL & ROD @4,893' SLM. WELL S/I ON DEPARTURE. 11/20/2023 - Monday 11/17/2023 - Friday Past 24 hrs: Cont. RIH w/ 4-1/2" jet pump completion, Tag, space out. land hanger, RILDS. Reverse in CI brine. Drop ball & rod. Pressure up TBG. Have communication to IA. Trouble shoot. 11/15/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Past 24 hrs: Cont. POOH w/ 4-1/2" Jet pump completion. L/D completion jewelry. P/U 7" scraper assy. RIH. Thaw out kelly hose. Wash dw & stuff returns into liner. 11/16/2023 - Thursday Past 24 hrs: Cont. Wash dw, fluff& stuff returns into liner. Monitor well. POOH. L/D scraper BHA. R/U slick line. RIH w/ READ caliper tool. POOH. R/D slick line. P/U & M/U 4-1/2" jet pump completion. Slickline: WELL S/I on ARRIVAL. RAN READ 40 ARM CALIPER LOG FROM 5144' SLM TO 0' SLM (good data). WELL S/I ON DEPARTURE. Have communication to IA. Trouble shoot. AN HES LDL. LOG FROM 4912' SLM / 4200' SLM. PULL 4-1/2 RHC @ 4926' SLM / 4936' MD. WELL S/I ON DEPARTURE POOH w/ 4-1/2" Jet pump completion. P/U & M/U 4-1/2" jet pump completion. RIH w/ 4-1/2" jet pump completion, Tag, space out. land hanger, RILDS. Reverse in CI brine. Drop ball & rod. Pressure up TBG. 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: P & R Rev. Circ Jet Pump 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,000'N/A Casing Collapse Conductor N/A Surface 3,090psi Tieback 4,790psi Tieback 4,790psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Baker 7" x 4-1/2" Ret. Prem. & 5-1/2" Tendaka Swell Packers (x3) and N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 5,563 MD/ 4,433 TVD, 6,175 MD/ 4,423, 6,238 MD/ 4,423 TVD & 6,878 MD/ 4,422 TVD 11,000' Perforation Depth MD (ft): 5,571' See Schematic 5,437' See Schematic 4-1/2" 4,341'4-1/2" 113' 20" 9-5/8" 7-5/8' 5,687' 7-5/8'2,659' 2,880' MD N/A 6,890psi 5,750psi 6,890psi 4,436' 2,835' 4,434' 5,721' 2,912' Length Size Proposed Pools: 113' 113' 12.6 / L-80 / TXP TVD Burst 5,581' 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047437 / ADL0047438 216-027 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23566-00-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/20/2023 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT B-28 4,341' 10,995' 4,341' 746 N/A MILNE POINT / SCHRADER BLUFF OIL No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:28 am, Oct 05, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.10.04 10:33:43 - 08'00' Taylor Wellman (2143) 323-544 746 MGR30OCT23 DSR-10/5/23SFD 10/5/2023 10-404 * BOPE test to 2500 psi. * Before pulling tubing, assure overbalanced fluids to pore pressure and that fluids are balanced T x IA. *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.30 16:09:22 -08'00'10/30/23 RBDMS JSB 110223 Well: MPB-28 RWO PTD: 216-027 API: 50-029-23566-00-00 Well Name:MPU B-28 API Number:50-029-23566-00-00 Current Status:JP Producer Rig:ASR 1 Estimated Start Date:October 20, 2023 Estimated Duration:5 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:216-027 First Call Engineer:Scott Pessetto 801-822-2203 Second Call Engineer:Brian Glasheen 907-545-1144 AFE Number: Current Bottom Hole Pressure:1,172 psi @ 4266’ TVD DHG reading 9/26/23 Maximum Expected BHP:1,172 psi @ 4266’ TVD 5.28 PPGE Max. Anticipated Surface Pressure:746 psi Gas Column Gradient (0.1 psi/ft) Min ID:3.725” @ 4910’ XN Nipple Brief Well Summary MPB-28 was drilled and completed in 2016 as a gas lift producer. In 2022 MPB-28 was converted to a jet pump completion to increase drawdown on the reservoir. During the recompletion to jet pump in 2022 the 7-5/8” tieback liner was pulled and a new 7” tieback liner was installed. Recent poor jet pump performance and a caliper log indicate the tubing has developed a hole(s) in the low velocity area below the jet pump. A workover is proposed to pull the tubing and re-run new tubing. Objective 1.Pull 4-1/2” reverse circulation jet pump completion. 2.Run new 4-1/2” reverse circulation jet pump completion with corrosion resistant tubing tail. Notes on Well Condition x New 7” casing installed 8/26/2022 x MIT-OA to 1,500 psi passed on 9/28/2023 x Baker Premier production packer cut to release @ 4,841’ RKB x Sliding sleeve currently open @ 4,702’ RKB x Planned SSV Pilot Settings o Power fluid SSV high pressure trip will not exceed 3,000 psi o Power fluid SSV low pressure trip will be set to 50 percent of header pressure o Production SSV high pressure trip not to exceed 650 psi o Production SSV low pressure trip not to be below 75 psi Procedure: Slickline (Non-Sundried Work) 1. MIRU E-line. Pressure test PCE to 250 low / 2,500 psi high. 2. Drift with dummy mechanical cutter to XN nipple at 4,910’. 3. RDMO E-Line (Non-Sundried Work) 1. MIRU E-line. Pressure test PCE to 250 low / 2,500 psi high. 2. Pickup mechanical cutter and CCL 3. Confirm located inside packer cut zone. a. See attached packer schematic b. Cut zone is 2.01’ in length. c. Top of pup collar above packer to top of cut zone is 16.65’. d. Top of pup collar below packer to the bottom of the cut zone is 11.41’. 4. Perform cut. 5. RDMO. Well: MPB-28 RWO PTD: 216-027 API: 50-029-23566-00-00 Brief RWO Procedure (Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If required, kill well w/ 8.4 ppg source water prior to setting CTS plug. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure off casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well w/ 8.4 ppg source water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2022 workover was 56k lbs on D14 (40k block weight removed). b. Baker Premier packer was cut pre-rig. If the packer does not release: i. Mobilize E-Line, cut tubing at first joint above packer. Cut at 4815’ RKB. ii. Lay down 4-1/2” jet pump completion. iii. Call out BOT to mill and fish Premier packer 6. Confirm hanger free, lay down tubing hanger. 7. POOH and lay down the 4-1/2” tubing. a. Keep all jewelry and tubing joints 1-115 for reuse. b. Note any over-torqued or damaged connections and set aside for disposal. 8. PU 7” casing scraper and mule shoe. 9. Clean out down to liner top packer focusing on cleaning up solids between old packer depth and liner top (4,841’ – 5,563’ RKB). a. Returns will be challenged, focus on fluffing and stuffing solids into production liner to reduce potential corrosion on the 7” casing after running the new completion. 10. Pick up new 4-1/2” jet pump completion and RIH to tag on XO sub below SLZXP liner top packer at ~5,581’ RKB (Doyon 14). a. Clamp gauge wire every other joint b. Test gauge every 2,000’. Nom. (OD)Length Item Lb/ft Material Notes 4-1/2"41 Mule Shoe Jt 12.6 13Cr Set at 5581' 4-1/2"615 4-1/2" jts 12.6 13Cr 4-1/2"10 4-1/2" Pup 12.6 9Cr 5.03"2 3.813" XN Nipple - RHC Installed 9Cr ~4913, 68° 4-1/2"10 4-1/2" Pup 12.6 9Cr 4-1/2"41 4-1/2" jts 13Cr 4-1/2"10 4-1/2" Pup 12.6 9Cr 6"10 7" x 4-1/2" Retrievable Packer 9Cr 4-1/2"10 4-1/2" Pup 12.6 9Cr 4-1/2"41 4-1/2" jts 12.6 13Cr Assure overbalanced fluids to pore pressure and that fluids are balanced T x IA. -mgr Well: MPB-28 RWO PTD: 216-027 API: 50-029-23566-00-00 4-1/2"10 4-1/2" pup 12.6 9Cr 4-1/2"6 Gauge Carrier, Baker Zenith 9Cr 4-1/2"10 4-1/2" pup 12.6 9Cr 4-1/2"41 4-1/2" jts 12.6 13Cr 4-1/2"10 4-1/2" TXP Pup Jt 12.6 9Cr 5.6"2 4-1/2" Sliding Sleeve, 3.813" X, open down, port covered for I wire L-80 4-1/2"10 4-1/2" TXP Pup Jt 12.6 L-80 4-1/2"4633 4-1/2" TXP 12.6 L-80 4-1/2"10 Space out pup 12.6 L-80 30 Tbg hanger, Seaboard, TC-1A L-80 11. Space out and land hanger. a. Take extra care to not damage gauge wire while landing hanger. b. Note pickup and slack off weight prior to landing hanger. 12. RILDS. Lay down landing joint. 13. Pump 50 barrels of 1% KCL with 1% by volume corrosion inhibitor (CI) down the IA, taking returns up the tubing. a. This is to inhibit the casing from below the sliding sleeve to the top of the liner top packer. 14. Displace CI with 55 barrels of diesel freeze protect down the annulus. 15. Consult OE/WSL on whether to FP tubing prior to RDMO. 16. Drop ball and rod and pump to seat in XN nipple below the packer. Set the packer per vendor setting procedure. 17. Pressure test the tubing to 3,000 psi, charted for 30 minutes. 18. Pressure test the IA to 3,000 psi, charted for 30 minutes. a. B-pad power fluid pressure is 2,600 psi. 19. Set CTS. 20. RDMO ASR. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. 5. Pull CTS. 6. RD crane. Move 500 bbl returns tank and rig mats to next well location. 7. Replace gauge(s) if removed. 8. Turn well over to production. RU well house and flowlines for a Jet Pump completion. Slickline 1. Spot Slickline unit and RU. 2. Pressure test lubricator to 250 psi low and 2,500 psi high. 3. Pull ball and rod. 4. Pull RHC profile. 5. Shift sliding sleeve open 6. Set 12B jet pump in sliding sleeve. Well: MPB-28 RWO PTD: 216-027 API: 50-029-23566-00-00 Attachments: 1. Well Schematic Current 2. Well schematic Proposed 3. BOP Drawing 4. Baker Premier drawing _____________________________________________________________________________________ Revised By: TDF 9/6/2022 SCHEMATIC Milne Point Unit Well: MPU B-28 Last Completed: 8/27/2022 PTD: 216-027 TD =11,000’ (MD) / TD =4,341’(TVD) 20” Orig. KB Elev.:57.2’/ GL Elev.: 23.5’ RKB – THF: 30.55’ (Doyon 14) 4 79-5/8” 1 2 3 5 See Screen/ Solid Liner Detail PBTD =10,995’ (MD) / PBTD =4,341’(TVD) 9-5/8” ‘ES’ Cementer @ 2,126’ 4-1/2” Shoe @ 11,000’ 6 8 9 10 4-1/2” 7” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 113’ N/A 9-5/8" Surface 40 / L-80 / TC II 8.835 Surface 5,721’ 0.0758 7” Tieback 26 / L-80 / TXP 6.151 Surface 5,570’ 0.0368 4-1/2” Liner (250ђ Screens) 12.6 / L-80 / H521 3.958 5,563’ 11,000’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.958 Surf 5,581’ 0.0087 OPEN HOLE / CEMENT DETAIL 42" ~29 bbls (6 Yards dumped down backside) 12-1/4" 333 bbls in 12-1/4” Hole Cement to Surface 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 221’ Max Hole Angle = 94.5 deg. @ 8,502’ MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23566-00-00 Drilled and Cased by Doyon 14 - 3/25/2016 Install 7” Tieback and Tubing By Doyon 14 – 8/27/2022 4-1/2”SOLID LINER DETAIL Jts Top (MD) Btm (MD) 31 5,585’ 6,934’ 2 7,433’ 7,516’ 2 8,385’ 8,468’ 3 8,676’ 8,799’ SWELL PACKER DETAIL Top (MD) Btm (MD) 6,175’ 6,186’ 6,238’ 6,249’ 6,878’ 6,888’ JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 4,702’ Sliding Sleeve opens down, 3.813" X profile, covered ports for I-wire bypass 2 4,774’ Gauge Carrier, Baker, Zenith Gauge 3 4,841’ Baker 7'' x 4-1/2" Retrievable Premier packer 4 4,910’ 4-1/2” XN-Nipple w/ 3.725" No-Go 5 5,541’ 4-1/2” WLEG – Bottom @5,581 Lower Completion 6 5,563’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.200” 7 5,562’ 7” Tieback Assy. (8.25” OD No-Go @ 5,561’) 6.151” 8 See Below 5-1/2” 17# Tendeka Swell Packers 4.982” 9 10,963’ 4-1/2” Drillable Packoff Sub 2.400” 10 10,995’ WIV Valve LTC BxB (1.5” Ball on Seat/Closed) - 4-1/2”Screens LINER DETAIL Jts Top (MD) Btm (MD) 12 6,934’ 7,433’ 21 7,516’ 8,385’ 5 8,468’ 8,676’ 52 8,799’ 10,961’ _____________________________________________________________________________________ Revised By: TDF 9/26/2023 PROPOSED Milne Point Unit Well: MPU B-28 Last Completed: 8/27/2022 PTD: 216-027 TD =11,000’ (MD) / TD =4,341’(TVD) 20” Orig. KB Elev.:57.2’/ GL Elev.: 23.5’ RKB – THF: 30.55’ (Doyon 14) 4 79-5/8” 1 2 3 5 See Screen/ Solid Liner Detail PBTD =10,995’ (MD) / PBTD =4,341’(TVD) 9-5/8” ‘ES’ Cementer @ 2,126’ 4-1/2” Shoe @ 11,000’ 6 8 9 10 4-1/2” 7” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 78.6 / A-53 / Weld N/A Surface 113’ N/A 9-5/8" Surface 40 / L-80 / TC II 8.835 Surface 5,721’ 0.0758 7” Tieback 26 / L-80 / TXP 6.151 Surface 5,570’ 0.0368 4-1/2” Liner (250ђ Screens) 12.6 / L-80 / H521 3.958 5,563’ 11,000’ 0.0152 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.958 Surface ±4,841’ 0.0087 4-1/2" Tubing 12.6 / Cr13 / JFE Bear 3.958 ±4,841’ ±5,581’ 0.0087 OPEN HOLE / CEMENT DETAIL 42" ~29 bbls (6 Yards dumped down backside) 12-1/4" 333 bbls in 12-1/4” Hole Cement to Surface 8-1/2” Cementless Screens Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 221’ Max Hole Angle = 94.5 deg. @ 8,502’ MD TREE & WELLHEAD Tree Seaboard 3 1/8" 5M Wellhead Seaboard 16 3/4" 3M x 11" 5M Multibowl w/11" x 3 1/2" EUE Top and Bottom with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23566-00-00 Drilled and Cased by Doyon 14 - 3/25/2016 Install 7” Tieback and Tubing by Doyon 14 – 8/27/2022 4-1/2” SOLID LINER DETAIL Jts Top (MD) Btm (MD) 31 5,585’ 6,934’ 2 7,433’ 7,516’ 2 8,385’ 8,468’ 3 8,676’ 8,799’ SWELL PACKER DETAIL Top (MD) Btm (MD) 6,175’ 6,186’ 6,238’ 6,249’ 6,878’ 6,888’ JEWELRY DETAIL No. Top MD Item ID Upper Completion 1 ±4,702’ Sliding Sleeve opens down, 3.813" X profile, covered ports for I-wire bypass 2 ±4,774’ Gauge Carrier, Baker, Zenith Gauge 3 ±4,841’ Baker 7'' x 4-1/2" Retrievable Premier packer 4 ±4,910’ 4-1/2” XN-Nipple w/ 3.725" No-Go 5 ±5,541’ 4-1/2” WLEG – Bottom @ ±5,581 Lower Completion 6 5,563’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.200” 7 5,562’ 7” Tieback Assy. (8.25” OD No-Go @ 5,561’) 6.151” 8 See Below 5-1/2” 17# Tendeka Swell Packers 4.982” 9 10,963’ 4-1/2” Drillable Packoff Sub 2.400” 10 10,995’ WIV Valve LTC BxB (1.5” Ball on Seat/Closed) - 4-1/2” SCREENS LINER DETAIL Jts Top (MD) Btm (MD) 12 6,934’ 7,433’ 21 7,516’ 8,385’ 5 8,468’ 8,676’ 52 8,799’ 10,961’ Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR 30.07' Drift Size : 3.833" Type of Tool :Inspectors : Date : Well No. : Threads : Rig : 598-387 7" Preimer Packer Supervisor :Date :Field Inspector :R.Wood 4-½" TXP Box x TXP Pin down . MPB-28 Doyon 14 8/22/2022 Product Removal Record Operator : Hilcorp Alaska, LLC. Uncontrolled Form-Data Reference only Verified by Caliper Serial No. BAK 1256 5.97" 5.88" 5.89" 5.89" 5.86" 5.88" 5.90" 3.97" 6.85' 4.93" 3.96" 4.53" CU T Z O N E 3858 ft/lbs Premier Production Packer Size : Threads : Initial Shear : Set Shear : Comm. No. : S/N : 598-387 , 7.00" 4.5 IN 12.6# TC-II 1,650 PSI 2,100 PSI H784630265 107862184 10.52' 2.01' 9.75' Tubing Pup Jt. Size : 4.50" 12.6# L-80 Threads : TCII Box x TXP Pin Drifted 3.833" Customer Stock Customer Stock 5.04" 3.96" 4.53" 9.80' Tubing Pup Jt. Size : 4.50" 12.6# L-80 Threads : TXP Box x TCII Pin Drifted 3.833" Customer Stock 2700 psi set @ Hold 15 min. 4151 ft/lbs 3.73' 4.93" 4.52" 4.52" Batch# 0001887715 Drifted 3.833" Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/29/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230929 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-28 50029235660000 216027 9/22/2023 READ Caliper Survey MPU G-02 50029219260000 189028 9/18/2023 READ Caliper Survey MPU K-13 50029226550000 196040 9/18/2023 READ Caliper Survey MPU L-29 50029225430000 195009 9/17/2023 READ Caliper Survey Please include current contact information if different from above. T38019 T38020 T38021 T38022 9/29/2023 MPU B-28 50029235660000 216027 9/22/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.09.29 12:48:41 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT B-28 JBR 09/06/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Used three test joints for test 3 1/2", 5"and 7-5/8".TIW and dart valve tested good. Tested gas alarms with rig electrician (all good) Tested PVT's and flow paddle with Driller. Accumulator air pump failed during bop test and was replaced, new pump working well. Test Results TEST DATA Rig Rep:HansenOperator:Hilcorp Alaska, LLC Operator Rep:Doug Yessak Rig Owner/Rig No.:Doyon 14 PTD#:2160270 DATE:8/22/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopSTS220823180615 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9 MASP: 774 Sundry No: 322-497 CLOSURE TIME (sec) Time/Pressure P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8"x5"P #2 Rams 1 blind P #3 Rams 1 7 5/8"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"x5000 P HCR Valves 2 3 1/8"x5000 P Kill Line Valves 2 3 1/8"x5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3025 Pressure After Closure P1600 200 PSI Attained P34 Full Pressure Attained P192 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P1954 ACC Misc FP1 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P15 #1 Rams P8 #2 Rams P8 #3 Rams P8 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 9 9 9 99 9 9 9 9 9 9 FP Accumulator air pump failed during bop test By Anne Prysunka at 1:43 pm, Sep 14, 2022 MGR16SEP2022 7\SHRI5HTXHVW $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 5HSDLU:HOO 2SHUDWLRQVVKXWGRZQ 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH 3XOO7XELQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HHQWHU6XVS:HOO $OWHU&DVLQJ 2WKHU 5HFRPSOHWHDV-HW3XPS 2SHUDWRU1DPH &XUUHQW:HOO&ODVV 3HUPLWWR'ULOO1XPEHU ([SORUDWRU\ 'HYHORSPHQW 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^ƵƌĨĂĐĞ ϭϭϯ͛ Eͬ ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬd// ϴ͘ϱϮϱ ^ƵƌĨĂĐĞ ϱ͕ϳϮϭ͛ Ϭ͘Ϭϳϱϴ ϳͲϱͬϴ͟dŝĞďĂĐŬ Ϯϵ͘ϳͬ>ͲϴϬͬ^>/:// ϲ͘ϳϱϬ ^ƵƌĨĂĐĞ Ϯ͕ϵϭϮ͛ Ϭ͘Ϭϰϱϵ dŝĞďĂĐŬ Ϯϵ͘ϳͬ>ͲϴϬͬsĂŵ^d> ϲ͘ϳϱϬ Ϯ͕ϵϭϮ͛ ϱ͕ϱϳϭ͛ Ϭ͘Ϭϰϱϵ ϰͲϭͬϮ͟ >ŝŶĞƌ;ϮϱϬђ^ĐƌĞĞŶƐͿ ϭϮ͘ϲͬ>ͲϴϬͬ,LJĚϱϮϭ ϯ͘ϴϯϯ ϱ͕ϱϲϯ͛ ϭϭ͕ϬϬϬ͛ Ϭ͘ϬϭϱϮ dh/E' d/> ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬ h ϴƌĚ Ϯ͘ϴϲϳ ^ƵƌĨ ϱ͕ϱϴϲ͛ Ϭ͘ϬϬϴϳ KW E,K> ͬ D Ed d/> ϰϮΗ ΕϮϵďďůƐ;ϲzĂƌĚƐĚƵŵƉĞĚĚŽǁŶďĂĐŬƐŝĚĞͿ ϭϮͲϭͬϰΗ ϯϯϯďďůƐŝŶϭϮͲϭͬϰ͟,ŽůĞĞŵĞŶƚƚŽ^ƵƌĨĂĐĞ ϴͲϭͬϮ͟ ĞŵĞŶƚůĞƐƐ^ĐƌĞĞŶƐ>ŝŶĞƌŝŶϴͲϭͬϮ͟ŚŽůĞ t >>/E>/Ed/KE d/> <KWΛϮϮϭ͛ DĂdž,ŽůĞŶŐůĞсϵϰ͘ϱĚĞŐ͘Λϴ͕ϱϬϮ͛D dZ Θt >>, dƌĞĞ ^ĞĂďŽĂƌĚϯϭͬϴΗϱD tĞůůŚĞĂĚ ^ĞĂďŽĂƌĚϭϲϯͬϰΗϯDdžϭϭΗϱDDƵůƚŝďŽǁůǁͬϭϭΗdžϯϭͬϮΗ h dŽƉĂŶĚ ŽƚƚŽŵǁŝƚŚϯΗ/tΗ,ΗWsƉƌŽĨŝůĞ͘ϮĞĂϯͬϴΗEWdĐŽŶƚƌŽůůŝŶĞƐ͘ ' E Z>t >>/E&K W/͗ϱϬͲϬϮϵͲϮϯϱϲϲͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďLJŽLJŽŶϭϰͲϯͬϮϱͬϮϬϭϲ ϰͲϭͬϮ͟^K>/>/E Z d/> :ƚƐ dŽƉ;DͿ ƚŵ;DͿ ϯϭ ϱ͕ϱϴϱ͛ ϲ͕ϵϯϰ͛ Ϯ ϳ͕ϰϯϯ͛ ϳ͕ϱϭϲ͛ Ϯ ϴ͕ϯϴϱ͛ ϴ͕ϰϲϴ͛ ϯ ϴ͕ϲϳϲ͛ ϴ͕ϳϵϵ͛ ^t >>W< Z d/> dŽƉ;DͿ ƚŵ;DͿ ϲ͕ϭϳϱ͛ ϲ͕ϭϴϲ͛ ϲ͕Ϯϯϴ͛ ϲ͕Ϯϰϵ͛ ϲ͕ϴϳϴ͛ ϲ͕ϴϴϴ͛ : t >Zz d/> EŽ͘ dŽƉD /ƚĞŵ / hƉƉĞƌŽŵƉůĞƚŝŽŶ '>DĞƚĂŝůʹϯͲϭͬϮ͟džϭ͟^WDKͲϭ͘ϬDǁͬ<>ĂƚĐŚĞƐ ϭ ϯϬ͘ϱϱ͛ dƵďŝŶŐ,ĂŶŐĞƌ͕ϯͲϭͬϮ͟ h dŽƉΘƚŵ Ϯ͘ϵϵϮ͟ Ϯ Ϯ͕ϬϬϴ͛ ϯ͘ϱ͟yEŝƉƉůĞƐƐĞŵďůLJ͕Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ Ϯ͘ϴϭϯ͟ ϯϮ͕ϭϳϴ͛^dηϯ͗WŽƌƚсϴͬϲϰ͕͟ϭ͕ϱϰϳdZK͕ƐĞƚϯͬϯϬͬϭϲ͕Ϯϭϲϯds Ϯ͘ϵϲϮ͟ ϰϰ͕ϬϬϵ͛^dηϮ͗WŽƌƚсϭϮͬϲϰ͕͟ϭ͕ϳϳϬdZK͕ƐĞƚϯͬϯϬͬϭϲ͕ϯ͕ϳϲϬds Ϯ͘ϵϲϮ͟ ϱϰ͕ϲϵϲ͛^dηϭ͗WŽƌƚсϮϬͬϲϰ͕͟K'>s͕ƐĞƚϱͬϬϱͬϮϭ͕ϰ͕ϮϮϰds Ϯ͘ϵϲϮ͟ ϲ ϰ͕ϳϴϴ͛ ϯ͘ϱ͟, ^y^ůŝĚŝŶŐ^ůĞĞǀĞ͕yƉƌŽĨŝůĞ͕Ϯ͘ϴϭϯ͟ƐĞĂůďŽƌĞ Ϯ͘ϴϭϯ͟ ϳ ϰ͕ϴϰϰ͛ ϳͲϱͬϴ͟,ĂůůŝďƵƌƚŽŶW,>WĂĐŬĞƌϱϰ͘ϲŬ^ŚĞĂƌƚŽZĞůĞĂƐĞ Ϯ͘ϴϴϱ͟ ϴ ϰ͕ϴϵϭ͘ϱ͛ ϯ͘ϱ͟yEEŝƉƉůĞϮ͘ϳϱϬ͟EŽͲ'Ž͕Ϯ͘ϴϭϯ͟WĂĐŬŝŶŐŽƌĞ DŝŶ/сϮ͘ϳϱϬ͟Ϯ͘ϵϵϮ͟ ϵ ϱ͕ϱϱϰ͛ ϯͲϭͬϮ͟DƵůĞ^ŚŽĞǁũƚ͘ Ϯ͘ϵϵϮ͟ >ŽǁĞƌŽŵƉůĞƚŝŽŶ ϭϬ ϱ͕ϱϲϯ͛ Kd^>yW>ŝŶĞƌdŽƉWĂĐŬĞƌǁͬ^ůŝƉƐϳ͟džϵͲϱͬϴ͟ ϲ͘ϮϬϬ͟ ϭϭ ϱ͕ϱϲϮ͛ ϳͲϱͬϴ͟dŝĞďĂĐŬƐƐLJ͘;ϴ͘Ϯϱ͟KEŽͲ'ŽΛϱ͕ϱϲϭ͛Ϳ ϲ͘ϭϱϭ͟ ϭϮ ϱ͕ϱϴϱ͛ ϳ͟,ϱϲϯdžϰͲϭͬϮ͟,ϱϮϭ>ͲϴϬyK ϯ͘ϵϬϬ͟ ϭϯ ^ĞĞĞůŽǁ ϱͲϭͬϮ͟ϭϳηdĞŶĚĞŬĂ^ǁĞůůWĂĐŬĞƌƐ ϰ͘ϵϴϮ͟ ϭϰ ϭϬ͕ϵϲϯ͛ ϰͲϭͬϮ͟ƌŝůůĂďůĞWĂĐŬŽĨĨ^Ƶď Ϯ͘ϰϬϬ͟ ϭϱ ϭϬ͕ϵϵϱ͛ t/ssĂůǀĞ>ddž;ϭ͘ϱ͟ĂůůŽŶ^ĞĂƚͬůŽƐĞĚͿ Ͳ ϰͲϭͬϮ͟^ĐƌĞĞŶƐ>/E Z d/> :ƚƐ dŽƉ;DͿ ƚŵ;DͿ ϭϮ ϲ͕ϵϯϰ͛ ϳ͕ϰϯϯ͛ Ϯϭ ϳ͕ϱϭϲ͛ ϴ͕ϯϴϱ͛ ϱ ϴ͕ϰϲϴ͛ ϴ͕ϲϳϲ͛ ϱϮ ϴ͕ϳϵϵ͛ ϭϬ͕ϵϲϭ͛ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB ZĞǀŝƐĞĚLJ͗dϴͬϭϴͬϮϬϮϮ WZKWK^ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWhͲϮϴ >ĂƐƚŽŵƉůĞƚĞĚ͗ϯͬϮϱͬϮϬϭϲ Wd͗ϮϭϲͲϬϮϳ ^/E' d/> ^ŝnjĞdLJƉĞtƚͬ'ƌĂĚĞͬŽŶŶ/dŽƉƚŵW& ϮϬΗŽŶĚƵĐƚŽƌϳϴ͘ϲͬͲϱϯͬtĞůĚEͬ^ƵƌĨĂĐĞϭϭϯ͛Eͬ ϵͲϱͬϴΗ^ƵƌĨĂĐĞϰϬͬ>ͲϴϬͬd//ϴ͘ϴϯϱ^ƵƌĨĂĐĞϱ͕ϳϮϭ͛Ϭ͘Ϭϳϱϴ ϳͲϱͬϴ͟dŝĞďĂĐŬϮϵ͘ϳͬ>ͲϴϬͬ^>/://ϲ͘ϴϳϱ^ƵƌĨĂĐĞϮ͕ϵϭϮ͛Ϭ͘Ϭϰϱϵ dŝĞďĂĐŬϮϵ͘ϳͬ>ͲϴϬͬ,ϱϮϭϲ͘ϴϳϱϮ͕ϵϭϮ͛ϰ͕ϴϬϬ͛Ϭ͘Ϭϰϱϵ ϳ͟dŝĞďĂĐŬϮϲͬ>ͲϴϬͬdϲ͘ϭϱϭϰ͕ϴϬϬ͛ϱ͕ϱϲϮ͛Ϭ͘Ϭϯϲϴ ϰͲϭͬϮ͟>ŝŶĞƌ;ϮϱϬђ^ĐƌĞĞŶƐͿϭϮ͘ϲͬ>ͲϴϬͬ,ϱϮϭϯ͘ϵϱϴϱ͕ϱϲϯ͛ϭϭ͕ϬϬϬ͛Ϭ͘ϬϭϱϮ dh/E' d/> ϰͲϭͬϮΗdƵďŝŶŐϭϮ͘ϲͬ>ͲϴϬͬ h ϴƌĚϯ͘ϵϱϴ^ƵƌĨцϱ͕ϱϴϬ͛Ϭ͘ϬϬϴϳ KW E,K> ͬ D Ed d/> ϰϮΗΕϮϵďďůƐ;ϲzĂƌĚƐĚƵŵƉĞĚĚŽǁŶďĂĐŬƐŝĚĞͿ ϭϮͲϭͬϰΗϯϯϯďďůƐŝŶϭϮͲϭͬϰ͟,ŽůĞĞŵĞŶƚƚŽ^ƵƌĨĂĐĞ ϴͲϭͬϮ͟ĞŵĞŶƚůĞƐƐ^ĐƌĞĞŶƐ>ŝŶĞƌŝŶϴͲϭͬϮ͟ŚŽůĞ t >>/E>/Ed/KE d/> <KWΛϮϮϭ͛ DĂdž,ŽůĞŶŐůĞсϵϰ͘ϱĚĞŐ͘Λϴ͕ϱϬϮ͛D dZ Θt >>, dƌĞĞ^ĞĂďŽĂƌĚϯϭͬϴΗϱD tĞůůŚĞĂĚ^ĞĂďŽĂƌĚϭϲϯͬϰΗϯDdžϭϭΗϱDDƵůƚŝďŽǁůǁͬϭϭΗdžϯϭͬϮΗ h dŽƉĂŶĚ ŽƚƚŽŵǁŝƚŚϯΗ/tΗ,ΗWsƉƌŽĨŝůĞ͘ϮĞĂϯͬϴΗEWdĐŽŶƚƌŽůůŝŶĞƐ͘ ' E Z>t >>/E&K W/͗ϱϬͲϬϮϵͲϮϯϱϲϲͲϬϬͲϬϬ ƌŝůůĞĚĂŶĚĂƐĞĚďLJŽLJŽŶϭϰͲϯͬϮϱͬϮϬϭϲ ϰͲϭͬϮ͟^K>/>/E Z d/> :ƚƐdŽƉ;DͿƚŵ;DͿ ϯϭϱ͕ϱϴϱ͛ϲ͕ϵϯϰ͛ Ϯϳ͕ϰϯϯ͛ϳ͕ϱϭϲ͛ Ϯϴ͕ϯϴϱ͛ϴ͕ϰϲϴ͛ ϯϴ͕ϲϳϲ͛ϴ͕ϳϵϵ͛ ^t >>W< Z d/> dŽƉ;DͿƚŵ;DͿ ϲ͕ϭϳϱ͛ϲ͕ϭϴϲ͛ ϲ͕Ϯϯϴ͛ϲ͕Ϯϰϵ͛ ϲ͕ϴϳϴ͛ϲ͕ϴϴϴ͛ : t >Zz d/> EŽ͘dŽƉD/ƚĞŵ/ hƉƉĞƌŽŵƉůĞƚŝŽŶ '>DĞƚĂŝůʹϯͲϭͬϮ͟džϭ͟^WDKͲϭ͘ϬDǁͬ<>ĂƚĐŚĞƐ ϭцϰ͕ϳϬϬ^ůŝĚŝŶŐ^ůĞĞǀĞ Ϯцϰ͕ϳϱϬ͛ŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ'ĂƵŐĞ ϯцϰ͕ϴϬϬ͛ϳͲϱͬϴ͟,ϱϮϭƚŽϳ͟dyK ϰцϰ͕ϴϬϬ͛ϰͲϭͬϮ͟džϳ͟WĂĐŬĞƌ ϱцϰ͕ϬϬϵ͛ϰͲϭͬϮ͟yEͲEŝƉƉůĞ ϲцϱ͕ϱϴϬ͛ϰͲϭͬϮ͟t> ' >ŽǁĞƌŽŵƉůĞƚŝŽŶ ϳϱ͕ϱϲϯ͛Kd^>yW>ŝŶĞƌdŽƉWĂĐŬĞƌǁͬ^ůŝƉƐϳ͟džϵͲϱͬϴ͟ϲ͘ϮϬϬ͟ ϴϱ͕ϱϲϮ͛ϳ͟dŝĞďĂĐŬƐƐLJ͘;ϴ͘Ϯϱ͟KEŽͲ'ŽΛϱ͕ϱϲϭ͛Ϳϲ͘ϭϱϭ͟ ϵϱ͕ϱϴϱ͛ϳ͟,ϱϲϯdžϰͲϭͬϮ͟,ϱϮϭ>ͲϴϬyKϯ͘ϵϬϬ͟ ϭϬ^ĞĞĞůŽǁϱͲϭͬϮ͟ϭϳηdĞŶĚĞŬĂ^ǁĞůůWĂĐŬĞƌƐϰ͘ϵϴϮ͟ ϭϭϭϬ͕ϵϲϯ͛ϰͲϭͬϮ͟ƌŝůůĂďůĞWĂĐŬŽĨĨ^ƵďϮ͘ϰϬϬ͟ ϭϮϭϬ͕ϵϵϱ͛t/ssĂůǀĞ>ddž;ϭ͘ϱ͟ĂůůŽŶ^ĞĂƚͬůŽƐĞĚͿͲ ϰͲϭͬϮ͟^ĐƌĞĞŶƐ>/E Z d/> :ƚƐdŽƉ;DͿƚŵ;DͿ ϭϮϲ͕ϵϯϰ͛ϳ͕ϰϯϯ͛ Ϯϭϳ͕ϱϭϲ͛ϴ͕ϯϴϱ͛ ϱϴ͕ϰϲϴ͛ϴ͕ϲϳϲ͛ ϱϮϴ͕ϳϵϵ͛ϭϬ͕ϵϲϭ͛ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB KW ^, Dd/ DŝůŶĞWŽŝŶƚhŶŝƚ tĞůů͗DWhͲϮϴ Wd͗ϮϭϲͲϬϮϳ Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -08'00' From:Rixse, Melvin G (OGC) To:Brian Glasheen Cc:DOA AOGCC Prudhoe Bay Subject:20220627 1715 APPROVAL Revision 4 Sundry 322-340 : Milne well B-28 PTD: 216-027 RWO Date:Monday, June 27, 2022 5:19:54 PM Attachments:MPB-28 RWO Program Rv4 6-27-22_.pdf Brian, Sundry revision 322-340 is approved as described in the attached document. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Inspectors From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Monday, June 27, 2022 4:49 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] FW: Milne well B-28 PTD: 216-027 RWO 403 Here you go Mel. Pressure are updated to 1500 psi. Brian Glasheen Operations Engineer 907-545-1144 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, June 27, 2022 3:45 PM To: Brian Glasheen <Brian.Glasheen@hilcorp.com> Subject: [EXTERNAL] FW: Milne well B-28 PTD: 216-027 RWO 403 Brian, All pressure tests are 1500 psi or .25 psi / ftTVD. Pressure tests should be to a minimum of 1500 psi. On step 21 b. Is this a CMIT 7-5/8” X 9-5/8” because you will have a hole in the 7-5/8” above the test packer? This test should be to 1500 psi. All else looks satisfactory. Please change minimum test pressures to 1500 psi then send back to me. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Brian Glasheen <Brian.Glasheen@hilcorp.com> Sent: Wednesday, June 22, 2022 3:51 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Milne well B-28 PTD: 216-027 RWO 403 Mel, Here is the revised program you and I chatted about today. If you can approve the new program with the red edits I would appreciate it. Let me know if you have any more questions. Thanks Brian Glasheen Operations Engineer 907-545-1144 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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ϲ͕ϵϯϰ͛ ϳ͕ϰϯϯ͛ Ϯϭ ϳ͕ϱϭϲ͛ ϴ͕ϯϴϱ͛ ϱ ϴ͕ϰϲϴ͛ ϴ͕ϲϳϲ͛ ϱϮ ϴ͕ϳϵϵ͛ ϭϬ͕ϵϲϭ͛ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗdžϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ • • Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Phone: 907/777-8547 scale JUIN u 7 2Ji June 5, 2018 RECEIVED Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission JUN 06 218 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 AOGCC Re: Conductor Annulus Corrosion Inhibitor Treatments 4/20/18-5/12/18 Dear Mr. Schwartz, Enclosedlease find multiple copies of a spreadsheet readsheet with a list of wells that were treated with p p p corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water "grease-like" filler displaces water to prevent external casing corrosion that could result in a surface casing leak. The attached spreadsheets include the well names, field, PTD and API numbers, treatment volumes and treatment dates. This treatment campaign represents primarily new Milne Point HAK drill wells along with two Northstar wells which previously had excavations and external surface casing leak repairs. If you have any additional questions, please contact me at 777-8547 or wrivard@hilcorp.com. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC ! ! 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Date Spudded: 15.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 March 6,2016 50-029-23566-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 5112'FSL,4265'FEL,Sec 19,T13N, R11 E, UM,AK March 16,2016 MPU B-28 ' Top of Productive Interval: 9. Ref Elevations: KB: 57.2 17. Field/Pool(s): Milne Point Unit • 384'FSL,2078'FEL,Sec 13,T13N, R10E, UM,AK GL:23.5 BF:23.5 Schrader Bluff Oil Pool . Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2275'FNL,72'FWL,Sec 13,T13N, R10E, UM,AK 10,995'MD/4,341'ND (SHL)ADL047438/(TPH/BHL)ADL047437 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 572028 y- 6022955 Zone- 4 11,000'MD/4,341'TVD N/A TPI: x- 568997 y- 6023478 Zone- 4 12.SSSV Depth MD/ND: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 565842 y- 6026070 Zone- 4 N/A 1,588'MD/1,580'ND 5. Directional or Inclination Survey: Yes Q(attached) No El 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary ROP-DGR-ADR-EWR-HORIZONTAL PRES 2IN MD, DGR-ADR-EWR INV/REV INTERVALS 21N ND 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 20" 78.6# A-53 Surface 113' Surface 113' 42" —29 bbls Stg 1 L-236 bbls/T-44 bbls 153 bbls 9-5/8" 40# L-80 Surface 5,721' Surface 4,435' 12-1/4" Stg 2 L-251 bbls/T-55 bbls 100 bbls 7-5/8" 29.7# L-80 Surface 5,571' Surface 4,434' Tieback Assy. 4-1/2" 12.6# L-80 5,563' 11,000' , 4,433' 4,341' 8-1/2" Cementless Screen Liner 24.Open to production or injection? Yes Q No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 5,585' 4,844'MD/4,298'ND Screen Depth Detail: 6,934'-7,433'MD/4,409'-4,402'ND ,r_ 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 7,516' 8,385'MD/4,399'-4,376'ND Was hydraulic fracturing used during completion? Yes❑ No 08,468'-8,676'MD/4,372'-4,361'ND // 8,799'-10,961'MD/4,360'-4,340'ND /2'S//6D Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 250p screens Lb- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/3/2016 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 4/18/2016 24 Test Period 1933 453 162 N/A 234 scf Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 200 N/A 24-Hour Rate 1933 453 162 19 Form 10-407 Revis 1/20 5 vc./ CON E PAGE 2 Submit ORIGINIAL onlci RBDMS t-U--APR 1 b 2016 28.CORE DATA Conventional CO): Yes ❑ No Sidewall Coreses ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1,588' 1,580' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 6,934' 4,409' information, including reports,per 20 AAC 25.071. SV1 2,659' 2,615' Ugnu 4,562' 4,150' Schrader Bluff NA 5,270' 4,398' Schrader Bluff ND 6,912' 4,410' Formation at total depth: Schrader ND 31. List of Attachments: Wellbore Schematic, Daily Drilling and Completion Reports, Days vs Depth, MW vs Depth,Casing and Cement Reports, Definitive Directional Surveys Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller Email: Ikeller(C�hiICorp.com Printed Name: Luke Keller Title: Drilling Engineer Signature: Phone: 777-8395 Date: 4/25/2016 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 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 11/2015 Submit ORIGINAL Only . . Milne PointMPUB-28 Unit ,11 Well: - SCHEMATIC Last Completed: 3/25/2016 Iiiiieorp Alaska,LLC PTD: 216-027 Orig.KBEIev.:57.2'/GLEIev.:23.5' TREE&WELLHEAD Tree Seaboard 3 1/8" 5M t i uSeaboard 16 3/4"3M x 11"5M Multibowl w/11"x 3 1/2"EUE Top and WellheadBottom with 3"CIW"H"BPV profile.2ea 3/8"NPT control lines. F - OPEN HOLE/CEMENT DETAIL A 42" ^'29 bbls(6 Yards dumped down backside) 12-1/4" 333 bbls in 12-1/4"Hole Cement to Surface 312' - 1 8-1/2" Cementless Screens Liner in 8-1/2"hole 4 CASING DETAIL ii g Size Type Wt/Grade/Conn Drift ID Top Btm BPF F IT 20" Conductor 78.6/A-53/Weld N/A Surface 113' N/A a 9-5/8" Surface 40/L-80/TC II 8.525 Surface 5,721' 0.0758 Tieback 29.7/L-80/Vam STL 6.750 2,912' 5,571' 0.0459 7-5/8Tieback 29.7/L-80/SW II 6.750 Surface 2,912' 0.0459 Cementer S `# 1410, mer@ ml fill!li 2 4-1/2" Liner(250p Screens) 12.6/L-80/Hyd 521 3.833 5,563' 11,000' 0.0152 212(i $ TUBING DETAIL 3 1/2" Tubing 9.3/L-80/EUE Srd 2.867 Surf 5,585' 0.0087 3 x# WELL INCLINATION DETAIL - KOP @ 221' oe Max Hole Angle=94.5 deg.@ 8,502'MD 4 oiof JEWELRY DETAIL Qc"' No. Top MD Item ID "4. Upper Completion 5 1 Tubing Hanger 2.992" c 2 2,008' 3.5"X Nipple Assembly,2.813"Packing Bore 2.813" 7.5/8 - — 3 2,178' 3.5"GLM 1"BK Latch 2.962" m , 6 4 4,009' 3.5"GLM Dummy valve w 1"BK Latch 3-1/2"x 1"Pocket 2.962" A' I 5 4,696' 3.5"GLM Dummy valve w 1"BK Latch 3-1/r x 1"Pocket 2.962" "iar4 7 k 0„ A 6 4,788' 3.5"Sliding Sleeve,X profile,2.813"seal bore 2.813" 8Lt. 7 4,844' 7-5/8"Haliburton PHL Packer 2.885" � *g 3.5"XN Nipple w/RHC ball catcher,2.750"No-Go,2.813" 4 1 8 4,891.5' 2.992" Packing Bore 9 5,554' 3-1/2"Mule Shoe wjt. 2.992" 11 9 Lower Completion ;n 10 10 5,563' BOT SLZXP Liner Top Packer w/BD Slips 7"x 9-5/8" 6.200" 9-5/8 12 11 5,562' 7-5/8"Tieback Assy.(8.25"OD No-Go @ 5,561') 6.151" � 12 5,585' 7"H563 x 4"H521 L-80 XO 3.900" — — 13 See Below 5-1/2"17#Tendeka Swell Packers 4.982" 13 14 10,963' 4-1/2"Drillable Packoff Sub 2.400" 15 10,995' WIV Valve LTC BxB(1.5"Ball on Seat/Closed) See d Screen/ Solid Liner 4-1/2"SOLID LINER DETAIL 4-1/2"Screens LINER DETAIL Detail SWELL PACKER DETAIL Jts Top(MD) Btm(MD) its Top(MD) Btm(MD) 31 5,585' 6,934' 12 6,934' 7,433' Top(MD) Btm(MD) 2 7,433' 7,516' 21 7,516' 8,385' 6,175' 6,186' 4-1/2"4-1/2" I 14 2 8,385' 8,468' 5 8,468' 8,676' 6,238' 6,249' Shoe @ 15 3 8,676' 8,799' 52 8,799' 10,961' 6,878' 6,888' 11,000' GENERAL WELL INFO TD=11,000'(MD)/TD=4,341'(11/D) API:50-029-23566-00-00 Revised by: PBTD=10,995'(MD)/PBTD=4,341'(TVD) Drilled and Cased by Doyon 14 -3/25/2016 C.Dinger Revised By:CJD 4/18/2016 Hilcorp Energy Company Composite Report 1:11 MP B-28 Field: County/State:,Alaska (LAT/LONG): ovation(RKB): API#: Spud Date:3/6/2016 Job Name:1610003D MP B-28 DRILLING Contractor Doyon 14 AFE#:1610003D AFE$:$4,818,800 r�(� 'µ;, o - - 11� 1,1r, �l� r �' �� IGAi.-: � .pit,�.,. �I�� ,4RV��.. 9.. ,,.-a '� J aF' 11: _ NINIUMENIENIMIKRESZErft 3/4/2016 Release from B-29. R/D and skid floor. Notify pad operator of move. Demob rig and mob over to B-28 well. Spot rig.;Work on shimming rig due to uneven pad.Continue nipple up diverter stack. Rig accepted @ 00:00.;Re-orient"1"'for diverter line. Begin rigging up and prep for skidding floor. Skid floor and continue nipple up. Prep pits for spud mud. 3/5/2016 Begin N/U diverter system out ODS.Submit to state to change plan and run diverter out the ODS instead of the DS due to B-25 distance.State did not approve to do so. R/D diverter system on the OD.;Freeze protect injection lines&well to B-25 with methanol.Milne electricians demobe electrical to well house.;Prep to remove well house. Continue loading 165 joints of DS-50 in the shed.Strap&tally. Prep shop to move to D pad.Spot Geo,MWD and mud shack. Move warm up shack to spot crane.;R/U Alaska crane and remove well house with Milne rig support. M/U 18 stands DS-50 Dp while working stack N/U& removing well house. Spot rock washer&R/U same.Work on Rig acceptance checklist.;Finish nipple up diverter stack. Demob DDI shop from B-pad and relocate on D-pad w/camp due to orientation of diverter on rig up of B-29.Clear snow and continue cleanup 6-29.Spot warm up shack.;P/U and rack back 8 stds 5",19.5#DS-50 drill pipe. Drift 2.35". RIH and tag btm @ 110'. Load pits w/580 bbls 8.8# spud mud. Prep RW and trucks for spud.;Diverter test.AOGCC rep Johnnie Hill witnessed.Test H2S 10/20 and LEL 20/40(test good).Start psi 3000,drawdown psi 1750,31 sec 200 psi inc and full charge @ 158 secs.;28 secs for annular closure,17 secs for knife valve open.6 bottle avg 2000 psi. State diverter test form completed and sent to state.;P/U remaining 26 stds 5",DS-50 DP,6 stds HWDP w/jars.33.6' RKB/GL,31.10'RKB/Clr diverter line,27.08'RKB/Ctr Annular.;Bring wear ring and running tool to rig floor. Set same. 15.25"ID. RILDS(34.3'RKB/LDS). Finish rig acceptance checklist.Give 2 hr notice to Sperry Gyro. 3/6/2016 P/U BHA#1, 12.256 bit,Motor,Stab,DM Collar,DGR Collar,EWR-P4 Collar,PWD Collar,HCMI Collar,TM HOC Collar,UBHO. Set orientate UBHO to MWD.Check with Haliburton Gyro.Down Load MWD.;Conduct Prespud saftey meeting while down loading MWD. R/U Haliburton gyro.;Fill hole with water.Check for leaks,Test lines to 3000 psi.Good. UBHO lockdowns leaking.Remove and thread tape. Recheck UBHO orientation.Good.Establish parameters @ 350 gpm 40 rpm.;UP/DN 70/70 350 gpm @ 300 psi, 40 RPM @ 1k tq.;Drill ahead F/110'T/215'. Drill down with water T/125'350 gpm,40 rpm,5-10k wob. Displace to 8.8 ppg spud mud on the fly.Loose prime on#1 pump.Troubleshoot while drilling ahead.;Drilling ahead F/125'T/215'. 350 GPM,700 psi 40 RPM,2K TO, 8.8 ppg,200 vis 5-10 WOB.;POOH T/176'.Pulled tight.Pump&Back ream @ 350 gpm,40 rpm.T/110'.RIH with no pumps good. Stand back HWDP, Blow down TD.P/U 3 NMFC.;Take gyro.Drilling ahead @ F/215'T/800' @ 500 gpm,1300 psi on,1180 psi off,40 rpm,3-4k tq on,1-2k tq off.84 ft/hr avg ROP. 10-15 wob.;Drill ahead F/800'-T/1274'MD,1270'TVD.490 gpm,1350 psi on,1200 psi off,42%flow,80 rpm,1.2k tq on,1k tq off,9.69 ECD's.Gyro svy's to 882'MD. MWD clean svy's @ 976'MD.;Release Gyro @ 1274'MD. Last 24 hrs 2.89 hrs sliding,5.83 hrs rotating. Svy @ 1070'MD-3'high and 1'left of plan. 88k total revs on bit.80 ft/hr avg ROP;Hauled 475 bbls to G&I for total=475 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 560 bbls from Vern Lake for total=560 bbls Hauled 350 bbls from L-Pad for total=350 bbls;Daily losses to formation 0 bbls for total=0 bbls 3/7/2016 Drill 12.25 Hole F/1274'T/1966'.692'ft 98 foh av 500-600 GPM,1450 psi, 80 rpm,2-4k tq MW 9.2,vis 220, 10.01 ECD Log permafrost @ 1594'.;Circ hole clean 1.5 btm up 500 gpm, 1200 psi 40 rpm,1-2k TQ Cuttings decreased by 50%@ btm up. Monitor well,BDTD.Static.;POOH F/1966'T/Surface on elevators. Tight spots 20-40 k over Wipe Clean,Good. 1710',1670',1330',1260-1230',1170',940',845',375-355'. Stand back BHA,Clean off stabs&Bit. LID UBHO.;TIH F/surface-T/1776'MD. 10k-20k drag for most of trip w/no issues.Took 40k wt @ 1776'MD.Work pipe on elevators(No Go).;Wash ream F/1776'-T/1966'MD.Wash and ream dn 3 bpm, 30 rpm to 1826'MD. Unable to work past.Orient HS and work past from 1826'to 1835'.Continue rotating past 1835 to std dn @ 1864'MD.;Backream std F/1864-T/1770'MD. Shut off pumps and rotary.TIH on elevators clean F/1770'-T/1864'MD.Wash do last std F/1864'to 1966'clean.Cont drlg.:Drill 12.25 Hole F/1966'T/2435'.469'@ 117 fph ay. 500-600 GPM,1710 psi, 80 rpm,2-4k tq MW 9.6,vis 220, 10.4 ECD Log permafrost @ 1594';Drill 12.25 Hole F/2435'T/3092'MD,2988'TVD.469'@ 110 fph ay. 566 GPM,1850 psi,45%flow 80 rpm,2-4k tq MW 9.3,vis 175,9.93 ECD Max gas 965 units @ 2235 btms up,drop back to 120 bgg;Continue to fight mud wt.Screen up to 140's,Screen up scalpers to 80's,limit ROP to 240'max,Set 10.2 as max ECD. BR full 90'between connections to increase circ time.;Saw ECD's go from 10.4 to 9.97 ppg ECD's. Increase pump rate to 567 gpm.1790 psi,45%flow,80 rpm,2k tq on,1.4k tq off.Continue work on 9-5/8"casing in shed.;Hauled 910 bbls to G&I for total=1385 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vem Lake for total=560 bbls Hauled 888 bbls from L-pad for total=1238 bbls;Daily losses to formation 0 bbls for total=0 bbls. Last svy @ 2860'MD.4.9'Low,1'Right 3/8/2016 Drill 12.25 Hole F/3092'T/3661 MD,569'Col 87 fph ay. 560 GPM,1850 psi,45%flow 80 rpm,2-4k tq MW 9.3,vis 175,9.93 ECD;Circ btm up @ 500 gpm. Slight packing off while circulating. After btm up bring rate to 620 GPM&pump second btm up.Cleaned up with small coal on the shakers.;Monitor well.Static, POOH F/3661.1/1900'. Over pulled 10-40 K most of the way 2960'T/1960'. Pulled through worked back down when swabbing.Correct fill on the second pull.;RIH on elevators T/2185'. Unable to work past.Pump down @ 120 gpm 20 rpm. Pumped and reamed @ 120 Gpm,20 rpm @ T/2361',2480,2535',2699'.:2699'.Taking over 10 wt.Trying to side track.Orient high side&slide 10'to 2710'. Ream down @ 120 gpm'20 rpm T/2735'.Still taking wt. Orient hight side&slide @ 450 gpm.Slide through.;Continue to wash and ream @ 120 gpm 15 rpm T/3567',Wash/Ream last std pumping 500 gpm,1600 psi,50 rpm to 3661'@ bttm. Note:12'fill on bttm.;CBU 2x pumping 500 gpm,1600 psi,rotate 80 rpm,work pipe 90',up slow down 50 rpm no increase in cuttings on 1st BU,Pump 35 bbl hi vis sweep w/5 ppb walnut and 15 gal condet.;Pump sweep around 550 gpm,1800 psi,sweep back 200 stks early w/50%increase,mostly clay balls and sand. PU 158K,SO 138K,ROT 148K.;Drill 12.25 Hole F/3661'T/3780'MD, 119'@ 60 fph ay. 556 GPM,1700 psi,45%flow, 80 rpm,5-7k tq,10-20k wob, MW 9.3, vis 150, 9.78 ECD;Drill 12.25 Hole F/3780'T/4127'MD, 347'@ 57 fph ay. 560 GPM,1820 psi,45%flow,PU 170,SO 140,ROT 150 80 rpm,5-8k tq,15-25k Wob. MW 9.3,vis 179, 9.82 ECD;Max gas 2953.;Daily losses to formation 0 bbls for total=0 bbls. 2.21 slide hrs,7.69 rotate hrs. Last survey 1.63'below the line,2.95'right of the line.;Hauled 1083 bbls to G&I for total=2468 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vem Lake for total=560 bbls Hauled 884 bbls from L-pad for total=2122 bbls 3/9/2016 Drill 12 25 Hole F/4127'T/4509'MD,382'Cal 63 v. • 560 GPM,1760 psi,45%flow,PU 178,SO 146,ROT 160 80 rpm,5-10k tq,15-25k Wob. MW 9.3+,vis 179, 9.66 ECD;Sliding 60-80'per stand. Having trouble Getting 6 deg DL. Drilling hard spots @ 5-20 fph&fast drilling @ 200-500 fph. Pumped sweep @ 4290 with 300%increase in cuttings.;Drill 12.25 Hole F/4509'T/5079'MD,570'@ 95 fph ay. 560 GPM,1760 psi,45%flow,PU 178,SO 146,ROT 160 80 rpm,5-10k tq,15-25k Wob. MW 9.3+, vis 179, 9.66 ECD;Sliding 80'of stands.Getting 6.8. @ 5030 showing 9.0 deg dogleg. Plan on back reaming high dogleg on the way out.;Pump 35 bbl hi vis sweep w/10 ppb walnut,1%condet @ 5060',sweep back on time w/25%increase mostly clay,some fine sand;Drill 12.25 Hole F/5079' T/5279'MD, 200'@ 33 fph ay. 550 GPM,1960 psi,45%flow,PU 184,SO 134,ROT 152 60 rpm,10k tq,20-25k Wob. MW 9.3,vis 129,9.88 ECD;Drill 12.25 Hole F/5279'T/5512'MD,233'@ 39 fph ay. 550 GPM,1870 psi,45%flow,PU 184,SO 134,ROT 152 60 rpm,10-12k tq,20-25k Wob. MW 9.2+,vis 82,9.81 ECD;Note:TD extended to 5700'+-due to Schrader N-sands @ 35'lower TVD Maintain 83 deg inclination. 5345 to 5355'slow drilling 5-7 fph. Oil show noted at the shakers.;Note:set cement silos and water tank in place,csg hanger made up to landing jt.;Daily losses to formation 0 bbls for total=0 bbls. 7.37 slide hrs,10.72 rotate hrs. Last survey 3.05'below the line,16.04'left of the line.;Hauled 1083 bbls to G&I for total=3551 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vem Lake for total=560 bbls Hauled 1038 bbls from L-pad for total=3160 bbls 3/10/2016 Drill 12.25 Hole F/5512'T/5700'. MD, 188'@ 75 fph ay. „..<9 550 GPM,1870 psi,45%flow,PU 184,SO 134,ROT 152 80 rpm,10-12k tq,20-25k Wob. MW 9.3+,vis 82, 9.81 ECD;SIide F/5607'T/5660'.Building up to 92 deg as per Geo.;Circ&condition @ 600 gpm,60 rpm. Geo extended TD to 5775'. Had to L/D single and then pick back up to continue drilling.;Dnll 12.25 Hole F/5700'T/5738'.TD called. 600 GPM,2310 psi,45%flow,PU 180,SO 128,ROT 150 80 rpm,10-12k tq,20-25k Wob. MW 9.4,vis 82,9.81 ECD;The well is landed in the NB with a Final Inc at 92.84 deg and 308.96 az.5690.63 survey depth.;Pump 35 bbl walnut/condent sweep @ 620 gpm,60 RPM. Start treating mud for casing run&cmt job. Sweep came back 50 bbl early.Well cleaned up good after btm up.Pumped total 1.5 btm up.;Pump out of the hole @ 600 Gpm F/5738'T/5070'. Pulling through tight spots cleaning up good. Back ream F/ 5070'T/4885 to ream out 9.0 deg dog leg.Worked through after reaming.;Continue to pump out of the hole F/4885'T/4500 still getting 10-20k over pulls. Pulled clean after 4500'.Continue pumping out @ 600 gpm F/4500'T/1700'.;Pulled slow F/1900'T/1700'to allow hole to clean up @ 500-600 GPM.Hole unloading.Cleaned up after btm up.;Attempt to POOH on elevators @ 1700'.Well swabbing.POOH F/ 1700'T/800'while pumping 100 gpm to prevent swabbing. POOH on elevators F/800'T/HWDP.;Rack HWDP and jars in derrick, L/D flex collars,Pull to bit,drain motor,L/D bit:Download MWD data.L/D MWD tools and mud motor.Monitor well. Bit grade=2-4-WT-G-E-3-NO-TD;Clear and clean rig floor,Load hanger and landing jt in pipeshed,Drain and rinse stack,pull wear bushing.Dummy run hanger per wellhead rep.;R/U Volant tool,power tongs and 9 5/8"handling equipment.PJSM for running casing. Continue to monitor well,static loss rate 1.5 bph;Bakerlock and M/U shoe track,ensure proper float operation,install 2 centralizers 10'from each end over stop collars on shoe jt and 1 mid tube over stop collar on FC jt. Check bypass baffle.;P/U and run 9 5/8"L-80,408 TCII casing per tally,use BOL 2000 pipe dope,torque to optimum @ 12600 ft/lbs,fill on the fly and every 5 jts Utilize dog collar clamp on lst 10 jts.;lnstall 1 centralizer every other jt on 1st 15 jts ran.RIH to 1196'(27 jts ran);Daily losses to formation 9 bbls,total losses 57 bbls.;Hauled 617 bbls to G&I for total=4168 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vem Lake for total=560 bbls Hauled 804 bbls from L-pad for total=3964 bbls 3/11/2016 PIU and run 9 5/8"L-80,408 TCII casing per tally F/1244'T/3000'.Joint 75. Torque to optimum @ 12600 ft/lbs, Filling pipe every 5 joints.;Found ding in collar.Change out collar.;P/U and run 9 5/8"L-80,408 TCII casing per tally F/3000'T/3550'. Torque to optimum @ 12600 ftllbs, Filling pipe every 5 joints.;Circ liner vol/1.5 Btm up.Staging up rate to 6 bpm @ 200 psi. MW 9.4 in 9.5 out. Mud in very good shape.Very little cuttings.;P/U and run 9 5/8"L-80,408 TCII casing per tally F/ 3550'T/3591/Joint 90. P/U Halliburton stage tool.Verify Good with 6 pins. Filling pipe every 5 joints.;P/U and run 9 5/8"L-80,4041TCII casing per tally F/36351/5721'. M/U landing joint&hanger.RIH&land with 140K. Filling pipe every 5 joints.;R/D Volant tool.BDTD. Make up cmt head.;Break circ @ 1 bpm.Stage up rate to 7 bpm @ 450 psi.Circ btm up with very fine cuttings.Mud coming back 200 vis 9.6.Mud in @ 9.4 75 vis. Off load pits. R/U Halliburton cmt lines&equipment.;Circ&condition mud.Never saw cuttings.Very fine sand and silt at the shakers.MW 9.5 in and out.VP 18. wUD Weatherford casing equipment&Clear floor.;PJSM,1st stage Cmt job with all hands. Load bypass plug.Test cmt lines to 4000 psi.Good. Pump 52 bbl 10.5 spacer,Pump 236 bbls 11.7 ppq lead cmt 4.2 Ci1.1� bpm,350 psi start,200 psi final.;Note:send in 24 hr BOP test notification to AOGCC on 3/11/16 @ 18:41 hrs.;Pump 44 bbls 15.8 tail cmt 3.5 bpm,start,220 psi final,drop closing plug,pump 20 bbls H2O w/cmt o-�7r pump,w/ng pump 207 bbls 9.45 ppg mud 6 bpm,130 psi start,310 psi final.;w/cmt pump 80 bbls H2O 5 BPM,615 psi start,815 psi final,w/rig pump 100 bbls 9.45 ppg mud 6 bpm,920 psi start,1180 psi final, slow pump to 3 bpm,1110 psi,FCP,;Plug appeared to bump @ 3216 stks,2.5 bbls early with a 200 psi increase spike to 1350 psi then pressure dropped to 600 psi,cont pumping calc displacement 3251 stks, ` 427 bbls total.;Note:15 bbl total losses while displacing cmt,;shut down pump,holding 260 psi,check floats,appear to be holding w/no flow back,Pump additional 2 bbls @ 1/2 shoe track vol.429 bbls.No press l increase,Shut down pump, CIP @ 22:30 hrs,;Decision made,drop opening tool,load 2nd stage closing plug,with rig,pump and open ES cmtr @ 660 psi,pump 3 bpm,350 psi start,80 PSI @ 118 bbls BU,15 bbls away see mud push retums,;65 bbls away see cmt retums,dump 52 bbls mud push and 53 bbls cmt.;Continue to circulate 5 bpm,150 psi,condition mud,clean rock washer,reduce active pit volume for 2nd stage cement job while WOC.;PJSM,2nd stage Cmt job with all hands.Pump 20 bbls water,47 bbls 10.7 ppg spacer 4 bpm,205 psi start,pump 251 bbls 10.7 ppg lead cmt,start 5.5 bpm,230 psi,final 360 psi,;230 bbls away see spacer retums,dump sam- - .•• •• •••• u -• •.u • r• ' • •••• 590 psi.Drop closing plug,pump 20 bbls water 6.5 bpm,520 psi.;Swap to rig pump,Pump 121.2 bbls 9.45 ppg mud,start 6 bbls per min,330 psi,final 6 bpm,760 psi,slow pump to 3 bpm,650 psi,pump 20 bbls mud 138.2 bbls FCP 670 psi;Note:plug bumped 3 bbls early(1369 stks)pressure up 1200 psi over FCP @ 1900 psi,shut down pump,confirm tool closed,no flow.bleed off Pressure CIP @ 06:12 hrs.:Note:47 bbls spacer and 90 bbls cmt retums to surface. / No losses pumping 2nd stage.;Hauled 865 bbls to G&I for total=5033 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vem Lake for total=560 bbls Hauled 287 bbls from L-pad for total=4251 bbls 3/12/2016 R/D cement head,flush casing spool,landing jt and annular with black water pumping 6 bpm,780 psi,function annular several times,continue to flush same,clean surface equip in pits.;UD casing running tools, continue to clean in mud pits,start R/D diverter lines,flush out cement valves on rig floor,M/U landing jt and packoff running tool.Install packoff per wellhead rep,RILDS;Flush Bowline and clear out any I/ remaining cmt,PJSM,N/D diverter stack,continue R/D diverter lines,knife valve and diverter tee,cleaning mud pits.;lnstall tubing spool,test hanger void seals to 500 psi low 5 min,3000 psi high for 10 min per li wellhead rep.:N/U 13 5/8"5M BOP stack dressed with 2 7/8"x 5"ram in upper,middle blind ram and 5"fixed ram in lower,install bell nipple,Bowline,BOP anchors,get RKB measurements.;R/U test equipment, XOs,3 1/2"test jt.AOGCC rep Guy Cook on location to witness BOP test.;Rig electrician calibrate and test gas alarms,Fill stack,perform BOP body test to 3000 psi.Test PVT system and flow line indicator.Test • upper 2 7/8"x 5"VBR rams,lower 5"solid rams,;Blind ram,upper and lower IBOP,3 FOSV,dart valve,mud cross valves,choke manifold valves to 250 psi low,3000 psi high 5 min ea.charted,pipe rams tested A. using 3 1/2"and 5"testjts.;Test annular to 250 psi low,2500 psi high 5 min ea.charted using 3 1/2"and 5"test jts.Perform manual and hydraulic choke efficency test.Perform accumulator draw down test.;Daily losses downhole 0 bbls,total losses 100 bbls.;Hauled 1215 bbls to G&I for total=6246 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 290 bbls from Vern Lake for total=850 bbls Hauled 0 bbls from L-pad for total=4251 bbls 3/13/2016 Finish testing BOPs to 250/3000 psi. Guy Cook w•AOGCC present to witness. No failures.;R/D testing equipment,Blow down sequipment. Set Wear bushing.R/U Geo Span.;P/U 8%cleanout BHA#2. HDBS 8%bit,Motor with 1.5 deg bend,3 NMFC,island HWDP with the jars. RIH P/U 5"DS 50 to 2103'. Make up stand in mouse hole.Wash down @ 400 gpm&tag cmt @ 2114'.;Drill cmt to 2126' @ 60 RPM 350-450 GPM.Drilled Closing plug&bomb plug.Worked through. Drilled 20'cmt below the plug. RIH TI 2210'.Hitting cmt stringers.;Wash down @ 400 gpm 60 RPM. F/2110'T/2445'. RIH on elevators F/2445'T/2730'. Hitting cmt stringers.Wash down @ 400 gpm 60 RPM. 5-7 WOB.Fl 2730'T/2765'.;P/U 5"DP F/2765'T/4040'.Fill Pipe.RIH F/4040'T/5589'(171 jts).;PJSM,Install FOSV,hang blocks,slip and cut 63'drlg line,UD FOSV,re-set and test crown saver.;P/U single RIH,tag top cmt @ 5592'wash and ream to 5612'just above Baffle adapter.;CBU,cleanup wellbore for casing test.Very thick clabbered mud,pump 325 gpm,720 psi.;UD single,BD top drive,R/U FOSV and head pin,close annular,pump down kill line and DP,test 9 5/8 csg to 3000 psi for 30 min,charted,good,bleed off press,open annular.;5.4 bbls pumped,5 bbls bled back.UD head pin and FOSV,BD kill line and cmt Iine.;Get SPR,PU 195K,SO 120,ROT 145K,drill hard cmt f/5612'pumping 500 gpm,60 rpm,8-10k torq,5-10 k wob, 1480 psi,drill baffle adapter on depth @ 5634',plug rubber seen @ shaker.;Drill out shoe track,make several passes cleaning up shoe,cleanout rathole and drill 20'new formation to 5758'.;Pull into 9 5/8"casing @ 5700'.CBU,500 gpm,1300 psi.PJSM for F.I.T.and displacing to new 8.8 ppg mud,ream shoe and cleanup.;Fill choke and kill line,Close annular,Perform F.I.T.to 12 ppg EMW using 9.1 ppg MW,apply 670 psi,1.8 bbls pumped,10 sec bled to 650 psi,5 min,5 min bled to 495 psi.;Trend slowed @ 550 psi,11.5 ppg EMW.1.5 bbls bled back.;Daily losses to tormation U bbls,total losses 1UU bbls;Hauled 219 bbls to G&I for total=6467 bbls Hauled 0 bbls to B-50 for total=0 bbls e Hauled 0 bbls from Vern Lake for total=850 bbls Hauled 462 bbls from L-pad for total=4713 bbls 3/14/2016 Displace well to 3%KCL Baradrill N,Solids Free Mud. Shut down and monitor well.Good. Broke down first Sand in the mouse hole due to elevators froze up.;POOH F/5700'T/2129'. Pulled 15K over.Rot Pipe 1/2 Turn.Pulled through slick. POOH,Stand back NMDC&UD BHA#2.;M/U BHA#3,8 1/2 PDC Bit,Geopilot,DGR,PWD,ILS,ADR,DM and TM,collars,upload MWD data,M/U FS,3 NMFCs,1 HWDP, combo jar,1 HWDP=272.48',Break in Geo-steer.;RIH f/272'to 5554'filling pipe every 2000',Move 5 stds HWDP f/ODS to DS.Continue RIH,tag baffle adapter,FC and shoe,ream and cleanup same,tag bttm @ 5758' Note:correct displacement on TIH.;Drill 8.25"Hole F/5758'T/6124'MD,366'@ 105 fph ay. 450 GPM,1100 psi,36%flow,PU 185,SO 110,ROT 145 80 rpm,12k tq,8-10k Wob. MW 8.8, vis 40, 9.4 ECD;Drill 8.25"Hole F/6124'T/6400'MD,276'@ 46 fph ay. 425 GPM,1120 psi,35%flow,PU 180,SO 110,ROT 145 80-90 rpm,12k tq,10-15k Wob. MW 9,vis 41,9.7 ECD;At 6308'pump tandem 30 bbl low 27 vis/30 bbl weighted 10.3 ppg sweep, Note:Both centrifuges running,adding water 15 bph,;Current BHL appears to be about 9'ND below the NB top-estimated local formation dip is about 90.75°-currently aiming for 91.0°. 5.41'below the line,13'right of the Iine.;Daily losses to formation 0 bbls,total losses 100 bbls;Hauled 911 bbls to G&I for total=7378 bbls Hauled 0 bbls to 8-50 for total=0 bbls Hauled 0 bbls from Vern Lake for total=850 bbls Hauled 312 bbls from L-pad for total=5025 bbls 3/15/2016 Drill 8 1/2"Hole F/6400'to 7064'(664')AROP 107 FPH 400 GPM,970 psi,35%flow,PU 190,SO 100,ROT 140 80-90 rpm,12k-14k tq,10-15k Wob. MW 9,vis 41,9.8 ECD;Last Sweep At 6308'pumped tandem 30 bbl low 27 vis/30 bbl weighted 10.3 ppg sweep, Note:Both centrifuges running,adding water 15 bph, Cross fault#1 @ 6700'MD,4413'tvd.;Drill 8 1/2"Hole Fl 7064'to 7440'(376')AROP 107 FPH 400 GPM,970 psi,35%flow,PU 190,SO 100,ROT 140 80-90 rpm,12k-14k tq,10-15k Wob, MW 9, vis 42,9.8 ECD;Load tandem sweep in pipe @ 7340'Continue to drill to 7440'. Note:Both centrifuges running,adding water 10 bph.;At 7440',pick up off bottom and circulate sweep OOH @ max flow rate Rot/Recip pipe,with 25%increase @ shakers.;Drill 8 1/2"Hole F/7440'to 7751' (311')AROP 155.5 FPH 403 GPM,980 psi,39%flow,PU 200,SO 80,ROT 140 80-90 rpm,14k-15k tq,10-15k Wob. MW 9, vis 39,10 ECD;Note:cross 2nd fault @ 7532'MD,4400'ND. B-18 injector has been shut in.Close approach with B-18 is now projected from about 8000'to 8100',;Dnll 8 1/2"Hole F/7751'to 8313'(562')AROP 93.6 FPH 489 GPM,1380 psi,39%flow,PU 203,SO 65,ROT 155 80 rpm,15-16k tq,10-15k Wob. MW 9, vis 39,10.1 ECD;Note:monitor 0-18 tbg psi from 8000'to 8100',slow ROP to 100 fph,80 rpm thru this section, Take Surveys every 45'from 7816'to 8100'until past 8-18 close approach, B-18 back online.;Drill 8 1/2"Hole F/8313'to 8760'(447')AROP 112 FPH, 550 GPM,1780 psi,41%flow,PU 198,SO 60,ROT 132, 80 rpm,15-16k tq,10-15k Wob, MW 9.1+, vis 43,10.4 ECD;Note:cross 3rd fault @ 8684'MD,4358'TVD.;While Geo confirms fault throw,pump tandem 30 bbl low 27 vis/30 bbl weighted 10.3 ppg sweep around @ max flow rate Rot/Recip pipe,with 25%increase @ shakers.;Drill 8 1/2"Hole F/8760'to 8790'with same parameters.;Currently 2.8'above the line,61'left of the line.;Daily losses to formation 0 bbls,total losses 100 bbls;Hauled 656 bbls to G&I for total=8034 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vem Lake for total=850 bbls Hauled 773 bbls from L-pad for total=5798 bbls 3/16/2016 Drill 8 1/2"Hole F/8790'to 9517'(727')AROP 121 FPH 400 GPM,1160 psi,41%flow,PU 216,SO 65,ROT 136, '7 80 rpm,16-18k tq,10-15k Wob. MW 9.2, vis 43,10.5 ECD.;Note:Both centrifuges running,adding water 10 bph.Peak Gas @ 8800u.Last Sweep pumped @ 8760';Drill 8 1/2"Hole F/951710 10250'(733')AROP 122 FPH 500 GPM,1700 psi,40%flow,PU 220,ROT 135,Have to rot to SO 80 rpm,19-21k tq,10-13k Wob. MW 9.2, vis 43,10,6 ECD;Note:Both centrifuges running,adding water 20 bph.Last Sweep pumped @ 9885'bring to surface w/drilling ahead.;Drill 8 1/2"Hole P/102501011000'@ TD(750')AROP 115 FPH �. 550 GPM,1880 psi,40%flow,PU 216,ROT 136,Have to rot to SO 80 rpm,18-20k tq,10-14k Wob. MW 9.2, vis 44,10.5 ECD;Last survey 49'below the line,161'right of the line.;Pump tandem 30 bbl l0 vis/30 bbl 10.3 ppg weighted sweep at 600 gpm,2200 psi,100 rpm,reciprocate pipe 90',sweep back on time with no increase in cuttings.;Continue to circulate 600 gpm,2180 psi rotating 20 rpm,working pipe,pump 2 1/2 circulations,Screen up shakers to API 200 mesh screens.;Continue to rotate 20 rpm,work pipe 90'pump 600 gpm,2180 psi.Pump 1 circulation across 200 mesh screens,start performing production screen tests.;Daily losses to formation 25 bbls,total losses 125 bbls.;Hauled 551 bbls to G&I for total= 8585 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vem Lake for total=850 bbls Hauled 650 bbls from L-pad for total=6448 bbls 3/17/2016 Finish up production screen test pumping 600 gpm,2180 psi,rotate 60 rpm, until passing PST achieved.Blow down top drive.;Monitor well for 30 minutes,well is static.;Pump and back ream out of the hole pumping 600 gpm,2300 psi f/10932'to 5649',work thru tight spots f/6930'to 6870',no other issues on trip to 9 5/8"shoe.;CBU in 9 5/8 casing @ 5649'pumping 600 gpm,1800 psi,hole unloaded @ BU, circulate clean,pump 30 bbl hi vis sweep around,no notable increase in cuttings.;Monitor well for 30 minutes,well static,PJSM for brine displacement.;Empty pits 1 and 4 to make room for displacement.Pump 30 bbl hi vis spacer,displace with 9.2 ppg 2%KCL pumping 230 gpm,300 psi until clean 9.2 ppg brine @ retums. Flow check well,static.;Blow down top drive,POH on elevators from 5649'to 5200',drop drift on wire.Move HWDP f/DS to ODS,drift same from derrick,coot POH f/5200'to 272';UD jars,2 jts HWDP,3 NMFCs,FLT Sub,Download MWD data,UD MWD/LWD tools,Geo-pilot and bit,grade=4-5-CT-A-X-3-WT-TD Note:4 bbls over calc disp on trip out f/shoe.;Load out BHA,Load 4 1/2"shoe jt,5 1/2"swell packers,baker tools into pipe shed.Load power tongs and handling equipment to rig floor.R/U same. Monitor well with trip tank,1.5 bph static loss;Strap and tally packers,XOs and remaining downhole tools.M/U 5"X 4 1/2"safety jt w/FOSV.Continue to clean mud pits.;Daily losses downhole 98 bbls,total losses 223 bbls.;Hauled 928 bbls to G&I for total=9513 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vem Lake for total=850 bbls Hauled 498 bbls from L-pad for total=6946 bbls • • Hilcorp Energy Company Composite Report Well Name: MP B-28 Field: County/State: ,Alaska i(LAT/LONG): evation(RKB): 33.2 API#: Spud Date: Job Name: 1610003C MP B-28 COMPLETION Contractor AFE#: 1610003C AFE$: 3/18/2016 Continue strap and tally packers,XOs and remaining downhole tools.M/U 5"X 4 1/2"safety jt w/FOSV.PU and MU Liner Top PKR/Swivel assembly on stand of DP,set back in derrick.,PJSM with all parties on running production screens.,RIH to 5410' picking up 4-'h"Hydril 521 Halliburton PetroGuard 250p premium screens with 4-'/2"12.6#/ft Hydril 521 blank pipe and 5-'/W"17#/Ft DWC/C bxp,Tendeka Swell Packers as per tally.MU TQ @ 4700ft/Ibs.,Running Order:4.5" Shoe/WIV/Pac off assy(38.89'),52 jts Sceens(2161.87'),3 jts Blank Pipe(123.12'),5 jts screens(208.14'),2 jts Blank Pipe(82.62'),21 jts screens(869.18'),2 jts Blank Pipe(82.75'),12 jts screens(499.55'),1 jt Blank Pipe(41.49'),Swell PKR#1(21.79'),15 jt Blank Pipe(617.13"),Swell PKR#2(21.62"),1 jt Blank Pipe(41.25'), Swell PKR#3(21.57'),14 jt Blank Pipe(579.20').,Total Screens run=90 jts @ 3738.74',Total Blank Pipe run=38 jts @ 1568.13',Total Swell Pkrs 3 ea.,Rig down 4 1/2"handling equipment,RU to run 2 3/8"PH-6 Inner String.Reconfigure safety joint for 2 3/8". M/U slick stick,XO,Drift,P/U and run 175 jts 2 3/8 PH6 tbg to 5390'w/174 jts and 8 1/2'in.,UD 2 jts 2 3/8 PH6,Space out with 2 3/8"pups. M/U hanger/packer assembly per Baker rep,inspect same,confirm 9 shear pins in packer,7 shear pins in pusher tool.P/U 150K,S/O 125K, UD swivel,pups and single DP. Loss rate continues @ 1 bph.,RIH with 2 stds 5"DP to 5636', M/U top drive.stage pump from 1.5 bpm,410 psi to 2.7 bpm 1200 psi,CBU w/no gas and no solids at shaker.Blow down top drive, Flow check well 5 min,static.,RIH w/4 1/2"completion conveyed on 5"DP 2-2.5 min per stand f/5636'to 6012'.,Rig fuel used 1300 gal,fuel on hand 5300 gal. Daily losses to well 24 bbls,total losses 247 bbls,Hauled 529 bbls to G&I for total=10,042 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vern Lake for total=850 bbls Hauled 62 bbls from L-pad for total=7008 bbls 3/19/2016 RIH w/4 1/2"completion conveyed on 5"DP 2-2.5 min per stand f/6012'to 9658',PU 250K,SO 55K.Stacking out at 9658'.MU Top Drive for push Wt and work down to 9850'w/no pump.Attempt to work past 9850'w/PU Wt @ 275K.Bring on pump @ 1.5 bpm/340 psi.Work string down to 10274'.Could not get past 10274'.,Note:When Stacked out @ 9850'EOP depth,the#1 Swell Pkr was across the 9 5/8"Shoe @ 5721'.,Receive ok to rotate string.Could not establish free rotation,set tq limit to 6K,work down to 10286'with slight rotation on the down stroke,staging pump from 1.5 bpm/350 psi to 2.5 bpm 940 psi.PU Wt 280K.,While working pipe @ 10286',lost 820 psi within seconds.Shut down pump.Investigate surface equipment.Close IBOP on TD and PT to 700 psi back to pumps,PT good.Consult with Project Engineer.Decision made to POOH and inspect Liner Top Pkr.,POOH on elevators from 10286'bringing Liner Top Pkr to surface.Had to pull 35K over to pull #1 Swell Pkr into 9 5/8"csg shoe.,lnspect Liner Top Pkr.Found that the pins had sheared on the Liner Top Pkr Hyd Setting Tool(Pusher / Tool).Slips and Element were ok.Break out to UD Pkr and found that the 2 7/8"Eue pup jt for making up the inner string,had backed off up inside the Liner °/ running tool.This explained the loss of pump pressure.Lay down Liner Hgr.Note:U-tubing out 2 3/8 tbg,pump 10 bbls dry job @ 10 ppg,Load out hanger/ packer assembly and send to baker shop to get inspected and install new pusher tool and running tool assembly. Wait on same.,While W/O tools,MU 2 3/8"swivel then Triple connect safety jt assembly to liner,RIH with 2 stands of 5"DP to 5606',M/U FOSV.,Continue to W/O packer/hanger assembly,Monitor well,hang blocks,cut and slip 83'drlg line,re-set and test crown saver.Service top drive,blocks,inspect saver sub.,Drift and P/U 9 jts HWDP using mouse hole and rack in derrick for push pipe.POH with 2 stds DP,R/U false table,R/U 2 3/8"elevators,UD Triple connect and swivel. Packer/hanger assembly back on location @ 04:30,Load same in pipe shed.,M/U XO,Space out inner string with 2 3/8"pup jts,Inspect and P/U new liner/hanger assembly,M/U swivel on 2 3/8"Inner string,and swivel on top packer/hanger assy.M/U assy to inner string and 4 1/2"tbg. Run hanger/packer assy in the hole,UD Swivel.P/U 160K,S/O 120K.,Rig fuel used 1500 gal,fuel on hand 7200 gal,fuel recieved 3400 gal. Daily losses to well 52 bbls,total losses 299 bbls,Hauled 422 bbls to G&I for total=10,464 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vern Lake for total=850 bbls Hauled 50 bbls from L-pad for total=7058 bbls 3/20/2016 Finish M/U Packer/hanger assy per Baker rep.RIH 2 stds f/5410'to 5623'.,Stage up pumps to 2.5 bpm,1140 psi,Circulate BU @ 317 bbls w/minimal gas.,Establish parameters,P/U 160K,S/O 120K,ROT 138K @ 15 rpm w/5-6K torq.BD top drive, RIH on elevators w/4 1/2"lower completion conveyed on 5" DP f/5623'to 7807',25 stds,Run 9 stands and single to 8773', fill pipe every 20 stds checking parameters,Continue RIH on elevators f/8773'to 9255'.Stack out @ 9255'.,Establish Parameters @ 9255'.Wash and Rotate liner from 9255'to 10,100'.PU 265K,Dn Wt Rot 125K/10 rpm,1.9 bpm/680 psi 8-10 Tq.,Top Drive stalling out @ 10,100'. Begin working pipe,averaging 1 ft increments on down stroke before stalling out.Worked liner to bottom from 10,100'to 11,000'.PU wt 225K So 55K,1-2 bpm/350-850 psi,working 11K Tq.Work Tq out of string.Put string in tension with 275K Up Wt. Note:Verify drill pipe count.,Pump and displace annulus to clean 9.2ppg 3%KCL pumping 2.4 bpm/1100 psi,circulate until clean brine @ returns.,B/O top drive at single,drop 1 1/2"ball,pump ball on seat 2 bpm,780 psi,ball hit early 632 stks,1075 stks calculated.pressure to 1500 psi,close WIV,hold f/1 min,pressure to 2700 psi,seen pusher tool shear @ 2540 psi.hold f/5 min.,S/O to 65k to confirm set.Pressure to 4000 psi,Seen neutralizer shear @ 3120 psi,S/O 10K, Bleed off pressure.P/U to 220k to confirm release,S/O to 125k,B/O Single and BD top drive,M/U top drive.P/U to neutral wt @160k, TOL @ 5562.61',packer element @ 5577',Line up kill line,close annular,pressure up to 1500 psi and test annulus for 30 min,charted,good test,P/U 15'and unsting.P/U 215K. Note:2.3 bbls pumped,2.2 bbls bled back.,Pump 2nd displacement @ 10955'with 2 3/8"inner string,pump 9.2 ppg,3%KCL brine 4.3 bpm @ 3200 psi.,Rig fuel used 1100 gal,fuel on hand 6100 gal,fuel recieved 0 gal. Daily losses to well 50 bbls,total losses 349 bbls,Hauled 290 bbls to G&I for total=10,754 bbls Hauled 0 bbls to B-50 for total=0 bbls Hauled 0 bbls from Vern Lake for total=850 bbls Hauled 52 bbls from L-pad for total=7110 bbls 3/21/2016 Continue with 2nd displacement,pumpi 4.2 bpm,3000 psi,displace 4 1/2"liner w/9.2 ppg 3%KCrine until clean returns.Blow down top drive.Flow check well,static.,POOH L/D 5"drill pipe f/10923'to 5543'.,M/U top drive,CBU pumping 4 bpm,2500 psi.Flow check well for 10 min,static.Pump 5 bbl 12.5 ppg dry job,BD top drive.,Continue POOH L/D 5"DP f/5543'to 5449',inspect and L/D Baker running tool,load out same. L/D total 178 jts 5"DP(includes 28 jts 5"HWDP),Ready 5"safety joint w/FOSV on top and xo to 2 3/8"PH6 on bttm.C/O handling equipment f/5"to 2 3/8", R/U power tongs.,POOH L/D 2 3/8"PH6 from 5443'to surface,L/D slick stick.L/D total 173 jts 2 3/8"PH6 Note:8 bbls over calculated displacement on TOH,Break down safety jt.RID 2 3/8"handling equipment,R/D Power tongs,load out equipment,remove 2 3/8 tbg from pipe shed,clear rig floor,R/U 5"handling equipment.,M/U mule shoe,RIH with 50 stands 5"DP from derrick to 4740',single out of hole L/D 5"DP to 3384', RIH with remaining 14 stands f/derrick,continue POH L/D 5"DP f/4700'to surface,L/D mule shoe.,Rig fuel used 1220 gal,fuel on hand 4880 gal,fuel recieved 0 gal. Daily losses to well 42 bbls,total losses 391 bbls,Hauled 637 bbls to G&I for total=11391 bbls Hauled 580 bbls to B-50 for total=580 bbls Hauled 0 bbls from Vern Lake for total=850 bbls Hauled 50 bbls from L-pad for total=7160 bbls 3/22/2016 R/U and pull wear bushing.,Drain stack,set test plug.Change out LPR from 5"to 7-5/8"solid rams.Mobilize tools and equipment needed for 7-5/8"Casing Tie Back(MOC submitted and approved by AOGCC on March 14,2016).,Test 7-5/8"Ram to 250/3000 psi.Rig down test equipment.Pull test plug.,Make drift run with 7-5/8"Casing Hanger.Mark RKB to Land @ 33.01'.Lay down Landing Jt and Hanger.,Rig up to run 7-5/8"Tie Back.Make up 1 stand DP and set back in derrick for Space out.Rig up Power Tongs and Elevators.MU FOSV crossed over to STL casing.,PU and MU Tie Back Seal Assy.RIH PU 65Jts(2643..31')7 5/8",29.7#L-80,Vam STL Casing,MU Crossover,7-5/8"29#,7-5/8"SLIJ II B x 7-5/8"STL pin,continue to run 71 Jts(2811.74')7 5/8",29.7#L-80,Vam SLIJ II Casing to 5475'. L/D(2)bad jts(#90-box and#91-pin). Tally adjusted for bad jts.,C/O elevators to 5"DP elevators. M/U XO and kelly up on 5"std. Wash dn 4 F/5475'-T/5562'@ 1 BPM,40 psi,10%flow. Tagged TOL on depth @ 5562'MD. Set dn 15k,increase in psi to 60 psi and flow dropped to 0%. S/D pumps 1 p and attempt to continue slack off engaging seals(No Go).,Continue working string as per onsite BOT rep. P/U and S/O with and without pumps attempting to engage seals in sealbore(No Go). Put 1/4 turn in string and re-attempt multiple times. Ended up with 1 rotation after all attempts(No Go). Set a max of 20k set dn wt while attempting to engage seals(No Go).,Conference call with onsite DSM,onsite BOT rep,BOT supervisor,BOT engineer. Decision made to attempt to tr engage seals w/30k max set dn wt. Continue trying to engage seals with 30k max set dn wt(No Go). Visually verify flow out stops when setting dn 30k and verify depths(tag depth 5562'and 5563'with 30k set dn). Indicators show mule shoe unable to pass TOL.,Suspend operations. B/D TDS. Service rig while monitoring well. WOO. Discuss situation with drilling engineer,DSM's,and onsite BOT rep. Decision made to POH and L/D tieback string to inspect seal assy. Build 20 bbl dry job and pump same. B/D TDS. P/U T/5475'and rack back stand of DP,B/O xo and prep to laydown casing.C/O elevators to 7-5/8 slip type.,POH laying down 7-5/8"tieback casing string F/5475'-T/4,995'MD. Clean,inspect and laydown same. 3/23/2016 Continue POH laying down 7-5/8"tieback casing string F/4995'-T/Surface. Clean,inspect and laydown Bullet Seal Assembly.Mule shoe showed signs of 6 1/2"of engagement into SBR with slight gouging as well.Discuss with Engineers and decision made to TIH on Drill pipe and Polish SBR.R/D Weatherford casing handling equipment.,Set 9-15/16"ID wear bushing.Start loading 175 jts DS-50 Drill Pipe and 3 jts HWDP in shed.,Continue loading Drill Pipe in pipe shed.Strap and Tallysame.Mix Hi Vis Sweeppits.Service rigand TD.Monitor hole on triptank 6 BPH Loss Rate.,Make in @ up,inspect and caliper 7.38"TBR Dress and Polish Mill Assembly.PU 3 jts HWDP Total BHA Length(22.53).TIH picking up 5"DS-50 Drill Pipe from pipe shed f/22.53'to 5555'MD. Drift=2.38". Spinners on ST-80 failed. Continued trip in using chain tongs for last 1000'+/-. Mob spinner hawks from DDI casing yard.,Ream dn F/5555'-T/tag depth 5571'MD working mills in SBR. 3 bpm,40 psi,12%flow,25 rpm,5k tq off,170k P/U,125k S/O,148k Rot. No issues entering top of liner or other indicators of damage to SBR. Work mills 3x in SBR as per BOT rep. 1st-10k wob w/12k tq,2nd-5wob w/10k tq,3rd-3k w/5k tq. 15-20 sec each time while milling w/wob.,P/U to 5555' and circulate 30 bbl hi vis sweep around. 12 bpm,230 psi,32%flow,20 rpm,5k tq. Saw 200%increase in cuttings(fine sand). 2 lbs metal(estimated)cleaned from ditch magnets post cleanup cycle.,Shut down pumps,monitor well(static/slight losses). Pump dry job. Stand back 1 stand in derrick. B/D TDS. R/U spinner hawks and prep for trip out.,POH laying down 5"DS-50 drill pipe from 5555'-T/mill assy. Inspect and laydown same. Top dress mill showed good markings confirming good tag on TOL. Polish mill showed no damage. 20 bbl loss displacement for trip out. Static losses 3-4 BPH.,P/U single. Pull wear ring. R/D spinner hawks. Prep floor for running 7-5/8"casing.,Hauled 0 bbls to G&I for total=11681 bbls Hauled 0 bbls to B-50 for total=580 bbls Hauled 0 bbls from Vern Lake for total=850 bbls Hauled 202 bbls from L-Pad Lake for total=7501 bbls Daily losses to formation 67 bbls for total=507 bbls 3/24/2016 Continue to prep floor for running 7-5/8"casing.,PU and MU Tie Back Seal Assy.RIH PU 65Jts(2643.31')7 5/8",29.7#L-80,Vam STL Casing,MU Crossover,7- 5/8"29#,7-5/8"SLIJ II B x 7-5/8"STL pin,continue to run 71Jts(2816.54')7 5/8",29.7#L-80,Vam SLIJ II Casing to 5480'.,C/O elevators to 5"DP elevators. M/U XO and kelly up on 5"std. Wash dn F/5480'-T/5562'@ 1 BPM,40 psi,10%flow,saw pressure increase @ 5563',continue slack off into SBR,seeing each set of seals engage SBR.Land out on NO Go Locator @ 5572.81 Mule Shoe Depth. POOH lay down 3 jts DP. PU and MU 8.91 Space out Pup,Jts 1 SLIJ II Casing, Cross Over Pup,H511 Box x SLIJ II Pin,Casing Pup Joint,Casing Hanger.,Slack off slowly into seal bore and land out casing hanger.Pull 1 Lock Down Screw and verify hanger Landed.PUH and park 3'above TOL.,CBU from 5559'to clear 10.0 ppg dry job from annulus @ 4 bpm/120 psi.,Freeze Protect-Close annular and break circulation to ensure proper lineup for reverse circulating. Pump 68 bbls 11.2 ppg Bromide pill(corrosion inhibited w/baracor 100),chased with 39 bbls diesel. Cleared lines with 3 more bbls of Bromide pill.Pump @ 3 BPM,110 psi,12%flow.,Open annular,S/O and landout on depth(shoe @ 5571'MD). Land hanger w/95k string wt. 3-6k drag when seals engaged SBR. B/O landing jt. Dress w/packoff and packoff running tool. Drain stack. Install packoff,test void (5000 psi w/10 min hold). Test good(witnessed by Shane Barber).,R/U test equipment. Test 9-5/8"x 7-5/8"annulus to 1000 osi w/30 min hnH(nk) Chart and record same. R/D test equipment.,Load shed with remaining completion tbg and jewelry. Strap and tally same. R/U weatherford casing for 3-1/2"tbg. M/U FOSV x 3-1/2 XO for tbg.,PJSM, Run 3-1/2"EUE 8rd,9.3#,L-80 tbg as per detail F/surface-T/3945'MD. Full mule shoe. RHC ball catcher installed in"XN" nipple,HAL PHL packer dressed w/(6)shear screws. (2)GLM's dressed w/1"dummy valves,(1)GLM dressed w/2800#DCK shear valve.3k tq on connections.,Static losses remain 3-4 BPH w/daily losses @ 115 bbls for total=622 bbls loss to formation,Hauled 232 bbls to MP G&I for total=11,913 bbls Hauled 290 bbls to GPB G&I for total=290 bbls Hauled 0 bbls to B-50 for total=580 bbls Hauled 0 bbls from Vern Lake for total=850 bbls Hauled 155 bbls from L-Pad lake for total=7656 bbls 3/25/2016 Continue to run 3'/2"Gas Lift completionTrom 3945'to 5543'.Space out and makeup the tubing han r/Landing joint.Rig up FOSV and 2"circulating line to top of landing joint.,Reverse circulate 117 bbls 9.2 ppg PKR Fluid down annulus and chase with 71 bbls 9.2 brine @ 1.5 BPM/540 psi.,Land hanger with EOP @ 5585.51. RILDS, Drop ball and Rod. PU Wt 92K,SO 82K.(27K set on Tbg Hgr),Pressure up the tubing to 500 psi for 5 minutes,stage up pump and saw Packer shear @ 2150 psi.Stage up to 3809. Test the tubina to 3800 osi for 30 minutes. Bleed off the tubing pressure to 1700 psi. Test the annulus to 3,000 psi for 30 min.Bleed off the tubing pressure to zero and shear the DCK valve in GLM#1.Rig down Landing joint and circulating equipment.,Set BPV,Rig down Landing joint and circulating equipment.Blow down choke,kill and hole fill lines.Suck out BOP Stack.UD Mouse Hole,Remove Weatherford casing equipment from Rig Floor.,C/O lower rams from 7-5/8"to 5"fixed body. Sim ops-Clean pits and prep for rig move.,Nipple down BOP equipment,pull riser,stand back on pedestal/ secure same for rig move.,Orient and install production tree. Test void 500/5000 psi w/5/15 min hold(ok). Pull BPV and install TWC. Test tree 500/5000 w/ 10/10 min hold(ok). Pull TWC.,Rig up LRS. Freeze protect tbg and 3.5"x 7.625"annulus from surface to 2173'MD. Pump 100 bbls total w/6 bbls diesel returned to surface. Pump @ 2 bpm w/FCP 350 psi. SITP-210 psi. R/D LRS and secure well.,Continue cleaning pits,clean cellar,install blanking flanges on IA and OA. R/D service lines on rig floor. Prep floor to skidding. PJSM,Skid floor into moving position. p Release rig @ 06:00.,Hauled 185 bbls to MP G&I for total=12098 bbls ��Jt T-(A Hauled 0 bbls to GPB G&I for total=290 bbls Hauled 0 bbls to B-50 for total=580 bbls Hauled 0 bbls from Vern Lake for total=850 bbls M t Hauled 75 bbls from L-Pad lake for total=7731 bbls Daily losses to formation 144 bbls for total=766 bbls. • • • 4a 7 h Hilcorp Energy Company Milne Point M Pt B Pad MPB-28 ,;C 50-029-23566-00-00 50-029-23566-00-00 f Sperry Drilling 11 Definitive Survey Report , l� 23 March, 2016 I, r�l� Ili �'i iP AI I Fl HALLIBURTON Sperry Drilling • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPB-28 Project: Milne Point TVD Reference: MPB-28 @ 57.10usft(Doyon 14(23.5+33.6)) Site: ! M Pt B Pad MD Reference: MPB-28 @ 57.10usft(Doyon 14(23.5+33.6)) Well: MPB-28 North Reference: True Wellbore: MPB-28 Survey Calculation Method: Minimum Curvature Design: MPB-28 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 04 Using geodetic scale factor Well MPB-28 Well Position +NI-S 0.00 usft Northing: 6,022,955.82 usft Latitude: 70°28'22.803 N +El-W 0.00 usft Easting: 572,028.79 usft Longitude: 149°24'42.050 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 23.50 usft Wellbore MPB-28 Magnetics - Model Name Sample Date Declination DipAngle ', FieldStrength' (°? (*) (nT) BGGM2015 3/17/2016 18.74 81.08 57,506 Design MPB-28 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 33.60 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 33.60 0.00 0.00 295.74 Survey Program Date 13/23/2416 From Ta (usft) (USft)- Survey(Wellbore) 'Toot Name Description Surrey Date 124.00 882.00 SRG-MS(MPB-28) SRG-MS Surface readout gyro multishot 03/02/2016 976.95 1,165.00 MPB-28 MWD(MPB-28) MWD+IFR2+sag Fixed:v2:IIFR declination correction+sag 03/07/2016 1,258.37 1,354.44 MPB-28 Interp Azim(MPB-28) MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 03/07/2016 1,444.78 5,690.63 MPB-28 MWD(2)(MPB-28) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/07/2016 5,765.28 10,927.13 MPB-28 MWD(3)(MPB-28) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/15/2016 Survey Map Map Vertical MD" Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1104')' (ft), survey Tool Name, 33.60 0.00 0.00 33.60 -23.50 0.00 0.00 6,022,955.82 572,028.79 0.00 0.00 UNDEFINED 124.00 0.60 102.13 124.00 66.90 -0.10 0.46 6,022,955.73 572,029.25 0.66 -0.46 SRG-MS(1) 221.00 0.95 173.65 220.99 163.89 -1.01 1.05 6,022,954.82 572,029.85 0.98 -1.38 SRG-MS(1) 318.00 2.08 167.46 317.96 260.86 -3.52 1.52 6,022,952.31 572,030.34 1.18 -2.90 SRG-MS(1) 413.00 2.95 184.12 412.86 355.76 -7.64 1.72 6,022,948.19 572,030.58 1.19 -4.87 SRG-MS(1) 505.00 3.96 195.36 504.70 447.60 -13.07 0.71 6,022,942.76 572,029.62 1.32 -6.31 SRG-MS(1) 603.00 4.59 201.28 602.42 545.32 -19.99 -1.61 6,022,935.82 572,027.37 0.78 -7.23 SRG-MS(1) 694.00 4.90 200.16 693.11 636.01 -27.03 -4.27 6,022,928.76 572,024.78 0.36 -7.89 SRG-MS(1) 788.00 5.36 206.24 786.74 729.64 -34.73 -7.60 6,022,921.02 572,021.53 0.76 -8.24 SRG-MS(1) 882.00 5.66 211.75 880.30 823.20 -42.61 -11.98 6,022,913.10 572,017.22 0.65 -7.72 SRG-MS(1) 3/23/2016 6:05:57PM Page 2 COMPASS 5000.1 Build 73 • Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference; Well MPB-28 Project: Milne Point TVD Reference: MPB-28 @ 57.10usft(Doyon 14(23.5+33.6)) Site; M Pt B Pad MD Reference: MPB-28 @ 57.10usft(Doyon 14(23.5+33.6)) Well: MPB-28 North Reference: True Wellbore: MPB-28 Survey Calculation Method; ! Minimum Curvature Design: MPB-28 Databases Sperry EDM-NORTH US+CANADA Survey Map' Map Vertical MD Inc Azi TVD TVDSS +N1-S +El--W Northing Easting 'DES Section (usft) (°) (°) (usft) (usft) ;' (usft) (usft) (ft) (ft} f17o0'j', (ft) Survey Tool Name 976.95 5.77 207.15 974.78 917.68 -50.84 -16.62 6,022,904.82 572,012.66 0.50 -7.11 MWD+IFR2+sag(2) 1,070.38 5.55 202.54 1,067.76 1,010.66 -59.19 -20.50 6,022,896.44 572,008.87 0.54 -7.25 MWD+IFR2+sag(2) 1,165.03 6.31 202.44 1,161.90 1,104.80 -68.23 -24.24 6,022,887.37 572,005.22 0.80 -7.81 MWD+IFR2+sag(2) 1,258.37 8.77 201.16 1,254.42 1,197.32 -79.61 -28.76 6,022,875.94 572,000.80 2.64 -8.67 MWD_InterpAzi+sag(3) , 1,354.44 8.73 200.05 1,349.38 1,292.28 -93.29 -33.91 6,022,862.22 571,995.79 0.18 -9.98 MWD_InterpAzi+sag(3) 1,444.78 8.05 199.15 1,438.75 1,381.65 -105.70 -38.33 6,022,849.76 571,991.49 0.77 -11.39 MWD+IFR2+MS+sag(4) 1,542.23 8.27 200.51 1,535.21 1,478.11 -118.71 -43.03 6,022,836.71 571,986.92 0.30 -12.81 MWD+IFR2+MS+sag(4) 1,637.87 8.42 204.18 1,629.84 1,572.74 -131.54 -48.30 6,022,823.83 571,981.77 0.58 -13.63 MWD+IFR2+MS+sag(4) 1,732.48 6.52 192.06 1,723.65 1,666.55 -143.12 -52.26 6,022,812.22 571,977.92 2.60 -15.09 MWD+IFR2+MS+sag(4) 1,825.37 6.79 190.68 1,815.91 1,758.81 -153.67 -54.38 6,022,801.64 571,975.90 0.34 -17.76 MWD+IFR2+MS+sag(4) 1,920.08 7.95 204.86 1,909.85 1,852.75 -165.12 -58.18 6,022,790,16 571,972.22 2.27 -19.32 MWD+IFR2+MS+sag(4) 2,009.68 9.75 212.23 1,998.38 1,941.28 -177.16 -64.83 6,022,778.06 571,965.69 2.37 -18.56 MWD+IFR2+MS+sag(4) 2,105.10 11.41 218.47 2,092.18 2,035.08 -191.38 -75.01 6,022,763.74 571,955.64 2.11 -15.57 MWD+IFR2+MS+sag(4) 2,200.35 12.95 221.87 2,185.28 2,128.18 -206.71 -87.99 6,022,748.29 571,942.81 1.78 -10.53 MWD+IFR2+MS+sag(4) 2,293.62 15.74 224.21 2,275.64 2,218.54 -223.56 -103.79 6,022,731.28 571,927.17 3.05 -3.62 MWD+IFR2+MS+sag(4) 2,388.67 18.56 225.87 2,366.45 2,309.35 -243.34 -123.65 6,022,711.32 571,907.52 3.01 5.67 MWD+IFR2+MS+sag(4) 2,482.43 21.43 228.34 2,454.55 2,397.45 -265.12 -147.16 6,022,689.31 571,884.22 3.19 17.39 MWD+IFR2+MS+sag(4) 2,577.66 24.21 227.65 2,542.32 2,485.22 -289.84 -174.59 6,022,664.33 571,857.03 2.93 31.36 MWD+IFR2+MS+sag(4) 2,664.24 27.07 229.33 2,620.37 2,563.27 -314.65 -202.66 6,022,639.26 571,829.20 3.41 45.87 MWD+IFR2+MS+sag(4) 2,762.39 30.09 231.13 2,706.55 2,649.45 -344.65 -238.76 6,022,608.91 571,793.39 3.20 65.36 MWD+IFR2+MS+sag(4) 2,860.05 30.25 231.88 2,790.98 2,733.88 -375.20 -277.18 6,022,577.99 571,755.28 0.42 86.69 MWD+IFR2+MS+sag(4) 2,954.30 31.87 230.30 2,871.72 2,814.62 -405.75 -315.00 6,022,547.08 571,717.76 1.92 107.49 MWD+IFR2+MS+sag(4) 3,047.49 31.97 229.59 2,950.81 2,893.71 -437.46 -352.72 6,022,515.01 571,680.36 0.42 127.69 MWD+IFR2+MS+sag(4) 3,144.06 32.28 229.92 3,032.60 2,975.50 -470.63 -391.91 6,022,481.46 571,641.49 0.37 148.58 MWD+IFR2+MS+sag(4) 3,238.85 31.94 229.53 3,112.89 3,055.79 -503.20 -430.35 6,022,448.52 571,603.37 0.42 169.06 MWD+IFR2+MS+sag(4) 3,332.85 32.38 230.74 3,192.47 3,135.37 -535.27 -468.76 6,022,416.09 571,565.28 0.83 189.72 MWD+IFR2+MS+sag(4) 3,424.51 31.95 232.11 3,270.06 3,212.96 -565.70 -506.90 6,022,385.30 571,527.43 0.92 210.87 MWD+IFR2+MS+sag(4) 3,519.93 32.28 232.23 3,350.88 3,293.78 -596.81 -546.97 6,022,353.80 571,487.67 0.35 233.44 MWD+IFR2+MS+sag(4) 3,615.82 32.36 232.72 3,431.91 3,374.81 -628.04 -587.63 6,022,322.18 571,447.32 0.29 256.50 MWD+IFR2+MS+sag(4) 3,709.08 33.70 232.44 3,510.10 3,453.00 -658.93 -628.00 6,022,290.91 571,407.26 1.45 279.45 MWD+IFR2+MS+sag(4) 3,803.59 33.58 239.60 3,588.81 3,531.71 -688.15 -671.34 6,022,261.27 571,364.20 4.20 305.80 MWD+IFR2+MS+sag(4) 3,898.21 33.02 246.30 3,667.92 3,610.82 -711.76 -717.54 6,022,237.22 571,318.24 3.93 337.15 MWD+IFR2+MS+sag(4) 3,992.75 33.78 252.01 3,746.87 3,689.77 -730.24 -766.13 6,022,218.27 571,269.83 3.42 372.89 MWD+IFR2+MS+sag(4) 4,088.34 37.77 259.21 3,824.44 3,767.34 -743.94 -820.21 6,022,204.05 571,215.89 6.06 415.65 MWD+IFR2+MS+sag(4) 4,181.14 42.75 265.34 3,895.27 3,838.17 -751.82 -879.58 6,022,195.59 571,156.61 6.85 465.70 MWD+IFR2+MS+sag(4) 4,275.80 45.12 269.99 3,963.45 3,906.35 -754.44 -945.17 6,022,192.34 571,091.06 4.23 523.64 MWD+IFR2+MS+sag(4) 4,369.28 47.37 273.60 4,028.10 3,971.00 -752.29 -1,012.63 6,022,193.84 571,023.59 3.68 585.34 MVVD+IFR2+MS+sag(4) 4,463.91 50.82 279.38 4,090.09 4,032.99 -744.12 -1,083.61 6,022,201.32 570,952.53 5.88 652.83 MWD+IFR2+MS+sag(4) 4,558.71 54.41 284.56 4,147.66 4,090.56 -728.43 -1,157.23 6,022,216.30 570,878.77 5.76 725.95 MWD+IFR2+MS+sag(4) 4,653.02 56.35 288.06 4,201.25 4,144.15 -706.61 -1,231.68 6,022,237.39 570,804.12 3.68 802.50 MWD+IFR2+MS+sag(4) 3/23/2016 6:05:57PM Page 3 COMPASS 5000.1 Build 73 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPB-28 Project: Milne Point TVD Reference: MPB-28 @ 57.10usft(Doyon 14(23.5+33.6)) Site: ! M Pt B Pad MD Reference: MPB-28 @ 57.10usft(Doyon 14(23.5+33.6)) Well: MPB-28 North Reference: True Wellbore: MPB-28 Survey Calculation Method: Minimum Curvature Design: MPB-28 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS tNRS E/W Northing Easting DIS + Section (usft) (°) ;(') (usft) (usft) (usft) (usft) (ft) (ft) (0!1001 oft Survey Tool Name 4,747.32 59.25 291.70 4,251.51 4,194.41 -679.45 -1,306.68 6,022,263.82 570,728.87 4.49 881.85 MWD+IFR2+MS+sag(4) 4,841.43 63.00 295.05 4,296.96 4,239.86 -646.72 -1,382.28 6,022,295.81 570,652.96 5.06 964.16 MWD+IFR2+MS+sag(4) 4,935.77 68.80 296.67 4,335.46 4,278.36 -609.16 -1,459.73 6,022,332.62 570,575.16 6.34 1,050.23 MWD+IFR2+MS+sag(4) 5,030.95 76.80 300.40 4,363.59 4,306.49 -565.71 -1,539.49 6,022,375.29 570,494.99 9.20 1,140.95 MWD+IFR2+MS+sag(4) 5,124.20 82.93 301.89 4,380.00 4,322.90 -518.25 -1,618.01 6,022,421.99 570,416.02 6.76 1,232.29 MWD+IFR2+MS+sag(4) 5,218.27 82.93 302.28 4,391.57 4,334.47 -468.66 -1,697.11 6,022,470.80 570,336.46 0.41 1,325.08 MWD+IFR2+MS+sag(4) 5,313.04 82.00 301.99 4,404.00 4,346.90 -418.69 -1,776.67 6,022,520.00 570,256.43 1.03 1,418.44 MWD+IFR2+MS+sag(4) 5,407.50 83.05 305.47 4,416.29 4,359.19 -366.69 -1,854.54 6,022,571.24 570,178.06 3.82 1,511.18 MWD+IFR2+MS+sag(4) 5,502.19 83.75 307.29 4,427.18 4,370.08 -310.90 -1,930.27 6,022,626.29 570,101.80 2.05 1,603.62 MWD+IFR2+MS+sag(4) 5,596.77 85.29 308.63 4,436.21 4,379.11 -252.99 -2,004.49 6,022,683.47 570,027.03 2.15 1,695.63 MWD+IFR2+MS+sag(4) 5,690.63 92.84 308.96 4,437.74 4,380.64 -194.23 -2,077.58 6,022,741.51 569,953.38 8.05 1,786.99 MWD+IFR2+MS+sag(4) 5,765.28 92.47 309.67 4,434.28 4,377.18 -146.98 -2,135.27 6,022,788.19 569,895.24 1.07 1,859.48 MWD+IFR2+MS+sag(5) 5,860.25 91.24 308.73 4,431.21 4,374.11 -86.99 -2,208.83 6,022,847.46 569,821.11 1.63 1,951.79 MWD+IFR2+MS+sag(5) 5,955.00 91.73 307.47 4,428.75 4,371.65 -28.55 -2,283.37 6,022,905.18 569,746.02 1.43 2,044.31 MWD+IFR2+MS+sag(5) 6,049.79 91.61 306.22 4,425.99 4,368.89 28.26 -2,359.19 6,022,961.25 569,669.66 1.32 2,137.29 MWD+IFR2+MS+sag(5) 6,143.30 91.42 305.70 4,423.52 4,366.42 83.16 -2,434.85 6,023,015.40 569,593.48 0.59 2,229.28 MWD+IFR2+MS+sag(5) 6,238.05 90.86 305.85 4,421.63 4,364.53 138.54 -2,511.71 6,023,070.03 569,516.09 0.61 2,322.56 MWD+IFR2+MS+sag(5) 6,332.97 90.80 305.95 4,420.26 4,363.16 194.19 -2,588.59 6,023,124.93 569,438.69 0.12 2,415.99 MWD+IFR2+MS+sag(5) 6,427.15 90.31 307.81 4,419.35 4,362.25 250.71 -2,663.92 6,023,180.71 569,362.82 2.04 2,508.38 MWD+IFR2+MS+sag(5) 6,520.77 91.36 309.28 4,417.98 4,360.88 309.03 -2,737.13 6,023,238.32 569,289.06 1.93 2,599.66 MWD+IFR2+MS+sag(5) 6,615.57 91.73 310.50 4,415.43 4,358.33 369.81 -2,809.84 6,023,298.39 569,215.77 1.34 2,691.56 MWD+IFR2+MS+sag(5) 6,709.89 92.10 310.04 4,412.27 4,355.17 430.74 -2,881.76 6,023,358.61 569,143.26 0.63 2,782.81 MWD+IFR2+MS+sag(5) 6,803.66 90.93 310.32 4,409.79 4,352.69 491.22 -2,953.38 6,023,418.39 569,071.07 1.28 2,873.59 MWD+IFR2+MS+sag(5) 6,898.32 89.44 309.63 4,409.49 4,352.39 552.03 -3,025.92 6,023,478.49 568,997.96 1.73 2,965.34 MWD+IFR2+MS+sag(5) 6,992.57 89.81 308.39 4,410.11 4,353.01 611.35 -3,099.15 6,023,537.10 568,924.16 1.37 3,057.07 MWD+IFR2+MS+sag(5) 7,086.64 92.16 309.48 4,408.49 4,351.39 670.46 -3,172.31 6,023,595.48 568,850.44 2.75 3,148.64 MWD+IFR2+MS+sag(5) 7,181.11 91.48 308.19 4,405.49 4,348.39 729.67 -3,245.86 6,023,653.97 568,776.33 1.54 3,240.60 MWD+IFR2+MS+sag(5) 7,275.62 89.81 306.71 4,404.42 4,347.32 787.13 -3,320.88 6,023,710.70 568,700.77 2.36 3,333.14 MWD+IFR2+MS+sag(5) 7,369.45 90.74 307.56 4,403.97 4,346.87 843.77 -3,395.68 6,023,766.61 568,625.43 1.34 3,425.11 MWD+IFR2+MS+sag(5) 7,464.33 91.85 307.02 4,401.83 4,344.73 901.24 -3,471.14 6,023,823.34 568,549.42 1.30 3,518.05 MWD+IFR2+MS+sag(5) 7,558.31 91.67 304.66 4,398.94 4,341.84 956.23 -3,547.28 6,023,877.59 568,472.75 2.52 3,610.52 MWD+IFR2+MS+sag(5) 7,653.02 91.98 304.27 4,395.93 4,338.83 1,009.80 -3,625.33 6,023,930.40 568,394.20 0.53 3,704.09 MWD+IFR2+MS+sag(5) 7,701.70 92.10 303.77 4,394.19 4,337.09 1,037.02 -3,665.65 6,023,957.22 568,353.62 1.06 3,752.23 MWD+IFR2+MS+sag(5) 7,741.75 91.67 304.07 4,392.88 4,335.78 1,059.36 -3,698.87 6,023,979.24 568,320.19 1.31 3,791.86 MWD+IFR2+MS+sag(5) 7,792.39 90.62 303.58 4,391.86 4,334.76 1,087.54 -3,740.93 6,024,007.01 568,277.87 2.29 3,841.98 MWD+IFR2+MS+sag(5) 7,839.56 90.68 302.74 4,391.33 4,334.23 1,113.34 -3,780.41 6,024,032.42 568,238.14 1.79 3,888.75 MWD+IFR2+MS+sag(5) 7,893.10 92.04 302.73 4,390.06 4,332.96 1,142.28 -3,825.44 6,024,060.93 568,192.84 2.54 3,941.88 MWD+IFR2+MS+sag(5) 7,935.07 92.10 302.02 4,388.54 4,331.44 1,164.74 -3,860.86 6,024,083.04 568,157.20 1.70 3,983.54 MWD+IFR2+MS+sag(5) 7,987.35 91.23 301.30 4,387.02 4,329.92 1,192.17 -3,905.34 6,024,110.03 568,112.46 2.16 4,035.52 MWD+IFR2+MS+sag(5) 8,030.51 91.11 300.89 4,386.14 4,329.04 1,214.46 -3,942.29 6,024,131.96 568,075.30 0.99 4,078.48 MWD+IFR2+MS+sag(5) 3/23!2016 6:05:57PM Page 4 COMPASS 5000.1 Build 73 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well MPB-28 Project: Milne Point TVD Reference: MPB-28 @ 57.10usft(Doyon 14(23.5+33.6)) Site: M Pt B Pad MD Reference: MPB-28 @ 57.10usft(Doyon 14(23.5+33.6)) Well; MPB-28 North Reference: f True Welibore: MPB-28 Survey Calculation Method: Minimum Curvature Design: MPB-28 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nt-S +Ei-W Northing Fasting DLS Section (usft) ';(e) (°} (usft} (usft) (usft) (usft) (ft) (ft} ('(100')' (ft) Survey Tool Name 8,079.33 91.55 300.64 4,385.01 4,327.91 1,239.42 -3,984.23 6,024,156.51 568,033.13 1.04 4,127.10 MWD+IFR2+MS+sag(5) 8,124.49 91.54 300.46 4,383.79 4,326.69 1,262.37 -4,023.11 6,024,179.08 567,994.04 0.40 4,172.09 MWD+IFR2+MS+sag(5) 8,176.81 92.41 300.02 4,381.99 4,324.89 1,288.70 -4,068.28 6,024,204.97 567,948.61 1.86 4,224.22 MVVD+IFR2+MS+sag(5) 8,218.34 91.98 300.71 4,380.40 4,323.30 1,309.68 -4,104.08 6,024,225.60 567,912.61 1.96 4,265.58 MWD+IFR2+MS+sag(5) 8,313.22 90.86 301.59 4,378.05 4,320.95 1,358.74 -4,185.26 6,024,273.87 567,830.97 1.50 4,360.01 MWD+IFR2+MS+sag(5) 8,406.75 92.29 304.53 4,375.48 4,318.38 1,409.74 -4,263.61 6,024,324.10 567,752.14 3.49 4,452.73 MWD+IFR2+MS+sag(5) 8,502.75 94.58 306.85 4,369.72 4,312.62 1,465.64 -4,341.43 6,024,379.24 567,673.79 3.39 4,547.10 MWD+IFR2+MS+sag(5) 8,596.47 93.15 306.12 4,363.41 4,306.31 1,521.23 -4,416.60 6,024,434.10 567,598.09 1.71 4,638.97 MWD+IFR2+MS+sag(5) 8,691.91 90.62 305.58 4,360.27 4,303.17 1,577.09 -4,493.92 6,024,489.21 567,520.25 2.71 4,732.87 MWD+IFR2+MS+sag(5) 8,785.92 89.14 307.31 4,360.46 4,303.36 1,632.94 -4,569.53 6,024,544.31 567,444.10 2.42 4,825.24 MWD+IFR2+MS+sag(5) 8,880.13 92.16 312.21 4,359.39 4,302.29 1,693.16 -4,641.92 6,024,603.82 567,371.14 6.11 4,916.60 MWD+IFR2+MS+sag(5) 8,973.98 90.80 313.89 4,356.97 4,299.87 1,757.20 -4,710.48 6,024,667.19 567,301.97 2.30 5,006.17 MWD+IFR2+MS+sag(5) 9,068.68 88.95 313.40 4,357.18 4,300.08 1,822.56 -4,779.00 6,024,731.88 567,232.83 2.02 5,096.28 MWD+IFR2+MS+sag(5) 9,161.80 90.00 314.41 4,358.03 4,300.93 1,887.13 -4,846.09 6,024,795.79 567,165.12 1.56 5,184.75 MWD+IFR2+MS+sag(5) 9,257.09 91.24 317.58 4,357.00 4,299.90 1,955.66 -4,912.27 6,024,863.67 567,098.28 3.57 5,274.14 MWD+IFR2+MS+sag(5) 9,351.64 92.41 317.52 4,353.99 4,296.89 2,025.38 -4,976.06 6,024,932.77 567,033.83 1.24 5,361.87 MWD+IFR2+MS+sag(5) 9,445.83 91.98 317.16 4,350.38 4,293.28 2,094.60 -5,039.84 6,025,001.36 566,969.39 0.60 5,449.39 MWD+IFR2+MS+sag(5) 9,541.05 91.79 315.85 4,347.25 4,290.15 2,163.64 -5,105.34 6,025,069.75 566,903.23 1.39 5,538.38 MWD+IFR2+MS+sag(5) 9,635.25 90.80 315.21 4,345.12 4,288.02 2,230.84 -5,171.31 6,025,136.31 566,836.62 1.25 5,626.99 MWD+IFR2+MS+sag(5) 9,728.66 90.43 315.28 4,344.12 4,287.02 2,297.17 -5,237.08 6,025,201.99 566,770.22 0.40 5,715.04 MWD+IFR2+MS+sag(5) 9,823.14 90.49 314.82 4,343.36 4,286.26 2,364.03 -5,303.82 6,025,268.20 566,702.84 0.49 5,804.20 MWD+IFR2+MS+sag(5) 9,917.22 90.68 315.36 4,342.40 4,285.30 2,430.66 -5,370.24 6,025,334.17 566,635.79 0.61 5,892.97 MWD+IFR2+MS+sag(5) 10,011.17 91.30 314.94 4,340.77 4,283.67 2,497.25 -5,436.49 6,025,400.12 566,568.90 0.80 5,981.57 MWD+IFR2+MS+sag(5) 10,105.79 90.68 313.62 4,339.14 4,282.04 2,563.30 -5,504.22 6,025,465.50 566,500.54 1.54 6,071.26 MWD+IFR2+MS+sag(5) 10,200.50 90.31 312.73 4,338.32 4,281.22 2,628.10 -5,573.28 6,025,529.62 566,430.86 1.02 6,161.62 MWD+IFR2+MS+sag(5) 10,294.46 91.11 313.52 4,337.16 4,280.06 2,692.33 -5,641.86 6,025,593.17 566,361.68 1.20 6,251.28 MWD+IFR2+MS+sag(5) 10,389.16 91.24 314.67 4,335.21 4,278.11 2,758.21 -5,709.85 6,025,658,39 566,293.05 1.22 6,341.14 MWD+IFR2+MS+sag(5) 10,483.67 90.12 314.26 4,334.09 4,276.99 2,824.41 -5,777.30 6,025,723.92 566,224.98 1.26 6,430.65 MWD+IFR2+MS+sag(5) 10,577.95 88.64 313.29 4,335.11 4,278.01 2,889.62 -5,845.37 6,025,788.47 566,156.29 1.88 6,520.29 MWD+IFR2+MS+sag(5) 10,672.16 90.19 313.87 4,336.08 4,278.98 2,954.56 -5,913.61 6,025,852.74 566,087.43 1.76 6,609.96 MWD+IFR2+MS+sag(5) 10,766.49 89.32 313.17 4,336.48 4,279.38 3,019.52 -5,982.01 6,025,917.03 566,018.41 1.18 6,699.79 MWD+IFR2+MS+sag(5) 10,861.34 88.39 311.93 4,338.37 4,281.27 3,083.64 -6,051.86 6,025,980.47 565,947.94 1.63 6,790.57 MWD+IFR2+MS+sag(5) 10,927.13 89.01 311.08 4,339.87 4,282.77 3,127.23 -6,101.12 6,026,023.57 565,898.27 1.60 6,853.87 MWD+IFR2+MS+sag(5) 11,000.00 89.01 311.08 4,341.13 4,284.03 3,175.11 -6,156.04 6,026,070.91 565,842.89 0.00 6,924.13 PROJECTED to TD brian.wheeier@halliburton.coo-�rww.aw cary.taylor@halliburton.c aww w�ntlraa�a �<«� Checked By: mm,m,v,,,v, Approved By: om ;,. Date: 3/23/2016 6:05:57PM Page 5 COMPASS 5000.1 Build 73 • • Hilcorp Energy Company • CASING&CEMENTING REPORT Lease&Well No. MP B-28 Date Run 10-Mar-16 County State Alaska Supv. S.Sunderland/D.Yessak CASING RECORD Surface V TD 5,738.00 Shoe Depth: 5,721.20 PBTD: No.Jts.Delivered 145 No.Jts.Run 138 No.Jts.Returned 7 Length Measurements W/O Threads Ftg.Delivered 5,814.95 Ftg.Run 5,512.94 Ftg.Returned 302.01 Casing(Or Liner)Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top Shoe 95/8 40.0 L-80 TCII DHP 3.02 5,721.24 5,718.22 1 Casing 9 5/8 40 L-80 TCII 40.52 5,718.22 5,677.70 Float Collar 95/8 40.0 L-80 TCII DHP 1.95 5,677.70 5,675.75 2 Casing 9 5/8 40 L-80 TCII 39.38 5,675.75 5,636.37 Baffle Adaptor 95/8 40.0 L-80 TCII Halliburton 1.80 5,636.37 5,634.57 90 Casing 9 5/8 40 L-80 TCII 3,504.71 5,634.57 2,129.86 ES Cementer 9 5/8 40.0 L-80 TCII Halliburton 3.42 2,129.86 2,126.44 142 Ca- 95/8 40 L-80 TCII 2,048.53 2,126.44 37.37 Pup Joint 95/8 40.0 L-80 TCII 2.15 37.37 35.22 Hanger 9 5/8 TCII Seaboard 0.85 35.22 34.37 RKB 34.37 34.37 Csg Wt.On Hook: 250,000 Type Float Collar Weatherford No.Hrs to Run: 13.5 Csg Wt.On Slips: 100,000 Type of Shoe: Weatherford Casing Crew: Weatherford Rotate Csg Yes X No Recip Csg _Yes X No 15 Ft.Min. 9.45 PPG Fluid Description: Spud Mud Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Floats Held X Yes No Centralizer Placement: 2 centralizers 10'from ea.end over stop collars on shoe jt,1 mid tube over stop collar on FC jt,1 every other jt to 5000',3 below and 3 above ES cementer CEMENTING REPORT Shoe @ 5721 FC @ 5,676.00 Top of Liner Pref lush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: ExtendaCem Density(ppg) 11.7 Volume pumped(BBLs) 236 Mixing/Pumping Rate(bpm): 4.2 Tail Slurry w Type: SwiftCem ;/ Density(ppg) 15.8 Volume pumped(BBLs) 44 Mixing/Pumping Rate(bpm): 3.5 k, r Post Flush(Spacer) rc Type: Density(ppg) Rate(bpm): Volume: Li Displacement: Type: Spud Mud Density(ppg) 9.45 Rate(bpm): 6 Volume(actual/calculated): 427/427 FCP(psi): 1110 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1350 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 95 Cement returns to surface? X Yes_No Spacer returns? X Yes No Vol to Surf: 153 ./ r4 V [./""' , Cement In Place At: 22:30 Date: 3/11/2016 Estimated TOC: • 2,126 '� Method Used To Determine TOC: Calc/ES Cementer Stage Collar @ 2126 Type ES Cementer Closure OK Y Preflush(Spacer) Type: Clean Spacer III Density(ppg) 10.5 Volume pumped(BBLs) 47 Lead Slurry Type: Permafrost L Density(ppg) 10.7 Volume pumped(BBLs) 251 Mixing/Pumping Rate(bpm): 5.5 Tail Slurry t Type: Swift Cem ,2„,, y v� Density(ppg) 15.8 Volume pumped(BBLs) 55 Mixing/Pumping Rate(bpm): 5 z Post Flush(Spacer) u Type: Density(ppg) Rate(bpm): Volume: w w Displacement: Type: Spud Mud Density(ppg) 9.45 Rate(bpm): 6 Volume(actual/calculated): 161.2/161.2 FCP(psi): 670 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1900 Casing Rotated? Yes X No Reciprocated? _Yes X No %Retums during job 100 Cement returns to surface? X Yes_No Spacer returns? X Yes_No Vol to Surf: 100 Cement In Place At: 6:12 Date: 3/12/2016 Estimated TOC: 0 • Method Used To Determine TOC: Cement to surface WELLHEAD Make Type Serial No. Size W.P. Test head to PSIG MIN OK Remarks: www.wellez.net WellEz Information Management LLC ver_020216bf • • M P B-28 FINAL Days vs Depth 0 l 500 �MPB 28 Actual -MPB-28 Plan 1000 — -MPB-28 Stretch Goal 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 0 5 10 15 20 25 30 Days 4/25/2016 2:33 PM • • MPB-28 MW vs Depth 0 MPB-28 Plan 1000 MPB 28 Actual 2000 3000 4000 5000 s aa, 6000 a co co w 7000 8000 9000 10000 11000 12000 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) r M 21 60 27 Maile Sweigart 2 6 9 9 1 Alaska North Slope Team Hilcorp Alaska,LLC 3800 Centerpoint Drive,Ste 1400 l Anchorage,Alaska 99503 Ifilrari:t4ii.ka.i.Ux: Office:907.777.8473 msweigart@hilcorp.com DATA LOGGED q/ 5/201(6 Date: 4/4/2016 M.K.BENDEk To: Alaska Oil & Gas Conservation Commission Makana Bender AECEIVED Natural Resource Technician 333 W 7th Ave Ste 100 APR 0 4 2016 Anchorage, AK 99501 AOGGC DATA TRANSMITTAL MP B-28 B-28 Prints: ROP-DGR-ADR-EWR-HORIZONTAL PRES 21N MD,DGR-ADR-EWR INV/REV INTERVALS 2IN TVD E log data CD 1 : Final Well Data Name Date modified Type MPB-28_DATA_CD 3124.x`20161:03 PM File folder Each folder contains subfolders: Name Date modified Type 14 DL.IS+LAS 4/4/2016 8:20 AM File folder 10 EMF 4/4/2016 8:21 AM File folder o Geosteering Data 4/4/2016 8:21 AM File folder to PDF 3/24+20161:03 PM File folder ki TIFF 4/4.2016 8:21 AM File folder jt CGM 4/4120168:22AIM File folder Definitive Survey 4x4.2016 8:22 AM File folder Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: 04")„ e.../.) `.e`GCCte: .1.4 Or T� • • g.0*` \�v1/4,''• THE STATE Alaska Oil and Gas ofLAS <:A Conservation Commission Ittof -#2 �� 333 West Seventh Avenue + r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 F Aire- Fax: 907.276.7542 www.aogcc.alaska.gov Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPB-28 Hilcorp Alaska, LLC Permit to Drill Number: 216-027 Surface Location: 5112'FSL, 4265' FEL, SEC. 19, T13N, R11E,UM, AK Bottomhole Location: 2826' FSL, 50' FWL, SEC. 13, T13N, R10E, UM, AK Dear Mr. Keller: 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, Cathy P oerster Chair DATED this Zbay of February, 2016. f4ECEIVED STATE OF ALASKA All"OIL AND GAS CONSERVATION COM N FEB 0 8 2016 PERMIT TO DRILL 20 MC 25.005 AOGCC la.Tyne of Work: 1 b.Proposed Well Class. Exploratory-Gas ❑ Service- WAG ❑ Service-Disc ❑ 1 c.Specify if well.Ls,proposed for: Drill ❑., ' Lateral ❑ Stratigraphic Test ❑ Development-Oil Q• Service- Wnj ❑ Single Zone ❑., q Coalbed Gas❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply El Multiple Zone El Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244• MPB-28 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 MD: 10,889' • ND: 4,406'• Milne Point Unit • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Schrader Bluff Oil Pool Surface: 5112'FSL,4265 FEL,Sec 19,T13N,R11 E,UM,AK • ADL047438(SHL)ADL047437(TPH,BHL) Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 420'FNL,1122'FEL,Sec 24,T13N,R10E,UM,AK N/A 3/8/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2826'FSL,50'FWL,Sec 13,T13N,R10E,UM,AK ADL047438-2544/ADL047437-2560 ' 3,295' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): 57.2 . 15.Distance to Nearest Well Open Surface: x-572028 y-6022955 Zone-4 • GL Elevation above MSL(ft): 23.5• to Same Pool: MPB-02 2,010' 16.Deviated wells: Kickoff depth: , 250 feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 90 degrees Downhole: 1600 • Surface: 1158 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade _ Coupling Length MD ND MD ND (including stage data) Conductor 20" 78.6# A-53 Weld 110' 0 0 110' 110' Stg 1 L-1213ft3/T-242ft3 12-1/4" 9-5/8" 40# L-80 DWC/C 5,572' 0 0 5,572' 4,421' Stg 2 L-1570 ft3/T-314 ft3 Tieback 7-5/8" 29.7# L-80 SLIJ-II 2,500' 0 0 2,500' 2,418' Tie Back Assembly Tieback 7-5/8" 29.7# L-80 VAM STL 2,900' 2,500' 2,418' 5,400' 4,406' Tie Back Assembly ,5 8-1/2" 4-1/2" 12.6# L-80 Hyd 521 5,489' 5,400' 4,406' 10,889' 4,406' Wire Wrapped Production Screens 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) 4- Total Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Pial Q BOP Sketci0 Drilling Program Q Time v.Depth Plot ❑✓ Shallow Hazard Analyss❑ Diverter Sketci❑✓ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requiremens❑✓ 21. Verbal Approval: Commission Representative: Date 22.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Luke Keller Email Ikeller@hilcorp.com Printed Name uke Keller / , Title Drilling Engineer Signature Phone 777-8395 Date 85/ °pVA Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: a i(0- 0,2:?_ 50- 0)::1-a3vop ,—03 -OO Date: a(?VAN 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 sh:d Other: X 30D0 106 L. j3 L') P -i.,,5 f- Samples req'd: Ye;❑ Ne[11 Mud log req'd:Yap No[2 ' S cc 1,-) .awl, fl t - H2S measures: Ye;[+1 Mb❑ Directional svy req'd:Ytj No[ L, ` t ' Spacing exception req'd: Ys❑ 1,112( Inclination-only svy req'd:YC Nb[� Post initial injection MIT req'd:Yi50 Nb❑ APPROVED BY / Approved by: .-- COMMISSIONER TM COMMISSION Date: a ''2j -f,!. ' ..1-.26•l6 5/1%aal i 7Z"1/ ' 2 X� 6 Submit Form and Form 1' ;�, (Revised 11/2015) Of16 from the a ofp71)O aI(20 AAC 005(g)) Attachments in Duplicate • Luke Keller • Hilcorp Alaska, LLC 11 Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8395 Email Ikeller@hilcorp.com Hilcorp Alaska,LLC February 8th, 2016 RECEWED FEB 0 8 2016 Commissioner Alaska Oil &Gas Conservation Commission AOGCC 333 W. 7th Avenue Anchorage, Alaska 99501 Re: MPB-28 Dear Commissioner, MPU B-28 is a grassroots producer planned to be drilled in the Schrader Bluff ND sand. B-28 is part of a(2)well pilot program targeting the ND sand. B-28 will be paired with a grassroots injector, B-29. The directional plan is a catenary wellpath build with 9-5/8" surface casing set into the top of the Schrader Bluff ND sand. A lateral section will then be drilled in the reservoir. Production screens will then be run inside the well to limit sand production from the well. A 3-1/2"gas lift completion will then be run to produce the well. Drilling operations are expected to commence approximately March 8th, 2016. Doyon Rig#14 will be used to drill and complete the wellbore. 7 If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, /2(/(--- Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 • • H Hilcorp Alaska, LLC Milne Point Unit (MPU) B-28 Drilling Program Version 0 Feb 3rd, 2016 • • Milne Point Drilling Procedure HilEnergYo Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Casing Inspection 4 6.0 Internal Reporting Requirements 5 7.0 Planned Wellbore Schematic 6 8.0 Drilling/Completion Summary 7 9.0 Mandatory Regulatory Compliance/Notifications 8 10.0 R/U and Preparatory Work 10 11.0 N/U 21-1/4"2M Diverter System 10 12.0 Drill 12-1/4"Hole Section 13 13.0 Run 9-5/8"Surface Casing 17 14.0 Cement 9-5/8"Surface Casing 23 15.0 BOP N/U and Test 28 16.0 Drill 8-1/2"Hole Section 30 17.0 Run 4-1/2"Production Screens 34 18.0 Run 7-5/8"Tieback 37 19.0 Run 3-1/2"Production Tubing 39 20.0 RDMO 39 21.0 Diverter Schematic 40 22.0 BOP Schematic 41 23.0 Wellhead Schematic 42 24.0 Days Vs Depth 43 25.0 Formation Tops 44 26.0 Anticipated Drilling Hazards 45 27.0 Doyon 14 Rig Layout 47 28.0 FIT Procedure 48 29.0 Choke Manifold Schematic 49 30.0 Casing Design Information 50 31.0 8-1/2"Hole Section MASP 51 32.0 Spider Plot(NAD 27)(Governmental Sections) 52 33.0 Surface Plat(As Built)(NAD 27) 53 34.0 Offset MW vs TVD Chart 54 35.0 Drill Pipe Information 5" 19.5#S-135 DS-50 55 • • Milne Point Unit B-28 Drilling Procedure Hilcorp Energy 1.0 Well Summary Well MPU B-28 Pad Milne Point"B"Pad Planned Completion Type 3-1/2"Gas Lift Target Reservoir(s) Schrader Bluff "ND" Sand Planned Well TD,MD/TVD 10,889.63' MD/4,406.5' TVD PBTD,MD/TVD 10,888' MD/4,406.5' TVD Surface Location(Governmental) 5112 FSL,4265' FEL, Sec 19,T13N,R11E,UM,AK' Surface Location(NAD 27—Zone 4) X=572,028.79 Y=6,022,955.82 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 420' FNL, 1122' FEL Sec 24,T13N,R10E,UM,AK TPH Location(NAD 27) X=570,069.29,Y=6,022,681.91 TPH Location(NAD 83) BHL(Governmental) 2826' FSL, 50' FWL, Sec 13,T13N,R10E,UM,AK BHL(NAD 27) X=565,822.50,Y=6,025,881.10 BHL(NAD 83) AFE Number 1610003D AFE Drilling Days 22 days AFE Completion Days 5 days AFE Drilling Amount $4,818,800.00 AFE Completion Amount $2,279,500.00 AFE Facility Amount $350,000.00 Maximum Anticipated Pressure (Surface) 1158 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1600 psig Work String 5" 19.5# S-135 DS-50(Weatherford Rental) KB Elevation above MSL: 33.7 ft+23.5 ft= 57.2 ft GL Elevation above MSL: 23.5 ft BOP Equipment 13-5/8"x 5M Annular, (3)ea 13-5/8"x 5M Rams Page 2 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcorp 2.0 Management of Change Information Hilcorp Alaska, LLC H�ilcor Changes to Approved Permit to Drill Date: 1-20-2016 Subject Changes to Approved Permit to Drill for MPU B-28 File 8: MPU 8-28 Drilling and Completion Program Any modifications to MPUB-28 Drilling&Completion Program will be documented and approved below_ Changes to an approved APD will be communicated&approved by the AOGCC. Sec Page Date Procedure Change Approved Approved BY BY Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 1 Feb 2016 • • Milne Point Unit B-28 11 Drilling Procedure Hilc_orp Energy Cow 3.0 Tubular Program: Cond 20" 19.25" - - 78.6 A-53 Weld --- 12-1/4" 9-5/8" 8.835" 8.75" 10.235" 40 L-80 DWC/C 5,750 3,090 916 8-1/2" 4-1/2" 3.894" 3.75" 5.307" 12.6# L-80 H521 - - 200 - 7-5/8" 6.875" 6.75" 7.711" 29.7# L-80 SLIJ-II 6890 4790 473 - 7-5/8" 6.875" 6.75" 7.625" 29.7# L-80 VAM 6890 4790 444 STL ----------- ----------- 4.0 Drill Pipe Information: All 5" 4.276" 3.25" 6.625" 19.5 S-135 GPDS50 36,100 43,100 560k 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 Feb 2016 • • Milne Point Unit B-28 11 Drilling Procedure HilcorpEmmy 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 , lkeller@hilcorp.com and cdinger@hilcorp.com 6.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am 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 hrs 6.5 Casing Tally • Send final"As-Run"Casing tally to lkeller(&,,hilcorp.com and cdinger@hilcorp.com 6.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller@hilcorp.com and cdinger@hilcorp.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 Luke Keller 907.777.8395 832.247.3785 lkeller@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Vanessa Hughes 907.777.8445 vhughes@hilcorp.com Drlg Environmental Coord Julieanna Orczewska 907.777.8444 907.715.7060 jorczewska@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 cajones@hilcorp.com EHS Field Coordinator Jimmy Watson 907.777.8450 907.744.7376 jiwatson@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cdinger@hilcorp.com Page 5 Version 1 Feb 2016 S • 111 Milne Point Unit B-28 Drilling Procedure Hilcorp Enargy Company 7.0 Planned Wellbore Schematic 1 ___,,.....-,..1.-+., CASING DETAIL Size Type Wt Grade Conn. ID Top Btm '. 20' Conductor 78.6 A-53 Weld 19.25' Surf 110' yq„ 9-5/8" Surf.Csg 40 L-80 DWC/C 8.835" Surf 5,572' 4-1/2' Scrod een5 12.6 L-80 ttydril 521 3.958 5,400' 10,889' TUBING DETAIL 3-1/2" Tubing 9.2 1-80 EUE 2.992" Surf 5,300' Tieback Detail 7-5/8" Tieback 29.7 L-80 VAM SLID-II 6.875' Surf 2500 7-5/8" Tieback 29.7 L-80 VAM STL 6.875" 2500 5400 2 s JEWELRY DETAIL No. Item Top MD BtmMD ID OD 3 1 Tub�g 32' 2 Stage Tool—ES Cementer 2,100 3 XNipple 2,100' 4 4 GLM PI 2,807 5 GLM P2 3,500' 6 GLM 85 5,000' 7 X Nipple 5,050' ' 8 Production Packer 5,250' 9 Wireline Re-Entry Guide 5,300' ID Liner Top Packer&tieback seals 5,400' II Production Screens 5,400 5 : , \k,11111 6 • 9-53'Shoe - r" , . 411 w s 1111111 1111111111111111 S 9 10 11 P131D=10,888'MD t 4,406.5'TVD TD=10,889'AID 1 4,406.5'TVD Max Deviation:!SL' Page 6 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilc_orp 8.0 Drilling / Completion Summary MPU B-28 is a grassroots producer planned to be drilled in the Schrader Bluff ND sand. B-28 is part of a (2)well pilot program targeting the ND sand. B-28 will be paired with a grassroots injector,B-29. The directional plan is a catenary wellpath build with 9-5/8" surface casing set into the top of the Schrader Bluff ND sand. A lateral section will then be drilled in the reservoir. Production screens will then be run inside the well to limit sand production from the well. A 3-1/2"gas lift completion will then be run to produce the well. Drilling operations are expected to commence approximately March 8th,2016. Doyon Rig#14 will be used to drill and complete the wellbore. Surface casing will be run to 5,572' MD/4,421' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6— 18 his after IP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste &mud generated during drilling operations will be hauled to the Milne Point G&I facilityiocated on"B"pad. General sequence of operations: 1. MOB Doyon#14 to well site 2. N/U 21-1/4"conductor and 16" diverter line.' 3. Drill 12-1/4"hole to TD of surface hole section. Run and cmt 9-5/8" surface casing. 4. N/D diverter,N/U & test 13-5/8"x 5M BOP. 5. Drill 8-1/2" lateral to well TD. Run 4-1/2"production screens. 6. Run 7-5/8"tieback. 7. Run production tubing. 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR+Res / 2. Production Hole: No mud logging. On site geologist. LWD: GR+Res Page 7 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcorp 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. • BOPs shall be tested at(2)week intervals during the drilling and completion of MPU B-28. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • 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. t`; Z'/1 " Ck 5,—/6 /4_ 2-- Page Page 8 Version 1 Feb 2016 • • II Milne Point Unit B-28 Drilling Procedure Hilcorp Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"2M diverter(Hydril MSP)w/16"diverter line Function Test Only • 13-5/8"x 5M Hydril"GK"Annular BOP • 13-5/8"x 5M Hydril MPL Double Gate Initial Test:250/3000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross w/3"x 5M side outlets 8-1/2" • 13-5/8"x 5M Hydril MPL Single ram • 3-1/8"x 5M Choke Line Subsequent Tests: • 3-1/8"x 5M Kill line 250/3000 • 3-1/8"x 5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc Primary closing unit: NL Shaffer, 6 station, 3000 psi, 180 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air pump, 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:guy.schwartz@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.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Version 1 Feb 2016 • Milne Point Unit B-28 11 Drilling Procedure Hilcor 10.0 R/U and Preparatory Work 10.1 A new conductor has been set for B-28,the surface location is just south of the current B-25 well. 10.2 Dig out and set impermeable cellar. 10.3 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 10.4 Install Seaboard slip-on 16-3/4" 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 Confirm that the rig is over the appropriate well slot. 10.8 MIRU Doyon#14. 10.9 Mud loggers WILL NOT be used on either hole section. 10.10 Mix spud mud for 12-1/4" surface hole section. Keep mud cool. 10.11 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 10.12 Install 6"liners in mud pumps. • Continental EMSCO FB-1600 mud pumps are rated at 4665 psi, 462 gpm @ 110 spm @ 95%volumetric efficiency. ./ 11.0 N/U 21-1/4" 2M Diverter System 11.1 N/U 21-1/4"Hydril MSP 2M diverter System(Diverter Schematic at Sec 20 at back of program). • N/U 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead. • N/U 21-1/4" 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 • Place drip berm at the end of diverter line. Page 10 Version 1 Feb 2016 • • II Milne Point Unit B-28 Drilling Procedure Hilcor Enemy 11.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 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 Set 15.375" ID wearbushing in wellhead. 11.5 Pad Drawing NNE SATE-- MPU B PAD ;` 1 ■P l 47 ( •■ f y GRAPHIC SCALEVI I U. 9 ,P e■ 1 Inah.60 It t-wow I j/ P. mti '// ,n0000 Ng 70.6461' W, jie-- , �• .. 577.3006' /', II ► .- II i ,,,,,, ,z• [-I] - /„,,,,,' j/ -I s / Lif � , ,,_, / i J , /i Page 11 Version 1 Feb 2016 i • II Milne Point Unit B-28 Drilling Procedure Hilcor 11.6 Rig&Diverter Orientation on"B"pad: _ 1 I a „yr/ .. ,:// . „ . on ion 1.—-- 127.0000' pa 1I 70.9461' f . i. .- 0 . ■ 577.3006' F 4F ' }. fI I .rrrrr + / 1°' - - ill.:- -• •' �.. ®!I ilk 7 /4/I/A 1 Ell IIF- Page 12 Version 1 Feb 2016 S Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 12.0 Drill 12-1/4" Hole Section 12.1 P/U 12-1/4" directional drilling assy: • 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. • Workstring will be 5" 19.5# S-135. • Run a solid float in the surface hole section. 12.2 12-1/4" BHA (GR+Res LWD and PWD planned in surface hole): COMPONENT DATA 1111 Item OD' ID Stiff ID Gauge Weight Top Length Total Location Descr;ption Connection (in) (in) (in) (in) (lbpf) (ft) (ft) (ft) Tricone 8.000 3.000 12.250 147.22 P 6-5/8"REG 1.10 ©8"SperryDrill Lobe 4/5-5.3 stg 8.000 5.000 5.000 103.09 B 6-5/8"REG 31.47 32.57 Stabilizer 12.125 4.28 ©Float Sub 8.000 2.880 2.880 149.10 B 6-5/8"REG 2.40 34.97 0 Stabilizer 8.000 3.000 3.000 10.250 147.22 B 6-5/8"REG 6.00 40.97 35.97 ©8"DM Collar(Directional) 8.000 3.500 3.544 147.40 B 6-5/8"REG 9.20 50.17 6 8"DGR Collar(Gamma) 8.000 1.920 4.997 142.70 B 6-5/8"REG 4.55 54.72 0 8"EWR-P4 Collar(Resistivity) 8.000 1.985 5.205 151.00 B 6-5/8"REG 12.19 66.91 8 8"PWD(Pressure ECDs) 8.000 1.920 4.760 143.40 B 6-5/8"REG 4.44 71.35 9 8"HCIM Collar(Processor) 8.000 1.920 4.309 149.90 B 6-5/8"REG 4.97 76.32 10 8"POS PULSER(Telemetry) 8.000 4.000 4.257 145.20 B 6-5/8"REG 15.44 91.76 El Orienting Sub UBHO 8.000 2.875 3.000 149.18 B 6-5/8"REG 2.50 94.26 ®NM Flex Collar 8.000 2.813 150.13 B 6-5/8"REG 31.00 125.26 ®NM Flex Collar 8.000 2.813 150.13 B 6-5/8"REG 31.00 156.26 14 NM Flex Collar 8.000 2.813 150.12 B 6-5/8"REG 31.00 187.26 8jts x 5"X 3"HWDP#49.3-NC50(IF) 5.000 3.000 49.30 240.00 427.26 16 Jar 7.500 2.813 2.813 129.38 B 4-1/2"IF 35.00 462.26 12jts x 5"X 3"HWDP#49.3-NC50(IF) 5.000 3.000 49.30 360.00 822.26 Total: 822.26 Page 13 Version 1 Feb 2016 4 i II Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 12.3 Primary Bit: 12-1 /4" VMD-3 ...� ' i: i. TOOTH BITS (311.2 mrn) • Ultra-Abrasive Formation Cutting Structure Specifically engineered for ultra-abrasive formations This steel tooth cutting structure has extra-thick hardfacing to ensure teeth stay sharper longer and deliver extended runs with improved penetration rates. ` tY, .,/ ! " • Metal Face Seal&Bearing System or, Longer bit life in high-RPM,motor,and high-temperature drilling applications,up to 400'F ti- (204`C).with the patented VM metalto metal sealing system. 11‘Allt:P+ 411 1, • XL&LX Hardfacing Features A patented.strategically places bead of hardfacing is added to key areas an specific teeth to �� retard tooth wear and improve tooth strength and durability. •" ' • Boss Stabilization System lee These unique integrated stabilizers provide near six-point contact with the borehole wall for unequaled stability and cutting structure protection. • STL Hardfacing Increased bit life and reliability with a precisely controlled application of patented.highly wear- resistant STL'"hardfacing that covers the entire shirttail and leg areas for superior protection from the potentially damaging effects of hole-wall contact a • Center Jet(C) A fourth jet is pos=tioned in the center of the bit and utilized to prevent bit balling and the associated reduction in penetration rate. • Clean Sweep Hydraulics(CS2) Biased nozzle configuration directs fluid toward areas where bit balling occurs.The Clean Sweep high-velocity core strikes heel and adjacent heel area on the backside of the cone. PRODUCT SPECIFICATIONS: !ADC. 137 Bearing 1 Seal Package: Journal/Metal Cutting Structure: Inner Row: ST Heel Row: ST Gauge Row: ST Gauge Trimmers: N/A Tooth Hardfacing: XULX OD Hardfacing: STL Nozzle Type: Standard Center Jet Display: FK or VK Makeup Torque: 28.0-32.0 klbf-ft(38.0-43.4 kNm) Connection: 6-5/8 REG API Approx. Shipping Weight: 235 lb(106.6 kg) Reference Part Number H2187000 OPERATING RECOMMENDATIONS: * Weight On Bit: 20-50.0 klb(9-22 to or kdaN) Rotation Speed: For High Speed Rotary/Motor Applications Page 14 Version 1 Feb 2016 • Milne Point Unit B-28 Drilling Procedure Hilcorp Enagy Company 12.4 5" Workstring, HWDP, and Jars will come from Weatherford. 12.5 Begin drilling out from 20"conductor at reduced flow rates to avoid broaching the conductor. 12.6 Drill 12-1/4"hole section to 5,572' MD/4,421.5' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • 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 600 - 650 gpm. Ensure shaker screens are set up to handle this flowrate. • Keep swab and surge pressures low when tripping. • For producer wells only: • Ensure to leave a"Pump Tangent" section that is approx. 300' long in the directional plan. The ESP will need a straight section to sit. This will occur very near TD of the hole section. • Efforts should be made to minimize dog legs in the surface hole. ESP equipment can be damaged if run through high dog legs. Keep DLS <6 deg/ 100. • Make wiper trips every 2000' unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section just into the target sand. Geologists and Drilling Engineers will help adjust well path to ensure well is landed correctly. • Take MWD surveys every stand drilled(95' intervals). • Watch returns closely for signs of gas when near the base of the permafrost and circulate out all gas cut mud before continuing to drill. There have been no indications of hydrates on any of the "B"pad wells to date. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • 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(1700' TVD) or 100' below the base. We want to leave this transition as undisturbed as possible. • Plan a bit trip (if necessary) before penetrating the UGNU LA3 sand. This interval caused an unintentional sidetrack on L-48. Page 15 Version 1 Feb 2016 V •11 i Milne Point Unit B-28 Drilling Procedure H&c Enemy 12.7 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. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system . with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM(10_ ppb total)BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high-clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5-9.0 range with caustic soda. Daily additions of ALDACIDE G/X- CIDE 207 MUST be made to control bacterial action. • Casing Running: Reduce system YP with DESCO as required for running casing as allowed (do not jeopardize hole conditions). Run casing carefully to minimize surge and swab pressures. Reduce the system rheology once the casing is landed to a YP<20(check with the cementers to see what YP value they have targeted). System Type: 8.8-9.2 ppg Pre-Hydrated Aquagel/freshwater spud mud. Properties: Depths Density iscosity Plastic Viscosity Yield Point API FL pH 80-5572' 8.8—9.2 85-250 20-40 25-75 <10 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(8.5-9.0 pH) BARAZAN D+ as needed BAROID 41 as required for 8.8-9.2 ppg PAC-L/DEXTRID LT if required for<10 FL ALDACIDE G 0.1 ppb Page 16 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcor EnerV 12.8 At TD;pump sweeps, CBU, and pull a wiper trip back to the 20"conductor shoe. 12.9 Should backreaming be necessary to get out of the hole: • Prior to initiating backreaming, ensure at least 3 —4 B/U have been circulated to get hole as clean as possible. • Pump at full drill rate (600—700 gpm), and maximize rotation. • Pull slowly, 5— 10 ft/minute. • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 12.10 TOH with the drilling assy, handle BHA as appropriate. 12.11 No open hole logging program planned. 13.0 Run 9-5/8" Surface Casing 13.1 R/U and pull 15.375"wearbushing. 13.2 Make a dummy run with the 9-5/8" casing hanger. 13.3 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8"DWC/C x DS50 XO on rig floor and M/U to FOSV. • Use BOL 2000 thread compound. Dope pin end only w/paint brush. • Consider R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.525"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. 13.4 P/U shoe joint, visually verify no debris inside joint. 13.5 Continue M/U&thread locking shoe track assy 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. Page 17 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilc_orp Bypass Baffle This end up. NON it • (1)Joint with Halliburton bypass baffle adapter bucked on pin&threadlocked. Install (1) centralizer mid tube over a stop collar. • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 18 Version 1 Feb 2016 • 11, Milne Point Unit B-28 II Drilling Procedure Hilcorp Energy Company 13.6 Float equipment and Stage tool equipment drawings: `'A _ ' -IIType Length Type H ES Cementer B ld Part No. :--:n.ID After Df HOU: ii i SO No. C Mai.7:(,I CD a D Hikorp ES-II Running Order AorNI Open-:.ea•. C os ng Sleeve No.Shear Pins �;1E I. -- Closing Seat ID 1I it Opening Sleeve �No.Shear Pins EPlug Set ES-II Cementer neMEMM ES Cementer Part No. Depth SO No. — MN Closing Plug , 1101111111r Br'a Adapter(uf used) OD shut off ID , Opening Plug 111 i Depth OD Baffle AdapterPlug OD __•____ ___ . Bypass or Shut-off Baffle I! I By-Pass Plug Depth \ / Shut-off Plug 1111 .....4 Float Collar ?Depth By Pass Baffle T 111 OD Float Collar 4. Ir Float Shoe Depth BYPass Plug (if used) Hole TO Float Shoe "Reference Cas ng fil OD Sales Manual - Section 5 I Page 19 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 13.7 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Install (1) centralizer every other joint for the first 15 joints. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cmt returns to surface. 13.8 Install the Halliburton Type H ES-II Stage tool so that it is positioned at 2100' MD/2064' 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 damaged 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. 9-5/8" 40#L-80 DWC/C Make Up Torques: Casing OD Min M/U Torque Max M/U Torque 9-5/8" 29,800 ft-lbs 34,800 ft-lbs Page 20 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company Technical Specifications Connection Type: Slze(O.D.): Weight(Wall): Grade: DWCIC Casing 9-5/8 in 40.00 lb/ft (0.395 in) L-80 sta ncta rd Material L-80 Grade 80.000 Minimum Yield Strength (psi) 11111111111111111111111.USA 95.000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston,TX 77041 Phone:713-479-3200 9.625 Nominal Pipe Body O.D. (in) Fax.713-47g-3234 8.835 Nominal Pipe Body I.D.(in) mail:VAMUSAsa{esi vam-usa.corn 0.395 Nominal Wall Thickness (in) 40.00 Nominal Weight (lbs?ft) 38.97 Plain End Weight(lbs/ft) 11.454 Nominal Pipe Body Area (sq in) 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 Properties 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) Page 21 Version 1 Feb 2016 • is 11 Milne Point Unit B-28 Drilling Procedure Hilcorp Enemy Company 13.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 13.10 Slow in and out of slips. 13.11 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 13.12 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 13.13 Have emergency slips ready to go in the event we cannot land the hanger. 13.14 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. Elevate hanger slightly above hang off point while circulating to avoid plugging the flutes. 13.15 After circulating, lower string and land hanger in wellhead again. ,/ Page 22 Version 1 Feb 2016 • Milne Point Unit B-28 Drilling Procedure Hilcor 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. • How to handle cmt returns at surface. Ensure vac trucks are on standby and ready to assist. • 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 cmt operation. • 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/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 14.5 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 14.6 Pump remaining 55 bbls 10.5 ppg tuned spacer. 14.7 Drop bottom plug (flexible bypass plug). Mix and pump cmt per below calculations for the 1st stage. 14.8 Cement volume based on annular volume+30%open hole excess. Job will consist of lead& tail, TOC brought to stage tool. Estimated Total Cement Volume: SJv 1.5 Section: Calculation. Vol(BBLS) Vol(ft3) 12-1/4" OH x 9-5/8" Casing (5072'- 2100')x .0558 bpf x 1.3 = 216 bbls 1213 ft3 annulus: 5t Total LEAD: 216 bbls 1213 ft3 12-1/4" OH x 9-5/8" Casing (5572'- 5072')x .0558 bpf x 1.3 = 36.3 bbls 203 ft3 annulus: 9-5/8" Shoe track: 90 x .0758 bpf = 6.8 bbls 38.3 ft3 Total TAIL: 43.1 bbls 242 ft3 2..0Y • • Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Cement Slurry Design (both 1st and 2°d stage cement jobs): Lead Slurry Tait Slurry System ArcticCEM TM System SwiftCEM TM System Density 10.7 lb/gal 15.8 lb/gal Yield 4.298 ft3/sk ./ 1.16 ft3/sk �✓ Mixed 21.13 gal/sk 5.04 gal/sk Water 14.9 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 14.10 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits. 14.11 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. To operate the stage tool hydraulically, the plug must be bumped. 14.12 Displacement calculation: 5482' x .0758 bpf=416 bbls total (216 bbl mud+ 80 bbl water+ 119 bbl mud) The 80 bbls of water must be left across stage tool to ensure proper operation once opened. 14.13 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 14.14 If plug is not bumped at calculated strokes, double check volumes and calculations. Overdisplace by no more than 10 bbls before consulting with drilling engineer. 14.15 If plug is not bumped consult with drilling engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 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 cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. Page 24 Version 1 Feb 2016 • Milne Point Unit B-28 Drilling Procedure Hilcor 14.17 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface. 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 cmt 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 cmt. Page 25 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcor Enciff Second Stage: 14.19 Prepare for the 2nd stage as necessary. Hold another pre job meeting if crew change has occurred. 14.20 Load ES cementer closing plug in cmt head. 14.21 Pump 5 bbls 10.5 ppg tuned spacer. Test surface cmt lines. 14.22 Pump remaining 55 bbls 10.5 ppg tuned spacer. 14.23 Mix and pump cmt per below recipe for the 2nd stage. 14.24 Cement volume based on annular volume+200% open hole excess. Job will consist of lead& tail, TOC brought to surface. However cmt will continue to be pumped until clean spacer is observed at surface. Estimated Total Cement Volume: ij m� Sim Section: Calculation: Vol(BBLS) Vol(ft3) 20" Conductor x 9-5/8" (110')x .27 bpf x 1 = 29.7 bbls 167 ft3 casing annulus: 12-1/4" OH x 9-5/8" Casing (1600'- 110')x .0558 bpf x 3 = 250 bbls 1403 ft3 annulus: Total LEAD: 279.7 bbls 1570 ft3 )< s 12-1/4" OH x 9-5/8" Casing (2100'- 1600')x .0558 bpf x 2 = 56 bbls 314 ft3 annulus: Total TAIL: 56 bbls 314 ft3 s2 o 14.25 Continue pumping lead until uncontaminated spacer is seen at surface,then switch to tail. 14.26 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 14.27 Displacement calculation: 2100' x .0758 bpf= 160 bbls mud Page 26 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcorp compiiny 14.28 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 14.29 Decide ahead of time what will be done with cmt returns once they are at surface. We should get back approx. 130 bbls of cmt slurry. 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. Back out and L/D landing joint. Flush out wellhead with FW. 14.31 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 14.32 Lay down landing joint and pack-off 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 a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally& casing and cement report to lkeller@hilcorp.com and cdinger@hilcorp.corn This will be included with the EOW documentation that goes to the AOGCC. Page 27 Version 1 Feb 2016 • i 11 Milne Point Unit B-28 Drilling Procedure Hilcor Energy 15.0 BOP N/U and Test 15.1 N/D the diverter&N/U 11" 5M tubing spool and DSA to 13-5/8" 5M. 15.2 N/U 13-5/8"x 5M 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" Single gate • Double ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 5" Fixed rams • N/U bell nipple, install flowline. • Install (1) manual valve & (1) HCR valve on kill side of mud cross. (manual valve closest to mud cross). • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 15.3 Run 5" BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • 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 at some point in the well: 5" (for 5"DP workstring). 3-1/2" (for 3-1/2"tubing). I(i/i `' 6-'n' `' 2-7/8" for wash pipe run inside of production screens. ,•71'�0 `4.-- 15.4 R/D BOP test assy. {- 15.5 Dump and clean mud pits, send spud mud to G&I pad for injection. 15.6 Mix 8.9 ppg Baradrill-N fluid for production hole. 15.7 Set 10"ID wearbushing in wellhead. 15.8 Rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 15.9 Keep 6" liners in mud pumps. 15.10 P/U used 8-1/2" Baker Hughes mill tooth bit and clean out BHA and TIH to TOC. 15.11 Note depth TOC tagged on AM report. Drill out s age 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. Approx 2-5 k is enough. • Apply weight and allow it to drill off before applying more. Page 28 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure E Hilcmily t;orp • After drilling out, chase any remaining debris to bottom with the drill bit. 15.12 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 15.13 R/U and test casing to 3000 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst= 5750/2 =—2875 psi, but maximum test pressure on the well is 3000 psi. 15.14 Drill out shoe track and 20' of new formation. 15.15 CBU and condition mud for FIT. 15.16 Conduct FIT to 12 ppg EMW. f - ° z`' 15.17 TOH with clean out assy for lateral drilling assy. Page 29 Version 1 Feb 2016 • • II I Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 16.0 Drill 8-1/2" Hole Section 16.1 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure 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 5" 19.5# S-135 . • Install ported float in the BHA. 16.2 8-1/2" Rotary Steerable (Includes at bit GR, at bit incl, ADR for geosteering, PWD): IFOMPONENT DATA II item Description Serial Number OD ID Gauge Weight Top Length Cumulative # (in) (in) (in) (Ibpf) Connection (ft) Length (ft) 1 PDC-Long Gauge 6.360 2.250 8 500 94 72 P 4-112"REG 2.19 2.19 Stabilizer 8.469 2 Geo-Pilot 7600 XL 25KSI -■ 7.625 1.490 8.375 113.00 B 4-112"IF 20.16 22.35 Ref Housing Stabilizer 8.375 3 6-3/4"DnIIDOC(WOBITOB) IIIIIIIIIIIIIIIIIIII 7.100 2.000 108.41 B 4-112"IF 7.10 29.45 4 6-3/4'DGR(Gamma) y 6.750 1.920 97.80 B 4-112"IF 8.43 37.88 5 6-314"PWD(Pressure) 6.750 1.920 96.30 B 4-112"IF 4.40 42.28 6 Inline Stabilizer(ILS) 6.750 1.920 8.250 112.09 B 4-112"IF 2.25 44.53 7 6-314"ADR Collar(Resistivity)v 6.750 1.920 109.40 B 4-112"IF 24.30 68.83 8 6-3/4"DM Collar(Directional) 6.750 3.125 103.40 B 4-112"IF 9.20 78.03 9 6-3/4"TM Collar(Mud Pulse �. 6.750 3.250 103.60 8 4-112"IF 10 00 88.03 Teleme 10 6-314"Float Sub 6.750 2.250 _ 108.40 ; 2.00 90.03 11 NMDC Slick 6 750 2.813 100.77 B 4-1:2" z 31.00 121.03 12 NMDC Slick 6.750 2.813 ® 100.77 B 4-112"IF 31.00 152.03 13 NMDC Slick 6.750 2.813 100.77 B 4-1'2" !F 31.00 183.03 En lit x 5"X 3"HWDP#49.3-4.51E 111111111111 5.000 3.000 49.30 31.00 214.03 15 Weatherford 6.25"Jar 6.250 2.250 9' 01 B 4-112"IF 30.00 244.03 16 lit x 5"X 3"HWDP#49.3-4.51F 5.000 3.000 49.30 ® 31.00 275.03 17 5"X 4.276"-19.5#6-5/8"X 2-3.4"- 5.000 4.276 22.60 31.00 306.03 4.51E Total: 306.03 Page 30 Version 1 Feb 2016 • 0 II Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 16.3 Primary Bit: KEWWellbore Technologies Design Specifications A. J' Make up Length(ft): .92 ` Shank Bore(ins): 2.300 Shank Diam(ins): 6.400 f tit " : Connection std: Y ,114, Connection Size(ins): 4.500 1 `,ti Connection Type: Apt Reg PTi Make up Torque(ft-lbs): 20000 aM IADC Code: M422 " Diameter:fins) 8 Yz" Body Material: Matrix HDK JSA(8 1A" SK616M,JI D Face =): 71.660 Face Volume:(ina) 71.66 Design Features of this bit Normalised Face vol: 53.26% Seeker"'Directional Drill Bits Seeker'"'directional drill hits are designed to overcome directional drilling challenges for both motor or RSS tools in a wide range of directional applications. Blade Oty: 6 Hellos"'Inferno"'Cutters-SpecializedGauge Length:(ins) 4.000 Hellos"' cutter technology engineered for specific applications that may require increased thermal resistance.increased abrasion resistance or increased toughness. Gauge Geometry: Spiral-Trailing Each Helios""InfemoT"'cutter has a unique cutter index value indicating performance characteristics. Gauge Profile: SmoothSteer SmoothTorque-"Torque Control Components-SmoothTorqu&' torque control components are Gauge Protection: TSP Tiled inserts placed between primary cutters to provide a predictable torque response to applied weight-on-bit and reduction in torque variance. Bit Profile: snort taper-stvaa*Corte SmoothSteer Gauges-SmoothSteerT"gauges deliver maximum gauge contact.lowering resistarce to steer by reducing torque.and leading to improved ROP and extended bit and tool life. Recommended Operating TSP Gauge Protection-Thermally stable product(TSP)tiles and welded hard metal gauge Parameters protection give both a highly durable and ultra-smooth gauge. Max Operating WOB(klbs):38 Spiral Gauge-Stabilityis improved byincreasingthe circumferential contact of the bitgauge. Mrn TFA(in2): 0.2946 Improved ut P Max TFA(in>2): 2.2272 stability enhances steeratNiity and ROP. Max Flow(gpm): 934 This bit/unit can accommodate BlackBoxT"'HD drilling recorder. HSI: 2-7 This bodied PDC bit features computer aided cutter placement and hydraulics optimized by nozzle location to deliver high performance and longer bit life. Bit Breaker. Thick 1', d7 sone appacarbns this M'is rem successtty beyond these parameters.Contact your NOV Reeeftcabg RepresentatVe M reconvrrettded operat re parameters Ill Dour appecation NOV ReedHycabg resersgs the MOW to revAse Mese speceXanonsnoSe1 on advances and improvements ort tecMOGyy. This report+s va.7 for 30 days from 72-Sec-201 Cutting Structure Nozzles & Ports Type Qty Location Diameter Shape Qty Type Size Primary 31 FACE 16 mrr CYLINDER ( 6 TNZ VARIABLE Primary 12 GAGE 13 mm CYLINDER Primary 6 BACK-ANGLE 13 min CYLINDER TCC 6 FACE 11 mm DOME TOPPED a Page 31 Version 1 Feb 2016 • Milne Point Unit B-28 Drilling Procedure - CMP 16.4 8-1/2"hole section mud program summary: • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system(1)ppg above highest anticipated MW. • Solids Concentration: It is imperative that the solids concentration be kept low while drilling the production hole section. Keep the shaker screen size optimized and fluid running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum(N-VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use 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. System Type: 8.9—9.2 ppg Baradrill-N drilling fluid Properties: Depthsen�si-ty Plastic Viscosity Yield Point Total Solids MBT HPHT pH 5572- 8.9-9.2 15-25 15-25 <10% <7 <11.0 8.5-9.5 10,889 System Formulation: Baradrill-N Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N-VIS 1.0— 1.5 ppb N-DRIL HT PLUS 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARACARB 50 2 ppg BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.015 ppb Page 32 Version 1 Feb 2016 j Milne Point Unit B-28 11 Drilling Procedure Hilcorp Compury 16.5 TIH w/8-1/2"directional assy. 16.6 On-bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations pulsed up real time. • If BHA begins to show excessive vibrations/whirl/stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. 16.7 Drill 8-1/2"hole section to section TD per Geologist and Drilling Engineer. • Pump at 600 - 650 gpm. • 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 water or other low vis sweeps to aid in hole cleaning. • Keep swab and surge pressures low when tripping. • Make wiper trips every 1500—2000 ft if necessary. • Take MWD surveys every stand drld. Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Ideally, we would like to stay in section 100% of the time and DO NOT want to serpentine between the upper and lower lobes. • Limit maximum instantaneous ROP to <200 fph. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. 16.8 Concretion drilling strategy: • Past experience has shown that no two hard streaks are the same. WOB and RPM may have to be constantly changed to drill effectively. • When a hard streak is encountered, first attempt to drill through it with low WOB (5k WOB, 150 RPMs at the bit). Gradually increase one or the other or both. Allow enough time to elapse after a parameter adjustment to make note of increased or decreased drilling efficiency. • DO NOT backream through concretions. This practice has been attributed to cutter damage in the past. • Normal backreaming can be done through soft/high ROP drilling areas. • Make all attempts at prolonging bit life when working through concretion intervals. Once the shoulder row of cutters has been chipped or damaged, the steerability and ROP will be significantly reduced. 16.9 Open hole sidetracking practice: • If a known fault is coming up, put a slight"kick-off ramp"in wellbore ahead of the fault so we have a nice place to low side. .� Page 33 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcor EnerlY • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft,working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. 16.10 At TD; pump low vis sweeps, CBU at least 3 times at maximum circulation and rotation, and pull a wiper trip back to the 9-5/8" shoe. If backreaming is necessary: • Circulate at full drill rate (600—650 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. 16.11 Circulate and condition mud. Perform"Screen Plugging Test" on return mud samples. Continue to circulate and condition mud as needed to pass "Screen Plugging Test". If unable to pass test, the hole may have to be swapped over to a new solids free mud system prior to POOH. 16.12 TOH with the drilling assembly to the 9-5/8" casing shoe. Swap over to clean filtered brine in preparation for running screens. Rotate and reciprocate as needed to ensure the mud is removed from the 9-5/8"casing. Continue to POH and stand back BHA if possible. Rabbit DP on TOH. 16.13 Only LWD open hole logs are planned for the hole section(GR+Res). There will not be any additional logging runs conducted. 17.0 Run 4-1/2" Production Screens 17.1 R/U 4-1/2" screen handling equipment. • Ensure 4-1/2"Hydril 521 x NC-50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been dre n 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. 17.2 Run 4-1/2"production liner per lower completion tally. • Use API Modified thread compound. Dope pin end only w/paint brush. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Handle screens with care,the wire mesh can easily be damaged which then allows formation solids to enter the completion. • Install swell ackers are per the lower completion tally./• Remove protective packaging on swell packers just prior to picking up • Do not place tongs or slips on the packer element Page 34 Version 1 Feb 2016 Milne Point Unit B-28 fl Drilling Procedure Hilcorp Energy Company 4-1/2" Hydril 521 M/U torques Casing OD Minimum Maximum Yield Torque 4.5" 3,900 ft-lbs 6,800 ft-lbs 15,300 ft-lbs PIPE BODY DATA GEOMETRY Standard Drift pit mina'OD 4.500 in. Nominal Weight 12.60 lbs./ft 3.833 in. Diameter Specal Dr:ft No-I-vial ID 3.958 in. Wa I Thickness 0.271 in. N/A Diamete Plain End Weight 12.25 lbs/ft PERFORMANCE Boo'Yield 288 lbs Internal Yield 8430 psi SMYS 80000 as; Collapse 7500 psi WEDGE 521"' CONNECTION DATA GEOMETRY Connect or OD 4.729 n nnection ID 3.918 in. Make-Up Lass 3.620 in. •:-tical Section .2.393sq. in. Threads per tn. 3.36 Area PERFORMANCE 192 x 1000 Internal Pressure Tension Efficiency 66.5% Joint Yield Strength 8430 7: lbs Capacity Compression Compression 248 x 1000 lbs 860°f Band rtg 54 2;100-t Strength Efficiency ExternaExterrai essu re 7500 psi Capacity MAKE-UP TORQUES Minimum 3900 ft-113s Optimum 4700 ft-lbs maximum ln 6800 ft-lbs OPERATIONAL LIMIT TORQUES Operating Torque 10200 ft-lbs Yield Torque 15300 ft-lbs BLANKING DIMENSIONS Blanking Dimensions • ' • ' Page 35 Version 1 Feb 2016 i • Milne Point Unit B-28 Drilling Procedure Hilcorp Energy OmPINY 17.4 Ensure to run enough liner to provide for approx 200' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. 17.5 R/U false rotary and run inner string. 17.6 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. 17.7 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. 17.8 Note weight of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 17.9 RIH w/liner on DP no faster than 1-1/2 min/stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. • 17.10 DP should autofill. 17.11 Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe depth+ S/O depth every stand. Record torque value if it becomes necessary to rotate the string to bottom. 17.12 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 17.13 If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 17.14 TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 17.15 Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. 17.16 Rig up to pump down the work string with the rig pumps. NOTE: The purpose of the extended wellbore cleanup is to ensure that as much of the mud in the open hole is removed from the wellbore in attempt to minimize the amount of mud that would be produced back through the screens. Page 36 Version 1 Feb 2016 • S Milne Point Unit B-28 Drilling Procedure Hilcorp 17.17 Break circulation and begin displacing wellbore to 8.9 ppg 2% KC1/NaC1 brine. Adjust brine weight to equal mud weight. Note the large OD on the swell packers. Begin circulating at—1 BPM and monitor pump pressures. Slowly bring rate up while circulating the lateral clean. 17.18 Monitor pump pressures closely and adjust pump rate if the well appears to be packing off at the swell packers. Note all losses. Catch mud for future use if feasible. 17.19 Displace entire wellbore to brine at 300 FPM annular velocity if possible (approximately 15 BPM). Monitor the returned fluids to ensure as much mud has been removed from the wellbore as possible. 17.20 Drop setting ball down the workstring and pump slowly(1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 17.21 Pressure up to 3000 psi and hold for 5-15 minutes to set SLZXP hanger packer. Continue pressuring up in 500 psi increments holding for 5 min each up to 4000 psi. / 17.22 Bleed DP pressure to zero, close BOP and test annulus to 1500 psi for 30 min and chart record ,/ same. 17.23 Bleed off pressure and pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 17.24 POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. 17.25 L/D remaining DP out of derrick. 18.0 Run 7-5/8" Tieback e to &4r 4 7� 18.1 R/U and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder to be used for tie-back space out calculation. Install and test 7-5/8" (250/3000 psi) casing rams, in top ram. 18.2 R/U 7-5/8" casing handling equipment. • Ensure XO to DP made up to FOSV and ready on rig floor. • Rig up computer torque monitoring service. • String should stay full while running, r/u fill up line and check as appropriate. 18.3 P/U tieback seal assy and set in rotary. 18.4 M/U first joint of 7-5/8"to seal assy. 18.5 Run 2500' of 7-5/8" STL casing and M/U crossover to 7-5/8"VAM STL Page 37 Version 1 Feb 2016 • Milne Point Unit B-28 Drilling Procedure Hilcorp 18.6 Ensure appropriate well control crossover is ready on rig floor. 18.7 Run 7-5/8"tieback to position seal assy two joints above tieback sleeve. Record up & down weights. • Following running procedure outlined above. 18.8 M/U 7-5/8" SLIJ-II to DP crossover. 18.9 M/U stand of DP to string, and M/U top drive. 18.10 Break circulation at 1 bpm and begin lowering string. 18.11 Note seal assy entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 18.12 Continue lowering string and land out on no-go. Set down 5 — 10k lbs. Mark the pipe at this depth as "NO-GO DEPTH". 18.13 P/U string & stand back DP stand, L/D XO. 18.14 M/U (or L/D) necessary joints and pup joints to position seal assy 1 ft above"NO-GO DEPTH" when tie-back hanger lands out in wellhead. 18.15 P/U hanger assy. Top of hanger landing joint is 7-5/8" SLIJ-II. Ensure crossover is available to allow circulation down the string. 18.16 R/U to circulate down 7-5/8"x 9-5/8"annulus,taking returns up the 7-5/8" casing. 18.17 Close annular on landing joint—ensure hanger is not across the annular when closing. 8.18 Pump 64.3 bbls 10.2 ppg NaCl/NaBr brine followed by 40.2 bbls 6.7 ppg diesel. This will balance to 8.9 ppg EMW and will put leading edge of diesel freeze protect at 2014' MD/2000' TVD. Check these calculations with actual well profile and brine/diesel weights. r 18.19 Open annular, slowly slack off and stab seal assy into polished bore receptacle. If there is any U- tube flow occurring, it will stop as soon as seal assy enters PBR. If there is U-tube flow occurring, DO NOT fill backside or 7-5/8",this will only make it worse. Continue slacking off and land hanger in wellhead. 18.20 Confirm hanger has seated properly in wellhead. Should be approx. 13k lb on hanger when 1/ landed. Make note of actual weight on hanger on morning rpt. 18.21 Run in hanger lock downs. Page 38 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcorp rgyC 18.22 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. Test void to 3000 psi/ 10 min. 18.23 R/D casing running tools and test 7-5/8"x 9-5/8"annulus to 1000 psi/30 min. 19.0 Run 3-1/2" Production Tubing (Upper Completion) 19.1 M/U wireline re-entry guide and packer assy as per the running order. RIH to setting depth on 3-1/2" production tubing. • Ensure appropriate well control crossovers on rig floor and ready. • Monitor displacement from wellbore while TIH. • Install WLEG,X nipples, sliding sleeve,and GLMs per tally supplied by completion engineer. • Packer set depth will be 4900' MD but is subject to change due to hole inclination or gas lift design. 19.2 Makeup the tubing hanger and landing joint. 19.3 Land hanger. RILDs and test hanger. 19.4 Continue pressurizing the tubing 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 3,000 psi for 30 min. d �— 19.5 Bleed off the tubing pressure to zero and shear the DCK valve 19.6 Circulate freeze protect down IA, allow freeze protect to U-tube down tubing. 19.7 Install BPV and N/D BOP. 19.8 N/U tree adapter and tree. Conduct pressure test of same to 500/5000 psi. 19.9 Shut in well. 20.0 RDMO Page 39 Version 1 Feb 2016 ! • Milne Point Unit B-28 Drilling Procedure Hike. Energy 21.0 Diverter Schematic 1 1 5 Schaffer 21-114" 2M Annular Nil MS MILL 000 oq 21-114"2M Riser---� 16"Full Opening Knife Valve NM ME ass O a 21-1/4" Diverler"1' 16"Diverter Line aaa as V 21-1/4" . Spacer Spool a a a 16-314"3M x+-1119 I 21-1/4"2M DSA i $ ce, V Seaboard Casinghead,5-224P-11 16"SOW x 16-3/4"3M; (2)ea 2.1116"5M studded outlets }" __2O Casing Page 40 Version 1 Feb 2016 I a 11 Milne Point Unit B-28 Drilling Procedure Hilcor EnerlY 22.0 BOP Schematic / 1 1 5 Hydril GK a Annular BOP 13-5/8"x 7 5M L.. ad 16.11.6. 6.1.1.1 ,_ tf ❑ 13-5/8" x 5M ❑-- I '7/✓ e /leg-- 00 o ® 0 1-i ii.. ill - 0E1 * DO ---1 I (y_f it)f.) 7,-3"x 5M HCR \ rvr rvv � � • (/, Kill Line I'■r ��`, -'11 as ss '�`�` ''�'or _~Choke Line I 3"x 5M Manual Gate Valve —p^11 13-5/8"x 5M e—"� I `i /2 1 r Ci `J mommei s s s -11"x5M I\ , I\ 9-5/8"DBL D Seal -_I 1'r r+ =�– 2-1/16"x5M I� Irl,, 0\ 16-3/4"x 3M .' Casing Hanger _�� r r i i 1 ' SMB-22 '` ,; r,;�.r ' 16-3/4 NOM A L 9-5/8"BTC Btm x 2-1/16"x 5M 10.5"-4 SA Pin Top W/Primary Sea 20"Casing 9-5/8"Casing Page 41 Version 1 Feb 2016 • Milne Point Unit B-28 11 Drilling Procedure Hilcorp Energy Company 23.0 Wellhead iliSchematic HILCORP ALASKA B-28 PRODUCER I Hilcorp __ Qin ._. ._ w 2-9/14 SM HOLD-DD ATI F LANG sP 24,6 ` 11 EST ADAo1E9•CSP-2C1. K/, E f..1` '1 x 2-9/14 Sle ° ��.� 4i--TOAGSTOOLcdv . rat- aliki. ti 94 THING HANGER 5-88-ESP 'I. id set 1e 2C.A.x _ [ t API MOD ono - E5T F/TAARUS PENEIRATCR• '. P - � JJI,. mph :dila 1 CASING HANGER.54+8-22 _ p MI 11 x 7-5/8—_-".- I 1a/Ia1IMARY'SEAL • _. 71.9 - tc‘in:HR • 9-1/8 Cal �.. •UII u' + 'ti.-. ,l 2 916 '1A Iil ,1611 i'AS1:-AI:.Fi I Ili x n--:;/!. i T 4 4/"4INAOT'>LAL i w��i S 26 el l ,.. L5• el ■ Til T•t• •,�- 1■ 1 1tAir SAAGF ADAPT.R, pir. 1 70 SOW. `.6 .IF ON 0114\ I --1 _a SM Al ■ 2C CASMC 9-5/8 CASING— 1q LAY01/T 120-000019 7-5/4 CASING . , MN 2-7A CASING 5.000 PSI ESP wELUCAD A36E119LY TIE BACK 11111.E KM 13-3/6 x 9-5/11 X 7-6/6 X 2-7/6 1/9I050I/5 SrlCAN•04 TMS 944994 Aif RESTRICTED CCINF-DENTIAL. DOCUMENT-- XPEN0.SCNIxA 9AIERJAR19CANF;JWIIT .NIMww�.urw."w PION 41 VI RPL "' 1:10 MIJAMII An #0 Q1,006 1C RAM WIERNL:[-IT IS SC 06ARAATCE d STAMP 141011 IS WWLW. �r..ricZT I—Im f,° aMO 14 ME490115 942911 59.0111,11 EF CENSINRFD r �+. TOP KAROO MAZES ULT. =r... 1�.1-. . ' ,�r `n�•• P-20968 Page 42 Version 1 Feb 2016 • . Milne Point Unit B-28 47:,,,,,,,--# Drilling Procedure c,j Hilcorp Energy Company 24.0 Days Vs Depth 0 MPU 5-28 AFE —L-49 Actua — L-46 Actua L-48 with NPT removed 2000 \\, — MPU B-28 STRETCH PLAN 4000 \\Lkk 49 6000 a a Z E. 8 L-46 k3C00 0 U L-48 10000 \ , 14000 16000 0 5 10 15 20 25 30 35 Days Page 43 Version 1 Feb 2016 • • II Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 25.0 Formation Tops MPU B-28 Projected Formation Tops Formation Top TVD Bottom ND SV6 1152 1172 SV1 2630 2650 Ugnu LA3 3918 3938 Schrader Bluff NA 4347 4357 Schrader Bluff ND 4420 4430 GENERALIZED GEOLOGICAL •RECAST SS I GEOLOGICAL TVD FM LITH DESCRIPTION SUGGESTED MUD WT. All Geol- fi • • 8.5 90 9,5 1'-0 108 ' Depths Gubik . Unconsolidated coarse to medium TV. Tolerance . sand and small gravel with minor ss MUD PPG .;_inn 6a , •' siltstone. Note:This is .6 . Heavy gravel conglomerate to 1400'. a generic mud 1,000' . Wood fragments throughout 150. weight chart. a • • ° permafrost zone. See individual well plan for 1700' Base permafrost specific mud weights. 2,000' C zoa. _ _ _ , Sagavaniridok L . 9.2 to 9.3 ppg A • Predominantly clay to+1.3000' with i interbeds of sand.clays and silt- at, stones with occasional shows of coal 9 4 , • • around 2700'. Pebbley gravel(up to 50%)down to 2700'. 3,000i Continued interbeds of sand,clays and i W illlomlo siltstones with heavy coal sections '•oor ~ —I— — milimms 2800.3200. KA: 3800- K-sands 3900 (-AB C D) UGNU: Series of coarsening upward UGNU L-sands Noini sands which are made up of: (from top MA: (-A.B) to bottom)coarse sand,fine sand,silty 4070- M-sands shale and some coal. Better developed 4140 (•A,B.C) intervening shales as you progress into iimoithe L and M(deeper). 4,000' eossii7- +[ocaruOn uca.lii.g ,alHis ao 0•] — — NA: 'Schrader Bluff Sands 4300- N•Sands Continued layered coarsening upward sands as 4600' (-A-B,C.D above except more condensed. r--,,,,,,,c i E.F) hydroca n bearing and potentially productive OA: 1 0-Sands in the"O' .., N"sands Tend to be water wet 4550- ;(-A.B.C. 4800' D.E.F) c more than a mile to the east. 11 i i Primarily clay with some silty sandstone 9•t pQ•' Page 44 Version 1 Feb 2016 • Milne Point Unit B-28 Drilling Procedure Hilcorp Enespy Company 26.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates 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 as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non-pressurized mud scale. The non-pressurized scale will reflect the actual mud cut weight. Add 1.0—2.0 ppb 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 H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. Page 45 Version 1 Feb 2016 III lb II Milne Point Unit B-28 Drilling Procedure Hilcc22 Energy 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. 8-1/2" Hole Section: Hole Cleaning: Maintain rheology of mud system. Sweep hole with low-vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore,pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 500 gpm. Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: There is at least(1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a"ramp" in the wellbore to aid in kicking off(low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected,wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Abnormal Pressures and Temperatures: There are no abnormal pressures or temperatures observed on this pad. Page 46 Version 1 Feb 2016 • • II Milne Point Unit B-28 Drilling Procedure Hilcor Emmy 27.0 Doyon 14 Rig Layout U' atN fir...._ a sona mama gm ria rinliblE gmensin 0 I J � W T J tlN III. III! ri , 1 . 1 ; PIPE srYn' 01 N v ur , iI . s - ... -1 g II 1 1 IT iii• , 0 0 , !1 i JA7Lm T l5 x xi Page 47 Version 1 Feb 2016 I • II Milne Point Unit B-28 Drilling Procedure Hilcor Energy 28.0 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 of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 48 Version 1 Feb 2016 • s II Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 29.0 Choke Manifold Schematic ...-.2..�, z o ynW " D rn °' z ,' Z m N N N_ n N •• N Q Q S 7 ? y N 03 . 3 2 3 �, 0 w N W A W L = 7 't a '< w A < ' m fl m © E w a ao ` F. o a v ro 0o v, 3 m s v, m w = a v- 3D 3 aro w 33 g X ki4,,,,' JO' N 0 XI rn C v9 3 ✓ Q 0 0 3 CJI . s' n -iz, 1� 4 L FC y a' n < a ria u z y 0 0 tw Al •n ,all e, I:, \ e 0 z � 4-, co ,-. e a 1111v jok Mini i i ,. 11,11 4111,10 , A e A r* i ►,,, 0 • a 03 1 'k a 4? a e_,..p. -6..,-. • __, ._, ,,, ,. J: Page 49 Version 1 Feb 2016 • • Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 30.0 Casing Design Information Calculation & Casing Design Factors DATE: 1/26/2016 WELL: MPU B-28 DESIGN BY:Luke Keller Design Criteria: Hole Size 8-112" Mud Density: 9.5 ppg Hole Size Mud Density: Hole Size Mud Density: Drilling Mode MASP: 1158 psi(see attached MASP determination&calculation) MASP: Production Mode MASP: 1158 psi(see attached MASP determination& calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress(0.494 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification _ 1 2 3 4 Casing OD 9-5/8" 4-112" Top(MD) 0 5,400 Top(TVD) 0 4,406 Bottom (MD) 5,572 10.889 Bottom (TVD) 4,421 4,406 Length 5.572 5,489 Weight(ppf) 40 12.6 Grade L-80 L-80 Connection DWC/C H521 Weight w/o Bouyancy Factor(lbs) 222,880 69,161 Tension at Top of Section (lbs) 222,880 69,161 Min strength Tension(1000 lbs) 916 200 Worst Case Safety Factor(Tension) 4.11 2.89 Collapse Pressure at bottom (Psi) 2,184 2,177 Collapse Resistance wio tension (Psi)._ 3,090 7,500 Worst Case Safety Factor(Collapse) 1.41 3.45 MASP(psi) 1,158 1,158 Minimum Yield (psi) 5,750 8,430 Worst case safety factor(Burst) 4.97 7.28 Page 50 Version 1 Feb 2016 • Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 31.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation Ficorp 8-1/2"Hole Section MPU B-28 Milne Point Unit MD ND Planned Top: 5572 4421 Planned TD: 10889 4406 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff ND Sand 4,421 1600 Oil/Wet 7.0 0.362 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date MPB-11 9.5-9.6 Surface 4,500 1985 MPB-12 9.0-9.8 Surface 4,500 1985 MPB-13 9.5-9.6 Surface 4,500 1985 MPB-14 9.1-9.4 Surface 4,500 1985 MPB-15 8.6-9.8 Surface 4,500 1985 MPB-16 8.9-9.6 Surface 4,500 1985 MPB-17 8.6-9.7 Surface 4,500 1985 MPB-19 9.2-9.7 Surface 4,500 1985 MPB-21 9.3- 10.1 Surface 4,500 1986 MPB-25 8.3-9.4 Surface 4,500 1997 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 4421(ft)x 0.78(psi/ft)= 3449 psi 3449{psi)-[0.1(psi/ft)*4421(ft)1= 3007 psi MASP from pore pressure(complete evacuation of wellbore to gas from Schrader Bluff sand) 4421(ft)x 0.362(psi/ft)= 1600 psi 1600(psi)-0.1(psi/ft)*4421(ft)= 1158 psi Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of entire wellbore to gas at 0.1 psi/ft. Page 51 Version 1 Feb 2016 • Milne Point Unit B-28 II Drilling Procedure Hilcorp Energy Company 32.0 S s ider Plot NAD 27 Governmental Sections) I ADL047433 Sec ?' eatS "! 7 ADL392703 Sec - , . 1828. / ,----- • omx'. �- ♦ _ r I . C I" f }4 `4 J ` i r ,' f AA • ♦1 • B-28 BHL • x eze) " N. Sec '3 • ♦ , • _ _ .> .Y` tl11113N011 E• ADL047437 .0. uo13No10E el F SHL , M1LNE POINT UNIT --- --- a ;TPH ADL047438 ` -- I .\ • f :; 1 FB 1 / . r♦ '. , 4 i / I Sec 19 %, ♦ , ' X1-4-,533' • ♦ Cf , 1 l i f it , 11 7 0 .. P'' N. E... . ,E 19` l 9.� ` r f 1 1Legend 4 ' - `•l ti__ /IIo MPB 28 wp01 ♦♦., , ,',9 1 Ba h9PB_28_wp01_BHL ♦•. . , �� h9P8 28wp01_TPH . 6.22AI•B1'•� ,cloy;•, w_ MPB_28_wp01_SHL l 19 — ••• -._. _- ADL625518 Sec.26 '- E-.e--'Sec.25 '��+„ Other Surface Holes(SHL) G1O I t ♦`♦ • Other Bottom tides(BHL) /,'• • t `. ���..`B�G OPE.: ; -- -- Other Well Paths , % _ Oil and Gas Unit Boundary Milne Point Unit 0 1,200 2,400 MPB-28 Well Feet •,,CC-ire 1•1.:'I Page 52 Version 1 Feb 2016 • 0 II Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 33.0 Surface Plat (As Built) (NAD 27) V 2bi1! J ii ? �.i+.!..1, T ' 0—PAD' 3`,1 r :4 73 15 Ell -98—PAD I za. p nes t�o,�c> ---.: 0 L \. ■21 ■19 A PAO \--- 1118: . 4 1'1 7• ■1411. • i TO CRAWL 9TTi -" :.,- ■16 0 9■ �P %' `_ J t'( '{E_PAp 1C• 23■ t 1 75 ', 30 s■ X22 VICINITY MAP - N.T.S 2• •BA 8-28 5 ••330 I ''` LEGEND: 1• a1 �' +AS—BULT CONDUCTOR • EX5'iNG CONDUCTOR FNlaro �,�'04* 11111Ill )1 ti ff' .. ``.P�� OF"q4 41 o�a�° B-PAD R.`'� "j}�• `.1 e .••4 0 /, • it • �... � S � r�.f/f 7 'Te ". 10200 ` Hams; ��cti '`'slaw, 4�` 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4 NAl 27 t1IlI ,ktMN" 2. GEODETIC COORDINATES ARE NADZ7. 3. HORIZONTAL AND VERTICAL CONTROL ARC BASED ON MP B—PAD SURVEYOR'S CERTIFICATE OPERATOR MCNUI )ITS 8-0 AND 9-2. I HEREBY CERTIFY THAT I AM 4. ELEVATIONS ARE MP B—PAD DATUM, MEAN SEA ..EVEL (M.S.L)- PROPERLY REG STEREO AND L5CENSED TO PRACTICE LANG SURVEYING IN 5. MEAN PAD SCALE FACTOR IS: 0.999905887 THE STATE Or ALASKA AND THAT B. DATE.OF SURVEY! JANUARY 20,. 2016. THIS AS—BUILT REPRESENTS A SURVEY MADE BY ME CR UNDER My DIRECT 7. REFERENCE FIELD 8001C HC-18—D1,PGS. 01-05. SUPERVISOR ANC THAT ALL DIMENSIONS AND OTHER DETAILS ARE COIRtECT AS OF JANUARY 20, 2016. LOCATED WITHIN PROTRACTED SEC. 19, T. 13 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC TOP OF SECTION BASE FLANGE NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D_DO) GRAVEL PAD OFFSETS ELEVATION PY=6,022,955.82 N 1,298.13 70'28'22.803" 70.4730009' 5.112' FSL 8-28 x- 572,028.79 E 599.97 149'24'42.051" 149.4116807' 23.5 4,265' FEL NA 414410t ism ,ter_ "A ' jHi1corP Alaska + n6 "� MILN£ POINT B—PAD WLiT DNS _, T"-i + AS-BUILT CONDUCTOR LOCATION V,,I/na/teARRR MWRIMIRM .. -_ boll tL'Ir4d0' WELL 8-28 1a INIV0 4, SY a•. Page 53 Version 1 Feb 2016 i • 111 Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 34.0 Offset MW vs TVD Chart 0 . 8-21 (1986) —B-25 (1997) 11 1111 ,\ , . -B-12 (1985) loon \iapOlp -B-11 (1985) gll 8-1.5 (1985) B-'14(1985) 2OOO8-13 (198.5) B-17(1985) B-19 (1985) 3000 °- B-16 (1985)il\fl i cy 4nOn ill ill "Awl" 5000 IlliliPJ411 , 6000 , ilkik, 4\,,, 1 11\\A . 7000 11111/011:vim` Pr _ E 8000 ` —J 8.0 9.0 10.0 11.0 12.0 Mud Weight (PPG) Page 54 Version 1 Feb 2016 • • 11 Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company 35.0 Drill Pipe Information 5" 19.5# S-135 DS-50 Drill Pipe Configuration Pipe Body OD '' 5.000 80%Inspection Class II Pipe Body Wail Thickness to 0.362 Nominal Weight Designation 19.50 Pipe Body Grade S-135 Drill Pipe Approximate Length 31.5 Drill Pipe Length Range2 ,SmoothEdge Height ,143/32 Raised 11 Connection GPOS50 .i Tool Joint SMYS kr.i,120.000 Tool Joint 00 6.625 Upset Type €EU Tool Joint ID :n,3.250 Max Upset OD (DTE) tin 5.125 1\.1111) Pin Tong 9 Friction Facia 11.0_ Box Tong n 12 N T v••r r, r d r Q_.._.. Drill Pipe Performance Drill-Pipe Length Range2 Performance of Drill Pipe with Pipe Body at 1 I Best Estimates I Nominal 80%Inspection Class ,:-..-.,..i a,n I "'I° (least s:cicynale-.c -"' Drill Pipe Adjusted'Pieigh: :mini 24 11 23.29 Operational Max Tension -'°' Torque In-ir51 also Fluid OisR€acement ia'-Its 0.37 0.36 Tension Only 0 560,800 Fluid Displacement 0015 0.p 0.0085 1(1))wkmt,m MI 43,100 „bl„ed�paCkm 39,600 410.500 Fluid Capacity 421,1110.71 0.70 0.72 Fluid Capacity ''eat.aro 0.0169 0.0167 0.0172 Mkenasn MILT 36,100 Tension Only 0 560,800 Dnft Size ':Ir'3.125 Combined Loa da/a 32,100 467.400 -'- - Note 00 field barrel equals 42 US gallons. holeOrli ppe assembly valdes are nest estrlatc's and may vary due to pipe beds mil lolerarce,In.erral plant caatrle and other factors Connection Performance GPDS5O ( 6.625 ta') OD X 3.250 tr> ID ) 120,000 050 Aon ed"'oke-up renswtl at SnnA"« Tens""at corner+p". Tool Joint Dimensions Togas Separa•.�or YeO In-est lbs; gm] Balanced Oo :int 6.435 Maidmtrm Make-up Torque 43.100 Tensile Limited1,046.900 kgranrn Tod Joni CO 915.1 5.930 Minimum Matte Make-up Torque 36,100 1.202.500 1,250.000 gm] Class lint "'" Nobe The maximum makelp/ague shcWa be aydled Alien possbb Minimize Tont Joint 00 liar 5,93 Note To maxleae cannecron anefa.rraf lernIe.a HUT 1141-3T,ICO tftJbsl 50.00 Ste r.: - 'Tool Joint Torsional Strength terbat 71,800 1 f Tool Joint Tensile Strength ram 1.250.000 Lounteebor. Ona Elevator Shoulder Information Elevator OD 3/32 Raised 6.812 1r„ e 1 SmoothEdge Height Nominal Tool Joint Worn to Bevel Worn to Min TJ OD for 3132 Raised OD Diameter API Premium Class Box OD l'"6.812 6.625 6 063 5.930 iElevator Capacity Ar-s'1,658.000 1.440.200 823,600 685,600 Note Elevate cadacuty based an assumed Elevate Bore,na'wear rata-are contact stress of 110.100051. Assumed Elevator Bore Diameter 15.219 I Nae A raised eeoator 00 Increases elevaicr capacirr'wsMlout atfeclung make-up torque. Pipe Body Slip Crushing Capacity Pipe Body Configuration( 5 ') OD 0.362 art Wall S-135) Nominal 80°Y5 Inspection Class API Premium Class �' ISlipCrushinp Capacity (m.)498.300 396,500 396.500 ...-•-"--"' .•.•••••.•••:•"'-'.•••. Kobe:Sip Cr./shine Sip cr.a-try bad s oykmin r • cuac e Spr.Rel'intd eSuSlor.ban VA'S'Ones DI Pte v Assumed Slip Length I rl.i 18.5 Fal In Pe sty Area oboe a.1955 nr,the st.era),aid hansverse load radon sneer and Is for reference CTran5Yef8e Load Factor(Kl 4.2 555 cectusiensoependerloneveslpamenandot iltre:oemclerl«Maw Wend005-rs Ener Zs erre'no and vat.ardnx!,se alter'Ames Casal e1Nt me sta narutactCrcr ter adenalal Pipe Body Performance Pipe Body Conl guration( 5 au OD 0.362(m) Wall S-135) Nominal 80%Inspection Class API Premium Class Pipe Tensile Strength ..it st 712.100 560,800 560,800 Pice Torsional Strength It-Irsl 74.10058.100 58,100 TJlPipeBody Torsional Ratio 0.97 1-24 1.24 80%Pipe Torsional Strength ..n'icsl 59.300 46.500 46.500 Burst too 17.105 15.638 15,638 Note Nominal Burst Colapse ':psi 1 15.672 10.029 10.029 ca'cutated at 07 5'a RBW ter API Pipe OD lint5.000 4.855 4.855 1 Wall Thickness 'r,,0.362 0.290 0.290 • Nominal Pipe ID aru 4.276 4.276 4.276 Cross Sectional Area of Pipe Body 5.275 4 154 4.154 Cross Sectional Area of OD tin^3119.635 18.514 18.514 Cross Sectional Area of ID 31 14.360 14.360 14.360 Section Modulus (11`31 5.708 4.476 4.476 IC Y Polar Section Modulus r1,'31.11.415 8.953 8.953 Grant Page 55 Version 1 Feb 2016 • 0 Milne Point Unit B-28 Drilling Procedure Hilcorp Energy Company Operational Limits of Drill Pipe Connection 'GPDS50 Tool Joint 00 ;,,,16.625 Tool Joint ID ,x,13.250 "col Join'Specified Minimum 120,000 Yield Strength ps,i Pipe Body 80%Inspection Class Pipe Body OD ,,,,15 Mall Thickness , ]0.362 Pipe Body Grade is-135 J Combined Loading for Drill Pipe at ,Combined Loading for Drill Pipe at Maximum Make-up Torque= 43,100tn-an Minimum Make-up Torque= 36,100 1,1-it. Operatianas Assembly Pipe Body Commence,Max Operarana Assembly ape erdr Cee:non MaxTorque Tension Max Tension Tion I Torque Max Tension Man Ter'•on Max TerOon .11-1n11 Mx: Onsi ars, ;'Wes; absi tins 7 zi 0 560.800 560,800 1.046.900 0 560.800 560.800 1202 5c: 2,100 560.400 560.400 1.046.900 1.700 560.500 560.530 1.202.500 4.200 559.300 559,300 1046.900 3.400 559.800 559,800 1202,500 6.300 557.500 557,500 1,046,900 5.100 558.600 558.600 1,202.500 8,300 555.000 555,000 1.046.900 6.800 556.900 556.900 1.202,500 10.400 551.700 551,700 1.046.900 8.400 554.900 554.900 1.202,500 12,500 547.600 547,600 1.046.900 10.100 552.200 552.200 1.202.500 14,600 542.800 542,800 1,046.900 11.800 549,100 549.100 1.202,500 16.700 537.100 537,100 1.046.900 13.500 545.400 545.400 1.202,500 18.800 530,600 530,600 1,046.900 15.200 541,200 541.200 1,202,500 20.800 523.600 523,600 1046.900 16.900 536.500 536.500 1,202.50: 22.900 515.400 515,400 1.046.900 18,600 531.300 531.300 1,202,500 25.000 506.200 506.200 1 046.900 20.300 525,400 525.400 1.202 50; 27,100 496.100 496,100 1.046.900 22.000 519,000 519.000 1,202,500 29.200 484.800 484,800 1.046.900 23.700 512.000 5'2.000 1,202.504_ 31,300 472,500 472,500 1.046.900 25.300 504.800 504.800 1,202.50: 33.300 459.600 459.600 1.046.900 27.000 496.600 40'6.500 1202.50: 35,400 444.700 444,700 1.046.900 28.700 487.600 487.600 1.202.5000- 37.500 428.400 428,400 ' 046.900 30 400 477.900 477.920 120250, 39.600 410.500 410.500 1.046.900 32.100 467.400 467.400 1.202.500 Operational drilling torque is limited by the Make-up Torque. Operational dulling torque is limited by the Make-up Torque. Connection Make-up Torque Range Make-up Torque Connection Max ,1„,Tension ,t., Min MUT 36.100 1,202,500 II)il 36.900 1,229,200 37.700 1,243,600 38.400 1,218,100 39.200 1,189,000 40.000 1,159,800 40.800 1,130,700 41.500 1,105,200 42,300 1,076,100 Max MUT 43,100 1,046,900 Page 56 Version 1 Feb 2016 • Milne Point Unit B-28 II Drilling Procedure Hilcorp Energy Company Connection Wear Table Connection G?OS50 Tcel.bin=OD ,, 6.625 Tool Joint ID ,k,43250 Tool Joan Specified Minimum 120,000 Yield Strength (owl Connection Wear Tool Connection Max Col-ectic't6rtaxMin MUT Connection?Jaz Joint 00 Torsional MUT Tensic^ Tension New ODStrength 1 6.625 71,800 43.100 1,046,900 35,900 1.195.900 6.562 71,800 43.100 1.034,900 35.900 1208.700 6.499 71,800 43,100 1,022,600 35.900 1,222.400 ININNI 6.435 71,800 43.100 1,009,800 35.900 1.237.500 6.372 71,200 42,700 1,008,100 35.600 1.245,200 Fili 6.309 68.000 40,800 1,057,300 34.004 1207.700 6.246 64,800 38,900 1,104,800 32.400 1.169.800 6.183 61,700 37.000 1,150,400 30.800 1.131.300 6.12 58,600 35,200 1,190,900 29.300 1,096.100 6.056 55,500 33.300 1,232,300 27.800 1.060.800 Worn OD 5.993 52,600 31,500 1,227,200 26.300 1.024.600 5.93 49,600 29,800 1,187,100 24.800 987.900 Pipe Body Combined Loading Table(Torque-Tension) Pipe Body 80%Inspection Class Pipe Body OD .. 5 Wall Thickness ,,,,0.362 Pipe Body Grade S-135 1j Pipe Body Torque 0 5.300 10.600 15.800 21.100 26.400 31.700 37.000 42.300 47.500 52.800 58.100 owes) , Pepe Body Max 560.800 558.400 551 400 539.600 522 500 499 606 470,000 432.400 384,500 323.100 234.300 12.200 Tension M ? a Page 57 Version 1 Feb 2016 I Hilcorp Energy Company Milne Point M Pt B Pad Plan MPB-28 MPB-28 Plan: MPB-28 WP01 Standard Proposal Report 14 December, 2015 isomm HALLIBURTON ilmsommums Sperry Drilling Services 0 0 Halliburton HALL I B U R T O N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Cm-ordinate Refere)tce:;, . Well Plan MPB-28 Company: Hilcorp Energy Company NO Reference: WELL©56.50usft project: Milne Point MD Reference: , WELL @ 56.50usft Silie: M Pt B Pad North Rafeiince: True Welt: Plan MPB-28 Survey Calculation o*'''' ' 3 Minimum Curvature `Mgre: MPB-28 ry MPB-28 WP01 Project --`'" MilnePoint,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 -„ M Pt B Pad,TR-13-11 Site Position: Northing: 6,021,548.49 usft Latitude: 70°28'8.986 N From: Map Easting: 571,775.55 usft Longitude: 149°24'49.895 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.55° Well - Plan MPB-28 Well Position +N/-S 0.00 usft Northing: 6,022,955.70 usft Latitude: 70°28'22.802 N +E/-W 0.00 usft Easting: 572,028.85 usft Longitude: 149°24'42.049 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 23.20 usft Wellbat*`>; MPB-28 Magnetics _ Model Name Sample Date Declination DIP Angle Field Strength (°) r) (nT) BGGM2015 12/4/2015 18.90 81.09 57,509 Design MPB-28 WP01 Audit Notes: Version: Phase: PLAN Tie On Depth: 33.30 Iferttcal Section: Depth From(TVD) +N/-S +EI4 r Direction hsstf (usft) (usft (•) 33.30 0.00 0.00 295.74 Plan Sections Measured Verticet- TYD Dogleg Build tum Depth Inhllnation Azimuth` Depth System 44414 +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (1100usft) (1l00usft) (11O0usft) (°) 33.30 0.00 0.00 33.30 -23.20 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 193.50 0.00 0.00 0.00 0.00 0.00 0.00 500.00 3.00 80.00 499.89 443.39 1.14 6.44 1.20 1.20 0.00 80.00 1,250.00 12.00 140.00 1,243.38 1,186.88 -55.35 76.09 1.44 1.20 8.00 73.71 2,356.32 29.91 236.09 2,293.47 2,236.97 -304.32 -83.39 3.00 1.62 8.69 115.07 3,792.11 29.91 236.09 3,538.03 3,481.53 -703.71 -677.58 0.00 0.00 0.00 0.00 5,321.99 85.00 307.55 4,399.71 4,343.21 -406.62 -1,764.83 5.00 3.60 4.67 76.24 5,571.99 85.00 307.55 4,421.50 4,365.00 -254.85 -1,962.29 0.00 0.00 0.00 0.00 5,677.52 90.28 307.54 4,425.85 4,369.35 -190.61 -2,045.87 5.00 5.00 0.00 -0.03 8,886.29 90.28 307.54 4,410.35 4,353.85 1,764.67 -4,590.04 0.00 0.00 0.00 0.00 8,889.63 90.11 307.55 4,410.34 4,353.84 1,766.70 -4,592.69 5.00 -5.00 0.20 177.75 10,889.63 90.11 307.55 4,406.50 4,350.00 2,985.61 -6,178.33 0.00 0.00 0.00 0.00 12/14/2015 6:20:04PM Page 2 COMPASS 5000.1 Build 73 • S Halliburton H A L L I B U R T O N Standard Proposal Report Database: SperryEDM-NORTH US+CANADA ax` ` LOW Coordinate Referan °Well Plan MPB-28 Company Hilcorp Energy CompanyTVDRaferancet ,:,..0.. .S Wt. .WELL @ 56.50usft Project: ' Milne Point MD Rafirenc.: t , WELL @ 56.50usft Site, M Pt B Pad Nonnnetssrence: 1- fix, True W0: Plan MPB-28 Survey CalculmlonMNi Minimum Curvature C1 ^ MPB-28 1 t MPB-28 WP01 1 T '3 - ti 1, w? X�a a� # ,. z hte ,u Vertical Map 0 *3tc °' .lnalhatlon Azimuth Depth TVDee +NI-$ *elm NorDdng Age: sI 4 F'' ton weft ( ! (1 (') Nee)�.� ��� usft; (uaTt) (0441-,?' l` i►fU k{ ) 40" 33.30 0.00 0.00 33.30 -23.20 0.00 0.00 6,022,955.70 572,028.85 0.00 0.00 100.00 0.00 0.00 100.00 43.50 0.00 0.00 6,022,955.70 572,028.85 0.00 0.00 200.00 0.00 0.00 200.00 143.50 0.00 0.00 6,022,955.70 572,028.85 0.00 0.00 250.00 0.00 0.00 250.00 193.50 0.00 0.00 6,022,955.70 572,028.85 0.00 0.00 300.00 0.60 80.00 300.00 243.50 0.05 0.26 6,022,955.75 572,029.11 1.20 -0.21 400.00 1.80 80.00 399.98 343.48 0.41 2.32 6,022,956.13 572,031.17 1.20 -1.91 500.00 3.00 80.00 499.89 443.39 1.14 6.44 6,022,956.90 572,035.28 1.20 -5.31 600.00 3.67 102.13 599.72 543.22 0.92 12.15 6,022,956.73 572,040.99 1.44 -10.55 700.00 4.71 116.04 699.45 642.95 -1.56 18.97 6,022,954.33 572,047.84 1.44 -17.77 800.00 5.91 124.63 799.02 742.52 -6.29 26.90 6,022,949.67 572,055.81 1.44 -26.96 900.00 7.21 130.25 898.37 841.87 -13.27 35.93 6,022,942.78 572,064.90 1.44 -38.12 1,000.00 8.55 134.13 997.42 940.92 -22.49 46.05 6,022,933.65 572,075.11 1.44 -51.25 1,100.00 9.92 136.97 1,096.13 1,039.63 -33.96 57.26 6,022,922.30 572,086.43 1.44 -66.32 1,200.00 11.30 139.11 1,194.42 1,137.92 -47.66 69.55 6,022,908.72 572,098.85 1.44 -83.35 1,250.00 12.00 140.00 1,243.38 1,186.88 -55.35 76.09 6,022,901.09 572,105.47 1.44 -92.58 1,300.00 11.44 146.86 1,292.34 1,235.84 -63.49 82.15 6,022,893.02 572,111.60 3.00 -101.57 1,400.00 10.87 162.13 1,390.47 1,333.97 -80.77 90.47 6,022,875.81 572,120.09 3.00 -116.57 1,500.00 11.10 177.87 1,488.66 1,432.16 -99.38 93.72 6,022,857.24 572,123.52 3.00 -127.58 1,600.00 12.09 192.02 1,586.64 1,530.14 -119.25 91.90 6,022,837.36 572,121.89 3.00 -134.57 1,700.00 13.67 203.51 1,684.14 1,627.64 -140.33 85.00 6,022,816.22 572,115.20 3.00 -137.52 1,800.00 15.66 212.40 1,780.89 1,724.39 -162.56 73.06 6,022,793.87 572,103.47 3.00 -136.42 1,900.00 17.93 219.21 1,876.63 1,820.13 -185.88 56.10 6,022,770.39 572,086.74 3.00 -131.27 2,000.00 20.38 224.49 1,971.09 1,914.59 -210.23 34.16 6,022,745.83 572,065.04 3.00 -122.09 2,100.00 22.96 228.65 2,064.03 2,007.53 -235.54 7.31 6,022,720.26 572,038.44 3.00 -108.90 2,200.00 25.62 232.00 2,155.17 2,098.67 -261.75 -24.37 6,022,693.75 572,007.02 3.00 -91.74 2,300.00 28.35 234.75 2,244.27 2,187.77 -288.77 -60.81 6,022,666.38 571,970.84 3.00 -70.66 2,356.32 29.91 236.09 2,293.47 2,236.97 -304.32 -83.39 6,022,650.61 571,948.42 3.00 -57.08 2,400.00 29.91 236.09 2,331.33 2,274.83 -316.47 -101.46 6,022,638.29 571,930.47 0.00 -46.08 2,500.00 29.91 236.09 2,418.01 2,361.51 -344.29 -142.85 6,022,610.08 571,889.36 0.00 -20.88 2,600.00 29.91 236.09 2,504.69 2,448.19 -372.11 -184.23 6,022,581.86 571,848.25 0.00 4.31 2,700.00 29.91 236.09 2,591.37 2,534.87 -399.92 -225.61 6,022,553.65 571,807.14 0.00 29.51 2,800.00 29.91 236.09 2,678.06 2,621.56 -427.74 -267.00 6,022,525.44 571,766.03 0.00 54.70 2,900.00 29.91 236.09 2,764.74 2,708.24 -455.56 -308.38 6,022,497.22 571,724.92 0.00 79.89 3,000.00 29.91 236.09 2,851.42 2,794.92 -483.37 -349.77 6,022,469.01 571,683.81 0.00 105.09 3,100.00 29.91 236.09 2,938.10 2,881.60 -511.19 -391.15 6,022,440.80 571,642.70 0.00 130.28 3,200.00 29.91 236.09 3,024.78 2,968.28 -539.01 -432.54 6,022,412.58 571,601.59 0.00 155.48 3,300.00 29.91 236.09 3,111.46 3,054.96 -566.82 -473.92 6,022,384.37 571,560.48 0.00 180.67 3,400.00 29.91 236.09 3,198.14 3,141.64 -594.64 -515.30 6,022,356.16 571,519.37 0.00 205.86 3,500.00 29.91 236.09 3,284.82 3,228.32 -622.46 -556.69 6,022,327.94 571,478.26 0.00 231.06 3,600.00 29.91 236.09 3,371.50 3,315.00 -650.27 -598.07 6,022,299.73 571,437.15 0.00 256.25 3,700.00 29.91 236.09 3,458.18 3,401.68 -678.09 -639.46 6,022,271.52 571,396.04 0.00 281.44 3,792.11 29.91 236.09 3,538.03 3,481.53 -703.71 -677.58 6,022,245.53 571,358.18 0.00 304.65 3,800.00 30.01 236.86 3,544.86 3,488.36 -705.89 -680.86 6,022,243.32 571,354.92 5.00 306.66 3,900.00 31.59 246.13 3,630.81 3,574.31 -730.17 -725.78 6,022,218.61 571,310.24 5.00 336.57 4,000.00 33.78 254.47 3,715.01 3,658.51 -748.22 -776.55 6,022,200.07 571,259.65 5.00 374.46 12/14/2015 6:20:04PM Page 3 COMPASS 5000.1 Build 73 I 0 Halliburton HALLIBURTON Standard Proposal Report Database: `, Sperry EDM-NORTH US+CANADA LOCOCOPOrdirtatttR$te of +: Well Plan MPB-28 Company: Hilcorp Energy Company ROM111C4i: WELL @ 56.50usft Prolect: Milne Point MD lance: WELL @ 56.50usft SIGyt M Pt B Pad Ne{ r'Riftrsnce: �w True VitOti Plan MPB-28 Survey Calculation Method: Minimum Curvature a-I491:e MPB-28 k‘' MPB-28 WP01 Planned Survey ice. a `°,_' 'a' °"� z `r a. �. " i , a`ya+ 'tl€ • WfrAeat ri'''"-.4:4-i,.. °$aP .l" x . ..„*ix ',',131 ,c „, n ., ? t,�f �� ILsiallon Aslmuf�t x` Depth ,w� s aNF$ +Pd-W N �n4 ���' L 'iNti� ori',`° ("'ft) (')` (1 cw+i usn (ustt) (ush) cpm (usrt) 3,740.33 4,100.00 36.46 261.81 3,796.83 3,740.33 -759.91 -832.78 6,022,187.84 571,203.54 5.00 420.03 4,200.00 39.54 268.21 3,875.65 3,819.15 -765.15 -894.05 6,022,182.01 571,142.33 5.00 472.95 4,300.00 42.93 273.80 3,950.87 3,894.37 -763.88 -959.88 6,022,182.64 571,076.49 5.00 532.80 4,400.00 46.55 278.70 4,021.91 3,965.41 -756.13 -1,029.79 6,022,189.71 571,006.52 5.00 599.13 4,500.00 50.36 283.03 4,088.23 4,031.73 -741.96 -1,103.23 6,022,203.17 570,932.95 5.00 671.44 4,600.00 54.32 286.89 4,149.33 4,092.83 -721.47 -1,179.66 6,022,222.92 570,856.34 5.00 749.18 4,700.00 58.38 290.39 4,204.75 4,148.25 -694.81 -1,258.47 6,022,248.81 570,777.28 5.00 831.75 4,800.00 62.53 293.60 4,254.06 4,197.56 -662.19 -1,339.09 6,022,280.64 570,696.36 5.00 918.53 4,900.00 66.75 296.56 4,296.88 4,240.38 -623.87 -1,420.88 6,022,318.17 570,614.20 5.00 1,008.86 5,000.00 71.03 299.35 4,332.89 4,276.39 -580.12 -1,503.24 6,022,361.12 570,531.43 5.00 1,102.04 5,100.00 75.34 301.99 4,361.82 4,305.32 -531.28 -1,585.53 6,022,409.15 570,448.68 5.00 1,197.38 5,200.00 79.68 304.54 4,383.45 4,326.95 -477.73 -1,667.13 6,022,461.90 570,366.58 5.00 1,294.13 5,300.00 84.04 307.01 4,397.61 4,341.11 -419.87 -1,747.41 6,022,518.98 570,285.74 5.00 1,391.58 5,321.99 85.00 307.55 4,399.71 4,343.21 -406.62 -1,764.83 6,022,532.06 570,268.20 5.00 1,413.03 5,400.00 85.00 307.55 4,406.51 4,350.01 -359.26 -1,826.45 6,022,578.82 570,206.14 0.00 1,489.10 5,500.00 85.00 307.55 4,415.23 4,358.73 -298.55 -1,905.43 6,022,638.75 570,126.57 0.00 1,586.61 5,571.99 85.00 307.55 4,421.50 4,365.00 -254.85 -1,962.29 6,022,681.90 570,069.30 0.00 1,656.81 5,572.00 85.00 307.55 4,421.50 4,365.00 -254.84 -1,962.30 6,022,681.91 570,069.29 0.00 1,656.82 9 518" 5,600.00 86.40 307.55 4,423.60 4,367.10 -237.83 -1,984.44 6,022,698.71 570,046.99 5.00 1,684.15 5,677.52 90.28 307.54 4,425.85 4,369.35 -190.61 -2,045.87 6,022,745.32 569,985.12 5.00 1,759.99 5,700.00 90.28 307.54 4,425.74 4,369.24 -176.92 -2,063.69 6,022,758.84 569,967.16 0.00 1,781.99 5,800.00 90.28 307.54 4,425.26 4,368.76 -115.98 -2,142.98 6,022,819.00 569,887.30 0.00 1,879.88 5,900.00 90.28 307.54 4,424.77 4,368.27 -55.05 -2,222.27 6,022,879.16 569,807.43 0.00 1,977.77 6,000.00 90.28 307.54 4,424.29 4,367.79 5.89 -2,301.55 6,022,939.32 569,727.56 0.00 2,075.65 6,100.00 90.28 307.54 4,423.81 4,367.31 66.83 -2,380.84 6,022,999.48 569,647.70 0.00 2,173.54 6,200.00 90.28 307.54 4,423.32 4,366.82 127.76 -2,460.13 6,023,059.64 569,567.83 0.00 2,271.42 6,300.00 90.28 307.54 4,422.84 4,366.34 188.70 -2,539.42 6,023,119.80 569,487.96 0.00 2,369.31 6,400.00 90.28 307.54 4,422.36 4,365.86 249.63 -2,618.71 6,023,179.96 569,408.10 0.00 2,467.20 6,500.00 90.28 307.54 4,421.88 4,365.38 310.57 -2,698.00 6,023,240.12 569,328.23 0.00 2,565.08 6,600.00 90.28 307.54 4,421.39 4,364.89 371.50 -2,777.28 6,023,300.28 569,248.36 0.00 2,662.97 6,700.00 90.28 307.54 4,420.91 4,364.41 432.44 -2,856.57 6,023,360.44 569,168.50 0.00 2,760.86 6,800.00 90.28 307.54 4,420.43 4,363.93 493.37 -2,935.86 6,023,420.60 569,088.63 0.00 2,858.74 6,900.00 90.28 307.54 4,419.94 4,363.44 554.31 -3,015.15 6,023,480.75 569,008.76 0.00 2,956.63 7,000.00 90.28 307.54 4,419.46 4,362.96 615.25 -3,094.44 6,023,540.91 568,928.90 0.00 3,054.51 7,100.00 90.28 307.54 4,418.98 4,362.48 676.18 -3,173.72 6,023,601.07 568,849.03 0.00 3,152.40 7,200.00 90.28 307.54 4,418.49 4,361.99 737.12 -3,253.01 6,023,661.23 568,769.16 0.00 3,250.29 7,300.00 90.28 307.54 4,418.01 4,361.51 798.05 -3,332.30 6,023,721.39 568,689.30 0.00 3,348.17 7,400.00 90.28 307.54 4,417.53 4,361.03 858.99 -3,411.59 6,023,781.55 568,609.43 0.00 3,446.06 7,500.00 90.28 307.54 4,417.05 4,360.55 919.92 -3,490.88 6,023,841.71 568,529.56 0.00 3,543.94 7,600.00 90.28 307.54 4,416.56 4,360.06 980.86 -3,570.17 6,023,901.87 568,449.70 0.00 3,641.83 7,700.00 90.28 307.54 4,416.08 4,359.58 1,041.79 -3,649.45 6,023,962.03 568,369.83 0.00 3,739.72 7,800.00 90.28 307.54 4,415.60 4,359.10 1,102.73 -3,728.74 6,024,022.19 568,289.96 0.00 3,837.60 7,900.00 90.28 307.54 4,415.11 4,358.61 1,163.67 -3,808.03 6,024,082.35 568,210.10 0.00 3,935.49 8,000.00 90.28 307.54 4,414.63 4,358.13 1,224.60 -3,887.32 6,024,142.51 568,130.23 0.00 4,033.38 12/14/2015 6:20:04PM Page 4 COMPASS 5000.1 Build 73 • • Halliburton HALL I B U R TO N Standard Proposal Report Slat, Sperry EDM-NORTH US+CANADA LocatCo•4tdhrnte Referents: Well Plan MPB-28 Oompan ; Hilcorp Energy Company NO Reference: K x 1.WELL @ 56.50usft Milne Point MD Reference; `'WELL©56.50usft M Pt B Pad North Reference: True 9" Plan MPB-28 Survey Calculation Method*'_•" Minimum Curvature + MPB-28 MPB-28 WP01 twr. Plannlail' . `, a f „'�, cal . q!o�tll InclinaBa► Atlmuth ' Ta +Nu-S +EPN € rthing Ea tng , Vert Becton Cu i. (') ( ; ;to u#ft (nett) (usft (tall) (tart) `,,, t, 5 8,100.00 90.28 307.54 4,414.15 4,357.65 1,285.54 -3,966.61 6,024,202.67 568,050.36 0.00 4,131.26 8,200.00 90.28 307.54 4,413.67 4,357.17 1,346.47 -4,045.90 6,024,262.83 567,970.50 0.00 4,229.15 8,300.00 90.28 307.54 4,413.18 4,356.68 1,407.41 -4,125.18 6,024,322.99 567,890.63 0.00 4,327.03 8,400.00 90.28 307.54 4,412.70 4,356.20 1,468.34 -4,204.47 6,024,383.15 567,810.76 0.00 4,424.92 8,500.00 90.28 307.54 4,412.22 4,355.72 1,529.28 -4,283.76 6,024,443.31 567,730.90 0.00 4,522.81 8,600.00 90.28 307.54 4,411.73 4,355.23 1,590.21 -4,363.05 6,024,503.47 567,651.03 0.00 4,620.69 8,700.00 90.28 307.54 4,411.25 4,354.75 1,651.15 -4,442.34 6,024,563.63 567,571.16 0.00 4,718.58 8,800.00 90.28 307.54 4,410.77 4,354.27 1,712.09 -4,521.62 6,024,623.79 567,491.30 0.00 4,816.46 8,886.29 90.28 307.54 4,410.35 4,353.85 1,764.67 -4,590.04 6,024,675.70 567,422.38 0.00 4,900.93 8,889.63 90.11 307.55 4,410.34 4,353.84 1,766.70 -4,592.69 6,024,677.71 567,419.71 5.00 4,904.20 8,900.00 90.11 307.55 4,410.32 4,353.82 1,773.02 -4,600.91 6,024,683.95 567,411.43 0.00 4,914.35 9,000.00 90.11 307.55 4,410.13 4,353.63 1,833.97 -4,680.19 6,024,744.12 567,331.57 0.00 5,012.23 9,100.00 90.11 307.55 4,409.94 4,353.44 1,894.91 -4,759.48 6,024,804.29 567,251.71 0.00 5,110.12 9,200.00 90.11 307.55 4,409.74 4,353.24 1,955.86 -4,838.76 6,024,864.46 567,171.85 0.00 5,208.00 9,300.00 90.11 307.55 4,409.55 4,353.05 2,016.80 -4,918.04 6,024,924.63 567,091.99 0.00 5,305.89 9,400.00 90.11 307.55 4,409.36 4,352.86 2,077.75 -4,997.32 6,024,984.80 567,012.13 0.00 5,403.77 9,500.00 90.11 307.55 4,409.17 4,352.67 2,138.69 -5,076.60 6,025,044.97 566,932.27 0.00 5,501.66 9,600.00 90.11 307.55 4,408.98 4,352.48 2,199.64 -5,155.89 6,025,105.14 566,852.41 0.00 5,599.54 9,700.00 90.11 307.55 4,408.78 4,352.28 2,260.58 -5,235.17 6,025,165.31 566,772.54 0.00 5,697.43 9,800.00 90.11 307.55 4,408.59 4,352.09 2,321.53 -5,314.45 6,025,225.48 566,692.68 0.00 5,795.31 9,900.00 90.11 307.55 4,408.40 4,351.90 2,382.48 -5,393.73 6,025,285.65 566,612.82 0.00 5,893.20 10,000.00 90.11 307.55 4,408.21 4,351.71 2,443.42 -5,473.01 6,025,345.82 566,532.96 0.00 5,991.08 10,100.00 90.11 307.55 4,408.02 4,351.52 2,504.37 -5,552.30 6,025,405.98 566,453.10 0.00 6,088.97 10,200.00 90.11 307.55 4,407.82 4,351.32 2,565.31 -5,631.58 6,025,466.15 566,373.24 0.00 6,186.85 10,300.00 90.11 307.55 4,407.63 4,351.13 2,626.26 -5,710.86 6,025,526.32 566,293.38 0.00 6,284.74 10,400.00 90.11 307.55 4,407.44 4,350.94 2,687.20 -5,790.14 6,025,586.49 566,213.52 0.00 6,382.62 10,500.00 90.11 307.55 4,407.25 4,350.75 2,748.15 -5,869.42 6,025,646.66 566,133.66 0.00 6,480.51 10,600.00 90.11 307.55 4,407.06 4,350.56 2,809.09 -5,948.71 6,025,706.83 566,053.80 0.00 6,578.39 10,700.00 90.11 307.55 4,406.86 4,350.36 2,870.04 -6,027.99 6,025,767.00 565,973.94 0.00 6,676.28 10,800.00 90.11 307.55 4,406.67 4,350.17 2,930.98 -6,107.27 6,025,827.17 565,894.08 0.00 6,774.16 10,889.62 90.11 307.55 4,406.50 4,350.00 2,985.60 -6,178.32 6,025,881.09 565,822.51 0.00 6,861.88 5112" 10,889.63 90.11 307.55 4,406.50 4,350.00 2,985.61 -6,178.33 6,025,881.10 565,822.50 0.00 6,861.89 Targets Target Name •hltlmiss target Dip Angie Dip Dir. ND +NI-S 4!410. Northing ' acting, •Shape ( (`) (usft) (ustt) -> Wit NagOlch) MPB-28 Heel 0.00 0.00 4,421.50 -254.85 -1,962.29 6,022,681.90 570,069.30 -plan hits target center -Circle(radius 100.00) MPB-28 Toe 0.00 0.00 4,406.50 2,985.61 -6,178.33 6,025,881.10 565,822.50 -plan hits target center -Circle(radius 100.00) 12/14/2015 6:20:04PM Page 5 COMPASS 5000.1 Build 73 • • Halliburton Standard Proposal Report HALLIBURTON Database: , Sperry EDM NORTH o�oMinMe N Well Plan MPB-28 C1 pany: Hilcorp Energy CompanyUS+CANADA �H#itC�fWeflc.: WELL @ 56. Project: Milne Ctt�1 Reitttettee: € WELL @ 56.5ousft50usft M Pt B PadPoint No ttt It l'et't• fleet True Wilk Plan MPB-28 purvey Cart stitl rd Minimum Curvature Wellbore: MPB-28 Design: MPB-28 WP01 _. ' r � �lt19te rCaatng Points Ya pr y4 sDi ' z } Na9-5/8D,p me 12-1 /4(usft) ("lei 5,572.00 4,421.50 9 5/8" 10,889.62 4,406.50 51/2" 5-1/2 8-1/2 COMPASS 5000.1 Build 73 12/14/2015 6:20:04PM Page 6 • • 3 a 0 B4 ce 3� me.- e 30 - Z0 W - c _ 2 m W N - Z N NNS 9 W .0 C •5 J - N 3(J Z N>C �N `;'so H —Vl gra ry, N ¢ MSS° 0 ooN o co = 170 m N o 2 Joe; 0 -N0$ - _ O d-- E Z N co - N P' Li,CO LL WWW c fn u00 —s z 35a = E. 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N (ui/�}sn 009) gidea leowen emu r CVO , vi I • • HALLIBURTON July 7,2015 Engineering Data Sheet EQUIPMENT MATERIAL NO.: 102338486 PGM DS,4.500-12.60,250 MIC,HAL GR L-80 L PART NUMBER:281JCR45003-A DESIGN SPECIFICATIONS MAXIMUM OD 5.307 inch MINIMUM ID 3.894 inch DRIFT BAR OUTSIDE DIAMETER 3.833 inch LENGTH 480.00 inch BASE PIPE SIZE 4.500 INCH BASE PIPE WEIGHT 12.60 LBS/FT MAXIMUM LENGTH 486 inch BASE PIPE MATERIAL HAL GRADE L-80 LOW ALLOY STEEL BASE PIPE MATERIAL YIELD STRENGTH MIN 80000 pounds/sq.inch BASE PIPE PERFORATION HOLE SIZE 3/8 BASE PIPE NUMBER OF HOLES PER FOOT 76 HOLES PER FOOT TOP THREAD 4 1/2-12.60 VAMTOP BOTTOM THREAD 4 1/2-12.60 VAMTOP CONNECTION TYPE BOX-PIN COUPLING OD 4.937 inch HANDLING LENGTH,TOP 42 inch HANDLING LENGTH,BOTTOM 38 inch MESH SCREEN GAUGE 250 micron SCREEN JACKET MAXIMUM OD 5.307 inch SCREENED LENGTH 384 inch SCREEN MATERIAL 3161_STAINLESS STEEL SERVICE STD CENTRALIZER TYPE NONE (END) (Unless specified,Dim-Inches,pres-psi,weight-lbs,temp-deg F) NOTE:Values of pressure,force and operating depths presented above are based upon empirical data and theoretical calculations.These values will vary within accepted engineering limits due to variations in material strength,dimensional tolerances and actual installed conditions. 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Maybe the email didn't go through or something. Info is attached below, I'll give you a call in a few minutes to make sure this email finds you. Luke Sent via the Samsung Galaxy S®6 active, an AT&T 4G LTE smartphone Original message From: Luke Keller<Ikeller@hilcorp.com> Date: 02/11/2016 9:23 AM (GMT-09:00) To: "'Bettis, Patricia K(DOA)" <patricia.bettis@alaska.gov> Cc: "Cody Dinger- (C)" <cdinger@hilcorp.com> Subject: RE: MPU B-28: Permit to Drill Application (PTD 216-027) Patricia, I apologize for the planar and cross section views, we forgot to attach them with the directional plan. They are included with this email. Regarding the MASP& maximum downhole pressure calculations,they were included with the PTD submission on page 51 of the drilling program (screen shot below). Is there something else or more specific you would like to see on this? Thanks, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 [cid:image001.jpg@O1D164AD.D2CB3E70] From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, February 10, 2016 2:51 PM To: Luke Keller Subject: MPU B-28: Permit to Drill Application (PTD 216-027 Good afternoon Luke, 1 • The proposed MPU B-28 well will be deviated. • Please submit both a planar and cross-section wellbore plat to be included in the application. These may be submitted to me via e-mail. Finally, please provided your calculations for both MASP and maximum downhole pressure. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907) 793- 1238 or patricia.bettis@alaska.gov<mailto:patricia.bettis@alaska.gov>. 2 • • Schwartz, Guy L (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Friday, February 26, 2016 9:36 AM To: Schwartz, Guy L(DOA) Cc: Cody Dinger- (C) Subject: RE: MPU B-28 Close crossing well (PTD 216-027) Guy, MPU B-18 is an active Kuparuk injector, currently injecting approx. 800 BWPD into the Kuparuk"C" sand. Mitigation measures during the close approach will include: 1. Stop injecting into B-18. 2. Reduce ROP and rpm, monitoring torque and drilling parameters closely. 3. Monitor shut in tubing pressure on B-18. Let me know if you would like to see additional mitigations in place, or additional information on C-18. Thanks, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, February 26, 2016 9:22 AM To: Luke Keller Subject: MPU B-28 Close crossing well (PTD 216-027) Luke, Well B-28 passes fairly close to B-18 which is an existing MPU Kuparuk completion. The Anti-collision printout shows that the eclipse separation fails. What are you doing when you drill by the well to mitigate the risk? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). 1 • • Schwartz, Guy L (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Thursday, February 25, 2016 1:54 PM To: Schwartz,Guy L(DOA) Cc: Cody Dinger- (C); Paul Chan Subject RE: B-28 (PTD 216-027) Attachments: MPK 44 -WP02 - Proposal Report.pdf;4.5in PetroGuard DS Data Sheet.pdf Guy, Sorry about that,the A/C docs are at the back of attachment. Let me know if you need to see more detail. Also attached is some info about the screens we will be running. As far as swell packers go—if we are able to stay in zone 100%of the time,there will be no swell packers. If we see any major faulting or spend time out of zone,we would try to isolate with swell packers. Correct me if I'm wrong on any of this, Paul. This is more your department than mine. Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, February 25, 2016 12:22 PM To: Luke Keller Subject: B-28 (PTD 216-027) Luke, Looking at B-28 PTD. 1) I didn't see a anti-collision document. 2) 2) Are there going to be swell packers included with the screen liner?Any specs on the screens..was just curious what you are running. 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 1 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: (A, Z - ' PTD: a/c, -O .7- Development _Service Exploratory Stratigraphic Test Non-Conventional FIELD: 411 1 I AE. -? F POOL: 11111114.- POl(F) o,cl0� 2/kff— &'7 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are / also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 • 0 r_7 N a) a , N0 Q , O, , U) J o' (7 Co , " ' N RS D co 7 W u) O, �, 4? N, a E. O o, a c, a o, c. E O , Z r p m g N o u O a, 3, _c, o Z. > a), ca y, to �' 3. __ v, oc, N C, c G �, E, 0 d, o, �, a), 3. v, N.. c y a) Q: 170.' ' o, o, ac), m "0 Y, o, w o, .y �) , 1 , co �. 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