The URL can be used to link to this page

Home My WebLink About219-1571. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Punch 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 14,940 feet N/A feet true vertical 3,468 feet N/A feet Effective Depth measured 14,940 feet 5,488' & 6,794'feet true vertical 3,468 feet 3,341' & 3,568'feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 / EUE 8rd 7,087' 3,595' Retrievable & Packers and SSSV (type, measured and true vertical depth)SLZXP LTP 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 13. Prior to well operation: Subsequent to operation: 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 14,940' 3,569' 3,468' 7,240psi N/A 5,410psi N/A Hilcorp Alaska LLC Tieback Slotted Liner 6,803' 8,129' 7" 6-5/8" 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi Burst N/A 5,750psi 19,491psi 777-8485 20" x 34" 9-5/8" 4" 3,587' 3,472' 20,141psi 295 Length 107' 6,960' 6,064' Surface Drill Pipe Liner Milne Point Unit M-26 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 213 Gas-Mcf 2,795 Casing Pressure Tubing Pressure 200 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-205 294 Authorized Signature with date: Authorized Name: Abhijeet Tambe Abhijeet.Tambe@hilcorp.com 3,023 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 219-157 50-029-23656-00-00 Plugs ADL0025514 & ADL0355023 5. Permit to Drill Number: Milne Point Field / Schrader Bluff Oil Pool Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 465 Representative Daily Average Production or Injection Data 29913 Oil-Bbl measured true vertical Packer Size N/A Casing Conductor WINJ WAG 273 Water-Bbl MD 107' 6,960' 13,146' TVD 107' 6,803' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:35 pm, Jun 10, 2021 Chad Helgeson (1517) 2021.06.10 15:25:10 - 08'00' DSR-6/11/21 RBDMS HEW 6/11/2021 MGR30JUL2021 _____________________________________________________________________________________ Revised By: NLW 5/15/2021 SCHEMATIC Milne Point Unit Well: MPU M-26 Last Completed: 4/5/2021 PTD: 219-157 + TD =14,940’ (MD)/ TD = 3,468’(TVD) 20” Orig. KB Elev.: 51.5’/ GL Elev.: 25.3’ (Innovation) Surface Casing Reference Doyon 14 KB 59’ 7” 9-5/8” 1 5 CTU perfed stuck drill pipe inside slotted liner. 7,500 - 7530' 8,270 - 8300' 11,300 - 11,330' 11,496 - 11,526' PBTD =14,940’ (MD) / TD = 3,468’(TVD) 9-5/8”‘ES’ Cementer @ 2,523’ 109 9 13 4 2 7 & 8 11 6 See Slotted/ Solid Liner Detail 3 12 Min ID 2.750” 6-5/8” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"x34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.835” Surface 6,960’ 0.0758 7” Tieback 26/ L-80 / TXP 6.276” Surface 6,803’ 0.0383 6-5/8” Liner 20 / L-80 / Hydril 563 6.049” 6,811’ 14,940’ 0.0355 4” Drill Pipe Liner 14 / S-135 / XT39 2.687” 7,082’ 13,146’ 0.0102 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 7,087’ 0.0087 OPEN HOLE / CEMENT DETAIL 42” 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4” 1st stage L – 585 sx/ T – 400 sx 12-1/4” 2nd stage L – 515 sx / T – 270 sx 8-1/2” Cementless Slotted Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 226’ Max Hole Angle = 97 TREE & WELLHEAD Tree Cameron 3 1/8” 5M Wellhead FMC 11" 5M TC-1A w/11" x 3 1/2" TC-II Top and Bottom Tubing Hanger with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23656-00-00 Surface Drilled by Doyon 14 Production Drilled by Innovation Complete – 1/7/2020 Jet Pump Completion Doyon 14 - 4/5/2021 6-5/8” SLOTTED & SCREENED LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 21 6,982’ 3,589’ 7,817’ 3,603’ 19 8,216’ 3,566’ 8,976’ 3,546’ 94 9,096’ 3,543’ 12,863’ 3,471’ 48 12,982’ 3,468’ 14,898’ 3,467’ 4 rows, 8 slots/row, 2”x0.125” slots on 6” centers JEWELRY DETAIL No. Top MD Item ID 1 29’ Tubing Hanger 2.992” 2 5,427’ 3.5” Gauge Mandrel (Discharge Gauge) 2.992” 3 5,433’ 3.5” Sliding Sleeve, 2.813” X (Set jet pump 13B 5-15-21)2.992” 4 5,439’ 3.5” Ported Gauge Sub w/ ¼” Wire (Intake Gauge) 2.992” 5 5,488’ 3-1/2” x 7” Premier Retrievable Packer (cut to release) 2.992” 6 5,544’ 3.5” XN Nipple (2.813” Packing Bore) –Min ID 2.750” 7 6,794’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.170” 8 6,803’ 7” Tieback Assy. (8.25” OD No-Go) 6.151” 9 6,811’ 7” Hydril 563 L-80 x 6-5/8” Hydril 563 L-80 XO 5.924” 10 7,080’ Poorboy non-sealing overshot (bottom at 7,087’) 3.940“ 11 13,146’ 4” HWDP 2.563” 12 13,610’ Cleanout BHA, bottom of bit at 13,651’ 1.500” 13 14,940’ 6-5/8” Floatshoe Bullnose - Well Name Rig API Number Well Permit Number Start Date End Date MP M-26 CTU #6 50-029-23656-00-00 219-157 5/11/2021 5/16/2021 OPEN PERMIT W/PAD-OP, LRS PT PCE 250L/3000H. LRS PUMP 30bbls DIESEL DOWN TBG (well injecting). RUN 3-1/2 BRUSH AND SWARF MAGNET TO 5450' SLM (recovered ~1 cup swarf with minimal perf gun debris chunks). STANDBY WHILE PAD- OP BRING ON WELL (well starting to flow). RDMO, CLOSE PERMIT W/PAD-OP*. 5/14/2021 - Friday OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. SHIFT XD-SS OPEN WITH 3-1/2 42BO (keys down) AT 5418' SLM/5433' MD. ATTEMPT TO SET 3" JET PUMP IN XD-SS AT 5418' SLM/5433' MD (unsuccessful, tools returned full of swarf). MAKE 2 RUNS WITH 3-1/2 BRUSH AND SWARF MAGNET (recovered ~2 cups swarf with perf gun debris). L/D FOR THE NIGHT, NOTIFY PAD- OP. CONTINUE TICKET 05-15-2 5/15/2021 - Saturday OPEN PERMIT W/PAD-OP, PT PCE 250L/2500H. MAKE 2 RUNS WITH 3-1/2 BRUSH AND SWARF MAGNET TO 5450' SLM (recovered ~2 cups swarf with perf gun debris). RUN JUNK CATCHER W/2.75" BELL GUIDE AND SD AT 5472' SLM (returned empty). SET 3" JET PUMP (serial# HC-00022, ratio: 11C, screen, OAL=69") IN XD-SS AT 5419' SLM/5433' MD. RDMO, CLOSE PERMIT W/PAD-OP, TAG WELL. 5/16/2021 - Sunday 5/13/2021 - Thursday SLB Coiled tubing, SLB TCP, Baker rep on location. JSA & PTW. Deploy perforating BHA open hole while pumping across the top of tree to trip tank. Perforate 11,496 - 11,526'. Perforate 11,300 - 11,330'. Perforate 8270 - 8300'. Perforate 7500 - 7530'. POOH with perforating BHA. Laydown guns and verify all shots fired. RDMO. Hilcorp Alaska, LLC Weekly Operations Summary 5/12/2021 - Wednesday Coiled tubing MU 1.75 slim BHA nozzle. RIH and tag top of drill pipe stub at 7092' ctmd. POOH. Laydown BHA. Mu Quadco milling BHA with 2.29" tapered mill. Tag at 7092' ctmd. Mill through obstruction to 7115' ctmd. POOH. Laydown milling BHA,RIH with 2" dummy gun drift. Drift to 12,316' and coiled tubing stopped due to lock up. POOH. Laydown drift BHA. Blow down lines. LDFN. MIRU SLB coiled tubing with 1.75" coil. MU and RIH with 2" dummy gun drift. Pump 1% Slick KCl down backside to kill well. Tag drill pipe stub at 7083' ctmd. Make several attempts to past restriction by pumping down coil and backside, no success. POOH. Laydown dummy perf gun, no obvious marks on bottom. LDFN. 5/11/2021 - Tuesday 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: Tubing Punch 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? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,940'N/A Casing Collapse Conductor N/A Surface 8,090psi Tieback 5,410psi Slotted Liner 3,470psi Drill Pipe Liner 20,141psi 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name:Abhijeet Tambe Operations Manager Contact Email:abhijeet.tambe@hilcorp.com Contact Phone: 777-8485 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 3-1/2" Perforation Depth MD (ft): See Schematic See Schematic 3-1/2" x 7" Retrievable Packer 5,488' MD / 3,341' TVD 6,090psi 5,750psi 7,240psi 14,940'6-5/8"6,889' 9-5/8" 7" 6,960' 6,803' Tubing Size:Perforation Depth TVD (ft): 7" x 9-5/8" SLZXP Liner Top Packer and N/A 6,794' MD / 3,568' TVD and N/A 6,960' 9.3 / L-80 / EUE 8rd 7,087' 3,587' 3,569' N/A MILNE PT UNIT M-26 107'107'107'20" x 34" TVD BurstMD N/A 3,468' 6,803' Length Size 3,468'14,940'3,468' C.O. 477.05 PRESENT WELL CONDITION SUMMARY 1,009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025514 / ADL0355023 219-157 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23656-00-00 MILNE POINT / SCHRADER BLUFF OIL Hilcorp Alaska LLC COMMISSION USE ONLY Authorized Name: Authorized Signature: 6,064' 4" 13,146' 3,472' 19,491psi Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Tubing Grade: 5/3/2021 ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:20 am, Apr 22, 2021 321-205 Chad Helgeson (1517) 2021.04.21 16:16:18 - 08'00' MGR22APR21 DLB 04/22/2021 DSR-4/22/21 10-404X Comm 4/23/21 dts 4/22/2021 RBDMS HEW 4/23/2021 To: Alaska Oil & Gas Conservation Commission From: Abhijeet Tambe Operations Engineer Date: April 21, 2021 Re: MPU M-26 Producer (Sundry 321-115) Operations Update Below is the summary of all previous work that has been completed on MPU M-26 with Doyon 14 and the plan forward to complete the work, as some work has changed since sundry 321-115 was approved. Summary of completed work: The 4-1/2” jet pump completion was pulled in2 pieces and an attempt was made to run the planned 4-1/2” screened liner completion, but did not make it to the desired depth and stalled at ~7,092’ MD. The screens were pulled and laid down. The decision was made to make a cleanout run to clear any obstruction with a mill on 4” DP. During this cleanout, the drill pipe got stuck at 13,640’ MD. After several unsuccessful attempts to free the pipe, a decision was made to leave the fish (6,608’ of 4” drill pipe) in the hole and perforate the fish with coil tubing, after the 3-1/2” completion was run and the rig was moved off the well. (For additional details on the work completed by the rig, see previous submitted weekly well operations summaries) A proposed wellbore schematic is attached for reference. Details from completed Rig Workover: 1. Pulled existing 4-1/2” jet pump completion. 2.Left 6,608’ of fish in the well (6,608’ – 193 jts 4” DP (6,103 ft), 15 jts 4” HWDP (464 ft) and 41 ft fishing BHA) 3. Ran 3-1/2” upper completion a. Ran tubing stub overshot assembly to 7,080’ MD (top of fish) b. Installed 3-1/2” X 7” production packer at 5,488’ MD c. Landed tubing hanger and RILDS d. Nippled up tubing head adapter flange and 3-1/8” tree e. Pressure tested tubing hanger void to 250 psi low and 5,000 psi high f. Pressure tested tree to 250 psi low and 5,000 psi high 4. Reverse circulated 8.4 ppg corrosion inhibited source water down IA taking returns out of tubing and freeze protected the well from ~2,500’ TVD a. Pressure tested tubing to 3,500 psi for 30 mins b. Pressure tested IA to 3,500 psi for 30 mins (Planned Work) 5. Rig up Coiled Tubing Unit. Make up 2” drill pipe punch string and punch 4’ drill pipe left in hole (establish communication through pipe with reservoir.) a. Punch holes in lower, middle, and upper sections of stuck drill pipe that was planned to be screened liner b. Lay down guns & coiled tubing c. Freeze protect well from ~2,500’ TVD d. RDMO 6. RU Slickline a. Open sliding sleeve and install the jet pump b. RDMO Drill Pipe punches: x Plan is to punch holes in the OA1 and OA3 sand undulations through stuck drill pipe to regain communication to the reservoir and return well to production x 2”, 6 SPF, 60 deg phasing, spiral orientation x Total gun footage: estimated 120’ MD x Approximate zones to be punched: o ±7,500’ to ±7,530’ MD (30’) o ±8,270’ to ±8,300’ MD (30’) o ±11,300’ to ±11,330’ MD (30’) o ±13,050’ to ±13,080’ MD (30’) Abhijeet Tambe CC: Well File Operations Engineer Tom Fouts 907-331-9184 _____________________________________________________________________________________ Revised By: IAT 4/20/2021 SCHEMATIC Milne Point Unit Well: MPU M-26 Last Completed: 4/5/2021 PTD: 219-157 + TD =14,940’ (MD)/ TD = 3,468’(TVD) 20” Orig.KB Elev.:51.5’/ GL Elev.:25.3’(Innovation) Surface Casing Reference Doyon 14 KB 59’ 7” 9-5/8” 1 5 PBTD =14,940’ (MD) / TD = 3,468’(TVD) 9-5/8”‘ES’ Cementer @ 2,523’ 109 9 13 4 2 7 & 8 11 6 See Slotted/ Solid Liner Detail 3 12 Min ID 2.750” 6-5/8” CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"x34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.835” Surface 6,960’ 0.0758 7” Tieback 26/ L-80 / TXP 6.276” Surface 6,803’ 0.0383 6-5/8” Liner 20 / L-80 / Hydril 563 6.049” 6,794’ 14,940’ 0.0355 4” Drill Pipe Liner 14 / S-135 / XT39 2.687” 7,082’ 13,146’ 0.0102 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 7,087’ 0.0087 OPEN HOLE / CEMENT DETAIL 42” 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4” 1st stage L – 585 sx/ T – 400 sx 12-1/4” 2nd stage L – 515 sx / T – 270 sx 8-1/2” Cementless Slotted Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 226’ Max Hole Angle = 97 TREE & WELLHEAD Tree Cameron 3 1/8" 5M Wellhead FMC 11" 5M TC-1A w/11" x 3 1/2" TC-II Top and Bottom Tubing Hanger with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. GENERAL WELL INFO API: 50-029-23656-00-00 Surface Drilled by Doyon 14 Production Drilled by Innovation Complete – 1/7/2020 Jet Pump Completion Doyon 14 - 4/5/2021 6-5/8” SLOTTED & SCREENED LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 21 6,982’ 3,589’ 7,817’ 3,603’ 19 8,216’ 3,566’ 8,976’ 3,546’ 94 9,096’ 3,543’ 12,863’ 3,471’ 48 12,982’ 3,468’ 14,898’ 3,467’ 4 rows, 8 slots/row, 2”x0.125” slots on 6” centers JEWELRY DETAIL No. Top MD Item ID 1 29’ Tubing Hanger 2.992” 2 5,427’ 3.5” Gauge Mandrel (Discharge Gauge) 2.992” 3 5,433’ 3.5” Sliding Sleeve, 2.813” X 2.992” 4 5,439’ 3.5” Ported Gauge Sub w/ ¼” Wire (Intake Gauge) 2.992” 5 5,488’ 3-1/2” x 7” Premier Retrievable Packer (cut to release) 2.992” 6 5,544’ 3.5” XN Nipple (2.813” Packing Bore) –Min ID 2.750” 7 6,794’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.170” 8 6,803’ 7” Tieback Assy. (8.25” OD No-Go) 6.151” 9 6,811’ 7” Hydril 563 L-80 x 6-5/8” Hydril 563 L-80 XO 5.924” 10 7,080’ Poorboy non-sealing overshot (bottom at 7,087’) 3.940“ 11 13,146’ 4” HWDP 2.563” 12 13,610’ Cleanout BHA, bottom of bit at 13,651’ 1.500” 13 14,940’ 6-5/8” Floatshoe Bullnose - _____________________________________________________________________________________ Revised By: TDF 4/21/2021 PROPOSED Milne Point Unit Well: MPU M-26 Last Completed: 4/5/2021 PTD: 219-157 + TD =14,940’ (MD)/ TD = 3,468’(TVD) 20” Orig.KB Elev.:51.5’/ GL Elev.:25.3’(Innovation) Surface Casing Reference Doyon 14 KB 59’ 7” 9-5/8” 1 5 PBTD =14,940’ (MD) / TD = 3,468’(TVD) 9-5/8”‘ES’ Cementer @ 2,523’ 109 9 13 4 Min ID 2.750” 2 7 & 8 11 6 See Slotted/ Solid Liner Detail 3 12 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"x34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.835” Surface 6,960’ 0.0758 7” Tieback 26/ L-80 / TXP 6.276” Surface 6,803’ 0.0383 6-5/8” Liner 20 / L-80 / Hydril 563 6.049” 6,794’ 14,940’ 0.0355 4” Drill Pipe Liner 14 / S-135 / XT39 2.687” 7,082’ 13,146’ 0.0102 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 7,087’ 0.0087 OPEN HOLE / CEMENT DETAIL 42” 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4” 1st stage L – 585 sx/ T – 400 sx 12-1/4” 2nd stage L – 515 sx / T – 270 sx 8-1/2” Cementless Slotted Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 226’ Max Hole Angle = 97 TREE & WELLHEAD Tree Cameron 3 1/8" 5M Wellhead FMC 11" 5M TC-1A w/11" x 3 1/2" TC-II Top and Bottom Tubing Hanger with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. JEWELRY DETAIL No. Top MD Item ID 1 29’ Tubing Hanger 2.992” 2 5,427’ 3.5” Gauge Mandrel (Discharge Gauge) 2.992” 3 5,433’ 3.5” Sliding Sleeve, 2.813” X 2.992” 4 5,439’ 3.5” Ported Gauge Sub w/ ¼” Wire (Intake Gauge) 2.992” 5 5,488’ 3-1/2” x 7” Premier Retrievable Packer (cut to release) 2.992” 6 5,544’ 3.5” XN Nipple (2.813” Packing Bore) –Min ID 2.750” 7 6,794’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.170” 8 6,803’ 7” Tieback Assy. (8.25” OD No-Go) 6.151” 9 6,811’ 7” Hydril 563 L-80 x 6-5/8” Hydril 563 L-80 XO 5.924” 10 7,080’ Poorboy non-sealing overshot (bottom at 7,087’) 3.940“ 11 13,146’ 4” HWDP 2.563” 12 13,610’ Cleanout BHA, bottom of bit at 13,651’ 1.500” 13 14,940’ 6-5/8” Floatshoe Bullnose - GENERAL WELL INFO API: 50-029-23656-00-00 Surface Drilled by Doyon 14 Production Drilled by Innovation Complete – 1/7/2020 Jet Pump Completion Doyon 14 - 4/5/2021 6-5/8” SLOTTED & SCREENED LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 21 6,982’ 3,589’ 7,817’ 3,603’ 19 8,216’ 3,566’ 8,976’ 3,546’ 94 9,096’ 3,543’ 12,863’ 3,471’ 48 12,982’ 3,468’ 14,898’ 3,467’ 4 rows, 8 slots/row, 2”x0.125” slots on 6” centers DRILL PIPE PUNCH DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status OA3 ±7,500’ ±7,530’ ±3,612’ ±3,612’ 30 Future Pending ±8,270’ ±8,300’ ±3,560’ ±3,558’ 30 Future Pending ±11,300’ ±11,330’ ±3,502’ ±3,502’ 30 Future Pending OA1 ±13,050’ ±13,080’ ±3,471’ ±3,472’ 30 Future Pending Gun Data:2”, 6 SPF, 60 deg phasing, spiral orientation 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: Install Screens______ 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,940'N/A Casing Collapse Conductor N/A Surface 8,090psi Tieback 5,410psi Slotted Liner 3,470psi 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name:Ian Toomey Operations Manager Contact Email:itoomey@hilcorp.com Contact Phone: 777-8520 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025514 / ADL0355023 219-157 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23656-00-00 MILNE POINT / SCHRADER BLUFF OIL Hilcorp Alaska LLC Length Size 3,468' 14,940' 3,468' C.O. 477.05 PRESENT WELL CONDITION SUMMARY 1,009 N/A MILNE PT UNIT M-26 107'107' 12.6 / L-80 / TXP TVD Burst 6,818' MD N/A 6,090psi 5,750psi 7,240psi 3,587' 3,569' 3,468' 6,960' 6,803' 107'20" x 34" 9-5/8" 7" 6,960' 6,803' Authorized Signature: 3/20/2021 4-1/2" Perforation Depth MD (ft): See Schematic See Schematic Tubing Size:Perforation Depth TVD (ft): 7" x 4-1/2" HAL AHR Retrievable Packer and N/A 4,987 MD / 3,1454 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 14,940'6-5/8"6,889' Tubing Grade: ___ ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:54 am, Mar 08, 2021 321-115 Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517), ou=Users Date: 2021.03.08 10:40:52 -06'00' Chad Helgeson (1517) MGR9MAR21 10-404 BOPE test to 2500 psi. SFD 3/8/2021 SFD 3/8/2021 DSR-3/8/21Comm q Yes 3/10/21 dts 3/9/2021 JLC 3/9/2021 RBDMS HEW 3/11/2021 Install 4-1/2” Screens Well: MPU M-26 Date: 3/3/2021 Well Name:MPU M-26 API Number:50-029-23656-00-00 Current Status:OLOil Well Pad:M-Pad Estimated Start Date:March 20 th , 2021 Rig:Doyon 14 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:219-157 First Call Engineer:Ian Toomey (907) 777-8434 (O) (907) 903-3987 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE Number:TBD Job Type:Install 4-1/2” Screens Current Gauge BHP:1,284 psi @ 3,126’ TVD |EMW = 7.9 ppg Maximum Expected BHP:1,321 psi @ 3,126’ TVD 30 day PBU Extrapolation| EMW= 8.2 ppg MPSP:1,009 psi Gas Column Gradient = 0.1 psi/ft Max Inclination relevant to RWO 70+° from 5,584’ MD to PBTD Max Dogleg:8.7°/100ft at 5,939’ MD Tree:Cameron 4-1/16” 5M Wellhead:FMC Gen 5, 11” 5M Tubing Hanger Lift threads:4-1/2” H563 top & bottom BPV Profile:4” CIW Type H Brief Well Summary: Well M-26 was drilled and completed in January 2020 as a 4-1/2” JP Schrader Bluff producer. The well was completed with 6-5/8” slotted liner and is known to produce some solids. Notes Regarding the Well & Design x 7” Casing MIT to 3,500 psi passed on 1/08/2020 with brine & diesel to 4,987’ MD. x Offset Injector Support o M-25: OL as of 3/03/21. Objective: x Pull 4-1/2” JP completion x Install 4-1/2” screened liner. x Run 3-1/2” JP completion Pre-Rig Procedure: 1. RD well house and flowlines. Clear and level area around the well. 2. Set 4” BPV. Install 4-1/2” Screens Well: MPU M-26 Date: 3/3/2021 RWO Procedure: 3. MIRU Doyon 14, ancillary equipment and lines to returns tank. 4. Pull the BPV. Bleed gas to 0 psi on the tubing and IA (if needed). 5. Reverse circulate a minimum of 170 bbls of seawater down the IA up the tubing to the kill tank until clean seawater is seen at surface. Then bullhead 29 bbls of seawater down the tubing. 6. Monitor to confirm the well is dead for 30 minutes. If not, contact Operations Engineer and record SITP/SICP. 7. Set 4” HP BPV. 8. ND Tree. Inspect the lift threads on the tubing hanger. Install the plug off tool into the BPV. 9. NU 13-5/8” BOP stack with 2-7/8” x 5” VBR’s in the upper and lower ram cavities. 10. Test BOPE to 250/2,500 psi and annular to 250/2,500 psi. a. Notify the AOGCC 24 hours in advance of BOP test. b. Confirm test pressures per the Sundry Conditions of approval. c. Test VBR’s and annular with 3-1/2” & 4-1/2” test joints. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test if test witness was waived. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 11. RU to pull 4-1/2” JP completion. 12. Pull plug off tool, check for pressure under the BPV, if needed kill the well with KWF and pull the BPV. 13. MU the landing joint to the tubing hanger, BOLDS and unseat the tubing hanger. a. String PU = 91K and SO = 61K when landed by Doyon 14 (block weight = 40K) in 9.2 ppg brine. 14. Pull the hanger to the rig floor. Lay down the landing joint and tubing hanger. RU to pull TEC wire over sheaves to spooling unit. a. Inspect the tubing hanger and note any corrosion or damage. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 15. POOH laying down the 4-1/2” tubing spooling TEC wire and removing all jewelry as it presents itself. Lay down packer assembly. Install 4-1/2” Screens Well: MPU M-26 Date: 3/3/2021 a. Note any corrosion, sand, scale, damage or over torqued connections on the tubing with associated depths on the morning report. Equipment Disposition Tubing hanger Visually inspect on site then restock Tubing & Pup joints Visually inspect on site then restock Sliding Sleeve/Gauge Sub/Nipple Visually inspect on site then restock Packer Send to Halliburton for redress Cannon clamps (125)Visually inspect on site then restock 16. Install the wear ring. 17. Ensure the 4” safety joint is made up with the appropriate crossover(s) prior to running the screens and inner string. 18. PU, MU and RIH with the following 4-1/2” screen liner to ±14,937’: a. Float Shoe, 4-1/2”, 12.6#, L-80, BTC b. WIV, 4-1/2”, 12.6#, L-80, BTC c. Solid Liner Joint, 4-1/2”, 12.6#, L-80, BTC d. Drillable Pack-off, 4-1/2”, 12.6#, L-80, BTC e. Crossover, 4-1/2” H625 Box x BTC Pin f. 100ђ Screen Joints, 4-1/2”, 13.5#, L-80 H625; (±14,899’ – ±6,981) g. Solid Liner Joints, 4-1/2”, 12.6#, L-80, BTC 19. RU false rotary table. RIH with slick stick on 2-3/8”, 4.7#, PH-6 inner string 20. PU and MU the following packer assembly: a. Crossover, 4-1/2” TCII Box x H625 Pin b. Premier Packer, 4-1/2” TCII Box x Pin c. Crossover, 5” H521 x 4-1/2” TCII Pin d. Liner Setting Sleeve e. HRDE Liner Running Tool. 21. RIH with 4-1/2” screen liner on 4” DP to packer setting depth at ±6,767’. Note: If fill is encountered attempt to wash down. If unable to wash down, POOH and a cleanout run will be made. 22. Drop the setting ball and slowly pump (1-2 BPM) the ball to the seat (do not slam the ball into the seat). 23. Continue to pressure up to 3,000 psi to set the Premier Packer and hold for 15 minutes. 24. RU and PT the IA to 3,500 psi for 30 minutes (charted). RD testing equipment. 25. Release the HRDE liner running tool. 26. POOH laying down 4” DP, liner running tool and 2-3/8” inner string. 27. Pull the wear ring. 28. RU to run 3-1/2” JP completion. 29. PU, MU and RIH with the following JP completion: a. Tie Back Seal Assembly, 5” TXP Box up. Safety joint to have crossover to 4-1/2" screen liner. Safety joint to have appropriate crossovers to inner string and screens (if not dropping inner string). Install 4-1/2” Screens Well: MPU M-26 Date: 3/3/2021 b. Crossover, 3-1/2” EUE 8rd Box x 5” TXP Pin c. 1 Tubing Joint, 3-1/2”, 9.3#, L-80 EUE 8rd d. Pup Joint, 3-1/2”, 9.3#, L-80 EUE 8rd e. Nipple, 2.813” XN with 2.75” no-go f. Pup Joint, 3-1/2”, 9.3#, L-80 EUE 8rd g. Pup Joint, 3-1/2”, 9.3#, L-80 EUE 8rd h. Ported Gauge Sub, 3-1/2”, 9.3#, L-80 EUE 8rd i. Pup Joint, 3-1/2”, 9.3#, L-80 EUE 8rd j. Sliding Sleeve, 2.813” X, 3-1/2”, 9.3#, L-80 EUE 8rd k. Pup Joint, 3-1/2”, 9.3#, L-80 EUE 8rd l. Gauge Carrier, 3-1/2”, 9.3#, L-80 EUE 8rd m. Pup Joint, 3-1/2”, 9.3#, L-80 EUE 8rd n. XX Tubing Joints, 3-1/2”, 9.3#, L-80 EUE 8rd 30. Engage the seal assembly into the tie back sleeve and no-go out. 31. PU and space out with pups leaving one full joint below the tubing hanger. Space out should leave the bottom of the locator 1’-2’ off of no-go when the tubing hanger is landed. 32. PU and MU the 3-1/2” tubing hanger. Make final splice of the TEC wire to the tubing hanger and dummy off any additional control line ports if present. 33. Reverse circulate 66 bbls of diesel freeze protect. 34. Land tubing hanger and RILDS. Record PU and SO weights on tally and WellEZ. 35. PT the IA to 3,500 psi for 30 minutes (charted) 36. Set 3” HP BPV. 37. ND the BOP stack. Install the plug off tool. 38. NU the tubing head adapter and 3-1/8”, 5M tree. 39. PT tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. 40. Pull plug off tool and BPV. 41. Replace gauge(s) if removed. Secure the tree and cellar. 42. RDMO Post-Rig Procedure: 43. Turn well over to production via handover form. 44. RU well house and flowlines. 45. RU HES slickline. 46. Open the sliding sleeve and install the JP. 47. RD HES slickline. Attachments: 1. Current schematic 2. Proposed schematic 3. BOP Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By: TDF 2/19/2021 SCHEMATIC Milne Point Unit Well: MPU M-26 Last Completed: 1/7/2020 PTD: 219-157 + TD =14,940’ (MD) / TD = 3,468’(TVD) 20” Orig. KB Elev.: 51.5’/ GL Elev.: 25.3’(Innovation) Surface Casing Reference Doyon 14 KB 59’ 7” 9-5/8” 1 4 PBTD =14,940’ (MD) / TD = 3,468’(TVD) 9-5/8” ‘ES’ Cementer @ 2,523’ 6-5/8” Shoe @ 14,940’ 7 10 8 9 12 4-1/2” 3 Min ID 3.725” 8-1/2” Hole 2 6 11 5 See Slotted/ Solid Liner Detail CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"x34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.679” Surface 6,960’ 0.0758 7” Tieback 26/ L-80 / TXP 6.151” Surface 6,803’ 0.0383 6-5/8” Liner 20 / L-80 / Hydril 563 5.924” 6,794’ 14,940’ 0.0355 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958” Surface 6,818’ 0.0087 OPEN HOLE / CEMENT DETAIL 42” 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4” 1st stage L – 585 sx/ T – 400 sx 12-1/4” 2nd stage L – 515 sx / T – 270 sx 8-1/2” Cementless Slotted Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 226’ Max Hole Angle = 63 @ Jet Pump Max Hole Angle = 63 @ XN profile Max Hole Angle = 82 @ Tubing tail Max Hole Angle = 97 TREE & WELLHEAD Tree Cameron 3 1/8" 5M Wellhead FMC 11" 5M TC-1A w/11" x 3 1/2" TC-II Top and Bottom Tubing Hanger with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. JEWELRY DETAIL No. Top MD Item Drift ID Upper Completion 1 22’ Tubing Hanger (4-1/2” TC-II Top & Btm) 3.970” 2 4,925’ 4.5” SLB Discharge Pressure Gauge Mandrel (Discharge Gauge) 3.874” 3 4,936’ 4.5” HAL XD Sliding Sleeve 11C JP (11-20-20)3.813” 4 4,945’ 4.5” SLB Gauge Mandrel w/ ¼” Wire (Intake Gauge) 3.889” 5 4,966’ 4.5” X Nipple (3.813” Packing Bore) 3.813” 6 4,987’ 7” x 4.5” HAL PHL Retrievable Packer – Cut to release 3.890” 7 4,999’ 4.5” XN Nipple (MIN ID = 3.725”)3.813” 8 6,818’ 4.5” WLEG 3.958” Lower Completion 9 6,794’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.170” 10 6,803’ 7” Tieback Assy. (8.25” OD No-Go) 6.151” 11 6,811’ 7” Hydril 563 L-80 x 6-5/8” Hydril 563 L-80 XO 5.924” 12 14,940’ 4-1/2” Floatshoe Bullnose - GENERAL WELL INFO API: 50-029-23656-00-00 Surface Drilled by Doyon 14 Production Drilled by Innovation Complete – 1/7/2020 6-5/8” Slotted LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 21 6,982’ 3,589’ 7,817’ 3,603’ 19 8,216’ 3,566’ 8,976’ 3,546’ 94 9,096’ 3,543’ 12,863’ 3,471’ 48 12,982’ 3,468’ 14,898’ 3,467’ 4 rows, 8 slots/row, 2”x0.125” slots on 6” centers _____________________________________________________________________________________ Revised By: TDF 3/4/2021 PROPOSED Milne Point Unit Well: MPU M-26 Last Completed: 1/7/2020 PTD: 219-157 + TD =14,940’ (MD) / TD = 3,468’(TVD) 20” Orig. KB Elev.: 51.5’/ GL Elev.: 25.3’(Innovation) Surface Casing Reference Doyon 14 KB 59’ 7” 9-5/8” 1 5 PBTD =14,940’ (MD) / TD = 3,468’(TVD) 9-5/8” ‘ES’ Cementer @ 2,523’ 6-5/8” Shoe @ 14,940’ 8 10 9 9 15 4-1/2” 4 Min ID 3.725” 8-1/2” Hole 2 7 11 6 See Slotted/ Solid Liner Detail 3 12, 13 & 14 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"x34” Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / TXP 8.835” Surface 6,960’ 0.0758 7” Tieback 26/ L-80 / TXP 6.276” Surface 6,803’ 0.0383 6-5/8” Liner 20 / L-80 / Hydril 563 6.049” 6,794’ 14,940’ 0.0355 4-1/2” Screens 13.5 / L-80 / H625 3.920” ±6,767’ ±14,937’ 0.0149 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface ±6,754’ 0.0087 OPEN HOLE / CEMENT DETAIL 42” 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4” 1st stage L – 585 sx/ T – 400 sx 12-1/4” 2nd stage L – 515 sx / T – 270 sx 8-1/2” Cementless Slotted Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 226’ Max Hole Angle = 63 @ Jet Pump Max Hole Angle = 63 @ XN profile Max Hole Angle = 82 @ Tubing tail Max Hole Angle = 97 TREE & WELLHEAD Tree Cameron 3 1/8" 5M Wellhead FMC 11" 5M TC-1A w/11" x 3 1/2" TC-II Top and Bottom Tubing Hanger with 3" CIW "H" BPV profile. 2ea 3/8" NPT control lines. JEWELRY DETAIL No. Top MD Item Drift ID Upper Completion 1 22’ Tubing Hanger 2.992” 2 ±5,511’ 3.5” Gauge Mandrel (Discharge Gauge) 2.992” 3 ±5,515’ 3.5” Sliding Sleeve, 2.813” X 2.992” 4 ±5,522’ 3.5” Ported Gauge Sub w/ ¼” Wire (Intake Gauge) 2.992” 5 ±5,554’ 3.5” XN Nipple (2.813” Packing Bore) 2.992” 6 ±6,754 Tie Back Seal Assembly 5.250” Lower Completion 7 ±6,756 Tie Back Sleeve 5.750” 8 ±6,767 4-1/2” x 7” Retrievable Packer 3.860” 9 6,794’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.170” 10 6,803’ 7” Tieback Assy. (8.25” OD No-Go) 6.151” 11 6,811’ 7” Hydril 563 L-80 x 6-5/8” Hydril 563 L-80 XO 5.924” 12 ±14,900 Drillable Pack-off 2.400“ 13 ±14,932 WIV 1.000“ 14 ±14,937 Float Shoe - 15 14,940’ 4-1/2” Floatshoe Bullnose - GENERAL WELL INFO API: 50-029-23656-00-00 Surface Drilled by Doyon 14 Production Drilled by Innovation Complete – 1/7/2020 6-5/8” SLOTTED & SCREENED LINER DETAIL Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 21 6,982’ 3,589’ 7,817’ 3,603’ 19 8,216’ 3,566’ 8,976’ 3,546’ 94 9,096’ 3,543’ 12,863’ 3,471’ 48 12,982’ 3,468’ 14,898’ 3,467’ 4 rows, 8 slots/row, 2”x0.125” slots on 6” centers ] Milne Point Doyon 14 13-5/8” BOP Stack Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: March 3rd, 2021 Subject: Changes to Approved Sundry Procedure for Well MP M-26 Sundry #: XXX-XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: DATE 8/27/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU M-26 (219-157) Halliburton Geosteering 2 JAN 2020 MPU M-26 PTD: 2191570 E-Set: 33713 Received by the AOGCC 08/31/2020 Abby Bell 08/31/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23656-00-00Well Name/No. MILNE PT UNIT M-26Completion Status1-OILCompletion Date1/7/2020Permit to Drill2191570Operator Hilcorp Alaska LLCMD14940TVD3468Current Status1-OIL4/1/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP/ABG/DGR/EWR/ADR 2"/5" MD…ABG/DGR/EWR/ADR 2"/5" TVD PB1NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC3/25/2020105 14940 Electronic Data Set, Filename: MPU M-26 LWD Final.las32303EDDigital DataC3/25/20206940 14902 Electronic Data Set, Filename: MPU M-26 ADR Quadrants All Curves.las32303EDDigital DataC3/25/2020 Electronic File: MPU M-26 LWD Final MD.cgm32303EDDigital DataC3/25/2020 Electronic File: MPU M-26 LWD Final TVD.cgm32303EDDigital DataC3/25/2020 Electronic File: MPU M-26_Definitive Survey Report.pdf32303EDDigital DataC3/25/2020 Electronic File: MPU M-26_Definitive Survey Report.txt32303EDDigital DataC3/25/2020 Electronic File: MPU M-26_GIS.txt32303EDDigital DataC3/25/2020 Electronic File: MPU M-26_Plan.pdf32303EDDigital DataC3/25/2020 Electronic File: MPU M-26_Surveys.xlsx32303EDDigital DataC3/25/2020 Electronic File: MPU M-26_VSec.pdf32303EDDigital DataC3/25/2020 Electronic File: MPU M-26 LWD Final MD.emf32303EDDigital DataC3/25/2020 Electronic File: MPU M-26 LWD Final TVD.emf32303EDDigital DataC3/25/2020 Electronic File: MPU_M-26_Geosteering.dlis32303EDDigital DataC3/25/2020 Electronic File: MPU_M-26_Geosteering.ver32303EDDigital DataC3/25/2020 Electronic File: MPU M-26 LWD Final MD.pdf32303EDDigital DataC3/25/2020 Electronic File: MPU M-26 LWD Final TVD.pdf32303EDDigital DataC3/25/2020 Electronic File: MPU M-26 LWD Final MD.tif32303EDDigital DataC3/25/2020 Electronic File: MPU M-26 LWD Final TVD.tif32303EDDigital DataWednesday, April 1, 2020AOGCCPage 1 of 3PB1~MPU M-26 LWDFinal.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23656-00-00Well Name/No. MILNE PT UNIT M-26Completion Status1-OILCompletion Date1/7/2020Permit to Drill2191570Operator Hilcorp Alaska LLCMD14940TVD3468Current Status1-OIL4/1/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameInterval0 0 2191570 MILNE PT UNIT M-26 LOG HEADERS32303LogLog Header ScansC3/25/2020105 13622 Electronic Data Set, Filename: MPU M-26PB1 LWD Final.las32304EDDigital DataC3/25/20206940 13585 Electronic Data Set, Filename: MPU M-26PB1 ADR Quadrants All Curves.las32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1 LWD Final MD.cgm32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1 LWD Final TVD.cgm32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1_Definitive Survey Report.pdf32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1_Definitive Survey Report.txt32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1_GIS.txt32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1_Plan.pdf32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1_Surveys.xlsx32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1_VSec.pdf32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1 LWD Final MD.emf32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1 LWD Final TVD.emf32304EDDigital DataC3/25/2020 Electronic File: MPU_M-26PB1_Geosteering.dlis32304EDDigital DataC3/25/2020 Electronic File: MPU_M-26PB1_Geosteering.ver32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1 LWD Final MD.pdf32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1 LWD Final TVD.pdf32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1 LWD Final MD.tif32304EDDigital DataC3/25/2020 Electronic File: MPU M-26PB1 LWD Final TVD.tif32304EDDigital Data0 0 2191570 MILNE PT UNIT M-26 PB1 LOG HEADERS32304LogLog Header ScansWednesday, April 1, 2020AOGCCPage 2 of 3MPU M-26PB1 LWD Final.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23656-00-00Well Name/No. MILNE PT UNIT M-26Completion Status1-OILCompletion Date1/7/2020Permit to Drill2191570Operator Hilcorp Alaska LLCMD14940TVD3468Current Status1-OIL4/1/2020UICNoINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:1/7/2020Release Date:11/15/2019Wednesday, April 1, 2020AOGCCPage 3 of 3M. Guhl4/1/2020 DATE 03/23/2020 Dt-ara Oudean Hilcorp Alaska, LUZ GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU M-26 (219-157 MPU M-26 PB1 Halliburton LWD FINAL 11 JAN 2020 MPU M-26 & MPU M-26 PB1 CGM Definitive Survey EMF LAS PDF TIFF information if different from above. 1/11/2020 2:11 PM 1/1112020 2:11 PM 1/11/20202:11 PM 1/11/2020 2:11 PM 1 /11/21320 2:11 PM 1/11/220 2:11 PM 2191 57 Pf 15MO/� RECEIVED MAR 2 5 Z020 AOGCC Fife fclder File fclder File fclder File fclder File fclder File fclder Please include current contact Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: 11 ll lrorp Aluoku_ MA, DATE 03/23/2020 219157 Deura Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU M-26 (219-157 MPU M-26 PB3 Halliburton LWD FINAL 11 JAN 2020 MPU M-26 & MPU M-26 P1131 CGM Definitive Survey EMF LAS PDF TIFF information if different from above. 1/11,12020 2:11 PI'v1 File fclder 1.1111 2"1202:11 PM File folder 1 '11;` 202c, 2:11 Phv1 File folder 1;'11x20202:11 Ptvl Filefclder 1/11/20? STATE OF ALASKA JAN 2 8 2020 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT � 1a. Well Status: Oil ❑� , Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25,110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1 1 b. Well Class: Development ❑✓ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or Aband.: 1/7/2020 14. Permit to Drill Number/ Sundry: 219-157 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: November 24, 2019 15. API Number: 50-029-23656-00-00 4a. Location of Well (Governmental Section): Surface: 5039' FSL, 741' FEL, Sec 14, T13N, R9E, UM, AK Top of Productive Interval: 1890' FNL, 668' FWL, Sec 14, T11 3N, R9E, UM, AK Total Depth: 721' FSL, 597' FWL, Sec 23, T13N, R9E, UM, AK 8. Date TD Reached: December 31, 2019 16. Well Name and Number: MPU M-26 9. Ref Elevations: KB: 51.5' • GL: 25.3' • BF:25.3' (frig) 17. Field / Pool(s): Milne Point Field Schrader Bluff Oil Pool 10. Plug Back Depth MD/TVD: 14,940' MD / 3,468' TVD 18. Property Designation: ADL025514, ADL355023 • 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 533423 y- 6027889 Zone- 4 TPI: x- 529561 y- 6026222 + Zone- 4 Total Depth: x- 529533 y- 6018275 Zone- 4 11. Total Depth MD/TVD: 14,940' MD / 3,468' TVD 19. DNR Approval Number: LONS 16-004 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 2,280' MD / 1,826' TVD " 5. Directional or Inclination Survey: Yes : (attached) No ❑ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ROP/ABG/DGR/EWR/ADR 2"/5" MD ABG/DGR/EWR/ADR 2"/5" TVD PB1 23. CASING, LINER AND CEMENTING RECORD WGRADE T. PER CASING FT SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE AMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 216# X-52 Surface 107' Surface 107' 42" ±270 ft3 9-5/8" 40# L-80 Surface 6,960' Surface 3,587' 12-1/4" Stg 1 L - 585 sx / T - 400 sx Stg 2 L - 515 sx / T - 270 sx 220 bbls 7" 26# L-80 Surface 6,803' Surface 3,569' Tieback Tieback Assy. 6-5/8" 20# L-80 1 6,794' 14,940' 3,568' 3,468' 8-1/2" Cementless Slotted Liner 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): "Please see attached schematic for slotted liner detail"' Liner run on 1/3/20 ::OMPLtT10N DATE Zpyo �r�(I��IED 25. TUBING RECORD SIZE DEPTH SET (MD) IPACKER SET (MD/TVD) 4-1/2" 6,818' 4,987' MD / 3,145' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: 1/17/2020 Method of Operation (Flowing, gas lift, etc.): Jet Pump Date of Test: 1/26/2020 Hours Tested: 24 Production for Test Period Oil -Bbl: 875 Gas -MCF: 311 Water -Bbl: 0 Choke Size: N/A Gas -Oil Ratio: 355 Flow Tubing Press. 280 Casing Press: 880 Calculated 24 -Hour Rate Oil -Bbl: 875 Gas -MCF: 311 Water -Bbl: 0 Oil Gravity - API (corr): 16 Form 10-407 Revised 5/2017 Qf��j CONTINUED ON P GE 2.BpMS3�= JAN 3 <1 ZpLUubmit ORIGINIAL only Q Vr'e �ab� 02—/U '�G 4ye 28. CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q - If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base 2,280' 1,826' Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6,982' SB OA 3,589' information, including reports, per 20 AAC 25.071. SV5 1,387' 1,308' SV1 2,344' 1,857' Ugnu LA3 4,582' 2,963' SB OA 6,880' ' 3,579' Formation at total depth: SB OA 31. List of Attachments: Wellbore Schematic, Drilling and Completion Reports, Defintive Directional Surveys, Csg and Cmt Report, OH Sidetrack Summary. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdinger hilcorp.com Authorized Contact Phone: 777-8389 1Z91U40 Signature: ate: 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Hilcurp Alaska, LLC Orig. KB Elev.: 51.5/ GL Elev.: 25.3' (Innovation) Surface Casing Reference D on 14 KB 59' 1 I 1 s 20" 9-58"ES Cementer @ 2,523 4-1/2" 7" Mn ID 2.75W 3 SCHEMATIC TREE & WELLHEAD Milne Point Unit Well: MPU M-26 Last Completed: 1/7/2020 PTD: 219-157 TreeCameron 3 1/8" SM Wellhead FMC 11" SM TC -1A w/11" x 3 1/2" TC -II Top and Bottom Tubing 12-1/4" 2nd stage Hanger with 3" CIW "H" BPV profile. Zea 3/8" NPT control lines. OPEN HOLE/ CEMENT DETAIL 42" 50 bbls (10 Yards Pilecrete dumped down backside) 12-1/4" 1st stage L — 585 sx/ T — 400 sx 12-1/4" 2nd stage L — 515 sx / T — 270 sx 8-1/2" Cementless Slotted Liner in 8-1/2" hole CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20"x34" Conductor (Insulated) 215.5 / X-52 / Weld N/A Surface 107' N/A 9-5/8" Surface 40 / L-80 / TXP 8.679" Surface 6,960' 0.0758 7" Tieback 26/ L-80 / TXP 6.151" Surface 6,803' 0.0383 6-5/8" Slotted Liner 20 / L-80 / Hydril 563 5.924" 6,794' 14,940' 0.0355 3.813" 9 6,818' 4.5" WLEG 3.958" I TUBING DETAIL 4 „ 4-1/2" Tubing 12.6 / L-80 / TXP 3.958" Surface 6,818' 0.0087 6 WELL INCLINATION DETAIL KOP @ 226' Max Hole Angle = 63 @ Jet Pump 6 Max Hole Angle = 63 @ XN profile 9 Max Hole Angle = 82 @Tubing tail 7 Max Hole Angle = 97 JEWELRY DETAIL M-® 10 11 »" Lk 12 15/8" IIIIII See IIIIII No. Top MD—T—Item Top (TVD) Drift ID Btm (TVD) 4 Upper Completion 3,572' 1 22' Tubing Hanger (4-1/2" TC -II Top & Btm) 3.970" 3 4,925' 4.5" SLB Discharge Pressure Gauge Mandrel (Discharge Gauge) 3.874" 4 4,936' 4.5" HAL XD Sliding Sleeve HC 0001612C JP Set 01/08/20) 3.813" 5 4,945' 4.5" SLB Gauge Mandrel w/ X" Wire (Intake Gauge) 3.889" 6 4,966' 4.5" X Nipple (3.813" Packing Bore) 3.813" 7 4,987' 7" x 4.5" HAL PHL Retrievable Packer — Cut to release 3.890" 8 4,499' 4.5" XN Nipple (MIN ID = 3.725") 3.813" 9 6,818' 4.5" WLEG 3.958" Lower Completion 10 6,794' BOT SLZXP Liner Top Packer w/BD Slips 7" x 9-5/8" 6.170" . 11 6,803' 7" Tieback Assy. (8.25" OD No -Go) 6.151" 12 6,811' 7" Hydril 563 L-80 x 6-5/8" Hydril 563 L-80 XO 5.924" 14 14,940' 4-1/2" Floatshoe Bullnose Slotted) IIIIII Solid Liner 6-5/8" SOLID LINER DETAIL 6-5/8" Slotted LINER DETAIL Detail IIIIII , , IIIIII &/8 5 111111 r, shoe @ IIIIII Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD) 4 6,820' 3,572' 6,982' 3,589' 10 7,817' 3,603' 8,216' 3,566' 3 8,976' 3,546' 9,096' 3,543' 3 12,683' 3,471' 12,982' 3,468' 1 14,898' 3,467' 14,940' 3,468' 81/ 14,940' Hole 13 TD =14,940' (MD) / TD= 3,468 (ND) GENERAL WELL I N FO PBTD=14,94Y(MD)/TD=3,468'(TVD) API: 50-029-23656-00-00 Surface Drilled by Doyon 14 Production Drilled by Innovation Complete —1/7/2020 4 rows, 8 slots/row, 2 x0.125 slots on 6 centers Jts (Mp) Top (TVD) Btm (MD) Btm (TVD) 21 ' 6,982' 3,589' 7,817' 3,603' 19 8,216' 3,566' 8,976' 3,546' 94 9,096' 3,543' 12,863' 3,471' 48 r 12,982' 3,468' 14,898' 3,467' Revised By: GD 01/28/2020 MPU M-26 OH Sidetrack Summary PBI TD 13,622' MD / 3,338' TVD KOP 12,375' MD Date 12/30/2019 PTD: 219-157 / API: 50-029-23656-00-00 Hilcorp Energy Company Composite Report Well Name: MP M-26 Field: Milne Point County/State: North Slope Borough, Alaska (LAT/LONG): avation (RKB): API #: Spud Date: Job Name: 1915893D MPU M-26 Drilling Contractor Innovation AFE #: AFE $: Activity Date:: 0Summary 11123/2019 Clean up cellar box and wellhead. Prep rig floor and pipe shed for rig move. "` AOGCC notified of upcoming diverter test 18:32 on 22 Nov 2019 """;Skid rig floor into moving position. Cut & cap mouse hole in Cellar box.;Notify pad operator, PJSM. Move rig off M-15. Place matting boards and move rig to other side of the pad. Move rig onto M-26. Spot, level and shim rig. Perform Post pad inspection on M-15 with Pad operator;Skid rig floor into drilling position.;Work on rig acceptance checklist. R/U all stairs and landings. R/U rig floor steam, water, air and mud lines. Spot all fuel, geo, mud, MWD & 5 -star trailers. Diverter adapter and annular were installed prior to rig move. Install diverter riser. "' Rig accepted at 01:00 "';R/U diverter line. Install surface riser. Wellhead rep. installed grub screws in the diverter adapter. Install turnbuckles & conductor valves. Install 90' mouse hole. Spot rock washer. Begin loading mud into the pits. Load BHA into the pipe shed. Repair derrickman winch. 11/24/2019 C/O Saver sub, inspect backup dies, C/O same, prep and load 8.8 spud mud into pits, spot upright water tanks and cement silos, work on acceptance checklist.;Load 15 HWDP and jars into pipe shed. P/U jt 5" DP, Function knife valve to ensure proper operation. C/O derrick climber cable, perform derrick inspection. Totco perform pre -spud inspection;Continue to C/O derrick climber and finish up derrick inspection. Plumb in upright water tanks, fill with water, load Geo span to rig floor and R/U same. Rig electrician test gas alarms. SirnOps: HES loaded surface cement in silos, PJSM, crane out # 2 centrifuge decanter, Crane in new decanter.;PJSM, Make up and rack back 6 stands of 5" HWDP and Jars. -Perform diverter function test on 5" HWDP. Knife valve open in 14 sec & diverter close in 36 sec. 2950 PSI system pressure, 1825 PSI after closure, 33 sec. 200 PSI recovery in 137 sec. full recovery. 2008 PSI avg - 6 nitrogen bottles. Closest ignition source to end diverter 105'- wellhouse Iight;AOGCC rep Guy Cook waived witness for diverter test on 11/24/2019 11:12 am;M/U 12-1/4" Kymera bit, 8" SperryDrill mud motor w/ 1.5° AKO, XO sub to 33'. M/U stand of 5" HWDP and tag bottom of conductor at 112'.;Pre-spud meeting with all hands. Discuss all hazards and responsibilities. I.D. safe briefing areas. Make notification to G&I of upcoming spud.;All hands in position to drill. Fill trip tank with water. Conduct unannounced rig evacuation / diverter drill. Driller simulated closing diverter / opening knife valve. Made notification to Moose pad operator & Milne security.;All hands at muster area in 6.5 min. Roll call & all personnel accounted for in 8 min. Pad operator accounted for all other personnel working on Moose pad. Notified security drill complete. AAR w/ personnel - good response by all.; Fill conductor & stack w/ water, no leaks. Fill standpipe, kelly hose and Geo -span with water. Pressure test to 3500 PSI - good test. Clean out conductor ft 112'V 114' with 450 GPM & 40 RPM.;Drill 12-1/4" surface hole f/ 114't/ 217', 103' drilled, 68.7'/hr AROP. Drill 1st 10' w/ fresh water then displace to 8.8 ppg spud mud. 450 GPM, 550 PSI, 40 RPM, 1 K TQ, 4K WOB 53K PU / 54K SO / 55K ROT;Circulate a bottoms up. POOH f/ 217' t/ top of motor at 33'. P/U & inspect bit - good. M/U MWD tools (DGR, EWR, directional, Gyro While Drilling, PWD, HUM and TM) to 113'. Plug in, confidence test and initialize tools. M/U three NMDC to 201'. Shallow pulse test MWD & obtain gyro rotational checks.;Drill 12-1/4" surface hole f/ 217' t/ 385', 168' drilled, 67.2'/hr AROP. 450 GPM, 1020 PSI, 40 RPM, 4K TO, 5-1 OK WOB. 72K PU / 67K SO / 70 ROT;Hauled 0 bbls H2O from 6 -Mile Lake for total = 0 bbls Hauled 0 bbls H2O from B -Pad Creek for total = 0 bbls Hauled 0 bbls Source Water from G&I = 0 bbls Hauled 960 bbls from A -Pad = 960 bbls 11125/2019 Drill 12-1/4" surface hole f/ 385't/ 845' (842' TVD), 460' drilled, 76.6'/hr AROP. 475 GPM, 1220 PSI, 60 RPM, 2-41K TO, 10K WOB, 9 ppg MW, 150 vis, ECD 9.3 PU 88K / SO 90K / ROT 92K, max gas Ou. Continue 3°/100' build, at 550' build 4°/100';Drill 12-114" surface hole f/ 845't/ 1427' (1656' TVD), 582' drilled, 97'/hr AROP. 450 GPM, 1150 PSI, 60 RPM, 2-81K TO, 71K WOB, 9 ppg MW, 180 vis, 10.0 ECD PU 94K / SO 89K / ROT 91 K, max gas 58u. Continue to build 4°/100';Drill 12-114" surface hole f/ 1427't/ 1934' (1656' TVD), 507' drilled, 84.57hr AROP. 450 GPM, 1460 PSI, 60 RPM, 6K TO, 12K WOB, 9.3 ppg MW, 300 vis, 10.0 ECD. 102K PU / 85K SO / 90K ROT, max gas 88u. End of build at 1855', begin 60° tangent.;Drill 12-1/4" surface hole f/ 1934't/ 2761' MD (2061' TVD), 827' drilled, 137.8'/hr AROP. 500 GPM, 1620 PSI, 80 RPM, 6K TO, 3-7K WOB, 9.3 ppg MW, 93 vis, 10.36 ECD. 107K PU / 90K SO / 95K ROT, max gas 105u. Base of permafrost at 2280' MD / 1861' TVD. Pumped high vis sweep at 2666';Last survey at 2706.63' MD / 2035.64' TVD, 62.10° inc, 277.01' azm, 5.43' from plan, 2.83' low & 4.63' right.; Daily losses = 0 bbls, Cumulative losses = 0 bbls Hauled 0 bbis H2O from 6 -Mile Lake for total = 0 bbis Hauled 0 bbis H2O from B -Pad Creek for total = 0 bbis Hauled 0 bbls Source Water from G&I = 0 bbis Hauled 885 bbis from A -Pad = 1845 bbis Hauled 1810 bbls cuttinas/mud/cement = 1868 bbis 11/26/2019 Just after making connection @ 2761' Drag chain on # 2 conveyer failed, chain broke due to ice buildup, rack 1 stand back to 2750', circulate 2 bpm, 400 psi working pipe while repairing drag chain.;Service top drive, check gearbox level and grease swivel;BR 1 stand f/ 2754' to 2659' 500 gpm, 1600 psi, 80 rpm, 8k torque, make connection.; Drill 12-1/4" surface hole f/ 2761't/ 2950' MD (2152' TVD), 189' drilled, 75.6'/hr AROP. Hold 60 deg tangent, 500 GPM, 1600 PSI, 80 RPM, 6K TO, 8K WOB, 9.5 ppg MW, 115 vis, 10.4 ECD. , max gas 107u. PU/SO/ROT 110K/90K/96K;Drill 12-1/4" surface hole f/ 2950'V 3712' MD (2581' TVD), 762' drilled, 1277hr AROP. 500 GPM, 1680 PSI, 80 RPM, 8K TO, 5-15K WOB, 9.3 ppg MW, 85 vis, 10.4 ECD. , max gas 120u. PU/SO/ROT 125K/95K/106K Top of Ugnu @ 3066';Pump 30 bbi hi vis sweeps @ 3140', back on time w/ 25% increase & 3617', 300 stks late w/ 10% increase;Drill 12-1/4" surface hole f/ 3712' t/ 4283' MD (2825' TVD), 571' drilled, 95'/hr AROP. 525 GPM, 1920 PSI, 80 RPM, 11 K TO, 5-15K WOB, 9.2 ppg MW, 78 vis, 10.4 ECD. 135K PU / 95K SO / 109K ROT, max gas 77u. Pumped high vis sweep at 4245', no noticeable return Fault #1 @ 4183', 140' Throw DTN;Drill 12-1/4" surface hole f/ 4283' t/ 5008' MD (3159' TVD), 725' drilled, 120.8'/hr AROP. 525 GPM, 1910 PSI, 80 RPM, 10K TO. 5-10K WOB, 9.3 ppg MW, 85 vis, 10.4 ECD. 150K PU / 90K SO / 120K ROT, max gas 120u. Pumped high vis sweep at 4864', no noticeable return;Last survey at 4989.78' MD / 3150.66' TVD, 63.64° inc, 229.55° azm, 16.95' from plan, 14.75' high & 8.34' right.; Daily losses = 0 bbls, Cumulative losses = 0 bbis Hauled 395 bbis H2O from 6 -Mile Lake for total = 395 bbis Hauled 0 bbis H2O from B -Pad Creek for total = 0 bbls Hauled 0 bbis Source Water from G&I = 0 bbis Hauled 745 bbls from A -Pad = 2590 bbls Hauled 1336 bbis cuttings/mud/cement = 3204 bbls 11/27/2019 Drill 12-1/4" surface hole f/ 5008'U 5420' MD (3322' TVD), 412' drilled, 1177/hr AROP. 525 GPM, 2000 PSI, 80 RPM, 10K TO, 8K WOB, 9.2 ppg MW, 84 vis, 10.4 ECD. max gas 453u. 105K PU / 88K SO / 120K ROT.;Continue to build and turn 4 deg/100' targeting 85 deg inc @ 6200'.;Shakers blinding off, BR f/ 5420' to 5317', work thru tight hole and packing off issues f/ 5365 to 5325' cleaning up same, 430 gpm, 30 rpm, 15-25k tq, slow pump to 3 bpm, 400 psi, working pipe 15' while C/O back screens and cleaning the rest w/ screen kleen.;Ream to bottom @ 5420', 450 gpml 120 psi, 30 rpm, shakers loading up with sand, BR stand to 5325' before making connection letting hole cleanup.;Drill 12-1/4" surface hole f/ 5420't/ 5495' MD (3351' TVD), 75' drilled, 507hr AROP. 525 GPM, 1900 PSI, 80 RPM, 14K TO, 6-8K WOB, 9.3 ppg MW, 85 vis, 10.3 ECD. max gas 250u. 170K PU / 88K SO / 115K ROT.;Drill 12-1/4" surface hole f/ 5495't/ 5807' MD (3441' TVD), 312' drilled, 52'/hr AROP. 500 GPM, 1940 PSI, 80 RPM, 15K TO, 5-15K WOB, 9.2 ppg MW, 109 vis, 10.2 ECD, max gas 761 u. 170K PU / 85K SO 1120K ROT Pump 30 bbl hi vis sweep @ 5555', no increase at surface.;Drill 12-1/4" surface hole f/ 5807't/ 6148' MD (3481' TVD), 341' drilled, 56.87hr AROP. 550 GPM, 2150 PSI, 80 RPM, 15K TO, 5-15K WOB. 9.3 ppg MW, 108 vis, 10.1 ECD., max gas 616u. 165K PU / 85K SO 1116K ROT.;Pump 30 bbl hi vis sweep @ 6075', no increase at surface. Drilled through fault #2 at 5980'. Estimated 91' throw DTN placing bit from Ugnu MF to Schrader Bluff ND.;Drill 12-1/4" surface hole f/ 6148't/ 6664' MD (3555' TVD), 516' drilled, 86'/hr AROP. 550 GPM, 2150 PSI, 80 RPM, 16K TO, 10-15K WOB 9.4 ppg MW, 78 vis, 10.4 ECD, max gas 406u. 160K PU 180K SO / 116K ROT.;Last survey at 6609.73' MD / 3542.19' TVD, 77.24° inc, 178.64° azm, 19.31' from plan, 14.35' low & 12.92' right.;Daily losses = 0 bbls, Cumulative losses = 0 bbis Hauled 1105 bbis H2O from 6 -Mile Lake for total = 1500 bbis Hauled 0 bbis H2O from B -Pad Creek for total = 0 bbis Hauled 0 bbls Source Water from G&I = 0 bbis Hauled 745 bbis from A -Pad = 2590 bbis Hauled 1904 bbis cuttings/mud/cement = 5108 bbls 11/28/2019 Drill 12-1/4" surface hole f/ 6664' t/ 6966' MD (3594' TVD) TD in top OA -1, 302' drilled, avg rop 67 fph. 550 GPM, 2200 PSI, 80 RPM, 16-17K TQ, 10-15K WOB. 9.4 ppg MW, 56 vis, 10.4 ECD, max gas 521u. 165K PU / 90K SO/ 120K ROT.;Last survey at 6911.59' MD / 3589.83' TVD, 83.70° inc, 182.80° azm, 61.77' from plan, 61.58' low & 4.84' right. Top of SB_OA-1 sand @ 6880' MD / 3586' TVD.; Obtain final survey, pump 30 bbl hi vis sweep w/ nut plug marker around. Back on time w/ no increase. 550 GPM, 2090 PSI, 100 RPM, 18K TQ. Rack back a stand after a bottoms up. Circulated a total of 2 BU. YP at 20. Perform 10 min flow check - static. TIH f/ 6761't/ 6966'.;BROOH f/ 6966't/ 4030', 550 GPM, 2050 PSI, 60 RPM, 12-14K TQ. 5 min/stand pulling speed, slowing as necessary. Pull slow through tight spot f/ 4046' t/ 4030 after packing off and string stalled. Run stand back in with pumps off, backreamed out clean.;BROOH f/ 4030't/ 2463', 550 GPM, 1500 PSI, 60 RPM, 7-10K TQ. 5 min/stand pulling speed, slowing as necessary. Limit RPM to 60 while BROOH to accommodate GWD tool specs.; Daily losses = 0 bbls, Cumulative losses = 0 bbis Hauled 1105 bbis H2O from 6 -Mile Lake for total = 1500 bbis Hauled 0 bbls H2O from B -Pad Creek for total = 0 bbls Hauled 0 bbls Source Water from G&I = 0 bbls Hauled 1330 bbls frorn A -Pad = 3920 bbis Hauled 982 bbis cuttings/mud/cement = 6090 bbis 11/29/2019 BROOH f/ 2463't/ 762' racking back stds DP 550 GPM, 1500 PSI, 60 RPM, 7-10K TQ. 5 min/stand pulling speed, slowing as necessary. Limit RPM to 60 while BROOH f/ GWD. Condition mud on TOOH.;Work thru tight hole f/ 2043' to 2036', 1960' to 1955cleaning up same, 1880' hole started severally unloading, Pull slow until clean. Max gas 748u. 37.5 bbl losses BROOK; Flow check the well @ the HWDP, static, BD TD. POOH f/ 761' on elevators, rack back 5 stds HW, UD jars and 2 jts HWDP to 204', UD BN XO, NMFCs, upload MWD. UD remaining BHA.;Abrasion wear to the hard banding and body of the EWR P4 and damage to the resistivity receivers. Attempt to break the DM Collar with the rig tongs at 65k ft lbs with no success. Lay down DM w/ EWR P4. Bit graded: 1 -2 -CT -S -E -1 -NO -TD. Clear & clean rig floor.;PJSM. R/U to run 9-5/8" casing. M/U Doyon Volant casing running tool w/ cement swivel. R/U bail extensions, elevators, back-up strap tongs and 350T slips.;M/U 9-5/8" shoe track to 123': Float shoe, shoe joint, Baker -Loc joint, float collar & float collar joint. Fill casing & install bypass baffle. Check floats - good. M/U baffle adapter & baffle adapter joint to 163'. Baker -Loc first 4 connections,;9-5/8"x12-1/4" Expand-O- Lizer centralizer placement:2 on shoe joint w/ 4 stop rings, 1 on Baker -Loc joint free floating and 1 each w/ 2 each stop rings on float collar & baffle adapter joints.;Run 9-5/8" 40# L-80 TXP-BTC casing ft 163' t/ 2526' (joint #60) @ 15'/min. Torque to 20,960 ft/lbs w/ the Volant tool. Install one 9-5/8"x12-1/4" Expand- O-Lizer centralizer on joints #1-21, then every other joint #23-59. Fill pipe on the fly & top off every 10 joints. 4 bbis losses to this depth.; Below BPF, Fill pipe, slowly stage pump f/ 1/2 bpm to 5 bpm, 170 psi, reciprocate pipe 30', seeing fair amount sand returns through BU, circulate 1.75x BU total until clean. 19 BBL losses circulating. P/U 125K, S/O 100K.;Continue Run 9-518" casing f/ 2526' tl 2804' @ 15'/min, TQ to 20,960 ft/lbs Install one 9-5/8"x12-1/4" Expand-O-Lizer every other joint #61-67. Fill pipe on the fly & top off every 10 joints.;Daily losses (Midnight) = 19.5 bbls, Cumul losses= 19.5 bbls Hauled 610 bbis H2O from 6 -Mile Lake for total= 2110 bbis Hauled 0 bbis H2O from B -Pad Creek for total= 0 bbls Hauled 0 bbis Source Water from G&1= 0 bbls Hauled 70 bbis from A -Pad= 3990 bbis Hauled 982 bbis cuttings/mud/cement = 6090 bbls 11/30/2019 Continue to Run 9-5/8" casing f/ 2804' t/ 4420' A 15'/min TQ to 20,960 ft/lbs Install one 9-5/8"x12-1/4" Expand-O-Lizer every other joint #. 49-89 then every jt f/ 104 to 108, Fill pipe on the fly & top off every 10 joints.;Baker lock and M/U Halliburton ES cementer, ensure 6 shear pins set @ 3300 psi. install 1 centralizers ea over stop rings on Pup joints above and below ES cementer then every jt to #113, continue RIH f/ 4451' to 4530' @ jt 110.;Circulate B/U staging pump up slow to 5 bpm, 200 psi, reciprocating pipe 30', small amount of sand, condition mud f/9.1 in 9.5 ppg out to 9.1 in and 9.3 ppg out, 23 bbl losses running casing or circulating at this point.;Continue to run 9 518" casing fl 4530' to 6906' installing centralizer on every other jt f/ 115 to 166, M/U final jt 171, wash to 6945', M/U 20' casing pup jt, get parameters, verify pipe count. wash down 2 bpm to 6960' @ set depth. Cementers on location @ 15:00, spot and R./U same. PU/SO 275K/90K.;Remove elevators and bail extensions, remove casing slips., circulate and condition, stage pump slowly f/ 2 bpm, 300 psi to 5 bpm, 180 psi, while reciprocating pipe F/ 6962' T/ 6942'. Rotate 3 RPM w/ 21 K torque. Circulated 2x bottom up.; 16 bbis losses while circulating. Total 54 bbis loss during casing run. MW 9.2, vis 41, YP 7, P/U 275K, S/O 95K. PJSM w/ Doyon, Halliburton, M-1 and Peak.;Blow down TopDrive. R/U cement lines and clear floor. Flood the lines with 5 bbls of water. PT lines to 1100/4000 psi for 5 min each (good test). Line up, mix & pump 60 bbl 10.0 ppg tuned spacer w/red die & pol-e-flake in the first 10 bbls 4 bpm, 168 psi. Drop the bypass plug.;Line up, mix & pump 245 bbls 12 ppg lead cement (585 sacks) 4 bpm, 215 psi. Mix & pump 82 bbis 15.8 ppg tail cement (400 sacks) 4 bpm, 528 psi. Drop the closing plug. HES pumped 20 bbls fresh water. Line up to the rig and start displacement.;With rig pump 296.8 bbls 9.2 ppg mud 6 bpm, 195 ICP, HES pump 80 bbls 9.4 ppg tuned spacer, Rig displace with 118.3 bbls mud, slow to 2.5 bpm @ 4000 stks, FCP 520 psi, bumped plug @ 4110 stks, 34 stks early f/ calculated @ 4144 stks.;CIP @ 01:50, pressure to 1100 psi, hold 5 min, bleed off pressure, pressure to 2960 psi, shifting cementer open. Reciprocated and rotated 1-5 rpm, 20k torque throughout the job until last 15 bbis before bumping plug. No losses while pumping and displacing cement. Shoe set @ 6960'.; Circulate hole from ESC up @ 2525'6 bpm, 300 psi. 2200 stks away dump contaminated mud, 2300 stks away spacer returns, 3100 stks away contaminated mud, 3700 stks take good mud to pits. 4600 stks dump contaminated mud, 4900 stks take good mud to pits. Continue to circulate 60 bbis @ 6 BPM, 235 psi.;100 bbis contaminated mud and 80 bbls spacer dumped to rock washer.;Shut down, flush bag, riser and surface equipment. Blow down Volant tool. Rig up circulating swedge. Continue to circulate through ESC @ 6 BPM while WOC to reach 100 psi compressive strength in 8 hrs. Hold PJSM for laying down 5" DP from Derrick using tugger, single joint elevators and mousehole;Daily losses (Midnight) = 35 bbis, Cumul losses= 54.5 bbis Hauled 0 bbis H2O from 6 -Mile Lake for total= 2110 bbls Hauled 0 bbis H2O from B -Pad Creek for total= 0 bbls Hauled 510 bbis Source Water from G&1= 510 bbls Hauled 650 bbis from A -Pad= 4640 bbls Hauled 695 bbis cuttings/mud/cement= 6785 bbis 12/1/2019 Circulate hole from ESC up @ 2525'6 bpm, 300 psi, start seeing clabbered mud after 4.5 BU, shut down pumps, clear flow line and possum belly, establish circulation staging pumps slowly to 6 bpm, 300 psi dumping additional 37 bbls of clabbered thick mud.;Continue to circulate thru ESC 6 BPM, 300 PSI with no issues while WOC, UD 65 stds 5" DP and 5 stds HWDP from derrick utilizing the mouse hole, single joint elevators and hoist. Prep for 2nd stage cement job. Loss rate 3 bph circulating.; Shut down pump, R/D headpin and circ hose, M/U volant tool and cement line, Hold PJSM with all parties. HES batch up while continue to circulate through ES Cementer, 5 BPM.;PT lines w/ H2O t/ 1230 psi low 4600 psi high. Pump 60 bbl of 10 ppg tuned spacer with 4# red dye and 0.5 ppb Poly flake in the 1 st 10 bbis at 4 BPM 208 psi. Pump 404 bbis of 10.7# lead Perm L Cmt. (515 SX), at 4 BPM 250 psi . Pump 56.2 bbl of 15.8 Tail cmt. (270 SX) at 4 BPM 450 psi.;Drop closing plug. Pump 20 bbls H2O. Line up to rig for displacement with 9.2 ppg spud mud. Pump 1500 strokes (151.5 bbls) at 6 BPM then slow to 3 BPM. Shift ESC closed and bump plug 11 strokes late at 1712 stks (172.9 bbls).; Pressure up to 1270 psi,870 psi over FCP at 400 psi, and observe ESC shift closed. Bleed down. No flow.;Got mud push back with 290 bbis Lead pumped, spacer was strung out and clobbered. Good cement back before swapping to Rig for mud displacement. No losses on second stage. CIP at 22:30 with 220 bbl total good lead cmt back at surface.; Disconnect knife valve, drain stack and flush with black water, functioning bag several times. Flush all surface equip with black water and blow down. Remove mouseholes. NID diverter line. Prep to lift 20" diverter equipment. SimOps: Cleaning Mud Pits.;Cellar bridge crane had a seal fail when moving to position for picking annular preventer. Pull crane out of service and rig up 8 ton hoist from rig floor to supplement other bridge crane.;Lift 20" diverter equip. Install casing slips as per wellhead rep. with 135K on slips. Cut casing. UD cut jt. (16.63' total cut).;N/D Surface stack, Riser and Diverter Tee. Submit 24 hour Diverter test notification to AOGCC.; Daily losses (Midnight) = 19 bbls, Cumul losses= 73.5 bbls Hauled 0 bbls H2O from 6 -Mile Lake for total= 2110 bbls Hauled 0 bbls H2O from B -Pad Creek for total= 0 bbls Hauled 265 bbls Source Water from G&1= 775 bbls Hauled 305 bbis from A -Pad= 4945 bbls Hauled 1411 bbls cuttings/mud/cement= 8196 bbl 12/2/2019 N/U Well head, test WH to 500 psi for 5 min and 2480 psi for 10 min as per Wellhead rep, good test, N/U tbg spool. Remove 4" valves on conductor and install caps. SimOps: R/U 3 1/2" handling equipment. AOGCC rep Brian Bixby waived witnesss for M-24 diverter test @ 06:18 on 12/2/19.;PJSM, M/U Mule shoe, P/U and RIH w/ 3 1/2" 9.3# L-80 EUE kill string to 2470' torque to 2300 ft/lbs, Monitor returns going to cellar box from open annulus valve. Vac out cellar. M/U PUP jt/tbg hanger, M/U landing jt. Land hanger w/ 15k on hanger.;RILDS, UD landing jt. Install BPV, PU/SO 60k/55k. Mule shoe set at 2505.16'.;NU adaptor and tree, test hanger void to 500/5000 psi 5 min ea, test tree to 250/5000 psi 5 min ea. Pull BPV. SimOps: R/D outside equipment.;R/U for reverse circulating. Displace well with H2O, pump 225 bbis down IA taking returns through tubing to rockwasher. Pump 201 bbls diesel down IA, taking returns through tubing to rockwasher, divert last 41 bbls to cuttings tank. 182.5 bbls diesel freeze protect left in wellbore.; Blow down lines to cuttings tank, rig down lines. Clean cellar box & wellhead. Empty cuttings box at rockwasher. Rig down mud pumps, prep pits for move. Cut and cap mousehole in cellar box. Sim ops: Prep M-24 for diverter system. Rig released @ 00:00.;Move rig to M-24. See M-24 drilling report for details.; Daily losses (Midnight) = 0 bbis, Cumul losses= 73.5 bbls Hauled 235 bbls H2O from 6 -Mile Lake for total= 2345 bbls Hauled 0 bbls H2O from B -Pad Creek for total= 0 bbis Hauled 0 bbis Source Water from G&1= 775 bbls Hauled 0 bbls from A -Pad= 4945 bbis Hauled 1933 bbls cuttings/mud/cement= 10129 bbls 12/3/2019 12/21/2019 PJSM Pull Mud Mod and Catwalk off Matt boards. Walk off Sub and install steering hitch. Install Jeep on Mud Mod. Stage Mods around F Pad in order for convoy to Moose Pad. SIMOPS Remove spacer spool and DSA from Sub. C/O Geo Pilot skid. Load all necessary rig matts and Equip for rig move on Moose Pad 12/22/2019 PJSM Wait for production change out and start moving all mods at 06:30 F/ F Pad to M Pad. Stage Gen and Mud Mod on M Pad. Back Sub unto M-26. Unhook D8. Remove steering arms F/ Sub. Walk Sub over well center on M-26 . Set Catwalk, lower stairs and scope up cattle chute.;Set Pipe Shed and Mud Mod. Hook up inner connects. Spot Beyond choke house. Hook onto Gen Mod and maneuver truck and jeep to get lined up to Mud Mod. Congested area required unhooking truck and adjusting jeep multiple times. Hook up inner connects. Spot cutting box and assemble containment.; Turn on steam around rig. Spot Beyond Nitrogen bottle rack and boxes. Assist electrician W/ plugging in connections. Went on Gen power at 22:30.;PJSM Spot Office trailer on M Pad. Spot Break Shack, Enviro Vac and cutting box. Scope up Derrick and bridle down. Cont. working on rig acceptance check list. Load 5" D.P. in Pipe Shed. C/O Saver Sub F/ XT 39 to NC50.;Daily hauled 0 bbls to G&I total = 0 bbls Daily hauled to ORT 0 bbis total = 0 bbls Hauled 0 bbls from 6 mile lake, Total 0 bbls .Daily Fluid lost 0 bbls total = 0 bbls 12/23/2019 PJSM Finish C/O Saver Sub F/ XT39 to NC50. Cont working on rig acceptance check list. SIMOPS Cont loading and process 5" D.P. in pipe shed. Peak released at 07:00.;Rig accepted at 08:00. PJSM Remove Diesel F/ Tree. Install CTS BPV as per NOS. N/D Tree. Install CTS plug. SIMOPS Cont. loading and process 5" D.P. in pipe shed.;PJSM Install 13 5/8" DSA. Remove adapter flange F/ BOP. Set MPD head and orientate on BOP. SIMOPS Cont. loading and process 5" D.P. in pipe shed. Work on EAMS.;PJSM Transfer RCD F/ Bridge Cranes to Blocks. Hook up Bridge Cranes to BOP. P/U RCD and set BOP on DSA. Install RCD to BOP. N/U BOP. M/U hard lines for MPD. SIMOPS Cont. loading and process 5" D.P. in pipe shed. Work on EAMS. Perform monthly Gearbox to spline greasing for Drawwroks.;PJSM M/U Choke and Kill lines. Install drip pan. RKB. Prep for testing BOPE. Install hydraulic 5" elevators. SIMOPS Cont W/ 5" D.P. in pipe shed.;PJSM M/U test sub to Top Drive. P/U 3.5" and 5" test juts, make marks for upper and lower reams. M/U 5" Dart, 5" TIW and side entry sub on 5" test jnt.;PJSM R/U to test 5" test jnt. Flush and work air out of Choke Manifold, Choke, Kill and testing lines. SIMOPS Cont processing 5" D.P.;PJSM Perform BOPE test W/ 5" to 250 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 4-13 & 15, 5" Dart, 2 ea 5" TIW, Upper and lower IBOP, Mez Kill, HCR Choke and Kill, Manual Kill, manual and Super Choke, Upper and lower VRB Rams (2,875" X 5.5"), Annular Bag.;Test H2S 10-20 ppm, LEL 20-40°x, PVT high/ low level alarms. Witnessed waived by AOGCC Rep Brian Bixby. SIMOPS Cont processing 5" D.P.;Daily hauled 0 bbls to G&I total = 0 bbls Daily hauled to ORT 0 bbis total = 0 bbls Hauled 780 bbis from L Pad, Total 780 bbls Dail Fluid lost 0 bbls total = 0 bbl 12/24/2019 PJSM Cont resting BOPE W/ 5" test jnt 250 PSI low and 3,000 PSI high 5 min on chart. Test Manual Choke (Fail/Pass), Blind Rams, Choke Valves 1-3 & 14. Test W/ 3.5" test joint Upper and lower VRB Rams (2,875" X 5.5") and Annular Bag. Koomey draw drown Initial System 3,050 PSI, Manifold 1,650 PSI,;Annular 1,250, after System 1,450 PSI, Man 1,650 PSI, Annular 1,275 PSI. 200 PSI increase 26 Sec, full charge 100 sec. Nitrogen 6 bottle average 2,383 PSI. Witnessed waived by AOGCC Rep Brian Bixby. SIMOPS Process 5" D.P. Load 580 bbls Baridril N in pits.;PJSM Drain Stack and pull riser. Set RCD test plug W/ 5" HWDP. Test MPD Choke to 250 PSI low 5 min and 1,500 PSI high for 15 min. SIMOPS Process 5" D.P. SIMOPS Cont processing 5" D.P.;PJSM RID test Equip and pull RCD test plug. Install flow riser. Blow down Choke, kill and kelly. Grease Equip. SIMOPS Cont processing 5" D.P.;PJSM Pull TWC, no Press. M/U 5" D.P. and X/O to TC2 to Hanger as per NOS. ROLDS. Pull Hanger, unseated at 73K P/U. SIMOPS Cont processing 5" D.P.;PJSM PT mud lines to 3,000 PSI. Circ. at 6 BPM, 120 PSi tacking returns to cutting box, displaced 182 bbls Diesel W/ H2O. SIMOPS Cont processing 5" D.P.;PJSM R/U Weatherford tools and Equip for 3.5" EUE Tubing.. UD Hanger and send out W/ NOS Rep. SIMOPS Cont processing 5" D.P.;PJSM POOH L/D to pipe shed 3.5" 9.3# L-80 EUE Kill String F/ 2,473' to surface. P/U 53K, SLK 48K SIMOPS Cont processing 5" D.P.;PJSM RID LID Weatherford tools and Equip. SIMOPS Cont processing 5" D.P.;PJSM Install Wear Bushing 10.25" OD, 9" ID, 38" Lngt. Load shed W/ Motor, Jars and HWDP.;PJSM P/U M/U 8.5" Clean Out BHA 8.5" Smith Tricone RR (1 -1 -WT -A -E -1 -CD), 6.75" StrataForce Lobe 6:7-6 stg 1.5° bend motor ( install crows foot over float), 6 ea 5" HWDP, 6.5" SLB Hydra Jars, 11 ea 5" HWDP total 593.56' MD.;Tagged up at 156' MD washed down at 300 GPM, 240 PSI with no WOB to 416' MD. Probably ice on outside wall. Cont. single in hole 5" HWDP. on elevators F/ 416' to 593' MD.;PJSM Single in hole BHA W/ 5" D.P. NC50 F/ 593' to 2,025' MD. Drift (3.125" OD) off Skate.;PJSM Hung Blocks and cut 113'(18 Wraps) Slipped new drilling line onto drum. ACTM 21,402. Left on spool 1,879'. Check brake gaps. Torque Deadman clamp bolts 80 ft/lb, mount bolts 225 ft/lb. Removed hang off line. Set all Top Drive limits. SIMOPS Circ 1 bpm, 50 PSI Bring Vis up 35 40 sec/gt.;PJSM Service Rig. Grease Crown, Blocks, Wash Pipe, Top Drive, Drawworks, Iron Roughneck, Spinners and IBOP. Check oil in Top Drive.;PJSM Single in hole BHA W/ 5" D.P. NC50 F/ 2,025' to 2,465' MD. Drift (3.125" OD) off Skate.;Daily hauled 347 bbis to G&I total = 347 bbis Daily hauled to ORT 0 bbls total = 0 bbis Hauled 260 bbls from L Pad, Total 1,040 bbis Daily Fluid lost 0 bbls total = 0 bbls 12/25/2019 PJSM Drill cement strinaers F/ 2 497' to 2,516' MD. 330 GPM 315 PSI, 50 RPM, TRQ 4.5-5.5K, WOB 5-7K. Drill ES Cementer F/ 2,519' to 2,521' MD 330 GPM, 330 PSI, 50 RPM, TRQ 5-6K, WOB 12-17K. CBU 2X and wash down to 2,534' MD until rubber/ cement cleaned up at Shakers. P/U 98K, SLK 70K.;PJSM Blow down Top Drive. Cont. P/U 5" D.P. singles F/ Skate F/ 2,534' to 5,046' MD. Rabbit (3.125" OD) filling every 2,000'. P/U 162K, SLK 72K.;PJSM Cont. P/U5" D.P. singles F/ Skate F/ 5,046' to 6,318' MD. Rabbit (3.125" OD) filling every 2,000'. P/U 165K, SLK 50K.;PJSM Wash and ream down F/ 6,318' to 6,797' MD to TOC tagged WI 10K, 210 GPM, 625 PSI. P/U 190K, SLK 55K.;PJSM CBU Reciprocate F/ 6,797' to 6,760MD 515 GPM, 1,125 PSI. Pumped a total of 5,650 sts, 350 bbls.;R/U Head Pin and Halliburton valves to DS. Blow down Top Drive , Choke and Kill lines to verify clear of obstructions. Pump through Kill and Choke lines to fluid pack Equip. Shut Upper Pipe Rams. Press up to 2,700 PSI for 30 min on chart (lost 30 PSI), good. L� Pumped 5.2 bbls, bled back 5.2 bbls.;Open Rams and blow down Equip. Align back for drilling. Close both Kill and Choke manual valves for drilling cement. Rig Crew released for Christmas dinner F/ 17:00 to 19:00.;PJSM Drill cement F/ 6,797' to 6,781' MD 475 GPM, 980 PSI, 40 RPM, TRQ 17K, WOB 2-17K. Baffl Adapt at 6,829' MD, FC at 6,870' MD. P/U 175K, SLK 58K.;PJSM Drill Shoe track F/ 6,870' to 6,954' MD 475 GPM, 690 PSI, 40 RPM, TRQ 16-17.5K, WOB 5-10K, RF 43%. Shoe at 6,954' MD.;PJSM Drill F/ 6,954' to 6,980' MD W/ 20' new hole. 475 GPM, 690 PSI, 40 RPM, TRQ 16-17.5K, WOB 5-10K, RF 43%. P/U 195K, SLK 52K, ROT 105K. Work through shoe W/ and W/ out ROT. No issues.;PJSM Displace Mud 483 bbis Spud Mud W/ 8.9 ppg Baridril N W/ 53 bbl Hi Vis 8.9 ppg 300+ Vis Spacer followed W/ 483 bbis 8.9 ppg Baridril N at 4-8 bpm. 536 PSI, 40 RPM, TRQ 15.5K. P/U 187K, SLK 71 K, ROT 109K. Montitor well, static. LID single 5" D.P.;SPR at 6,980' MD (3,588' TVD) MW 8.9 ppg MP #1 32-221, 48-260 MP #2 32-190, 48-205;Distance to WP #5 68.75', 68.43' Low, 6.63' Right;Daily hauled 228 bbls to G&I total = 575 bbis Daily hauled to ORT 0 bbis total = 0 bbls Daily hauled 70 bbls F/ K2, total 70 bbls Daily hauled 390 bbis from L -Pad, Total 1,480 bbis Daily Fluid lost 0 bbis total = 0 bbls 12/26/2019 PJSM At 6,948' MD R/U test Equip. Flood Choke, Kill and Choke manifold working air out. Perform FIT to 12 ppg EMW W/ 9.0 ppg MW. Press up to 560 PSI, Pumped 2.1 bbls, bled back 1.9 bbls. Blow down and R/D.;PJSM POOH 2 stands to 6,822' MD. to ensure no swabbing. RIH to 6,953' MD and drop Gyro tool W/ 45 min delay. Pumped down staging up to 400 GPM 790 PSI for 30 min when landed. Pump 22 bbl 10.7 ppg Dry Job. Blow down top drive. Monitor well for 10 min, static.;PJSM POOH racking back 5" D.P. F/ 6,953' to 593' MD. Obtaining surveys W/ Gyro every connection. No losses. P/U 165K, SLK 56K.;PJSM LID 5" HWDP and Jars. Pull Gyro from last Jnt 5" HWDP. LID the rest of the BHA. Bit Grade 1 -1 -WT -A -E -1 -NO -BHA. Clean and clear rig floor.;PJSM P/U stage BHA tools on rig floor. P/U M/U 8.5" NOV SK61MJ1 PDC, 8.5" NOV NRP, 7.625" Geo -Pilot 7600, 6.75" ADR/HCIM Collar, 6.75" ILS, 6.75" DGR Collar, 6.75" PWD, 6.75" DM Collar, 6.75" TM Collar and 6.75" Float Sub (Non ported plunger) 85.5". Plug in and download tools.;Cont. P/U 2 ea 6.5" NM FC, 6.75" Float Sub (Non ported plunger), 2 jnts 5" HWDP. 6.5" SLB Hydra Jars and 1 jnt 5" HWDP Total BHA 275.51'.;PJSM Single in BHA #3 W/ 5" D.P. F/ 275' to 731' MD. AT 370' MD Shallow hole test MWD and break in Geo Pilot seals as per MWD and DD. Blow down. Rabbit (3.135" OD) off skate. No losses.;PJSM Single in BHA #3 W/ 5" D.P. F/ 731' to 2,500' MD. P/U 77K, SLK 60K Rabbit (3.135" OD) off skate. No losses.;PJSM POOH racking back 5" D.P. F/ 2,500' to 275' MD. P/U 54K, SLK 53K.;PJSM Single in BHA #3 W/ 5" D.P. F/ 275' to 1,736' MD. P/U 71 K, SLK59K Rabbit (3.135" OD) off skate. Filling every 2,000; MD. No Iosses.;Daily hauled 689 bbls to G&I total = 1,264 bbls Daily hauled to O RT 0 bbls total = 0 bbls Daily hauled 90 bbis F/ K2, total 160 bbls Daily hauled 0 bbls from L -Pad, Total 1,480 bbls Daily Fluid lost 0 bbls total = 0 bbis 12/27/2019 Continue to single in the hole from 275' to 6945' drifting on skate. Fill pipe every 2000'. PUW 165K, SOW 65K. Calculated displacement observed.; Circulate bottoms up at 455 gpm, 1160 psi, ECD 9.95 ppg EMW with 9.0 ppg mud. Max gas 7U. Monitor well, static. Blow down top drive.;Service top drive. Open coffin and locate leak on top drive.;Pick up MPD element. drain and pull riser. Install MPD rotating head, M/U clamp. Flood lines and check for leaks - good.;Drill 8-112" hold from 6980' to 7139' (total 159', AROP = 106 fph). 455 gpm, 1260 psi, 130 rpms, 15Kft-lbs, WOB 2-4K, ECD 10.3 ppg EMW, MW 9.0 ppg. PUW 170K, SOW 52K, ROTW 98K. Undulating down to OA -2 sands at 7036'. Backream 30' every stand.;Drill 8-1/2" hold from 7139' to 7552' (total 413', AROP = 69 fph). 455 gpm, 1260 psi, 130 rpms, 15Kft-lbs, WOB 2-4K, Max Gas 825U, ECD 10.5 ppg EMW, MW 9.0 ppg. PUW 170K, SOW 52K, ROTW 98K. Undulating down to OA -3 sands at 7,293'. Backream 30' every stand.;Drill 8-1/2" hold from 7552' to 8160' (total 608', AROP = 101 fph). 455 gpm, psi, 120-140 rpms, 13-18Kft-lbs, WOB 2-4K, Max Gas 1096U, ECD 10.8 ppg EMW, MW 9.0 ppg. PUW 130K, SOW 68K, ROTW 91 K. Undulating up to OA -2 at 7720' and crossing fault at 7954' with est. 45' DTN throw, below OA sand.;Pumped High vis/wt sweep at 7966' with 20% increase in cuttings, on time. Increase lube concentration to 2% to mitigate stick slip.;3 concretions have been drilled so far for a total footage of 10' (0.9% of the lateral) 1 fault has been crossed so far this lateral; 7,954' Total footage in OA -1 = 84', OA -2 = 491', OA -3 =427' Distance to WP#06b: 88.46', 61.58' low, 4.86' right;Daily hauled 114 bbis to G&I total = 1,378 bbls Daily hauled 90 bbls from K2 lake, total 250 bbis Daily hauled 0 bbis from L -Pad, Total 1,480 bbis Daily Fluid lost 0 bbls total = 0 bbis 12/28/2019 Drill 8-1/2" hold from 8160' to 8855' (total 695', AROP = 116 fph). 525 gpm, 1805 psi, 130 rpms, 15-20Kft-lbs, WOB 5-10K, Max Gas 973U, ECD 11.2 ppg EMW, MW 9.2 ppg. PUW 155K, SOW 58K, ROTW 87K. Backrearn full stands.;Drill 8-1/2" hold from 8855' to 9490' (total 635', AROP = 106 fph). 525 gpm, 1930 psi, 100 rpms, 15.5Kft-lbs, WOB 8K, Max Gas 8550U, ECD 11.4 ppg EMW, MW 9.2 ppg. PUW 150K, ROTW 90K. Backream full stands.;Drill 8-1/2" hold from 9490' to 10,063' (total 573', AROP = 96 fph). 525 gpm, 1980 psi, 140 rpms, 15Kft-lbs, WOB 10K, Max Gas 855U, ECD 11.4 ppg EMW, MW 9.2 ppg. PUW 137K, SOW 55K, ROTW 95K. Backream full stands. Pump high wt/vis sweep at 10,000' with 20°% increase of cuttings, on time.;Drill 8-1/2" hold from 10,063' to 10,698' (total 635', AROP = 106 fph). 525 gpm, 2160 psi, 130-150 rpms, 12-14Kft-lbs, WOB 5-12K, Max Gas 875U, ECD 11.9 ppg EMW, MW 9.3 ppg. PUW 140K, SOW 55K, ROTW 85K. Backream full stands.;35 concretions have been drilled so far for a total footage of 134' (3.7% of the lateral). 5 fault has been crossed so far this lateral; 7,954'; 8,407'; 8,650'; 8,970'; 9,790' Total footage in OA -1 = 1046', OA -2 = 1004', OA -3 = 1176' Distance to WP#06b: 3.99', 3.87' low, 0.97' right;Daily hauled 627 bbls to G&I total = 2,005 bbls Daily hauled 0 bbls from K2 lake, total 250 bbls Daily hauled 0 bbls from L -Pad, Total bbls Daily hauled 650 bbls from 6 mile creek total =650 bbls IDaily Fluid lost 0 bbls total = 0 bbls 12/29/2019 Drill 8-1/2" hole from 10,698' to 11,398' (total 700', AROP = 117 fph). 525 gpm, 2270 psi, 130 rpms, 10-12Kft-lbs, WOB 8-13K, ECD 12.09 ppg EMW, MW 9.3 ppg. PUW 137K, SOW 61 K, ROTW 86K. Max Gas 1664U. Backream full stands. Pump high wt/vis sweep at10,700' with 50% increase, 400 strokes Iate.;Drill 8-1/2" hole from 11,398' to 12,090' (total 692', AROP = 115 fph). 540 gpm, 2150 psi, 140 rpms, 11 Kft-lbs, WOB 10-13K, Max Gas 972U, ECD 12.01 ppg EMW, MW 9.3 ppg. PUW 135K, SOW 52K, ROTW 92K. Backream full stands.;Drill 8-1/2" hole from 12,090' to 12,672' (total 582', AROP = 97 fph). 540 gpm, 2470 psi, 140 rpms, 14.5Kft-lbs, WOB 17-19K, Max Gas 1340U, ECD 12.01 ppg EMW, MW 9.3 ppg. PUW 138K, SOW NA, ROTW 92K. Lost slack off wt at 12,227'. Backream full stands. Crossed fault #6 at 12,526'.;Drill 8-1/2" hole from 12,672' to 13,016' (total 344', AROP = 57 fph). 540 gpm, 2600 psi, 130 rpms, 13 -150 -lbs, WOB 13-20K, Max Gas 920U, ECD 12.02 ppg EMW, MW 9.2 ppg. PUW 137K, SOW 45, ROTW 82K. Backream full stands.; Fault #6 at 12,562' estimated 75' DTN throw, and appears to faulted below OA sands into OBA sands, build angle to re -acquire OA sands.;59 concretions have been drilled so far for a total footage of 235' (3.9°% of the lateral). 6 fault has been crossed so far this lateral; 7,954'; 8,407'; 8,650'; 8,970'; 9,790',12,526' Total footage in OA -1 = 1,535', OA -2 = 1,329', OA -3 = 2,306' Distance to WP#06b: 15.54', 11.35' low, 10.62' right;Daily hauled 632 bbls to G&I total = 2,637 bbls Daily hauled 0 bbls from K2 lake, total 250 bbls Daily hauled 0 bbls from L -Pad, Total 1480 bbls Daily hauled 780 bbis from 6 mile creek total =1430 bbls IDaily Fluid lost 0 bbls total = 0 bbl 12/30/2019 Drill 8-1/2" hole from 13,016' to 13,494' (total 478', AROP = 80 fph). 540 gpm, 2600 psi, 130 rpms, 16Kft-lbs, WOB 10-20K, ECD 12.39 ppg EMW, MW 9.3 ppg. PUW 139K, SOW 45K, ROTW 82K. Backream full stands. Pumped 10.5 ppg/240 vis sweep at 13244', 25°% increase, on time. Continue building inc.;Drill 8-1/2" hole from 13,494' to 13,622' (total 128', AROP = 85 fph). 540 gpm, 2660 psi, 130rpms, 18Kft-lbs, WOB 11-13K, Max Gas 530U, ECD 11.9 ppg EMW, MW 9.3 ppg. PUW 140K, SOW 55K, ROTW 85K. Backream full stands. Cont. building inc. looking for OA sands; determine wellbore in the N sands..;Swap to Hi -Line power at 13:05.;Circulate bottoms up at 540 gpm/2615 psi reciprocating pipe;Pump out of hole from 13,622' to 12,735' at 540 gpm/2590 psi.;Sidetrack wellbore. Trough from 12,735' to 12,750' at 540 gpm, 2560 psi; 130 rpms, 13Kft-lbs x 5, Observe ABI inclination drop 0.79°, control drill at 5 fph from 12,750' staging up ROP as separation is observed; at 12790' MD 2.55° inc drop from beginning of sidetrack with 1.2' of seperations.;Drill 8-1/2" hole from 12,790' to 13,244' (total 454', AROP = 90fph). 540 gpm, 2380 psi, 130rpms, 14Kft-lbs, WOB 8-12K, Max Gas 745U, ECD 12.06ppg EMW, MW 9.3 ppg. PUW 142K, SOW NA, ROTW 87K. Backream full stands. Dropped inclination and geosteered into OA sands at 12,970'.;Drill 8-1/2" hole from 13,244' to 13,941' (total 697', AROP = 116fph). 520 gpm, 2280 psi, 130rpms, 15-17 Kft-lbs, WOB 8-13, Max Gas 773U, ECD 12.1 ppg EMW, MW 9.2 ppg. PUW 145K, SOW NA, ROTW 84K. Backream full stands.;64 concretions have been drilled so far for a total footage of 251' (3.6°% of the lateral) At least 7 faults have been crossed so, final interpretation of the faults is pending. ; 7,954'; 8,407% 8,650'; 8,970'; 9,790',12,526' Total footage in OA -1 =1535', OA -2 = 1329', OA -3 = 2306';One Sidetrack has been drilled with PB 12,735'- 13,622' Distance to WP#06b: 21.72', 16.63' low, 13.97' right; Daily hauled 1,491 bbls to G&I total = 4,128 bbls Daily hauled 0 bbis from K2 lake, total 250 bbis Daily hauled 0 bbis from L -Pad, Total 1480 bbls Daily hauled 1040 bbls from 6 mile creek total =2470 bbls Daily Fluid lost 0 bbls total = 0 bbis 12/31/2019 Drill 8-1/2" hole from 13,941' to 14,196' (total 255', AROP = 43 fph). 520 gpm, 2160 psi, 120 rpms, 17Kft-lbs, WOB 10K, ECD 11.7 ppg EMW, MW 9.2 ppg. PUW 170K, SOW N/A, ROTW 86K. Backream full stands.;Drill 8-1/2" hole from 14,196' to 14,755' (total 559', AROP = 93fph). 540 gpm, 2380 psi, 130 rpms, 18Kft-lbs, WOB 7-11 K, Max Gas 7500, ECD 12.0 ppg EMW, MW 9.2 ppg. PUW 157K, SOW N/A, ROTW 85K. Backream full stands.;Drill 8-1/2" hole from 14,755' to 14,940' (total 185', AROP = 123 fph). 540 gpm, 2400 psi, 130 rpms, 19-20Kft-lbs, WOB 8K, Max Gas 811 U, ECD 11.9 ppg EMW, MW 9.3 ppg. PUW 140K, SOW 55K, ROTW 85K. Backream full stands.;Obtain final survey. Circulate hole clean 4 x BU racking back 1 stand every BU to 14,707'. 540 gpm, 2250 psi, 120 rpms, 14-18Kft-lbs. ECD 12.Oppg EMW, MW 9.2 ppg. Prep pits for SAPP train and displacement.;Wash and ream from 14,771' to TD 14,940' at 510 gpm, 2250 psi, 120 rpms, 14Kft-Ibs.;Pump SAPP train and displace to Quick: pump (3) 35 bbls SAPP pills followed by 25 bbls Quick -drill with last SAPP pill chased with high vis spacer, followed by 9.2 ppg Quick -Drill viscosified brine. 8-10 bpm, 1300 psi, 120 rpms final torque 16Kft- Ibs. Obtain SPR's. Monitor well through MPD choke:;Allow pressure to build for 5 minutes then bleed off x 3. First pressure build 21 psi, final 14 psi.;BROOH from 14,940' to 14,686'; 530 gpm, 1860 psi; 120 rpms, 16,000 ft -lbs. PUW 152K, SOW 49K, ROTW 86K. At 14,686 iron roughneck extended on its own, shut valve. Rig up tongs, so mechanic/electrician can troubleshoot.;83 concretions were drilled for a total footage of 313' (3.9%) of the lateral 7 faults has been crossed so far this lateral; 7,954'; 8,407'; 8,650% 8,970'; 9,790'; 12,526% 12,893'. Total footage in OA -1 = 3010', OA -2 = 1626', OA -3 = 2871' 1 sidetrack with PB 12,735'- 13,622'; Distance to WP#06b: 51.12', 31.56' low, 40.22' right;Daily hauled 1650 bbis to G&I total = 5,778 bbls Daily hauled 0 bbls from K2 lake, total 250 bbls Daily hauled 0 bbls from L -Pad, Total 1480 bbls Daily hauled 1680 bbls from 6 mile creek total =4050 bbls Daily Fluid lost 0 bbls total = 0 bbis 1/1/2020 BROOH from 14,686to 12,545' at 400 gpm, 1150 psi, 120 rpms, 13Kft-lbs, pulling speeds 20-30 fph as hole dictates. At 13,600' hole unloaded and blinded off shakers, Circulate hole clean staging up from 280 gpm to 400 gpm. PUW 156K, SOW 45K.;Cont. BROOH from 12,545to 10,955' at 400 gpm, 1050 psi, 120 rpms, 11 Kft-lbs, pulling speeds 20-40 fph as hole dictates. Max Gas 722U. PUW 135K, SOW 44K, ROT 95K.;BROOH from 10,955' to 8,018' at 450 gpm, 1050 psi, 120 rpms, 11 Kft-lbs, pulling speeds 5-30 fph as hole dictates; slow pulling speed at 9950', 8900', 8640'-8470' and 8100' due to erratic torque. PUW 133K, SOW 69K, ROTW 103K.;BROOH from 8,018' to 6,925' at 420 gpm, 1050 psi, 120 rpms, 7.5ft-lbs, pulling speeds 30 fph, slow to 10fpm at 7,855' due to erratic torque and pressure increase for 3 stands until hole cleans up. Pull BHA through shoe with no rotation, 10K overpull as bit entered shoe.;Pump tandem low vis/high vis sweep 10% increase in cuttings and circulate 2 x BU at 530 gpm , 1480 psi.;Blow down top drive and Geo-span. Service rig, grease blocks and top drive. Check gear and hyd oil levels. Grease crown. SimOps: Monitor well prior to pulling RCD bearing - static.;Remove MPD clamp and pull RCD element.; Daily hauled 1858 bbis to G&I total = 7,636 bbls Daily hauled 0 bbls from K2 lake, total 250 bbis Daily hauled 0 bbls from L-Pad, Total 1480 bbls Daily hauled 330 bbls from 6 mile creek total =4380 bbls Daily Fluid lost 0 bbls total = 0 bbls 1/2/2020 Monitor well (static). Pump dry job, B/D TDS. Drop drift on wire 2.42" OD. 102k up, 92k dn. POOH racking back 5" NC-50 DP F/ 6948'- T/ 4,402' MD.;POOH laying down NC-50 drill pipe F/ 4,402'- T/ BHA (275'). Monitor well @ BHA (static).;L/D BHA and download MWD. Bit grade 3-2-BT-A-X-1-WT- TD.;Rig up to RIH with 6-5/8" slotted liner. Rig up power tongs, C/O elevators, bring centralizers to rig floor, M/U safety joint.; M/U shoe joint and RIH with 6- 5/8", 20#, L-80, 563W slotted liner as per detail to 4,007'. M/U torque 7100 ft-lbs. PUW 79K, SOW 70K.;Cont to 6-5/8", 20#, L-80, 563W slotted liner as per detail from 4,007' to 8116'. M/U torque 7100 ft-lbs. PUW 120K, SOW 67K. Change out elevators.;M/U ball seat to hanger. M/U hanger. RIH with 2 stands and circulate to ensure clear 1 bpm, 62 psi; 3 bpm, 135 psi. BID top drive. Continue to RIH with 6-5/8" liner on drill pipe to 8724'.;Daily hauled 258 bbls to G&I total = 7,894 bbls Daily hauled 0 bbls from K2 lake, total 250 bbls Daily hauled 0 bbls from L-Pad, Total 1480 bbls Daily hauled 360 bbls from 6 mile creek total =4740 bbls IDaily Fluid lost 0 bbls total = 0 bbls 1/3/2020 C-ontinue.RlH w/ 6-5/8" 563 Wedge, 20#, 1 -80 slotted liner on 5" dp out of derrick F/ 8724'- T/ 11,971' MD. 156k up, 60k do @ 11,971' MD. Proper displacement. (60 stands out of derrick/ 168 stds total prior to trip).;Continue RIH F/ 11,971' - T/ 14,940' with 6-5/8" slotted liner on 95 jts NC-50 HWDP out of shed. P/U 2 jts 5" NC-50 drill pipe to landout with. 6 bbl loss for total liner trip.;Tag btm @ 14,940' MD w/ 15k do (274k up to break over to 255k up, 80k dn). Break circulation and staged up to 3 bpm/290 psi. Drop 29132" phenolic ball. Tag btm and P/U until string broke over putting liner on depth @ 14,940' MD in tension (TOL @ 6786.49').; Reduce pump rate @ 900 stks to 2 bpm/190 psi. Ball on seat @ 1456 stks (1463 stks calculated). Slowly increase psi to 2600 (psi fluctuation 100 psi) shifting pusher tool. Inc psi to 3k w/ 5 min hold. S/O to 125k. Park and psi up setting and releasing packer @4250 psi.;Observed slight pipe jump and psi fell off. LID 2 jts DP and 1 jt HWDP. R/U and test annulus against SI ZXP to 1500 psi w/ 10 min hold (chart and record same), Test good. 2 bbls pumped/ 2 bbls bled back (19 psi drop over 15 mins).;PJSM, Hang blocks. C/O leaking hydraulic hose on drawworks. Cut and slip drilling line.; POOH laying down DP and HWDP from 6766'. LID HRDE running tool. Cal hole fill 86 bbls, actual 103 bbls.;Clear and clean rig floor. Send out casing tongs. Load mule shoe and no-go. prep tongs for trip in hole. Get OD/ID and lengths.; RIH with 3-1/2" Muleshoe and No-Go from surface to 6823' (No-Go depth 6794) and tag up on depth with 10K. PUW 120K, SOW 97K. Calculated displacement.;Circulate bottoms up slowly pulling mule shoe out of top of liner at 425 gpm, 430 psi. Monitor well -static. Pump dryjob. BID top drive.; Last drilling report for M-26, switch to completion AFE.;Daily hauled 0 bbls to G&I total= 7,894 bbls Daily hauled 0 bbls from K2 lake, total 250 bbls Daily hauled 0 bbls from L-Pad, Total 1480 bbls Daily hauled 100 bbls from 6 mile creek total =4840 bbls Daily Fluid lost 25 bbls total = 25 bbls Hilcorp Energy Company Composite Report Well Name: MP M-26 Field: Milne Point County/State: North Slope Borough, Alaska (LAT/LONG): avation (RKB): API #: Spud Date: Job Name: 1915893C MPU M-26 Completion Contractor AFE #: AFE $: Activity Rate.: (Ips Summary 1/4/2020 Continue POOH laying down DP F/ 6794' - T/ surface. B/O and L/D 3.5" mule shoe with 8" NO GO. 8 bbl loss for total trip out.,Close blind rams and monitor well via kill/choke, Bleed down and isolate koomey lines to upper rams for system. Difficulty breaking bolts on BOP doors. C/O upper VBR's to 7" fixed body rams. R/U and test UPR's to 250/3000 psi w/ 5 min hold on each. Chart and record same. R/D and UD test tools.,Rig up power tongs. Break down 6-5/8" safety joint. Pick up landing joint and hanger. Dummy run hanger.,Continue to rig up to RIH with 7" casing, complete liner running checklist. C/O elevators, bring up slips, rig up torque turn. Strap and tally 5 additional joints - 169 joints in shed.,Service rig. Remove leaking hydraulic 'T' on top drive frame extend cylinder. Cap and plug lines. Sim Ops: Grease Crown and blocks..RIH with 7". 26#. L-80 TXP casing as per detail to 1228'_ Pick up seals and inspect. Test torque turn. M/U 1st joint to seals, overtorqued, check torque turn and change out bad cable. Break out joint, observe slight galling on pin end, box end is good. M/U TO 14750 ft -lbs. Slow running speed to displacing fluid overtop of stump. Calc disp 12, Act 7. PUW 60K, SOW 60K.,Cont. RIH with 7", 26#, L- 80 TXP casing as per detail from 1228' to 5358'. PUW 115K, SOW 94K. Stop at 2455' and pump heavy slug due to fluid running out top while running. Calculated displacement 51.2 bbls, actual 36.9 bbls.,Daily hauled 285 bbis to G&I total = 8,179 bbis �Q Daily hauled 0 bbis from K2 lake, total 250 bbis Daily hauled 0 bbis from L -Pad, Total 1480 bbls �v Daily hauled 130 bbis from 6 mile creek total =4970 bbis Daily Fluid lost 20 bbls total = 45 bbls 1/5/2020 Continue RIH w/ 7", TXP L-80, 26# tieback from 5358' to landout depth of 6794' MD. Set down 25k (verified 2x). Spaceout laying down 3 jts. P/U 14,84' pup jt and M/U #164. M/U hanger and landing jt. RIH and landout 1.15' off "No Go" w/ 48k on hanger. 136k up, 83k dn. Reduce annular psi to 450 psi. Close same. Psi up 75 on backside and strip up to locate 1" ports with psi drop + 8".,Establish circulation @ 5 bpm, 325 psi reverse circulating. 177k up w/ bag closed, 62k do w/ bag closed.,Reverse circulate displacing well over to clean 9.2 NaCl KCL @ 5 bpm, 315 FCP, pumped a total of 442 bbis followed by 75 bbis diesel to freeze protect 7" x 9-5/8" annulus.,S/O and landout on depth 6803' (btm of seal assy). Bleed down psi and open annular (static). B/O and remove landing joint. Dress with packoff and install same. Test packoff 500/5000 w/ 5/15 min hold (test good).,R/U and test 7" x 9-5/8" annulus to 1000 psi w/ 30 min hold. Chart and record same (test good). 1070 initial psi, 1040 psi 15 min, 1030 psi 30 min. Estimated 2 bbis pumped w/ test pump.,C/O UPR's from 7" SBR to 2-7/8" x 5.5" VBR's. Set test plug and test on 4-1/2" TJ. R/D, UD test joint. Blow down choke and kill Iines.,R/U to RIH with 4-1/2" upper completion. R/D 7" handling equipment, clear rig floor. Bring up cannon clamps, SLB job boxes, TEC line spooler, hang line in sheave in derrick. Put on 4-1/2" elevators.,RIH with 4-1/2", 12.6#, L-80 TXP completion as per detail to 1480'. M/U Tq 6170 ft -lbs. PUW 46K, SOW 46K. Calc displacement 5.4 bbis, Act. 1.8 bbls.,Cont. to RIH with 4-1/2", 12.6#, L-80 TXP completion as per detail from 1480' to 1808'. M/U 'XN' nipple, PHL packer, 'X' Nipple, SLB gauge mandrel, sliding sleeve, SLB gauge mandrel. Connect TEC wire to gauge mandrel and test gauge to 5000 psi - good.,Cont. to RIH with 4-1/2", 12.6#, L-80 TXP completion as per detail from 1808' to 3502'. Installing cannon clamps every joint. PUW 69K, SOW 57K.,Daily hauled 865 bbis to G&I total = 9,044 bbis Daily hauled 0 bbls from K2 lake, total 250 bbls Daily hauled 0 bbis from L -Pad, Total 1480 bbis Daily hauled 130 bbis from 6 mile creek total =5100 bbls Daily Fluid lost 17 bbis total = 62 bbls 1/6/2020 Continue RIH with 4.5" TXP, 12.6#, L-80 upper completion from 3,502' to 6,787' MD. M/U hanger w` blast pup. M/U landing jt. 97 cannon clamps, 1 mid tube clamp. 91 k up, 61 k dn. Tested control line every 1 hr during trip with no failures., Terminate SLB control line to hanger. Drain stack. S/O and landout on depth w/ 26k on hanger and final set depth of 6817' "LEG). Make final test on control line prior to landing out (test good). RILDS and L/D landing jt. Prep and remove extra 45 jts 4.5" from shed.,Clean and clear rig floor. R/D overhead sheaves and equipment. R/D Weatherford equipment and laydown same. All operations slowed from extreme cold weather (-40° F).,Blled off accumulator. Blow down hole fill line. Pull riser. Remove choke and kill lines. Remove Beyond high pressure lines, and drip pan.,Hook up cranes. Break nuts off DSA. Rack back BOP on pedestal and chain off. Remove DSA.,Bring in dry hole tree and dress. Feed TEC line through well head, test TEC line - good. N/U tree. Prep plumbing for reverse circulating and U -Tubing. SimOps: Attempt to pressure up tires, not holding pressure due to cold weather (-40). Replace tire seal, seal extremely stiff. Build hooch around motor mod. tires and heat.,Test tubing hanger voids 500/5000 psi - good. Rig up and test tree 500/5000 psi - good.,Pull BPV. Rig up to freeze protect well. Reverse circulate 90 bbis of diesel followed by 10 bbis of brine to clear lines at 2 bpm FCP 420 psi.,Rig up hoses and allow freeze protect to U-tube. Sim Ops: clean out cellar box. Clear tools off rig floor. Install bridle line dogs on top drive.,Daily hauled 114 bbls to G&I total = 9,128 bbls Daily hauled 0 bbis from K2 lake, total 250 bbis Daily hauled 0 bbis from L -Pad, Total 1480 bbls Daily hauled 130 bbis from 6 mile creek total =5100 bbls Daily Fluid lost 0 bbis total = 62 bbls 1/7/2020 Shut in well from "Ll" tube operations. Bleed down surface lines. Remove pump in cap. R/U to top of tree with lubricator extension (ball and rod installed inside w/ roller stern) and ball and rod held with master valve closed. Open master to closed system and dropped ball and rod. Closed master, R/D extension and M/U pump in cap to tree.,R/U to pump and monitor 4.5' tbg / IA (7" x 9-5/8" annulus). Chart and record same. Pressure up @ 1 bpm staging up to 3500 psi on tbg. Saw no indication of packer set (Pkr set pinned for 2250 psi). P/T tbg @ 3500 psi w/ 30 min hold (test good). Bleed down to 2000 psi on tbg. Pressure up 3500 on IA w/ 500 psi increase on tbg to 2500 psi. P/T against production pkr 3500 w/ 30 min hold (test good)., Bleed down IA to 0 psi. Bleed down tbg to 230 psi. R/D pump in equipment. M/U lubricator dressed with BPV. Install BPV, secure well.,RDMO. Finish cleaning pits. Blow down water. Perform TD EAM - C/O gear box oil and filter. Bridle up and scope down. Build hooch over catwalk and pipeshed tires and begin heating tires; tires not holding air due to stiff seals from cold weather. Continue filling warm tires under hooch in Gen Mod/Mud Mod. Changing seal as needed., disconnect interconnects; except air and steam. Prep landing with come-a-longs and straps. Set herculite and mats for sub on M-24. Continue heating and filling tires. Rig released from M-26 at 00:00. Next well M-24., Daily hauled 182 bbis to G&I total= 9,310 bbls Daily hauled 0 bbls from K2 lake, total 250 bbls Daily hauled 0 bbls from L-Pad, Total 1480 bbls Daily hauled 0 bbls from 6 mile creek total =5100 bbls Daily Fluid lost 0 bbls total = 62 bbls H i (corp Alaska, LLC Milne Point M Pt Moose Pad MPU M-26 500292365600 Sperry Drilling Definitive Survey Report 03 January, 2020 HALLIBURTON Sperry Drilling Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-26 Wellbore: MPU M-26 Design: MPU M-26 Halliburton Definitive Survey Report Local Co-ordinate Reference: Well MPU M-26 TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Map Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA )reject Milne Point, ACT, MILNE POINT nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point nap Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-26, Slot 10 Well Position +N/ -S 0.00 usft Northing: 6,027,889.58 usfi Latitude: 70° 29' 14.020 N +E/ -W 0.00 usft Easting: 533,423.92 usfi Longitude: 149° 43' 36.519 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 25.30 usft Wellbore MPU M-26 Magnetics Model Name Sample Date BGGM2018 12/30/2019 Design MPU M-26 Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (TVD) (usft) 26.15 Declination Dip Angle Field Strength (nT) 16.30 80.94 57,403.01219206 ACTUAL Tie On Depth: 12,726.52 +N/ -S +E/ -W Direction (usft) (usft) (°) 0.00 0.00 180.00 Survey Program Date 1/2/2020 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 198.24 785.09 MPU M-26PB1 SH Gyrodata GWD Gyro 3_Gyro-MWD70 H055Ga: Gyro-MWD70 11/18/2019 785.09 6,903.84 MPU M -26P61 SH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 11/26/2019 6,904.00 12,726.52 MPU M-26PB1 PH MWD+IR2+MS+Sag 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 12/24/2019 12,735.00 14,867.76 MPU M-26 PH MWD+IFR2+MS+Sag (3) 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 12/30/2019 Survey 1/3/2020 12:31:33PM Page 2 COMPASS 5000.15 Build 91E Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001) (ft) Survey Tool Name 26.15 0.00 0.00 26.15 -25.30 0.00 0.00 6,027,889.58 533,423.92 0.00 0.00 UNDEFINED 198.24 0.70 306.21 198.24 146.79 0.62 -0.85 6,027,890.20 533,423.07 0.41 -0.62 3_Gyro-MWD70 (1) 226.35 1.06 312.02 226.34 174.89 0.90 -1.18 6,027,890.47 533,422.74 1.32 -0.90 3_Gyro-MWD70 (1) 320.02 3.35 319.60 319.94 268.49 3.56 -3.60 6,027,893.12 533,420.31 2.46 -3.56 3_Gyro-MWD70 (1) 406.75 5.81 318.54 406.38 354.93 8.78 -8.15 6,027,898.32 533,415.73 2.84 -8.78 3_Gyro-MWD70(1) 503.81 8.19 313.25 502.71 451.26 17.20 -16.44 6,027,906.71 533,407.41 2.54 -17.20 3_Gyro-MWD70 (1) 597.31 11.54 306.03 594.82 543.37 27.27 -28.85 6,027,916.72 533,394.95 3.81 -27.27 3_Gyro-MWD70 (1) 689.69 15.07 300.21 684.71 633.26 38.75 -46.71 6,027,928.12 533,377.04 4.08 -38.75 3_Gyro-MWD70 (1) 785.09 18.85 295.81 775.95 724.50 51.71 -71.31 6,027,940.96 533,352.38 4.18 -51.71 3_Gyro-MWD70 (1) 887.93 21.37 295.35 872.51 821.06 66.96 -103.21 6,027,956.07 533,320.42 2.46 -66.96 3_MWD+IFR2+MS+Sag (2) 983.36 23.54 293.62 960.70 909.25 82.05 -136.39 6,027,971.00 533,287.18 2.38 -82.05 3_MWD+IFR2+MS+Sag (2) 1/3/2020 12:31:33PM Page 2 COMPASS 5000.15 Build 91E Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: MPU M-26 Wellbore: MPU M-26 Design: MPU M-26 Survey Halliburton Definitive Survey Report Local Co-ordinate Reference: Well MPU M-26 TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft North Reference: Map Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA Vertical Section (ft) Survey Tool Name -96.42 3_MWD+IFR2+MS+Sag (2) -109.91 3_MWD+IFR2+MS+Sag (2) -122.28 3_MWD+IFR2+MS+Sag (2) -133.75 3_MWD+IFR2+MS+Sag (2) -144.53 3_MWD+IFR2+MS+Sag (2) -154.12 3_MWD+IFR2+MS+Sag (2) -162.26 3_MWD+IFR2+MS+Sag (2) -170.25 3_MWD+IFR2+MS+Sag (2) -178.68 3_MWD+IFR2+MS+Sag (2) -185.94 3_MWD+IFR2+MS+Sag (2) -191.96 3_MWD+IFR2+MS+Sag (2) -197.86 3_MWD+IFR2+MS+Sag (2) -204.32 3_MWD+IFR2+MS+Sag (2) -212.85 3_MWD+IFR2+MS+Sag (2) -223.22 3_MWD+IFR2+MS+Sag (2) -233.70 3_MWD+IFR2+MS+Sag (2) -244.71 3_MWD+IFR2+MS+Sag (2) -255.55 3_MWD+IFR2+MS+Sag (2) -266.40 3_MWD+IFR2+MS+Sag (2) -277.34 3_MWD+IFR2+MS+Sag (2) -288.37 3_MWD+IFR2+MS+Sag (2) -298.84 3_MWD+IFR2+MS+Sag (2) -308.17 3_MWD+IFR2+MS+Sag (2) -316.31 3_MWD+IFR2+MS+Sag (2) -323.04 3_MWD+IFR2+MS+Sag (2) -330.00 3_MWD+IFR2+MS+Sag (2) -337.55 3_MWD+IFR2+MS+Sag (2) -345.68 3_MWD+IFR2+MS+Sag (2) -354.12 3_MWD+IFR2+MS+Sag (2) -362.50 3_MWD+IFR2+MS+Sag (2) -371.36 3_MWD+IFR2+MS+Sag (2) -378.29 3_MWD+IFR2+MS+Sag (2) -380.00 3_MWD+IFR2+MS+Sag (2) -375.74 3_MWD+IFR2+MS+Sag (2) -366.15 3_MWD+IFR2+MS+Sag (2) -350.55 3_MWD+IFR2+MS+Sag (2) -326.39 3_MWD+IFR2+MS+Sag (2) -295.43 3_MWD+IFR2+MS+Sag (2) -259.44 3_MWD+IFR2+MS+Sag (2) -219.36 3_MWD+IFR2+MS+Sag (2) 1/32020 12:31:33PM Page 3 COMPASS 5000.15 Build 91E Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') 1,078.83 24.82 289.65 1,047.80 996.35 96.42 -172.73 6,027,985.22 533,250.78 2.17 1,174.77 29.42 286.54 1,133.17 1,081.72 109.91 -214.30 6,027,998.52 533,209.15 5.02 1,269.99 34.36 282.26 1,214.01 1,162.56 122.28 -263.02 6,028,010.67 533,160.38 5.70 1,366.11 37.26 281.30 1,291.95 1,240.50 133.75 -318.07 6,028,021.88 533,105.29 3.07 1,460.72 41.02 279.57 1,365.32 1,313.87 144.53 -376.79 6,028,032.40 533,046.52 4.14 1,556.30 45.63 277.35 1,434.84 1,383.39 154.12 -441.64 6,028,041.70 532,981.63 5.08 1,651.33 50.11 275.98 1,498.57 1,447.12 162.26 -511.62 6,028,049.53 532,911.62 4.83 1,746.78 55.43 276.08 1,556.30 1,504.85 170.25 -587.17 6,028,057.17 532,836.04 5.57 1,842.58 59.15 275.94 1,608.06 1,556.61 178.68 -667.32 6,028,065.25 532,755.86 3.89 1,936.97 58.71 274.36 1,656.77 1,605.32 185.94 -747.84 6,028,072.14 532,675.32 1.51 2,032.92 60.12 273.99 1,705.59 1,654.14 191.96 -830.22 6,028,077.78 532,592.93 1.51 2,126.78 60.24 274.32 1,752.27 1,700.82 197.86 -911.44 6,028,083.32 532,511.69 0.33 2,221.50 61.78 274.63 1,798.17 1,746.72 204.32 -994.04 6,028,089.41 532,429.07 1.65 2,316.90 61.38 277.04 1,843.58 1,792.13 212.85 -1,077.50 6,028,097.56 532,345.58 2.26 2,412.56 60.51 277.21 1,890.04 1,838.59 223.22 -1,160.47 6,028,107.56 532,262.57 0.92 2,508.43 61.49 277.15 1,936.52 1,885.07 233.70 -1,243.66 6,028,117.66 532,179.34 1.02 2,604.08 60.86 277.95 1,982.63 1,931.18 244.71 -1,326.73 6,028,128.30 532,096.23 0.99 2,698.88 62.10 277.01 2,027.90 1,976.45 255.55 -1,409.32 6,028,138.76 532,013.61 1.57 2,793.76 61.28 277.93 2,072.89 2,021.44 266.40 -1,492.14 6,028,149.25 531,930.75 1.21 2,888.87 61.42 277.13 2,118.49 2,067.04 277.34 -1,574.88 6,028,159.81 531,847.96 0.75 2,983.53 60.70 278.18 2,164.30 2,112.85 288.37 -1,656.98 6,028,170.47 531,765.82 1.23 3,079.36 60.64 276.21 2,211.24 2,159.79 298.84 -1,739.87 6,028,180.56 531,682.90 1.79 3,174.96 60.14 276.69 2,258.48 2,207.03 308.17 -1,822.45 6,028,189.53 531,600.28 0.68 3,269.53 60.93 274.66 2,305.00 2,253.55 316.31 -1,904.38 6,028,197.29 531,518.32 2.05 3,365.14 60.91 274.58 2,351.47 2,300.02 323.04 -1,987.67 6,028,203.65 531,435.02 0.08 3,460.25 60.62 275.04 2,397.92 2,346.47 330.00 -2,070.37 6,028,210.24 531,352.29 0.52 3,555.02 58.91 275.55 2,445.64 2,394.19 337.55 -2,151.90 6,028,217.42 531,270.74 1.86 3,650.46 58.51 275.89 2,495.21 2,443.76 345.68 -2,233.05 6,028,225.18 531,189.56 0.52 3,746.16 58.93 275.96 2,544.90 2,493.45 354.12 -2,314.40 6,028,233.26 531,108.18 0.44 3,840.26 58.64 276.00 2,593.67 2,542.22 362.50 -2,394.44 6,028,241.28 531,028.11 0.31 3,935.24 59.20 276.50 2,642.70 2,591.25 371.36 -2,475.30 6,028,249.78 530,947.22 0.74 4,030.27 59.39 273.23 2,691.23 2,639.78 378.29 -2,556.70 6,028,256.34 530,865.80 2.97 4,125.88 59.27 269.15 2,740.02 2,688.57 380.00 -2,638.89 6,028,257.68 530,783.61 3.67 4,220.78 58.13 264.81 2,789.34 2,737.89 375.74 -2,719.83 6,028,253.06 530,702.69 4.09 4,315.80 59.74 261.67 2,838.38 2,786.93 366.15 -2,800.64 6,028,243.10 530,621.94 3.30 4,410.00 62.32 256.56 2,884.02 2,832.57 350.55 -2,881.52 6,028,227.14 530,541.14 5.48 4,505.39 62.67 250.25 2,928.11 2,876.66 326.39 -2,962.54 6,028,202.62 530,460.24 5.88 4,600.45 63.23 246.85 2,971.35 2,919.90 295.43 -3,041.32 6,028,171.31 530,381.61 3.24 4,696.14 63.70 243.42 3,014.11 2,962.66 259.44 -3,118.97 6,028,134.98 530,304.12 3.24 4,791.27 62.81 240.26 3,056.93 3,005.48 219.36 -3,193.86 6,028,094.57 530,229.42 3.11 Vertical Section (ft) Survey Tool Name -96.42 3_MWD+IFR2+MS+Sag (2) -109.91 3_MWD+IFR2+MS+Sag (2) -122.28 3_MWD+IFR2+MS+Sag (2) -133.75 3_MWD+IFR2+MS+Sag (2) -144.53 3_MWD+IFR2+MS+Sag (2) -154.12 3_MWD+IFR2+MS+Sag (2) -162.26 3_MWD+IFR2+MS+Sag (2) -170.25 3_MWD+IFR2+MS+Sag (2) -178.68 3_MWD+IFR2+MS+Sag (2) -185.94 3_MWD+IFR2+MS+Sag (2) -191.96 3_MWD+IFR2+MS+Sag (2) -197.86 3_MWD+IFR2+MS+Sag (2) -204.32 3_MWD+IFR2+MS+Sag (2) -212.85 3_MWD+IFR2+MS+Sag (2) -223.22 3_MWD+IFR2+MS+Sag (2) -233.70 3_MWD+IFR2+MS+Sag (2) -244.71 3_MWD+IFR2+MS+Sag (2) -255.55 3_MWD+IFR2+MS+Sag (2) -266.40 3_MWD+IFR2+MS+Sag (2) -277.34 3_MWD+IFR2+MS+Sag (2) -288.37 3_MWD+IFR2+MS+Sag (2) -298.84 3_MWD+IFR2+MS+Sag (2) -308.17 3_MWD+IFR2+MS+Sag (2) -316.31 3_MWD+IFR2+MS+Sag (2) -323.04 3_MWD+IFR2+MS+Sag (2) -330.00 3_MWD+IFR2+MS+Sag (2) -337.55 3_MWD+IFR2+MS+Sag (2) -345.68 3_MWD+IFR2+MS+Sag (2) -354.12 3_MWD+IFR2+MS+Sag (2) -362.50 3_MWD+IFR2+MS+Sag (2) -371.36 3_MWD+IFR2+MS+Sag (2) -378.29 3_MWD+IFR2+MS+Sag (2) -380.00 3_MWD+IFR2+MS+Sag (2) -375.74 3_MWD+IFR2+MS+Sag (2) -366.15 3_MWD+IFR2+MS+Sag (2) -350.55 3_MWD+IFR2+MS+Sag (2) -326.39 3_MWD+IFR2+MS+Sag (2) -295.43 3_MWD+IFR2+MS+Sag (2) -259.44 3_MWD+IFR2+MS+Sag (2) -219.36 3_MWD+IFR2+MS+Sag (2) 1/32020 12:31:33PM Page 3 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-26 Project: Milne Point TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Site: M Pt Moose Pad MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Well: -MPU M-26 North Reference: "True Wellbore: MPU M-26 Survey Calculation Method: Minimum Curvature Design: MPU M-26 Database: NORTH US + CANADA Survey 1/3202012:31:33PM Page 4 COMPASS 5000.15 Build 91E Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,886.81 63.23 235.13 3,100.29 3,048.84 173.88 -3,265.79 6,028,048.76 530,157.71 4.80 -173.88 3 MWD+IFR2+MS+Sag (2) 4,982.03 63.64 229.55 3,142.91 3,091.46 121.86 -3,333.17 6,027,996.45 530,090.57 5.26 -121.86 3_MWD+IFR2+MS+Sag (2) 5,077.58 64.40 224.36 3,184.78 3,133.33 63.25 -3,395.90 6,027,937.57 530,028.10 4.95 -63.25 3_MWD+IFR2+MS+Sag (2) 5,172.83 66.17 220.07 3,224.62 3,173.17 -0.82 -3,454.00 6,027,873.24 529,970.30 4.49 0.82 3_MWD+IFR2+MS+Sag (2) 5,268.96 67.51 216.74 3,262.44 3,210.99 -70.08 -3,508.88 6,027,803.74 529,915.73 3.48 70.08 3_MWD+IFR2+MS+Sag (2) 5,364.00 68.58 215.41 3,297.97 3,246.52 -141.32 -3,560.78 6,027,732.27 529,864.16 1.72 141.32 3_MWD+IFR2+MS+Sag (2) 5,458.87 70.87 213.34 3,330.85 3,279.40 -214.77 -3,611.01 6,027,658.61 529,814.27 3.16 214.77 3_MWD+IFR2+MS+Sag (2) 5,554.94 70.41 211.77 3,362.70 3,311.25 -291.16 -3,659.78 6,027,582.01 529,765.84 1.61 291.16 3_MWD+IFR2+MS+Sag (2) 5,649.45 72.84 208.55 3,392.50 3,341.05 -368.70 -3,704.82 6,027,504.27 529,721.16 4.13 368.70 3_MWD+IFR2+MS+Sag (2) 5,745.13 74.12 205.41 3,419.71 3,368.26 -450.44 -3,746.42 6,027,422.36 529,679.93 3.42 450.44 3_MWD+IFR2+MS+Sag (2) 5,839.77 76.98 201.24 3,443.33 3,391.88 -534.57 -3,782.68 6,027,338.07 529,644.06 5.23 534.57 3_MWD+IFR2+MS+Sag (2) 5,939.39 83.44 195.36 3,460.28 3,408.83 -627.70 -3,813.42 6,027,244.81 529,613.73 8.71 627.70 3_MWD+IFR2+MS+Sag (2) 6,031.15 86.48 191.11 3,468.34 3,416.89 -716.65 -3,834.34 6,027,155.78 529,593.22 5.68 716.65 3_MWD+IFR2+MS+Sag (2) 6,126.85 88.39 187.60 3,472.62 3,421.17 -810.96 -3,849.87 6,027,061.41 529,578.11 4.17 810.96 3_MWD+IFR2+MS+Sag (2) 6,221.65 87.10 184.02 3,476.36 3,424.91 -905.18 -3,859.46 6,026,967.15 529,568.95 4.01 905.18 3_MWD+IFR2+MS+Sag (2) 6,317.04 83.19 180.83 3,484.43 3,432.98 -1,000.11 -3,863.49 6,026,872.21 529,565.35 5.28 1,000.11 3_MWD+IFR2+MS+Sag (2) 6,408.27 80.83 181.07 3,497.11 3,445.66 -1,090.44 -3,864.99 6,026,781.89 529,564.25 2.60 1,090.44 3_MWD+IFR2+MS+Sag (2) 6,507.36 78.70 178.75 3,514.72 3,463.27 -1,187.94 -3,864.84 6,026,684.40 529,564.84 3.15 1,187.94 3_MWD+IFR2+MS+Sag (2) 6,601.98 77.24 178.64 3,534.44 3,482.99 -1,280.46 -3,862.73 6,026,591.90 529,567.36 1.55 1,280.46 3_MWD+IFR2+MS+Sag (2) 6,697.77 79.77 179.64 3,553.53 3,502.08 -1,374.31 -3,861.33 6,026,498.07 529,569.19 2.83 1,374.31 3_MWD+IFR2+MS+Sag (2) 6,793.31 82.52 181.46 3,568.23 3,516.78 -1,468.69 -3,862.24 6,026,403.69 529,568.70 3.44 1,468.69 3_MWD+IFR2+MS+Sag (2) 6,885.87 82.89 182.34 3,579.99 3,528.54 -1,560.45 -3,865.28 6,026,311.93 529,566.07 1.02 1,560.45 3_MWD+IFR2+MS+Sag (2) 6,903.84 83.70 182.80 3,582.08 3,530.63 -1,578.28 -3,866.08 6,026,294.10 529,565.35 5.18 1,578.28 3_MWD+IFR2+MS+Sag (3) 6,975.69 85.98 184.03 3,588.55 3,537.10 -1,649.70 -3,870.35 6,026,222.66 529,561.41 3.60 1,649.70 3_MWD+IFR2+MS+Sag (3) 7,003.51 86.42 183.76 3,590.39 3,538.94 -1,677.40 -3,872.23 6,026,194.96 529,559.65 1.85 1,677.40 3_MWD+IFR2+MS+Sag (3) 7,067.33 87.59 183.94 3,593.72 3,542.27 -1,740.98 -3,876.51 6,026,131.36 529,555.65 1.85 1,740.98 3_MWD+IFR2+MS+Sag (3) 7,131.08 87.53 183.57 3,596.44 3,544.99 -1,804.54 -3,880.68 6,026,067.80 529,551.77 0.59 1,804.54 3_MWD+IFR2+MS+Sag (3) 7,195.15 86.72 183.93 3,599.65 3,548.20 -1,868.39 -3,884.87 6,026,003.93 529,547.87 1.38 1,868.39 3_MWD+IFR2+MS+Sag (3) 7,256.25 87.59 183.57 3,602.68 3,551.23 -1,929.29 -3,888.86 6,025,943.03 529,544.15 1.54 1,929.29 3_MWD+IFR2+MS+Sag (3) 7,322.49 87.65 183.01 3,605.44 3,553.99 -1,995.36 -3,892.66 6,025,876.95 529,540.65 0.85 1,995.36 3_MWD+IFR2+MS+Sag (3) 7,383.30 88.08 182.35 3,607.70 3,556.25 -2,056.06 -3,895.50 6,025,816.24 529,538.09 1.29 2,056.06 3_MWD+IFR2+MS+Sag (3) 7,449.53 87.52 181.67 3,610.24 3,558.79 -2,122.20 -3,897.82 6,025,750.10 529,536.06 1.33 2,122.20 3_MWD+IFR2+MS+Sag (3) 7,512.71 88.89 179.95 3,612.22 3,560.77 -2,185.34 -3,898.71 6,025,686.96 529,535.45 3.48 2,185.34 3_MWD+IFR2+MS+Sag (3) 7,576.02 90.43 178.88 3,612.60 3,561.15 -2,248.64 -3,898.07 6,025,623.67 529,536.38 2.96 2,248.64 3_MWD+IFR2+MS+Sag (3) 7,639.93 91.54 177.74 3,611.50 3,560.05 -2,312.51 -3,896.18 6,025,559.81 529,538.55 2.49 2,312.51 3_MWD+IFR2+MS+Sag (3) 7,703.32 92.97 176.89 3,609.00 3,557.55 -2,375.78 -3,893.21 6,025,496.56 529,541.81 2.62 2,375.78 3_MWD+IFR2+MS+Sag (3) 7,767.22 93.09 176.82 3,605.63 3,554.18 -2,439.50 -3,889.71 6,025,432.87 529,545.59 0.22 2,439.50 3_MWD+IFR2+MS+Sag (3) 7,830.66 93.27 177.23 3,602.11 3,550.66 -2,502.75 -3,886.43 6,025,369.64 529,549.16 0.70 2,502.75 3_MWD+IFR2+MS+Sag (3) 7,893.92 93.89 177.87 3,598.16 3,546.71 -2,565.83 -3,883.73 6,025,306.58 529,552.15 1.41 2,565.83 3_MWD+IFR2+MS+Sag (3) 7,957.01 94.94 178.90 3,593.30 3,541.85 -2,628.71 -3,881.95 6,025,243.71 529,554.20 2.33 2,628.71 3_MWD+IFR2+MS+Sag (3) 1/3202012:31:33PM Page 4 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-26 Project: Milne Point TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Site: M Pt Moose Pad MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Well: MPU M-26 North Reference: "'True Wellbore: MPU M-26 Survey Calculation Method: Minimum Curvature Design: MPU M-26 Database: NORTH US + CANADA Survey 1/32020 12:31:33PM Page 5 COMPASS 5000.15 Build 91E Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (-1100`) (ft) Survey Tool Name - 8,021.32 94.94 180.34 3,587.76 3,536.31 -2,692.77 -3,881.53 6,025,179.66 529,554.91 2.23 2,692.77 3 MWD+IFR2+MS+Sag (3) 8,085.08 96.00 180.22 3,581.69 3,530.24 -2,756.24 -3,881.84 6,025,116.19 529,554.89 1.67 2,756.24 3_MWD+IFR2+MS+Sag (3) 8,148.42 97.24 179.69 3,574.38 3,522.93 -2,819.16 -3,881.79 6,025,053.28 529,555.22 2.13 2,819.16 3_MWD+IFR2+MS+Sag (3) 8,211.95 96.68 179.63 3,566.68 3,515.23 -2,882.22 -3,881.42 6,024,990.23 529,555.88 0.89 2,882.22 3_MWD+IFR2+MS+Sag (3) 8,274.99 95.56 179.71 3,559.96 3,508.51 -2,944.90 -3,881.05 6,024,927.56 529,556.52 1.78 2,944.90 3_MWD+IFR2+MS+Sag (3) 8,338.78 93.76 179.49 3,554.78 3,503.33 -3,008.47 -3,880.61 6,024,864.00 529,557.25 2.84 3,008.47 3_MWD+IFR2+MS+Sag (3) 8,402.48 92.71 179.92 3,551.19 3,499.74 -3,072.07 -3,880.28 6,024,800.41 529,557.86 1.78 3,072.07 3_MWD+IFR2+MS+Sag (3) 8,465.64 92.96 180.24 3,548.06 3,496.61 -3,135.15 -3,880.37 6,024,737.33 529,558.06 0.64 3,135.15 3_MWD+IFR2+MS+Sag (3) 8,529.31 90.92 180.73 3,545.91 3,494.46 -3,198.78 -3,880.91 6,024,673.71 529,557.81 3.30 3,198.78 3_MWD+IFR2+MS+Sag (3) 8,592.12 89.06 181.27 3,545.92 3,494.47 -3,261.58 -3,882.01 6,024,610.91 529,556.99 3.08 3,261.58 3_MWD+IFR2+MS+Sag (3) 8,654.84 89.38 181.08 3,546.77 3,495.32 -3,324.28 -3,883.29 6,024,548.21 529,555.99 0.59 3,324.28 3_MWD+IFR2+MS+Sag (3) 8,718.54 91.05 181.88 3,546.53 3,495.08 -3,387.95 -3,884.94 6,024,484.54 529,554.63 2.91 3,387.95 3_MWD+IFR2+MS+Sag (3) 8,779.09 91.79 182.60 3,545.03 3,493.58 -3,448.44 -3,887.30 6,024,424.05 529,552.54 1.70 3,448.44 3_MWD+IFR2+MS+Sag (3) 8,842.52 89.87 180.21 3,544.11 3,492.66 -3,511.83 -3,888.86 6,024,360.65 529,551.27 4.83 3,511.83 3_MWD+IFR2+MS+Sag (3) 8,905.03 88.57 176.44 3,544.97 3,493.52 -3,574.30 -3,887.03 6,024,298.20 529,553.37 6.38 3,574.30 3_MWD+IFR2+MS+Sag (3) 8,973.90 88.82 175.05 3,546.53 3,495.08 -3,642.96 -3,881.92 6,024,229.57 529,558.79 2.05 3,642.96 3_MWD+IFR2+MS+Sag (3) 9,037.18 91.73 175.32 3,546.23 3,494.78 -3,706.01 -3,876.61 6,024,166.55 529,564.38 4.62 3,706.01 3_MWD+IFR2+MS+Sag (3) 9,100.85 93.52 176.29 3,543.31 3,491.86 -3,769.44 -3,871.96 6,024,103.15 529,569.32 3.20 3,769.44 3_MWD+IFR2+MS+Sag (3) 9,164.36 92.27 175.44 3,540.11 3,488.66 -3,832.70 -3,867.39 6,024,039.92 529,574.18 2.38 3,832.70 3_MWD+IFR2+MS+Sag (3) 9,228.12 93.03 177.51 3,537.16 3,485.71 -3,896.27 -3,863.47 6,023,976.37 529,578.38 3.46 3,896.27 3_MWD+IFR2+MS+Sag (3) 9,291.85 94.01 179.00 3,533.25 3,481.80 -3,959.85 -3,861.53 6,023,912.81 529,580.60 2.79 3,959.85 3_MWD+IFR2+MS+Sag (3) 9,355.39 92.65 180.51 3,529.55 3,478.10 -4,023.27 -3,861.26 6,023,849.39 529,581.16 3.20 4,023.27 3_MWD+IFR2+MS+Sag (3) 9,419.38 92.34 181.99 3,526.77 3,475.32 4,087.19 -3,862.66 6,023,785.48 529,580.05 2.36 4,087.19 3_MWD+IFR2+MS+Sag (3) 9,482.87 90.49 183.27 3,525.20 3,473.75 -4,150.59 -3,865.57 6,023,722.07 529,577.42 3.54 4,150.59 3_MWD+IFR2+MS+Sag (3) 9,547.04 90.12 182.93 3,524.86 3,473.41 -4,214.66 -3,869.04 6,023,657.99 529,574.24 0.78 4,214.66 3_MWD+IFR2+MS+Sag (3) 9,610.90 89.13 182.17 3,525.28 3,473.83 -4,278.46 -3,871.88 6,023,594.19 529,571.69 1.95 4,278.46 3_MWD+IFR2+MS+Sag (3) 9,673.84 90.62 181.55 3,525.41 3,473.96 -4,341.36 -3,873.92 6,023,531.28 529,569.93 2.56 4,341.36 3_MWD+IFR2+MS+Sag (3) 9,737.36 90.61 180.34 3,524.73 3,473.28 -4,404.87 -3,874.97 6,023,467.78 529,569.17 1.90 4,404.87 3_MWD+IFR2+MS+Sag (3) 9,801.17 91.29 180.60 3,523.68 3,472.23 -4,468.67 -3,875.49 6,023,403.99 529,568.93 1.14 4,468.67 3_MWD+IFR2+MS+Sag (3) 9,864.86 91.85 181.93 3,521.93 3,470.48 -4,532.31 -3,876.90 6,023,340.34 529,567.81 2.27 4,532.31 3_MWD+IFR2+MS+Sag (3) 9,928.69 92.28 182.63 3,519.63 3,468.18 -4,596.05 -3,879.44 6,023,276.59 529,565.56 1.29 4,596.05 3_MWD+IFR2+MS+Sag (3) 9,992.01 93.39 184.14 3,516.50 3,465.05 -4,659.18 -3,883.17 6,023,213.46 529,562.11 2.96 4,659.18 3_MWD+IFR2+MS+Sag (3) 10,055.99 94.76 185.03 3,511.95 3,460.50 -4,722.79 -3,888.27 6,023,149.83 529,557.30 2.55 4,722.79 3_MWD+IFR2+MS+Sag (3) 10,119.42 96.75 185.01 3,505.59 3,454.14 -4,785.66 -3,893.79 6,023,086.94 529,552.06 3.14 4,785.66 3_MWD+IFR2+MS+Sag (3) 10,183.59 96.31 184.44 3,498.29 3,446.84 -4,849.19 -3,899.04 6,023,023.39 529,547.09 1.12 4,849.19 3_MWD+IFR2+MS+Sag (3) 10,247.40 95.19 183.52 3,491.90 3,440.45 -4,912.53 -3,903.45 6,022,960.04 529,542.97 2.27 4,912.53 3_MWD+IFR2+MS+Sag (3) 10,310.69 93.52 182.94 3,487.09 3,435.64 -4,975.53 -3,907.01 6,022,897.03 529,539.70 2.79 4,975.53 3_MWD+IFR2+MS+Sag (3) 10,374.56 92.09 181.61 3,483.97 3,432.52 -5,039.27 -3,909.54 6,022,833.29 529,537.45 3.06 5,039.27 3_MWD+IFR2+MS+Sag (3) 10,438.18 90.61 181.22 3,482.47 3,431.02 -5,102.85 -3,911.11 6,022,769.70 529,536.17 2.41 5,102.85 3_MWD+IFR2+MS+Sag (3) 10,502.22 89.44 180.12 3,482.44 3,430.99 -5,166.89 -3,911.86 6,022,705.68 529,535.71 2.51 5,166.89 3_MWD+IFR2+MS+Sag (3) 1/32020 12:31:33PM Page 5 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU W26 Project: Milne Point TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Site: M Pt Moose Pad MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Well: MPU M-26 North-Refetence: ""---- -True " Wellbore: MPU M-26 Survey Calculation Method: Minimum Curvature Design: MPU M-26 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,565.30 88.76 180.00 3,483.43 3,431.98 -5,229.96 -3,911.92 6,022,642.61 529,535.93 1.09 5,229.96 3 MWD+IFR2+MS+Sag (3) 10,629.49 87.59 179.55 3,485.48 3,434.03 -5,294.12 -3,911.67 6,022,578.46 529,536.47 1.95 5,294.12 3_MWD+IFR2+MS+Sag (3) 10,692.47 87.65 178.89 3,488.09 3,436.64 -5,357.03 -3,910.81 6,022,515.55 529,537.60 1.05 5,357.03 3_MWD+IFR2+MS+Sag (3) 10,755.30 88.58 180.84 3,490.16 3,438.71 -5,419.83 -3,910.67 6,022,452.77 529,538.03 3.44 5,419.83 3_MWD+IFR2+MS+Sag (3) 10,818.80 88.27 182.07 3,491.91 3,440.46 -5,483.28 -3,912.28 6,022,389.31 529,536.71 2.00 5,483.28 3_MWD+IFR2+MS+Sag (3) 10,883.41 87.40 182.26 3,494.35 3,442.90 -5,547.80 -3,914.72 6,022,324.79 529,534.56 1.38 5,547.80 3_MWD+IFR2+MS+Sag (3) 10,947.12 87.21 182.33 3,497.34 3,445.89 -5,611.39 -3,917.27 6,022,261.20 529,532.30 0.32 5,611.39 3_MWD+IFR2+MS+Sag (3) 11,010.99 88.52 181.67 3,499.72 3,448.27 -5,675.17 -3,919.49 6,022,197.41 529,530.36 2.30 5,675.17 3_MWD+IFR2+MS+Sag(3) 11,075.44 89.07 182.23 3,501.08 3,449.63 -5,739.57 -3,921.69 6,022,133.01 529,528.45 1.22 5,739.57 3_MWD+IFR2+MS+Sag (3) 11,138.61 89.32 181.78 3,501.96 3,450.51 -5,802.69 -3,923.90 6,022,069.88 529,526.53 0.81 5,802.69 3_MWD+IFR2+MS+Sag (3) 11,202.03 89.75 181.83 3,502.48 3,451.03 -5,866.08 -3,925.89 6,022,006.50 529,524.81 0.68 5,866.08 3_MWD+IFR2+MS+Sag(3) 11,265.66 90.12 181.80 3,502.55 3,451.10 -5,929.68 -3,927.91 6,021,942.89 529,523.09 0.58 5,929.68 3_MWD+IFR2+MS+Sag (3) 11,328.78 90.68 182.31 3,502.11 3,450.66 -5,992.76 -3,930.17 6,021,879.81 529,521.11 1.20 5,992.76 3_MWD+IFR2+MS+Sag (3) 11,392.50 90.92 182.17 3,501.22 3,449.77 -6,056.42 -3,932.66 6,021,816.14 529,518.90 0.44 6,056.42 3_MWD+IFR2+MS+Sag (3) 11,456.18 91.23 182.95 3,500.03 3,448.58 -6,120.03 -3,935.51 6,021,752.53 529,516.34 1.32 6,120.03 3_MWD+IFR2+MS+Sag (3) 11,519.18 90.67 181.59 3,498.98 3,447.53 -6,182.97 -3,938.00 6,021,689.59 529,514.13 2.33 6,182.97 3_MWD+IFR2+MS+Sag (3) 11,581.52 90.24 178.84 3,498.49 3,447.04 -6,245.30 -3,938.23 6,021,627.26 529,514.18 4.46 6,245.30 3_MWD+IFR2+MS+Sag (3) 11,645.86 90.31 177.35 3,498.18 3,446.73 -6,309.60 -3,936.10 6,021,562.98 529,516.61 2.32 6,309.60 3_MWD+IFR2+MS+Sag (3) 11,710.25 90.49 177.07 3,497.73 3,446.28 -6,373.91 -3,932.96 6,021,498.69 529,520.03 0.52 6,373.91 3_MWD+IFR2+MS+Sag(3) 11,773.95 90.43 177.58 3,497.22 3,445.77 -6,437.54 -3,929.99 6,021,435.08 529,523.29 0.81 6,437.54 3_MWD+IFR2+MS+Sag (3) 11,837.98 89.19 177.96 3,497.43 3,445.98 -6,501.52 -3,927.50 6,021,371.12 529,526.07 2.03 6,501.52 3_MWD+IFR2+MS+Sag (3) 11,901.14 89.44 178.97 3,498.18 3,446.73 -6,564.65 -3,925.81 6,021,308.00 529,528.04 1.65 6,564.65 3_MWD+IFR2+MS+Sag (3) 11,964.79 89.44 179.26 3,498.81 3,447.36 -6,628.29 -3,924.82 6,021,244.37 529,529.31 0.46 6,628.29 3_MWD+IFR2+MS+Sag(3) 12,027.99 91.24 180.14 3,498.43 3,446.98 -6,691.49 -3,924.49 6,021,181.19 529,529.93 3.17 6,691.49 3_MWD+IFR2+MS+Sag (3) 12,090.91 93.21 179.50 3,495.99 3,444.54 -6,754.35 -3,924.29 6,021,118.33 529,530.41 3.29 6,754.35 3_MWD+IFR2+MS+Sag (3) 12,155.21 94.70 179.33 3,491.55 3,440.10 -6,818.50 -3,923.64 6,021,054.19 529,531.35 2.33 6,818.50 3_MWD+IFR2+MS+Sag (3) 12,219.55 94.38 178.90 3,486.46 3,435.01 -6,882.63 -3,922.65 6,020,990.07 529,532.63 0.83 6,882.63 3_MWD+IFR2+MS+Sag (3) 12,282.90 92.21 179.18 3,482.82 3,431.37 -6,945.86 -3,921.59 6,020,926.85 529,533.97 3.45 6,945.86 3_MWD+IFR2+MS+Sag (3) 12,346.17 89.99 177.76 3,481.60 3,430.15 -7,009.09 -3,919.90 6,020,863.64 529,535.94 4.16 7,009.09 3_MWD+IFR2+MS+Sag (3) 12,410.12 90.06 176.07 3,481.58 3,430.13 -7,072.94 -3,916.46 6,020,799.81 529,539.67 2.64 7,072.94 3_MWD+IFR2+MS+Sag (3) 12,473.53 91.29 176.77 3,480.83 3,429.38 -7,136.22 -3,912.50 6,020,736.55 529,543.91 2.23 7,136.22 3_MWD+IFR2+MS+Sag (3) 12,537.17 92.22 177.16 3,478.88 3,427.43 -7,199.74 -3,909.13 6,020,673.05 529,547.57 1.58 7,199.74 3_MWD+IFR2+MS+Sag (3) 12,600.99 93.21 178.98 3,475.86 3,424.41 -7,263.45 -3,906.98 6,020,609.36 529,550.00 3.24 7,263.45 3_MWD+IFR2+MS+Sag (3) 12,663.28 93.15 179.38 3,472.40 3,420.95 -7,325.64 -3,906.09 6,020,547.18 529,551.17 0.65 7,325.64 3_MWD+IFR2+MS+Sag (3) 12,726.52 92.71 179.71 3,469.17 3,417.72 -7,388.80 -3,905.59 6,020,484.04 529,551.96 0.87 7,388.80 3_MWD+IFR2+MS+Sag (3) 12,735.00 92.82 179.92 3,468.76 3,417.31 -7,397.27 -3,905.57 6,020,475.57 529,552.02 2.79 7,397.27 3_MWD+IFR2+MS+Sag (4) 12,790.44 91.04 180.25 3,466.89 3,415.44 -7,452.67 -3,905.65 6,020,420.17 529,552.19 3.27 7,452.67 3_MWD+IFR2+MS+Sag (4) 12,854.16 89.74 180.04 3,466.46 3,415.01 -7,516.39 -3,905.81 6,020,356.46 529,552.31 2.07 7,516.39 3_MWD+IFR2+MS+Sag (4) 12,917.96 89.57 180.17 3,466.84 3,415.39 -7,580.19 -3,905.93 6,020,292.66 529,552.48 0.34 7,580.19 3_MWD+IFR2+MS+Sag (4) 12,981.54 87.58 180.22 3,468.42 3,416.97 -7,643.74 -3,906.14 6,020,229.11 529,552.55 3.13 7,643.74 3_MWD+IFR2+MS+Sag (4) 1/312020 12.31:33PM Page 6 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU K26 Project: Milne Point TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Site: M Pt Moose Pad MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft -Well:. __-__.._..._.MPU M-26 North Reference: "True Wellbore: MPU M-26 Survey Calculation Method: Minimum Curvature Design: MPU M-26 Database: NORTH US + CANADA Survey 1111y 1�l by B -1 -in Hand Checked By: Chelsea Wrightoae2,2,..l 308807°2x00' Approved By: Benjamin Hand Da 2,20.O1e0608:4534-09'00. Date: 01-03-2020 1/32020 12:31:33PM Page 7 COMPASS 5000.15 Build 91E Map Map Vertical MD Inc Azi TVD TVDSS +N1 -S +E/ -W Northing Easting DLS Section (usft) (1) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,045.09 87.77 180.24 3,471.00 3,419.55 -7,707.24 -3,906.40 6,020,165.62 529,552.58 0.30 7,707.24 3 MWD+IFR2+MS+Sag (4) 13,108.94 89.82 180.48 3,472.35 3,420.90 -7,771.07 -3,906.80 6,020,101.80 529,552.47 3.23 7,771.07 3_MWD+IFR2+MS+Sag (4) 13,172.36 92.17 182.71 3,471.24 3,419.79 -7,834.45 -3,908.56 6,020,038.42 529,550.99 5.11 7,834.45 3_MWD+IFR2+MS+Sag (4) 13,235.18 90.86 182.22 3,469.58 3,418.13 -7,897.19 -3,911.26 6,019,975.67 529,548.57 2.23 7,897.19 3_MWD+IFR2+MS+Sag (4) 13,299.36 91.17 182.75 3,468.45 3,417.00 -7,961.30 -3,914.05 6,019,911.56 529,546.08 0.96 7,961.30 3_MWD+IFR2+MS+Sag (4) 13,363.34 90.98 182.12 3,467.25 3,415.80 -8,025.21 -3,916.76 6,019,847.64 529,543.65 1.03 8,025.21 3_MWD+IFR2+MS+Sag (4) 13,426.83 92.78 183.25 3,465.16 3,413.71 -8,088.59 -3,919.74 6,019,784.25 529,540.96 3.35 8,088.59 3_MWD+IFR2+MS+Sag (4) 13,490.73 90.61 181.88 3,463.27 3,411.82 -8,152.39 -3,922.59 6,019,720.45 529,538.39 4.02 8,152.39 3_MWD+IFR2+MS+Sag (4) 13,553.88 90.61 179.87 3,462.60 3,411.15 -8,215.53 -3,923.56 6,019,657.31 529,537.71 3.18 8,215.53 3_MWD+IFR2+MS+Sag (4) 13,617.61 90.30 178.70 3,462.09 3,410.64 -8,279.25 -3,922.76 6,019,593.60 529,538.79 1.90 8,279.25 3_MWD+IFR2+MS+Sag (4) 13,681.44 90.92 177.93 3,461.42 3,409.97 -8,343.05 -3,920.89 6,019,529.82 529,540.95 1.55 8,343.05 3_MWD+IFR2+MS+Sag (4) 13,745.03 91.05 176.50 3,460.32 3,408.87 -8,406.55 -3,917.80 6,019,466.34 529,544.33 2.26 8,406.55 3_MWD+IFR2+MS+Sag (4) 13,808.74 89.93 176.21 3,459.78 3,408.33 -8,470.13 -3,913.75 6,019,402.78 529,548.66 1.82 8,470.13 3_MWD+IFR2+MS+Sag (4) 13,872.62 87.77 175.70 3,461.06 3,409.61 -8,533.84 -3,909.24 6,019,339.11 529,553.45 3.47 8,533.84 3_MWD+IFR2+MS+Sag (4) 13,934.25 91.49 180.32 3,461.46 3,410.01 -8,595.40 -3,907.10 6,019,277.56 529,555.87 9.62 8,595.40 3_MWD+IFR2+MS+Sag (4) 13,996.27 89.87 180.95 3,460.72 3,409.27 -8,657.41 -3,907.79 6,019,215.55 529,555.46 2.80 8,657.41 3_MWD+IFR2+MS+Sag (4) 14,062.02 90.68 183.57 3,460.41 3,408.96 -8,723.10 -3,910.38 6,019,149.86 529,553.16 4.17 8,723.10 3_MWD+IFR2+MS+Sag (4) 14,125.92 91.60 187.29 3,459.13 3,407.68 -8,786.69 -3,916.43 6,019,086.25 529,547.40 6.00 8,786.69 3_MWD+IFR2+MS+Sag (4) 14,189.76 90.24 187.34 3,458.11 3,406.66 -8,850.00 -3,924.55 6,019,022.91 529,539.56 2.13 8,850.00 3_MWD+IFR2+MS+Sag (4) 14,253.63 87.58 185.39 3,459.32 3,407.87 -8,913.46 -3,931.63 6,018,959.43 529,532.77 5.16 8,913.46 3_MWD+IFR2+MS+Sag (4) 14,317.17 85.97 185.06 3,462.90 3,411.45 -8,976.63 -3,937.41 6,018,896.23 529,527.28 2.59 8,976.63 3_MWD+IFR2+MS+Sag (4) 14,380.86 87.03 184.44 3,466.79 3,415.34 -9,039.98 -3,942.67 6,018,832.86 529,522.30 1.93 9,039.98 3_MWD+IFR2+MS+Sag (4) 14,444.36 87.53 183.52 3,469.80 3,418.35 -9,103.26 -3,947.08 6,018,769.58 529,518.18 1.65 9,103.26 3_MWD+IFR2+MS+Sag (4) 14,508.16 87.65 182.55 3,472.48 3,421.03 -9,166.91 -3,950.45 6,018,705.92 529,515.09 1.53 9,166.91 3_MWD+IFR2+MS+Sag (4) 14,571.81 88.76 181.37 3,474.48 3,423.03 -9,230.49 -3,952.63 6,018,642.33 529,513.20 2.54 9,230.49 3_MWD+IFR2+MS+Sag (4) 14,635.63 90.06 179.79 3,475.13 3,423.68 -9,294.30 -3,953.27 6,018,578.53 529,512.84 3.21 9,294.30 3_MWD+IFR2+MS+Sag (4) 14,699.75 89.81 177.39 3,475.21 3,423.76 -9,358.39 -3,951.70 6,018,514.45 529,514.71 3.76 9,358.39 3_MWD+IFR2+MS+Sag (4) 14,763.43 90.49 176.14 3,475.04 3,423.59 -9,421.97 -3,948.10 6,018,450.89 529,518.59 2.23 9,421.97 3_MWD+IFR2+MS+Sag (4) 14,827.25 92.54 175.55 3,473.35 3,421.90 -9,485.60 -3,943.48 6,018,387.29 529,523.50 3.34 9,485.60 3_MWD+IFR2+MS+Sag (4) 14,867.76 92.59 175.21 3,471.54 3,420.09 -9,525.94 -3,940.22 6,018,346.97 529,526.94 0.85 9,525.94 3_MWD+IFR2+MS+Sag (4) 14,940.00 92.59 175.21 3,468.28 3,416.83 -9,597.85 -3,934.19 6,018,275.10 529,533.29 0.00 9,597.85 PROJECTED to TD 1111y 1�l by B -1 -in Hand Checked By: Chelsea Wrightoae2,2,..l 308807°2x00' Approved By: Benjamin Hand Da 2,20.O1e0608:4534-09'00. Date: 01-03-2020 1/32020 12:31:33PM Page 7 COMPASS 5000.15 Build 91E Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-26PB1 500292365670 Sperry Drilling Definitive Survey Report 03 January, 2020 HALLIBURTON Sperry Drilling Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: - - -- MPU M-26 Wellbore: MPU M-26PB1 Design: MPU M-26PB1 Halliburton Definitive Survey Report Local Co-ordinate Reference: Well MPU M-26 TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft "NortliReference: ` " ' '-True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MPU M-26, Slot 10 Well Position +N/ -S 0.00 usft Northing: 6,027,889.58 usfl Latitude: 70° 29' 14.020 N +E/ -W 0.00 usft Easting: 533,423.92 usfl Longitude: 149° 43' 36.519 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 25.30 usft Wellbore MPU M-26PB1 Magnetics Model Name Sample Date Declination Dip Angle (I (I BGGM2018 11/19/2019 16.36 80.94 Field Strength (nT) 57,407.19402629 Design MPU M-26PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 26.15 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 26.15 0.00 0.00 180.00 Survey Program Date 12/30/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 198.24 785.09 MPU M-26PB1 SH Gyrodata GWD Gyro 3_Gyro-MWD70 H055Ga: Gyro-MWD70 11/18/2019 785.09 6,903.84 MPU M-26PB1 SH MWD+IFR2+MS+Sac 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 11/26/2019 6,904.00 13,553.78 MPU M-26PB1 PH MWD+IR2+MS+Sag 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi -station analysis + sa 12/24/2019 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 26.15 0.00 0.00 26.15 -25.30 0.00 0.00 6,027,889.58 533,423.92 0.00 0.00 UNDEFINED 198.24 0.70 306.21 198.24 146.79 0.62 -0.85 6,027,890.20 533,423.07 0.41 -0.62 3_Gyro-MWD70 (1) 226.35 1.06 312.02 226.34 174.89 0.90 -1.18 6,027,890.47 533,422.74 1.32 -0.90 3_Gyro-MWD70(1) 320.02 3.35 319.60 319.94 268.49 3.56 -3.60 6,027,893.12 533,420.31 2.46 -3.56 3_Gyro-MWD70(1) 406.75 5.81 318.54 406.38 354.93 8.78 -8.15 6,027,898.32 533,415.73 2.84 -8.78 3_Gyro-MWD70 (1) 503.81 8.19 313.25 502.71 451.26 17.20 -16.44 6,027,906.71 533,407.41 2.54 -17.20 3_Gyro-MWD70 (1) 597.31 11.54 306.03 594.82 543.37 27.27 -28.85 6,027,916.72 533,394.95 3.81 -27.27 3_Gyro-MWD70 (1) 689.69 15.07 300.21 684.71 633.26 38.75 -46.71 6,027,928.12 533,377.04 4.08 -38.75 3_Gyro-MWD70 (1) 785.09 18.85 295.81 775.95 724.50 51.71 -71.31 6,027,940.96 533,352.38 4.18 -51.71 3_Gyro-MWD70(1) 887.93 21.37 295.35 872.51 821.06 66.96 -103.21 6,027,956.07 533,320.42 2.46 -66.96 3_MWD+IFR2+MS+Sag (2) 983.36 23.54 293.62 960.70 909.25 82.05 -136.39 6,027,971.00 533,287.18 2.38 -82.05 3_MWD+IFR2+MS+Sag (2) 1,078.83 24.82 289.65 1,047.80 996.35 96.42 -172.73 6,027,985.22 533,250.78 2.17 -96.42 3_MWD+IFR2+MS+Sag(2) 1131202012:31:02PM Page 2 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-26 Project: Milne Point TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Site: M Pt Moose Pad MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Well: `" MPU M-26 North Reference: True Wellbore: MPU M-26PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-26PB1 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,174.77 29.42 286.54 1,133.17 1,081.72 109.91 -214.30 6,027,998.52 533,209.15 5.02 -109.91 3 MWD+IFR2+MS+Sag (2) 1,269.99 34.36 282.26 1,214.01 1,162.56 122.28 -263.02 6,028,010.67 533,160.38 5.70 -122.28 3_MWD+IFR2+MS+Sag(2) 1,366.11 37.26 281.30 1,291.95 1,240.50 133.75 -318.07 6,028,021.88 533,105.29 3.07 -133.75 3_MWD+IFR2+MS+Sag (2) 1,460.72 41.02 279.57 1,365.32 1,313.87 144.53 -376.79 6,028,032.40 533,046.52 4.14 -144.53 3_MWD+IFR2+MS+Sag (2) 1,556.30 45.63 277.35 1,434.84 1,383.39 154.12 -441.64 6,028,041.70 532,981.63 5.08 -154.12 3_MWD+IFR2+MS+Sag(2) 1,651.33 50.11 275.98 1,498.57 1,447.12 162.26 -511.62 6,028,049.53 532,911.62 4.83 -162.26 3_MWD+IFR2+MS+Sag (2) 1,746.78 55.43 276.08 1,556.30 1,504.85 170.25 -587.17 6,028,057.17 532,836.04 5.57 -170.25 3_MWD+IFR2+MS+Sag (2) 1,842.58 59.15 275.94 1,608.06 1,556.61 178.68 -667.32 6,028,065.25 532,755.86 3.89 -178.68 3_MWD+IFR2+MS+Sag(2) 1,936.97 58.71 274.36 1,656.77 1,605.32 185.94 -747.84 6,028,072.14 532,675.32 1.51 -185.94 3_MWD+IFR2+MS+Sag (2) 2,032.92 60.12 273.99 1,705.59 1,654.14 191.96 -830.22 6,028,077.78 532,592.93 1.51 -191.96 3_MWD+IFR2+MS+Sag (2) 2,126.78 60.24 274.32 1,752.27 1,700.82 197.86 -911.44 6,028,083.32 532,511.69 0.33 -197.86 3_MWD+IFR2+MS+Sag (2) 2,221.50 61.78 274.63 1,798.17 1,746.72 204.32 -994.04 6,028,089.41 532,429.07 1.65 -204.32 3_MWD+IFR2+MS+Sag (2) 2,316.90 61.38 277.04 1,843.58 1,792.13 212.85 -1,077.50 6,028,097.56 532,345.58 2.26 -212.85 3_MWD+IFR2+MS+Sag (2) 2,412.56 60.51 277.21 1,890.04 1,838.59 223.22 -1,160.47 6,028,107.56 532,262.57 0.92 -223.22 3_MWD+IFR2+MS+Sag (2) 2,508.43 61.49 277.15 1,936.52 1,885.07 233.70 -1,243.66 6,028,117.66 532,179.34 1.02 -233.70 3_MWD+IFR2+MS+Sag (2) 2,604.08 60.86 277.95 1,982.63 1,931.18 244.71 -1,326.73 6,028,128.30 532,096.23 0.99 -244.71 3_MWD+IFR2+MS+Sag (2) 2,698.88 62.10 277.01 2,027.90 1,976.45 255.55 -1,409.32 6,028,138.76 532,013.61 1.57 -255.55 3_MWD+IFR2+MS+Sag (2) 2,793.76 61.28 277.93 2,072.89 2,021.44 266.40 -1,492.14 6,028,149.25 531,930.75 1.21 -266.40 3_MWD+IFR2+MS+Sag (2) 2,888.87 61.42 277.13 2,118.49 2,067.04 277.34 -1,574.88 6,028,159.81 531,847.96 0.75 -277.34 3_MWD+IFR2+MS+Sag (2) 2,983.53 60.70 278.18 2,164.30 2,112.85 288.37 -1,656.98 6,028,170.47 531,765.82 1.23 -288.37 3_MWD+IFR2+MS+Sag (2) 3,079.36 60.64 276.21 2,211.24 2,159.79 298.84 -1,739.87 6,028,180.56 531,682.90 1.79 -298.84 3_MWD+IFR2+MS+Sag (2) 3,174.96 60.14 276.69 2,258.48 2,207.03 308.17 -1,822.45 6,028,189.53 531,600.28 0.68 -308.17 3_MWD+IFR2+MS+Sag (2) 3,269.53 60.93 274.66 2,305.00 2,253.55 316.31 -1,904.38 6,028,197.29 531,518.32 2.05 -316.31 3_MWD+IFR2+MS+Sag (2) 3,365.14 60.91 274.58 2,351.47 2,300.02 323.04 -1,987.67 6,028,203.65 531,435.02 0.08 -323.04 3_MWD+IFR2+MS+Sag (2) 3,460.25 60.62 275.04 2,397.92 2,346.47 330.00 -2,070.37 6,028,210.24 531,352.29 0.52 -330.00 3_MWD+IFR2+MS+Sag (2) 3,555.02 58.91 275.55 2,445.64 2,394.19 337.55 -2,151.90 6,028,217.42 531,270.74 1.86 -337.55 3_MWD+IFR2+MS+Sag (2) 3,650.46 58.51 275.89 2,495.21 2,443.76 345.68 -2,233.05 6,028,225.18 531,189.56 0.52 -345.68 3_MWD+IFR2+MS+Sag (2) 3,746.16 58.93 275.96 2,544.90 2,493.45 354.12 -2,314.40 6,028,233.26 531,108.18 0.44 -354.12 3_MWD+IFR2+MS+Sag (2) 3,840.26 58.64 276.00 2,593.67 2,542.22 362.50 -2,394.44 6,028,241.28 531,028.11 0.31 -362.50 3_MWD+IFR2+MS+Sag (2) 3,935.24 59.20 276.50 2,642.70 2,591.25 371.36 -2,475.30 6,028,249.78 530,947.22 0.74 -371.36 3_MWD+IFR2+MS+Sag (2) 4,030.27 59.39 273.23 2,691.23 2,639.78 378.29 -2,556.70 6,028,256.34 530,865.80 2.97 -378.29 3_MWD+IFR2+MS+Sag (2) 4,125.88 59.27 269.15 2,740.02 2,688.57 380.00 -2,638.89 6,028,257.68 530,783.61 3.67 -380.00 3_MWD+IFR2+MS+Sag (2) 4,220.78 58.13 264.81 2,789.34 2,737.89 375.74 -2,719.83 6,028,253.06 530,702.69 4.09 -375.74 3_MWD+IFR2+MS+Sag (2) 4,315.80 59.74 261.67 2,838.38 2,786.93 366.15 -2,800.64 6,028,243.10 530,621.94 3.30 -366.15 3_MWD+IFR2+MS+Sag (2) 4,410.00 62.32 256.56 2,884.02 2,832.57 350.55 -2,881.52 6,028,227.14 530,541.14 5.48 -350.55 3_MWD+IFR2+MS+Sag (2) 4,505.39 62.67 250.25 2,928.11 2,876.66 326.39 -2,962.54 6,028,202.62 530,460.24 5.88 -326.39 3_MWD+IFR2+MS+Sag (2) 4,600.45 63.23 246.85 2,971.35 2,919.90 295.43 -3,041.32 6,028,171.31 530,381.61 3.24 -295.43 3_MWD+IFR2+MS+Sag (2) 4,696.14 63.70 243.42 3,014.11 2,962.66 259.44 -3,118.97 6,028,134.98 530,304.12 3.24 -259.44 3_MWD+IFR2+MS+Sag (2) 4,791.27 62.81 240.26 3,056.93 3,005.48 219.36 -3,193.86 6,028,094.57 530,229.42 3.11 -219.36 3_MWD+IFR2+MS+Sag (2) 4,886.81 63.23 235.13 3,100.29 3,048.84 173.88 -3,265.79 6,028,048.76 530,157.71 4.80 -173.88 3_MWD+IFR2+MS+Sag (2) 1/32020 12:31:02PM Page 3 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: _- MPU M-26 Wellbore: MPU M -26P61 Design: MPU M -26P[31 Survey MD Inc Azi TVD TVDSS +N/ -S (usft) (°) V) (usft) (usft) (usft) 4,982.03 63.64 229.55 3,142.91 3,091.46 121.86 5,077.58 64.40 224.36 3,184.78 3,133.33 63.25 5,172.83 66.17 220.07 3,224.62 3,173.17 -0.82 5,268.96 67.51 216.74 3,262.44 3,210.99 -70.08 5,364.00 68.58 215.41 3,297.97 3,246.52 -141.32 5,458.87 70.87 213.34 3,330.85 3,279.40 -214.77 5,554.94 70.41 211.77 3,362.70 3,311.25 -291.16 5,649.45 72.84 208.55 3,392.50 3,341.05 -368.70 5,745.13 74.12 205.41 3,419.71 3,368.26 -450.44 5,839.77 76.98 201.24 3,443.33 3,391.88 -534.57 5,939.39 83.44 195.36 3,460.28 3,408.83 -627.70 6,031.15 86.48 191.11 3,468.34 3,416.89 -716.65 6,126.85 88.39 187.60 3,472.62 3,421.17 -810.96 6,221.65 87.10 184.02 3,476.36 3,424.91 -905.18 6,317.04 83.19 180.83 3,484.43 3,432.98 -1,000.11 6,408.27 80.83 181.07 3,497.11 3,445.66 -1,090.44 6,507.36 78.70 178.75 3,514.72 3,463.27 -1,187.94 6,601.98 77.24 178.64 3,534.44 3,482.99 -1,280.46 6,697.77 79.77 179.64 3,553.53 3,502.08 -1,374.31 6,793.31 82.52 181.46 3,568.23 3,516.78 -1,468.69 6,885.87 82.89 182.34 3,579.99 3,528.54 -1,560.45 6,903.84 83.70 182.80 3,582.08 3,530.63 -1,578.28 6,975.69 85.98 184.03 3,588.55 3,537.10 -1,649.70 7,003.51 86.42 183.76 3,590.39 3,538.94 -1,677.40 7,067.33 87.59 183.94 3,593.72 3,542.27 -1,740.98 7,131.08 87.53 183.57 3,596.44 3,544.99 -1,804.54 7,195.15 86.72 183.93 3,599.65 3,548.20 -1,868.39 7,256.25 87.59 183.57 3,602.68 3,551.23 -1,929.29 7,322.49 87.65 183.01 3,605.44 3,553.99 -1,995.36 7,383.30 88.08 182.35 3,607.70 3,556.25 -2,056.06 7,449.53 87.52 181.67 3,610.24 3,558.79 -2,122.20 7,512.71 88.89 179.95 3,612.22 3,560.77 -2,185.34 7,576.02 90.43 178.88 3,612.60 3,561.15 -2,248.64 7,639.93 91.54 177.74 3,611.50 3,560.05 -2,312.51 7,703.32 92.97 176.89 3,609.00 3,557.55 -2,375.78 7,767.22 93.09 176.82 3,605.63 3,554.18 -2,439.50 7,830.66 93.27 177.23 3,602.11 3,550.66 -2,502.75 7,893.92 93.89 177.87 3,598.16 3,546.71 -2,565.83 7,957.01 94.94 178.90 3,593.30 3,541.85 -2,628.71 8,021.32 94.94 180.34 3,587.76 3,536.31 -2,692.77 1/32020 12:31:02PM Local Co-ordinate Reference: Well MPU M-26 TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft North`Reference: `" - - __.. ` - True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA Map Map Vertical +E/ -W Northing Easting DLS Section (usft) (ft) (ft) (°/1oo,) (ft) Survey Tool Name -31333.17 6,027,996.45 530,090.57 5.26 -121.86 3_MWD+IFR2+MS+Sag (2) -3,395.90 6,027,937.57 530,028.10 4.95 -63.25 3_MWD+IFR2+MS+Sag (2) -3,454.00 6,027,873.24 529,970.30 4.49 M 0.82 3_WD+IFR2+MS+Sag (2) -3,508.88 6,027,803.74 529,915.73 3.48 70.08 3_MWD+IFR2+MS+Sag (2) -3,560.78 6,027,732.27 529,864.16 1.72 141.32 3_MWD+IFR2+MS+Sag (2) -3,611.01 6,027,658.61 529,814.27 3.16 214.77 3_MWD+IFR2+MS+Sag (2) -3,659.78 6,027,582.01 529,765.84 1.61 291.16 3_MWD+IFR2+MS+Sag (2) -3,704.82 6,027,504.27 529,721.16 4.13 368.70 3_MWD+IFR2+MS+Sag (2) -3,746.42 6,027,422.36 529,679.93 3.42 450.44 3_MWD+IFR2+MS+Sag (2) -3,782.68 6,027,338.07 529,644.06 5.23 534.57 3_MWD+IFR2+MS+Sag (2) -3,813.42 6,027,244.81 529,613.73 8.71 627.70 3_MWD+IFR2+MS+Sag (2) -3,834.34 6,027,155.78 529,593.22 5.68 716.65 3_MWD+IFR2+MS+Sag (2) -3,849.87 6,027,061.41 529,578.11 4.17 810.96 3_MWD+IFR2+MS+Sag (2) -3,859.46 6,026,967.15 529,568.95 4.01 905.18 3_MWD+IFR2+MS+Sag (2) -3,863.49 6,026,872.21 529,565.35 5.28 1,000.11 3_MWD+IFR2+MS+Sag (2) -3,864.99 6,026,781.89 529,564.25 2.60 1,090.44 3_MWD+IFR2+MS+Sag (2) -3,864.84 6,026,684.40 529,564.84 3.15 1,187.94 3_MWD+IFR2+MS+Sag (2) -3,862.73 6,026,591.90 529,567.36 1.55 1,280.46 3_MWD+IFR2+MS+Sag (2) -3,861.33 6,026,498.07 529,569.19 2.83 1,374.31 3_MWD+IFR2+MS+Sag (2) -3,862.24 6,026,403.69 529,568.70 3.44 1,468.69 3_MWD+IFR2+MS+Sag (2) -3,865.28 6,026,311.93 529,566.07 1.02 1,560.45 3_MWD+IFR2+MS+Sag (2) -3,866.08 6,026,294.10 529,565.35 5.18 1,578.28 3_MWD+IFR2+MS+Sag (3) -3,870.35 6,026,222.66 529,561.41 3.60 1,649.70 3_MWD+IFR2+MS+Sag (3) -3,872.23 6,026,194.96 529,559.65 1.85 1,677.40 3_MWD+IFR2+MS+Sag (3) -3,876.51 6,026,131.36 529,555.65 1.85 1,740.98 3_MWD+IFR2+MS+Sag (3) -3,880.68 6,026,067.80 529,551.77 0.59 1,804.54 3_MWD+IFR2+MS+Sag (3) -3,884.87 6,026,003.93 529,547.87 1.38 1,868.39 3_MWD+IFR2+MS+Sag (3) -3,888.86 6,025,943.03 529,544.15 1.54 1,929.29 3_MWD+IFR2+MS+Sag (3) -3,892.66 6,025,876.95 529,540.65 0.85 1,995.36 3_MWD+IFR2+MS+Sag (3) -3,895.50 6,025,816.24 529,538.09 1.29 2,056.06 3_MWD+IFR2+MS+Sag (3) -3,897.82 6,025,750.10 529,536.06 1.33 2,122.20 3_MWD+IFR2+MS+Sag (3) -3,898.71 6,025,686.96 529,535.45 3.48 2,185.34 3_MWD+IFR2+MS+Sag (3) -3,898.07 6,025,623.67 529,536.38 2.96 2,248.64 3_MWD+IFR2+MS+Sag (3) -3,896.18 6,025,559.81 529,538.55 2.49 2,312.51 3_MWD+IFR2+MS+Sag (3) -3,893.21 6,025,496.56 529,541.81 2.62 2,375.78 3_MWD+IFR2+MS+Sag (3) -3,889.71 6,025,432.87 529,545.59 0.22 2,439.50 3_MWD+IFR2+MS+Sag (3) -3,886.43 6,025,369.64 529,549.16 0.70 2,502.75 3_MWD+IFR2+MS+Sag (3) -3,883.73 6,025,306.58 529,552.15 1.41 2,565.83 3_MWD+IFR2+MS+Sag (3) -3,881.95 6,025,243.71 529,554.20 2.33 2,628.71 3_MWD+IFR2+MS+Sag (3) -3,881.53 6,025,179.66 529,554.91 2.23 2,692.77 3_MWD+IFR2+MS+Sag (3) Page 4 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Project: Site: Well: Wellbore: Design: Hilcorp Alaska, LLC Milne Point M Pt Moose Pad MPU M-26 MPU M-26PB1 MPU M-26PI31 Local Co-ordinate Reference: Well MPU M-26 TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft North` Reference: .__"-True Survey Calculation Method: Minimum Curvature Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,085.08 96.00 180.22 3,581.69 3,530.24 -2,756.24 -3,881.84 6,025,116.19 529,554.89 1.67 2,756.24 3_MWD+IFR2+MS+Sag (3) 8,148.42 97.24 179.69 3,574.38 3,522.93 -2,819.16 -3,881.79 6,025,053.28 529,555.22 2.13 2,819.16 3_MWD+IFR2+MS+Sag (3) 8,211.95 96.68 179.63 3,566.68 3,515.23 -2,882.22 -3,881.42 6,024,990.23 529,555.88 0.89 2,882.22 3_MWD+IFR2+MS+Sag (3) 8,274.99 95.56 179.71 3,559.96 3,508.51 -2,944.90 -3,881.05 6,024,927.56 529,556.52 1.78 2,944.90 3_MWD+IFR2+MS+Sag (3) 8,338.78 93.76 179.49 3,554.78 3,503.33 -3,008.47 -3,880.61 6,024,864.00 529,557.25 2.84 3,008.47 3_MWD+IFR2+MS+Sag (3) 8,402.48 92.71 179.92 3,551.19 3,499.74 -3,072.07 -3,880.28 6,024,800.41 529,557.86 1.78 3,072.07 3_MWD+IFR2+MS+Sag (3) 8,465.64 92.96 180.24 3,548.06 3,496.61 -3,135.15 -3,880.37 6,024,737.33 529,558.06 0.64 3,135.15 3_MWD+IFR2+MS+Sag (3) 8,529.31 90.92 180.73 3,545.91 3,494.46 -3,198.78 -3,880.91 6,024,673.71 529,557.81 3.30 3,198.78 3_MWD+IFR2+MS+Sag (3) 8,592.12 89.06 181.27 3,545.92 3,494.47 -3,261.58 -3,882.01 6,024,610.91 529,556.99 3.08 3,261.58 3_MWD+IFR2+MS+Sag (3) 8,654.84 89.38 181.08 3,546.77 3,495.32 -3,324.28 -3,883.29 6,024,548.21 529,555.99 0.59 3,324.28 3_MWD+IFR2+MS+Sag (3) 8,718.54 91.05 181.88 3,546.53 3,495.08 -3,387.95 -3,884.94 6,024,484.54 529,554.63 2.91 3,387.95 3_MWD+IFR2+MS+Sag (3) 8,779.09 91.79 182.60 3,545.03 3,493.58 -3,448.44 -3,887.30 6,024,424.05 529,552.54 1.70 3,448.44 3_MWD+IFR2+MS+Sag (3) 8,842.52 89.87 180.21 3,544.11 3,492.66 -3,511.83 -3,888.86 6,024,360.65 529,551.27 4.83 3,511.83 3_MWD+IFR2+MS+Sag (3) 8,905.03 88.57 176.44 3,544.97 3,493.52 -3,574.30 -3,887.03 6,024,298.20 529,553.37 6.38 3,574.30 3_MWD+IFR2+MS+Sag (3) 8,973.90 88.82 175.05 3,546.53 3,495.08 -3,642.96 -3,881.92 6,024,229.57 529,558.79 2.05 3,642.96 3_MWD+IFR2+MS+Sag (3) 9,037.18 91.73 175.32 3,546.23 3,494.78 -3,706.01 -3,876.61 6,024,166.55 529,564.38 4.62 3,706.01 3_MWD+IFR2+MS+Sag (3) 9,100.85 93.52 176.29 3,543.31 3,491.86 -3,769.44 -3,871.96 6,024,103.15 529,569.32 3.20 3,769.44 3_MWD+IFR2+MS+Sag (3) 9,164.36 92.27 175.44 3,540.11 3,488.66 -3,832.70 -3,867.39 6,024,039.92 529,574.18 2.38 3,832.70 3_MWD+IFR2+MS+Sag (3) 9,228.12 93.03 177.51 3,537.16 3,485.71 -3,896.27 -3,863.47 6,023,976.37 529,578.38 3.46 3,896.27 3_MWD+IFR2+MS+Sag (3) 9,291.85 94.01 179.00 3,533.25 3,481.80 -3,959.85 -3,861.53 6,023,912.81 529,580.60 2.79 3,959.85 3_MWD+IFR2+MS+Sag (3) 9,355.39 92.65 180.51 3,529.55 3,478.10 -4,023.27 -3,861.26 6,023,849.39 529,581.16 3.20 4,023.27 3_MWD+IFR2+MS+Sag (3) 9,419.38 92.34 181.99 3,526.77 3,475.32 -4,087.19 -3,862.66 6,023,785.48 529,580.05 2.36 4,087.19 3_MWD+IFR2+MS+Sag (3) 9,482.87 90.49 183.27 3,525.20 3,473.75 -4,150.59 -3,865.57 6,023,722.07 529,577.42 3.54 4,150.59 3_MWD+IFR2+MS+Sag (3) 9,547.04 90.12 182.93 3,524.86 3,473.41 -4,214.66 -3,869.04 6,023,657.99 529,574.24 0.78 4,214.66 3_MWD+IFR2+MS+Sag (3) 9,610.90 89.13 182.17 3,525.28 3,473.83 -4,278.46 -3,871.88 6,023,594.19 529,571.69 1.95 4,278.46 3_MWD+IFR2+MS+Sag (3) 9,673.84 90.62 181.55 3,525.41 3,473.96 -4,341.36 -3,873.92 6,023,531.28 529,569.93 2.56 4,341.36 3_MWD+IFR2+MS+Sag (3) 9,737.36 90.61 180.34 3,524.73 3,473.28 -4,404.87 -3,874.97 6,023,467.78 529,569.17 1.90 4,404.87 3_MWD+IFR2+MS+Sag (3) 9,801.17 91.29 180.60 3,523.68 3,472.23 -4,468.67 -3,875.49 6,023,403.99 529,568.93 1.14 4,468.67 3_MWD+IFR2+MS+Sag (3) 9,864.86 91.85 181.93 3,521.93 3,470.48 -4,532.31 -3,876.90 6,023,340.34 529,567.81 2.27 4,532.31 3_MWD+IFR2+MS+Sag (3) 9,928.69 92.28 182.63 3,519.63 3,468.18 -4,596.05 -3,879.44 6,023,276.59 529,565.56 1.29 4,596.05 3_MWD+IFR2+MS+Sag (3) 9,992.01 93.39 184.14 3,516.50 3,465.05 -4,659.18 -3,883.17 6,023,213.46 529,562.11 2.96 4,659.18 3_MWD+IFR2+MS+Sag (3) 10,055.99 94.76 185.03 3,511.95 3,460.50 -4,722.79 -3,888.27 6,023,149.83 529,557.30 2.55 4,722.79 3_MWD+IFR2+MS+Sag (3) 10,119.42 96.75 185.01 3,505.59 3,454.14 -4,785.66 -3,893.79 6,023,086.94 529,552.06 3.14 4,785.66 3_MWD+IFR2+MS+Sag (3) 10,183.59 96.31 184.44 3,498.29 3,446.84 -4,849.19 -3,899.04 6,023,023.39 529,547.09 1.12 4,849.19 3_MWD+IFR2+MS+Sag (3) 10,247.40 95.19 183.52 3,491.90 3,440.45 -4,912.53 -3,903.45 6,022,960.04 529,542.97 2.27 4,912.53 3_MWD+IFR2+MS+Sag (3) 10,310.69 93.52 182.94 3,487.09 3,435.64 -4,975.53 -3,907.01 6,022,897.03 529,539.70 2.79 4,975.53 3_MWD+IFR2+MS+Sag (3) 10,374.56 92.09 181.61 3,483.97 3,432.52 -5,039.27 -3,909.54 6,022,833.29 529,537.45 3.06 5,039.27 3_MWD+IFR2+MS+Sag (3) 10,438.18 90.61 181.22 3,482.47 3,431.02 -5,102.85 -3,911.11 6,022,769.70 529,536.17 2.41 5,102.85 3_MWD+IFR2+MS+Sag (3) 10,502.22 89.44 180.12 3,482.44 3,430.99 -5,166.89 -3,911.86 6,022,705.68 529,535.71 2.51 5,166.89 3_MWD+IFR2+MS+Sag (3) 10,565.30 88.76 180.00 3,483.43 3,431.98 -5,229.96 -3,911.92 6,022,642.61 529,535.93 1.09 5,229.96 3_MWD+IFR2+MS+Sag (3) 113202012:31:02PM Page 5 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-26 Project: Milne Point TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Site: M Pt Moose Pad MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Well: ""m' MPU M-26 North Reference: "' ` "" True Wellbore: MPU M-26PB1 Survey Calculation Method: Minimum Curvature Design: MPU M-26PB1 Database: NORTH US + CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,629.49 87.59 179.55 3,485.48 3,434.03 -5,294.12 -3,911.67 6,022,578.46 529,536.47 1.95 5,294.12 3_MWD+IFR2+MS+Sag (3) 10,692.47 87.65 178.89 3,488.09 3,436.64 -5,357.03 -3,910.81 6,022,515.55 529,537.60 1.05 5,357.03 3_MWD+IFR2+MS+Sag (3) 10,755.30 88.58 180.84 3,490.16 3,438.71 -5,419.83 -3,910.67 6,022,452.77 529,538.03 3.44 5,419.83 3_MWD+IFR2+MS+Sag (3) 10,818.80 88.27 182.07 3,491.91 3,440.46 -5,483.28 -3,912.28 6,022,389.31 529,536.71 2.00 5,483.28 3_MWD+IFR2+MS+Sag (3) 10,883.41 87.40 182.26 3,494.35 3,442.90 -5,547.80 -3,914.72 6,022,324.79 529,534.56 1.38 5,547.80 3_MWD+IFR2+MS+Sag (3) 10,947.12 87.21 182.33 3,497.34 3,445.89 -5,611.39 -3,917.27 6,022,261.20 529,532.30 0.32 5,611.39 3_MWD+IFR2+MS+Sag (3) 11,010.99 88.52 181.67 3,499.72 3,448.27 -5,675.17 -3,919.49 6,022,197.41 529,530.36 2.30 5,675.17 3_MWD+IFR2+MS+Sag (3) 11,075.44 89.07 182.23 3,501.08 3,449.63 -5,739.57 -3,921.69 6,022,133.01 529,528.45 1.22 5,739.57 3_MWD+IFR2+MS+Sag (3) 11,138.61 89.32 181.78 3,501.96 3,450.51 -5,802.69 -3,923.90 6,022,069.88 529,526.53 0.81 5,802.69 3_MWD+IFR2+MS+Sag (3) 11,202.03 89.75 181.83 3,502.48 3,451.03 -5,866.08 -3,925.89 6,022,006.50 529,524.81 0.68 5,866.08 3_MWD+IFR2+MS+Sag (3) 11,265.66 90.12 181.80 3,502.55 3,451.10 -5,929.68 -3,927.91 6,021,942.89 529,523.09 0.58 5,929.68 3_MWD+IFR2+MS+Sag (3) 11,328.78 90.68 182.31 3,502.11 3,450.66 -5,992.76 -3,930.17 6,021,879.81 529,521.11 1.20 5,992.76 3_MWD+IFR2+MS+Sag(3) 11,392.50 90.92 182.17 3,501.22 3,449.77 -6,056.42 -3,932.66 6,021,816.14 529,518.90 0.44 6,056.42 3_MWD+IFR2+MS+Sag (3) 11,456.18 91.23 182.95 3,500.03 3,448.58 -6,120.03 -3,935.51 6,021,752.53 529,516.34 1.32 6,120.03 3_MWD+IFR2+MS+Sag (3) 11,519.18 90.67 181.59 3,498.98 3,447.53 -6,182.97 -3,938.00 6,021,689.59 529,514.13 2.33 6,182.97 3_MWD+IFR2+MS+Sag(3) 11,581.52 90.24 178.84 3,498.49 3,447.04 -6,245.30 -3,938.23 6,021,627.26 529,514.18 4.46 6,245.30 3_MWD+IFR2+MS+Sag (3) 11,645.86 90.31 177.35 3,498.18 3,446.73 -6,309.60 -3,936.10 6,021,562.98 529,516.61 2.32 6,309.60 3_MWD+IFR2+MS+Sag (3) 11,710.25 90.49 177.07 3,497.73 3,446.28 -6,373.91 -3,932.96 6,021,498.69 529,520.03 0.52 6,373.91 3_MWD+IFR2+MS+Sag (3) 11,773.95 90.43 177.58 3,497.22 3,445.77 -6,437.54 -3,929.99 6,021,435.08 529,523.29 0.81 6,437.54 3_MWD+IFR2+MS+Sag(3) 11,837.98 89.19 177.96 3,497.43 3,445.98 -6,501.52 -3,927.50 6,021,371.12 529,526.07 2.03 6,501.52 3_MWD+IFR2+MS+Sag (3) 11,901.14 89.44 178.97 3,498.18 3,446.73 -6,564.65 -3,925.81 6,021,308.00 529,528.04 1.65 6,564.65 3_MWD+IFR2+MS+Sag (3) 11,964.79 89.44 179.26 3,498.81 3,447.36 -6,628.29 -3,924.82 6,021,244.37 529,529.31 0.46 6,628.29 3_MWD+IFR2+MS+Sag (3) 12,027.99 91.24 180.14 3,498.43 3,446.98 -6,691.49 -3,924.49 6,021,181.19 529,529.93 3.17 6,691.49 3_MWD+IFR2+MS+Sag (3) 12,090.91 93.21 179.50 3,495.99 3,444.54 -6,754.35 -3,924.29 6,021,118.33 529,530.41 3.29 6,754.35 3_MWD+IFR2+MS+Sag (3) 12,155.21 94.70 179.33 3,491.55 3,440.10 -6,818.50 -3,923.64 6,021,054.19 529,531.35 2.33 6,818.50 3_MWD+IFR2+MS+Sag (3) 12,219.55 94.38 178.90 3,486.46 3,435.01 -6,882.63 -3,922.65 6,020,990.07 529,532.63 0.83 6,882.63 3_MWD+IFR2+MS+Sag (3) 12,282.90 92.21 179.18 3,482.82 3,431.37 -6,945.86 -3,921.59 6,020,926.85 529,533.97 3.45 6,945.86 3_MWD+IFR2+MS+Sag (3) 12,346.17 89.99 177.76 3,481.60 3,430.15 -7,009.09 -3,919.90 6,020,863.64 529,535.94 4.16 7,009.09 3_MWD+IFR2+MS+Sag (3) 12,410.12 90.06 176.07 3,481.58 3,430.13 -7,072.94 -3,916.46 6,020,799.81 529,539.67 2.64 7,072.94 3_MWD+IFR2+MS+Sag (3) 12,473.53 91.29 176.77 3,480.83 3,429.38 -7,136.22 -3,912.50 6,020,736.55 529,543.91 2.23 7,136.22 3_MWD+IFR2+MS+Sag (3) 12,537.17 92.22 177.16 3,478.88 3,427.43 -7,199.74 -3,909.13 6,020,673.05 529,547.57 1.58 7,199.74 3_MWD+IFR2+MS+Sag (3) 12,600.99 93.21 178.98 3,475.86 3,424.41 -7,263.45 -3,906.98 6,020,609.36 529,550.00 3.24 7,263.45 3_MWD+IFR2+MS+Sag (3) 12,663.28 93.15 179.38 3,472.40 3,420.95 -7,325.64 -3,906.09 6,020,547.18 529,551.17 0.65 7,325.64 3_MWD+IFR2+MS+Sag (3) 12,726.52 92.71 179.71 3,469.17 3,417.72 -7,388.80 -3,905.59 6,020,484.04 529,551.96 0.87 7,388.80 3_MWD+IFR2+MS+Sag (3) 12,790.50 93.52 180.71 3,465.69 3,414.24 -7,452.68 -3,905.83 6,020,420.16 529,552.01 2.01 7,452.68 3_MWD+IFR2+MS+Sag (3) 12,854.11 93.39 180.75 3,461.86 3,410.41 -7,516.17 -3,906.64 6,020,356.67 529,551.49 0.21 7,516.17 3_MWD+IFR2+MS+Sag (3) 12,918.07 95.19 181.05 3,457.08 3,405.63 -7,579.94 -3,907.64 6,020,292.91 529,550.77 2.85 7,579.94 3_MWD+IFR2+MS+Sag (3) 12,981.62 96.87 181.91 3,450.40 3,398.95 -7,643.11 -3,909.27 6,020,229.73 529,549.42 2.97 7,643.11 3_MWD+IFR2+MS+Sag (3) 13,045.05 98.12 182.23 3,442.13 3,390.68 -7,705.96 -3,911.54 6,020,166.88 529,547.43 2.03 7,705.96 3_MWD+IFR2+MS+Sag (3) 13,108.67 98.31 182.32 3,433.04 3,381.59 -7,768.88 -3,914.04 6,020,103.96 529,545.22 0.33 7,768.88 3_MWD+IFR2+MS+Sag (3) 1/3/2020 12 31:02PM Page 6 COMPASS 5000.15 Build 91E Halliburton Definitive Survey Report Company: Hilcorp Alaska, LLC Local Co-ordinate Reference: Well MPU M-26 Project: Milne Point TVD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Site: M Pt Moose Pad MD Reference: MPU M-26 Actual Lateral RKB @ 51.45usft Well: MPU M-26 —North- Reference ----'----True +E/ -W Wellbore: MPU M-26PB1 Survey Calculation Method: Minimum Curvature Design: MPU M -26P61 Database: NORTH US + CANADA Survey Checked By: Chelsea WrightDateta2020O1e0309:d by 0'0`900 Approved By: Benjamin Hand Da[ea21020.O1e0608d by B46']4-0900'arnin d Date: 01-03-2020 1/3/2020 12:31:02PM Page 7 COMPASS 5000.15 Build 91E Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,172.61 98.24 182.14 3,423.83 3,372.38 -7,832.10 -3,916.50 6,020,040.73 529,543.04 0.30 7,832.10 3_MWD+IFR2+MS+Sag (3) 13,234.22 98.24 181.58 3,415.00 3,363.55 -7,893.04 -3,918.48 6,019,979.79 529,541.34 0.90 7,893.04 3_MWD+IFR2+MS+Sag (3) 13,297.91 99.99 179.89 3,404.91 3,353.46 -7,955.92 -3,919.29 6,019,916.91 529,540.81 3.80 7,955.92 3_MWD+IFR2+MS+Sag (3) 13,361.30 100.74 180.17 3,393.51 3,342.06 -8,018.28 -3,919.32 6,019,854.56 529,541.06 1.26 8,018.28 3_MWD+IFR2+MS+Sag (3) 13,425.37 100.93 180.24 3,381.46 3,330.01 -8,081.20 -3,919.55 6,019,791.64 529,541.11 0.32 8,081.20 3_MWD+IFR2+MS+Sag (3) 13,489.93 102.38 180.06 3,368.42 3,316.97 -8,144.43 -3,919.71 6,019,728.42 529,541.23 2.26 8,144.43 3_MWD+IFR2+MS+Sag (3) 13,553.78 103.91 180.68 3,353.90 3,302.45 -8,206.60 -3,920.11 6,019,666.25 529,541.11 2.58 8,206.60 3_MWD+IFR2+MS+Sag (3) 13,622.00 103.91 180.68 3,337.50 3,286.05 -8,272.82 -3,920.90 6,019,600.04 529,540.62 0.00 8,272.82 PROJECTED to TO Checked By: Chelsea WrightDateta2020O1e0309:d by 0'0`900 Approved By: Benjamin Hand Da[ea21020.O1e0608d by B46']4-0900'arnin d Date: 01-03-2020 1/3/2020 12:31:02PM Page 7 COMPASS 5000.15 Build 91E Hilcorp Energy Company CASING & CEMENTING REPORT Lease & Well No. MP M-26 County North Slope Borough State CASING RECORD Surface Tn R QFs nn Shoe moth R QRn nn Alaska Date Run 29 -Nov -19 Supv, D. Yessak / J. Vanderpool PRTn Csg Wt. On Hook: 175,000 Type Float Collar: Innovex No. Hrs to Run: Csg Wt. On Slips: 135,000 Type of Shoe: Innovex Casing Crew: Doyon Rotate Csg X Yes No Recip Csg X Yes _ No Ft. Min. 9.2 PPG Fluid Description: Spud Mud Liner hanger Info (Make/Model): Liner top Packer?: _Yes _ No Liner hanger test pressure: Floats Held X Yes _ No Centralizer Placement: 99 each 9-5/8" x 12-1/2' Expand-o-lizer centralizers ran. CEMENTING REPORT Shoe @ FC @ Casing (Or Liner) Detail Setting Depths Jts. Component Size Wt. Grade THD Make Length Bottom Top 1 Shoe 103/4 50.0 Type: Lead Cement TXP BTC -SR Innovex 1.60 6,960.00 6,958.40 2 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 79.67 6,958.40 6,878.73 1 Float Collar 103/4 40.0 Density (ppg) TXP BTC -SR Innovex 1.26 6,878.73 6,877.47 1 Casing 95/8 50.0 L-80 TXP BTC -5R Tenaris 40.35 6,877.47 6,837.12 1 Baffle Adapter 103/4 40.0 Type: Spud Med TXP BTC -SR HES 1.45 6,837.12 6,835.67 1091 Casing 95/8 40.0 1 L-80 TXP BTC -SR Tenaris 1 4,296.04 6,835.67 2,539.63 1 Pup Joint 95/8 40.0 L-80 TXP BTC -SR Tenaris 13.81 2,539.63 2,525.82 1 ESC II 103/4 40.0 Closure OK TXP BTC -SR HES 2.81 2,525.82 2,523.01 1 Pup Joint 95/8 40.0 L-80 TXP BTC -SR Tenaris 14.82 2,523.01 2,508.19 62 Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 2,454.51 1 2,508.19 53.68 1 Cut Joint of Casing 95/8 40.0 L-80 TXP BTC -SR Tenaris 22.23 53.68 31.45 1.17 N Density (ppg) 15.8 Volume pumped (BBLs) 56.2 Mixing / Pumping Rate (bpm): 4 o Z Post Flush (Spacer) Csg Wt. On Hook: 175,000 Type Float Collar: Innovex No. Hrs to Run: Csg Wt. On Slips: 135,000 Type of Shoe: Innovex Casing Crew: Doyon Rotate Csg X Yes No Recip Csg X Yes _ No Ft. Min. 9.2 PPG Fluid Description: Spud Mud Liner hanger Info (Make/Model): Liner top Packer?: _Yes _ No Liner hanger test pressure: Floats Held X Yes _ No Centralizer Placement: 99 each 9-5/8" x 12-1/2' Expand-o-lizer centralizers ran. CEMENTING REPORT V Shoe @ FC @ Top of Liner Preflush (Spacer) Type: Density (ppg) Volume pumped (BBLs) Lead Slurry Type: Lead Cement Sacks: 585 Yield: 2.35 Density (ppg) 12 Volume pumped (BBLs) 245 Mixing / Pumping Rate (bpm): 4 Tail Slurry Lu Type: Tail Cement Sacks: 400 Yield: 1.16 Density (ppg) 15.8 Volume pumped (BBLs) 82 Mixing / Pumping Rate (bpm): 4 w Post Flush (Spacer) z Type: Tuned Spacer Density (ppg) 10 Rate (bpm): 4 Volume: 60 w Displacement: Type: Spud Med Density (ppg) 92 Rate (bpm): 6 Volume (actual / calculated): 415.1/418.53 FCP (psi): 520 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1100 Casing Rotated? X Yes -No Reciprocated? X Yes -No % Returns during job 100 Cement returns to surface? X Yes No Spacer returns? X Yes -No Vol to Surf: 0.25 Cement In Place At: 1:50 Date: 12/1/2019 Estimated TOC: 2,526 Method Used To Determine TOC: Returns to surface Stage Collar @ 2525.82 Type ES Cementer Closure OK Preflush (Spacer) Type: Tuned Spacer Density (ppg) 10 Volume pumped (BBLs) 60 Lead Slurry Type: Perm L Sacks: 515 Yield: 4.41 Density (ppg) 10.7 Volume pumped (BBLs) 404 Mixing / Pumping Rate (bpm): 4 Tail Slurry w cs Type: Premium G Sacks: 270 Yield: 1.17 N Density (ppg) 15.8 Volume pumped (BBLs) 56.2 Mixing / Pumping Rate (bpm): 4 o Z Post Flush (Spacer) coi Type: Density (ppg) Rate (bpm): Volume: w w Displacement: Type: Spud Mud Density (ppg) 9.2 Rate (bpm): 5 Volume (actual / calculated): 172.9/171.8 FCP (psi): 400 Pump used for disp: Rig Bump Plug? X Yes No Bump press 1270 Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job 100 Cement returns to surface? X Yes -No Spacer returns? _Yes X No Vol to Surf: 220 Cement In Place At: 22:30 Date: 12/1/2019 Estimated TOC: 37 Method Used To Determine TOC: Returns to surface Post Job Calculations: Calculated Cmt Vol @ 0% excess: 428.8 Total Volume cmt Pumped: 787.2 Cmt returned to surface: 220 Calculated cement left in wellbore: 558.02 OH volume Calculated: 388.7 OH volume actual: 527.1 Actual % Washout: 35.6 www.weliez.net WellEz Information Management LLC ver 04818br V THE STATE °'ALASKA GOVERNOR MIKE DUNLEAVY Monty Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU M-26 Hilcorp Alaska, LLC Permit to Drill Number: 219-157 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Surface Location: 5039' FSL, 741' FEL, SEC. 14, TUN, R9E, UM, AK Bottomhole Location: 687' FSL, 638' FWL, SEC. 23, TI 3N, R9E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, VMce Chair DATED this 6 day of November, 2019. STATE OF ALASKA ALr,.,KA OIL AND GAS CONSERVATION COMMI__jON PERMIT TO DRILL 20 AAC 25.005 RECEIVEi NOV 12 2019 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. SptegiN ifrwell,f"roposed for: Drill Lateral ❑ Stratigraphic Test ❑ Development -Oil ❑✓ Service - Winj❑ Single Zone ❑ Coafb6&Gas ' GtAs Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 MPU M-26 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 MD: 14,940' TVD: 3,444' Milne Point Field Schrader Bluff Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 5039' FSL, 741' FEL, Sec 14, T13N, R9E, UM, AK ADL025514, ADL355023 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1470' FNL, 692' FWL, Sec 14, T13N, R9E, UM, AK LONS 16-004 11/19/2019 Total Depth: 1 9. Acres in Property: 14. Distance to Nearest Property: 687' FSL, 638' FWL, Sec 23, T13N, R9E, UM, AK 5815 2' to ncrest unit boundary ie4-n 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 59.0' 15. Distance to Nearest Well Open Surface: x- 533423 y- 6027889 ' Zone -4 GL / BF Elevation above MSL (ft): 25.3' Ito Same Pool: 3275' to MPU M-22 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90.7 degrees Downhole: 1540 Surface: 1199 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 20" 215# X-42 Weld 113' Surface Surface 113' 113' ±270 ft3 / Stg 1 L - 1236 ft3 T - 458 ft3Stg 12-1/4" 9-5/8" 40# L-80 TXP SR 6,535' Surface Surface 6,535' 3,524' 2 L - 1937 ft3 / T - 314 ft3 Tieback 7" 26# L-80 TXP SR 6,385' Surface Surface 6,385' 3,510' Tieback Assy. 8-1/2" 6-5/8" 20# L-80 Hyd 563 8,555' 6,385' 1 3,510' 14,940'. 3,444' Cementless Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes ❑ No ❑� 20. Attachments: Property Plat BOP Sketch ❑✓ Drilling Program ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Joe Engel Authorized Name: Monty Myers Contact Email: 'en el hilcor .com Authorized Title: Drilling Manager Contact Phone: 777-8395 � r� i� Y-1Authorized Signature: g Date: 1 — a Commission Use Only Permit to Drill VAPI �-- 150- Number: �j 3 Permit Approval I See cover letter for other Number: 2; 1,5 - 1 — Z zj Date: I I requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methaneas hydrates, or gas contained in shales: 0 Other: !F 3 ��a nSj(1 �� 1` j Samples req'd: Yes ❑ No® Mud log req'd: Yes ❑ No ['f H2S measures: Yes ❑ No ❑v Directional svy req'd: Yes 0 No ❑ Spacing exception req'd: Yes ❑ No 0 Inclination -only svy req'd: Yes ❑ No 0' Post initial injection MIT req'd: Yes ❑ No ❑ r APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401 is 7his permit is valid for 24 months f v 20 AAC 25.005(g) Attchm nts in Duplicate Milne Point Unit M-26 SB Producer Drilling Procedure 6.0 Planned Wellbore Schematic �--M N1411E Point Unit W it.IV,P1,1Iv! -267 Pron, Iced CHENPIATi La5tCompleted: Future f Crig. K8Elev.: 9.tr/C3.Elev_ 253 TREE & WELLHEAD Tree Cameron 4 1 5M Wellhead FN1C U' SM TC -1A will" x 41/2" TC -Il Top and Bottom Tubing Kange; with 3" CLlN "k1" BPV proft. Zea 318 NPT control dines_ OPEN HOLE / CEMENT DETAIL 4.1/2" 3 Size Type YW Grade/ Conn Drift tD Top 42° SONa {M? vardsiftoU dumped down bachidel £]nerxv. }23M 20'k34' Conductcr (insulate: y 215.5 / X-52 / Weld WA 12 1/4" 1st stage L-1236 ft3 / T-458 ft3 a 121/4" Znd rage L-1937 R3 / T— 314 ft3 rI B-ir' CkmiuUMSIctled Liner in 8-1/2" hole 114' WA 9.5/t, Surface 49/L-60/TXP r.AS[Nr nFTAli 4.1/2" 3 Size Type YW Grade/ Conn Drift tD Top 6 8PF 20'k34' Conductcr (insulate: y 215.5 / X-52 / Weld WA Surface 114' WA 9.5/t, Surface 49/L-60/TXP 8.674" Surface 6,535' 0.0758 7" Tieba;k 25/L -80I TXP 6.151" Surface 6,385' • 0.0383 6.5/8" Slotted Lirier 201 L-60/ t} 71.563 5.924" 6,385' 14,900' 0.0355 t U 61 WF Ut1A]L 4-1/2" Tubing 12.61 L-a0/TXP 3.358" Surface f6,DW 0.55i7 4 WELL INCLINATION DETAIL KAP LS 3W Max Hole Angle = @ let Pump 7 max Dale Angle = @ XN profile 41 Max KoleAngle Tu?.irgtail ii y o ri Maxt-leAngle= JEWELRY DETAIL '�Wmall No. Top MD item ih' ID Upper Ca etion 1 29` TubG� Hanger j4-1/2' TC -11 Top & 6�mj 3—qv, 3 '_5,709' 4.5'' Discharge Pressure Gauge Mandrel (Discharge Gauge) 3.874" 4 _5, 4.5' XD ng Sleeve 3.613 5 =5 4.5 GaugeMan re w1 Wire Inca Gauge 3. Ea9' 6 15,749' 4.5"'X Nipple{3.613"PaCldng Sorel 3.E13" 7 5,739 T x4.5 PHLRetrieva Pa 3.53}' B 15,79 45 XN Napp RHC-Pset 3.613 9 K, 4.5 4VLfG Lower Completion le 6,355 BOT SLZXP Liner Top Packer w/90 fps x 9-51&'fi_i L 6,393' T Tieback aC ASS. y. 5.25 OD ND -Co 6.251 12 6,395 T Int i n, 563 i -8D x 6-5/9- n 563 L -B0 XO 13 14,949' S-5/8'"SPa:e - SSr319 'l IIIIII � SQtI IIIIII Lsrnrw (I I II I 4-1/2" SOLID LINER DETAIL 4-1/2" Slotted LINER DETAIL D3e1 IIIIII(MD)TOP T°p (TUD}sn(ntD) (i rD) TBD IIIIII _ _ -- ��.. ..3,.49 -r-=14,WIMP /TD=j44.7(T'M GENERAL WELL INFO PBM=14,9CINPj TD=4444MAY,- Aa:TBo [rilled and Completed byDoyon 14 & le —Future Page 6 Hilcorp Alaska, LLC Milne Point Unit (MPU) M-26 Drilling Program Version 1 11/12/2019 Table of Contents 1.0 Well Summary.................................................................................................................................2 2.0 Management of Change Information............................................................................................3 3.0 Tubular Program: ........................................................................................................................... 4 4.0 Drill Pipe Information: ................................................................................................................... 4 5.0 Internal Reporting Requirements..................................................................................................5 6.0 Planned Wellbore Schematic.......................................................................................................6 7.0 Drilling / Completion Summary.....................................................................................................7 8.0 Mandatory Regulatory Compliance / Notifications.....................................................................8 9.0 R/U and Preparatory Work.........................................................................................................11 10.0 NIU 21-1/4" 2M Diverter System.................................................................................................12 11.0 Drill 12-1/4" Hole Section.............................................................................................................14 12.0 Run 9-5/8" Surface Casing...........................................................................................................17 13.0 Cement 9-5/8" Surface Casing.....................................................................................................22 14.0 N/D Diverter, NIU Wellhead, Run Killstring, RDMO...............................................................27 15.0 MIRU Innovation, BOP NIU and Test, Pull Killstring..............................................................28 16.0 Drill 8-1/2" Hole Section...............................................................................................................29 17.0 Run 6-5/8" Production Liner.......................................................................................................34 18.0 Run 7" Tieback..............................................................................................................................38 19.0 Run Upper Completion.................................................................................................................41 20.0 Doyon 14 Diverter Schematic.......................................................................................................43 21.0 Doyon 14 BOP Schematic.............................................................................................................44 22.0 Innovation BOP Schematic..........................................................................................................45 23.0 Wellhead Schematic......................................................................................................................46 24.0 Days Vs Depth...............................................................................................................................47 25.0 Formation Tops & Information...................................................................................................48 26.0 Anticipated Drilling Hazards.......................................................................................................49 27.0 Doyon 14 Layout............................................................................................................................52 28.0 Innovation Rig Layout..................................................................................................................53 29.0 FIT Procedure...............................................................................................................................54 30.0 Doyon 14 Choke Manifold Schematic.........................................................................................55 31.0 Innovation Choke Manifold.........................................................................................................56 32.0 Casing Design................................................................................................................................57 33.0 8-1/2" Hole Section MASP............................................................................................................58 34.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................59 35.0 Surface Plat (As Built) (NAD 27).................................................................................................60 36.0 Schrader Bluff OA Sand Offset MW vs TVD Chart..................................................................61 0 Hilcom E -U - 1.0 Well Summary Milne Point Unit M-26 SB Producer Drilling Procedure Well MPU M-26 Pad Milne Point "M" Pad Planned Completion Tye Jet Pump on 4-1/2 tubing Target Reservoir(s) Schrader Bluff OA Sand ' Planned Well TD, MD / TVD 14,940' MD / 3,,524' TVD 3,.� . A PBTD, MD / TVD 14,930' MD / 3,444' TVD Surface Location (Governmental) 240' FNL, 741' FEL, Sec 14, TON, R9E, UM, AK Surface Location (NAD 27) X= 533423.9, Y= 6027889.5 - Top of Productive Horizon (Governmental) 1470' FNL, 692' FWL, Sec 14, T13N, R9E, UM, AK TPH Location (NAD 27) X= 529583 Y= 6026642 BHL (Governmental) 687' FSL, 638' FWL, Sec 23, TON, R9E, UM, AK BHL (NAD 27) X= 529573, Y= 6018241 AFE Number AFE Drilling Days 19 AFE Completion Days 4 AFE Drilling Amount $4,227,470 AFE Completion Amount $1,978,973 AFE Facility Amount $391,000 Maximum Anticipated Pressure (Surface) 1199 psig Maximum Anticipated Pressure (Downhole/Reservoir) 1540 psig Work String 5" 19.5# S-135 NC 50 D14 KB Elevation above MSL: 33.7 ft + 25.3 ft = 59.0 ft Innovation KB above MSL: 26.5 ft + 25.3 ft = 51.8 ft GL Elevation above MSL: 25.3 ft BOP Equipment 13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams Page 2 2.0 Management of Change Information Hilcorp Alaska, LLC Heil rp Changes to Approved Permit to Drill Date: 11/11/2019 Subject: Changes to Approved Permit to Drill for MPU M-26 File *: MPU M-26 Drilling and Completion Program Any modifications to MPU M-26 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be approved in advance to the AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Prepared: Drilling Engineer Page 3 Date Date Milne Point Unit M-26 SB Producer Hilcompanyorp Energy C Drilling Procedure 2.0 Management of Change Information Hilcorp Alaska, LLC Heil rp Changes to Approved Permit to Drill Date: 11/11/2019 Subject: Changes to Approved Permit to Drill for MPU M-26 File *: MPU M-26 Drilling and Completion Program Any modifications to MPU M-26 Drilling & Completion Program will be documented and approved below. Changes to an approved APD will be approved in advance to the AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Prepared: Drilling Engineer Page 3 Date Date 3.0 Tubular Program: Milne Point Unit M-26 SB Producer Drilling Procedure Hole S OD (in) ID (in) Drift Conn OD Wt Grade Conn Burst (psi) Collapse Tensio Cond 20" 19.25" - - - X-52 Weld 6.625" 19.5 S-135 DS50 36,100 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 TXP 5,750 3,090 916 Tieback 7" 6.276" 6.151" 7.656 26 L-80 TXP 7,240 5410 604 8-1/2" 6-5/8 Slotted 6.049 5.924F7.390 20 L-80 Hydri1563 6,090 3,470 459 4.0 Drill Pipe Information: Hole OD ID (in) TJ ID TJ OD Wt Grade Conn M/U M/U Tension (in ' bs) 4.276" Surface & 5" 3.25" 6.625" 19.5 S-135 DS50 36,100 43,100 560klb Production 5" 4.276" 3.25" 6.625" 19.5 S-135 NC50 30,730 34,136 560klb All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery). Page 4 Hilcorp F.-0,= 5.0 Internal Reporting Requirements Milne Point Unit M-26 SB Producer Drilling Procedure 5.1 Fill out daily drilling report and cost report on WellEz. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area — this will not save the data entered, and will navigate to another data entry. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. • Enter the MD and TVD depths EVERY DAY whether you are making hole or not. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolinighilcorp.com, mmyers2hilcorp, jengel(2hilcorp.com and cdinger@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by lam on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. 5.4 EHS Incident Reporting • Health and Safety: Notify EHS field coordinator. • Environmental: Drilling Environmental Coordinator • Notify Drilling Manager & Drilling Engineer on all incidents • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As -Run" Casing tally to mmyerskhilcorp,com Lgelghilcorp.com and cdinger@hilcorp.com 5.6 Casing and Cement report • Send casing and cement report for each string of casing to mm_yeers_@hilcorp.com jengelghilcorp.com and cdinger@hilcorp.com 5.7 Hilcorp Milne Point Contact List: Title Name Work Phone Cell Phone Email Drilling Manager Monty Myers 907.777.8431 907.538.1168 mmyers@hilcorp.com Drilling Engineer Joe Engel 907.777.8395 805.235.6265 iengel@hilcorp.com Completion Engineer Taylor Wellman 907.777.8449 907.947.9533 twellman@hilcorp.com Geologist Kevin Eastham 907.777.8316 907.360.5087 keastham@hilcorp.com Reservoir Engineer Reid Edwards 907.777.8421 907.250.5081 reedwards@hilcorp.com Drilling Env. Coordinator Keegan Fleming 907.777.8477 907.350.9439 kfleming@hilcorp.com EHS Manager Carl Jones 907.777.8327 907.382.4336 calones@hilcorp.com Drilling Tech Cody Dinger 907.777.8389 509.768.8196 cd_inger@hilcorp.com Page 5 7.0 Drilling / Completion Summary Milne Point Unit M-26 SB Producer Drilling Procedure MPU M-26 is a grassroots jet pump producer planned to be drilled in the Schrader Bluff OA sand. M-26 is part of a multi well program targeting the Schrader Bluff sand on M -Pad. The directional plan is a catenary well path build, 12.25" hole with 9-5/8" surface casing set into the top of the Schrader Bluff OA sand. An 8.5" lateral section will then be drilled. A 6-5/8" slotted liner will be run in the open hole section and the well produced with a jet pump assembly. The M-26 directional plan has the surface hole crossing the unity boundary to the north, in to KRU, and then returning to MPU before landing in the target zone. M-26 will not be producing hydorcarbons from KRU and no pay zone will be open with 500 feet of the MPU boundary, in compliance with AOGCC regulations. A wellbore easement application has been approved. The Doyon 14 will be used to drill the surface hole. Once surface hole is cased and cemented, D 14 will run a freeze the wellbore. the well, and Drilling operations are expected to commence approximately November 19, 2019, pending rig schedule. Surface casing will be run to 6,535' MD / 3,524' TVD and cemented to surface via a 2 stage primary cement job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, necessary remedial action will then be discussed with AOGCC authorities. All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility. General sequence of operations: 1. MIRU Doyon 14 to well site cwt 2. N/U & Test 21-1/4" Diverter and 16" diverter line 3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing 4. N/D diverter, N/U wellhead, run kill string, freeze protect. RDMO Doyon 14. gyp. 5. MIRU Innovation Rig. NU 13-5/8" 5M BOP & Test, pull kill string 6. Drill 8-1/2" lateral to well TD. Run 6-5/8" production liner 7. Run 7" tieback 8. Run Upper Completion 9. N/D BOP, N/U Tree, RDMO Innovation Reservoir Evaluation Plan: 1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res ° / 2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering) Page 7 Hilcorp F—W 2 Milne Point Unit M-26 SB Producer Drilling Procedure 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations, specific regulations are listed below. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling and completion of MPU M-26. Ensure to provide AOGCC 24 hrs notice prior to testing BOPS. • The initial test of BOP equipment will be to 250/3000 psi & subsequent tests of the BOP equipment will be to 250/3000 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation or control fluid flow from the well bore, AOGCC is to be notified and we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". o Ensure the diverter vent line is at least 75' away from potential ignition sources • Ensure AOGCC approved drilling permit isposted on the rig floor and in Co Man office. / AOGCC Regulation Variance Requests: V No variances are requested at this time. See note in Section 7 regarding wellbore easement application. Page 8 Summary of Doyon 14 BOP Equipment & Test Requirements Hole Section Equipment Test Pressure(psi) 12 1/4" • 21-1/4" 2M Divertw/ 1�Di,,,tq Function Test Only Milne Point Unit • 13-5/8" x 5M Hydril "GK" Annular BOP M-26 SB Producer N/A Hilcorp Energy Cumpmy Drilling Procedure Summary of Doyon 14 BOP Equipment & Test Requirements Hole Section Equipment Test Pressure(psi) 12 1/4" • 21-1/4" 2M Divertw/ 1�Di,,,tq Function Test Only • 13-5/8" x 5M Hydril "GK" Annular BOP • 13-5/8" x 5M Hydril MPL Double Gate N/A o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets For Reference • 13-5/8" x 5M Hydril MPL Single ram • 3-1/8" x 5M Choke Line N/A • 3-1/8" x 5M Kill line 250/3000 • 3-1/8" x 5M Choke manifold • 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. Summary of Innovation BOP Equipment & Test Requirements Hole Section Equipment Test Pressure(psi) For Reference • 13-5/8" 5M CTI Annular BOP w/ 16" diver -ter line N/A • 13-5/8" x 5M Control Technology Inc Annular BOP • 13-5/8" x 5M Control Technology Inc Double Gate Initial Test: 250/3000 o Blind ram in btm cavity • Mud cross w/ 3" x 5M side outlets 8-1/2" • 13-5/8" x 5M Control Technology Single ram • 3-1/8" x 5M Choke Line Subsequent Tests: • 3-1/8" x 5M Kill line 250/3000 • 3-1/8" x 5M Choke manifold • Standpipe, floor valves, etc Primary closing unit: Control Technology Inc. (CTI), 6 station, 3000 psi, 220 gallon accumulator unit. Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is an electric triplex pump on a different electrical circuit and emergency pressure is provided by bottled nitrogen. The remote closing operator panels are located in the doghouse and on accumulator unit. Page 9 Milne Point Unit M-26 SB Producer Drilling Procedure 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.reggAalaska.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(a,alaska. gov Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixsegalaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotifhtml Notification / Emergency Phone: 907-793-1236 (During normal Business Hours) Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours) Page 10 ff Hilcarp Energy Company 9.0 RX and Preparatory Work Milne Point Unit M-26 SB Producer Drilling Procedure 9.1 M-26 will utilize a newly set 20" conductor on M -Pad. Ensure to review attached surface plat and make sure rig is over appropriate conductor. 9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor. 9.3 Install landing ring. 9.4 Insure (2) 4" nipples are installed on opposite sides of the conductor with ball valves on each. 9.5 Level pad and ensure enough room for layout of rig footprint and R/U. 9.6 Rig mat footprint of rig. 9.7 MIRU Doyon 14. Ensure rig is centered over conductor to prevent any wear to BOPE or wellhead. 9.8 Mud loggers WILL NOT be used on either hole section. 9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<80°F). 9.10 Ensure 6" liners in mud pumps. • Continental EMSCO FB -1600 mud pumps are rated at 4665 psi, 462 gpm @ 110 spm @ 95% volumetric efficiency. Page 11 10.0 NX 21-1/4" 2M Diverter System 10.1 N/U 21-1/4" Hydril MSP 2M Diverter System (Diverter Schematic attached to 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 ienition source • Place drip berm at the end of diverter line. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. Page 12 Milne Point Unit M-26 SB Producer Hilco En��gy Cov� Drilling Procedure 10.0 NX 21-1/4" 2M Diverter System 10.1 N/U 21-1/4" Hydril MSP 2M Diverter System (Diverter Schematic attached to 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 ienition source • Place drip berm at the end of diverter line. 10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. Page 12 10.4 Rig & Diverter Orientation: • May change on location `P M-58 Ai -22 U-17 M-23 ■ ■ M-18 M-24 ji ■ M-19 M-26 7 i ill Diverter Line Drawing Not To Scale MPU — P a d Diverter Line May Be oriented Different On Dation Page 13 G p HI t Milne Point Unit M-26 SB Producer Hilcorp E -W C-pmy Drilling Procedure 10.4 Rig & Diverter Orientation: • May change on location `P M-58 Ai -22 U-17 M-23 ■ ■ M-18 M-24 ji ■ M-19 M-26 7 i ill Diverter Line Drawing Not To Scale MPU — P a d Diverter Line May Be oriented Different On Dation Page 13 G p HI t 11.0 Drill 12-1/4" Hole Section Milne Point Unit M-26 SB Producer Drilling Procedure 11.1 P/U 12-1/4" directional drilling assembly: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Be sure to run a UBHO sub for wireline gyro • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135. • Run a solid float in the surface hole section. 11.2 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor. • Consider using a trash bit to clean out conductor to mitigate potential damage from debris in conductor. 11.3 Drill 12-1/4" hole section to section TD, in the Schrader OA sand. Confirm this setting depth with the Geologist and Drilling Engineer while drilling the well. • Monitor the area around the conductor for any signs of broaching. If broaching is observed, Stop drilling (or circulating) immediately notify Drilling Engineer. • Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6 deg / 100. • Hold a safety meeting with rig crews to discuss: • Conductor broaching ops and mitigation procedures. • Well control procedures and rig evacuation • Flow rates, hole cleaning, mud cooling, etc. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Keep mud as cool as possible to keep from washing out permafrost. • Pump at 400-600 gpm. Monitor shakers closely to ensure shaker screens and return lines can handle the flow rate. • Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if packoffs, increase in pump pressure or changes in hookload are seen • Slow in/out of slips and while tripping to keep swab and surge pressures low • Ensure shakers are functioning properly. Check for holes in screens on connections. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea gravel, clay balling or packing off. • Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 minimum at TD (pending MW increase due to hydrates). • Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand drilled. Page 14 ON Gas hydrates have not been seen on M -Pad. However, be prepared for them. In MPU they have been encountered typically around 2100-2400' TVD (just below permafrost). Be prepared for hydrates: • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD • Monitor returns for hydrates, checking pressurized & non -pressurized scales • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. Surface Hole AC: • There are no wells with a clearance factor of <1.0 11.4 12-1/4" hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval WL(For Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.2+Hydrates if need based on offset wells) MW can be cut once —500' below hydrate zone • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. Page 15 Milne Point Unit M-26 SB Producer Hilcorp E -W �P�Y Drilling Procedure Gas hydrates have not been seen on M -Pad. However, be prepared for them. In MPU they have been encountered typically around 2100-2400' TVD (just below permafrost). Be prepared for hydrates: • Gas hydrates can be identified by the gas detector and a decrease in MW or ECD • Monitor returns for hydrates, checking pressurized & non -pressurized scales • Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing out additional permafrost. Attempt to control drill (150 fph MAX) through the zone completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to break out. Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well. MW will not control gas hydrates, but will affect how gas breaks out at surface. Surface Hole AC: • There are no wells with a clearance factor of <1.0 11.4 12-1/4" hole mud program summary: • Density: Weighting material to be used for the hole section will be barite. Additional barite or spike fluid will be on location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with 9.2+ ppg. Depth Interval WL(For Surface — Base Permafrost 8.9+ Base Permafrost - TD 9.2+Hydrates if need based on offset wells) MW can be cut once —500' below hydrate zone • PVT System: MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. • Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue. • Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM (10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while drilling the surface interval to prevent losses and strengthen the wellbore. • Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are recommended to reduce the incidence of bit balling and shaker blinding when penetrating the high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A. Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G / X- CIDE 207 MUST be made to control bacterial action. Page 15 Hilcorp E—,Zy Company Milne Point Unit M-26 SB Producer Drilling Procedure • 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: Section Density Viscosity Plastic Viscosit Yield Point AN FL pH Tem Surface 1 8.8-9.8-1 75-175 1 20-40 25-45 <10 8.5-9.0 1 5 70 F System Formulation: Gel + FW spud mud Product- Surface hole Size Pkg ppb or (% liquids) M -I Gel 50 lb sx 25 Soda Ash 50 lb sx 0.25 PolyPac Supreme UL 50 lb sx 0.08 Caustic Soda 50 lb sx 0.1 SCREENCLEEN 1 55 1 gal dm 1 0.5 11.5 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity. 11.6 RIE t/ bottom, proceed to BROOH t/ HWDP • Pump at full drill rate (400-600 gpm), and maximize rotation. • Pull slowly, 5 — 10 ft / minute, adjust as dictated by hole conditions • Monitor well for any signs of packing off or losses. • Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay balling. • If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until parameters are restored. 11.7 TOOH and LD BHA 11.8 No open hole logging program plarmed. ` Page 16 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV._ • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120' shoe track assembly consisting of - 9 -5/8" Float Shoe 1 joint — 9-5/8" TXP, 2 Centralizers 10' from each end w/ stop rings 1 joint — 9-5/8" TXP, 1 Centralizer mid joint w/ stop ring Milne Point Unit Float Collar w/ Stage Cementer Bypass Baffle `Top Hat' 1 joint — 9-5/8" TXP, 1 Centralizer mid joint with stop ring M-26 SB Producer HES Baffle Adaptor Hilco F—w Drilling Procedure 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment (CRT & Tongs) • Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV._ • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • R/U of CRT if hole conditions require. • R/U a fill up tool to fill casing while running if the CRT is not used. • Ensure all casing has been drifted to 8.75" on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U & thread locking 120' shoe track assembly consisting of - 9 -5/8" Float Shoe 1 joint — 9-5/8" TXP, 2 Centralizers 10' from each end w/ stop rings 1 joint — 9-5/8" TXP, 1 Centralizer mid joint w/ stop ring 9-5/8" Float Collar w/ Stage Cementer Bypass Baffle `Top Hat' 1 joint — 9-5/8" TXP, 1 Centralizer mid joint with stop ring 9-5/8" HES Baffle Adaptor • Ensure bypass baffle is correctly installed on top of float collar. This end up. Bypass Baffle • Ensure proper operation of float equipment while picking up. • Ensure to record S/N's of all float equipment and stage tool components. Page 17 Hilcorp Energy C—p-y 12.5 Float equipment and Stage tool equipment drawings: Type H ES Cementer Part No. SO No_ closing Sleeve No. Shear Pins Opening Sleeve No. Shear Pins ES Cementer Depth Bathe Adapter (if used) ID Depth Bypass or Shut-off Baffle ID Depth Float Collar Depth Float Shoe Depth Hole TD "Reference Casirxg Sales Manual Section S Page 18 "A C} a=all Length B Mie. ID After Drxllout C Id ex. Tool OD D Openag Seat ID E Closing Seat ID Plug Set Part No. • No - Closing ' OD_ Opening Plug OD OD Shut-off Plug OD Bypass Plug (if used) OD Milne Point Unit M-26 SB Producer Drilling Procedure Hikorp ESII Running Order ESB cementer SMrt Off Plug Bank Adapter By -Pass Plug t By Pass Baft Float Collar Float Shoe Milne Point Unit M-26 SB Producer Drilling Procedure 12.6 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: • 1 centralizer every joint t/ — 1000' MD from shoe • 1 centralizer every 2 joints to 2,000' above shoe (Top of Ugnu) • Verify depth of lowest Ugnu water sand for isolation with Geologist • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Break circulation prior to reaching the base of the permafrost if casing run indicates poor hole conditions. • Any packing off while running casing should be treated as a major problem. It is preferable to POH with casing and condition hole than to risk not getting cement returns to surface. 12.7 Install the Halliburton Type H ES -II Stage tool so that it is positioned at least 100' TVD below the permafrost (— 2,500' MD). (Halliburton ESIPC with packer element may be used). ✓ • Install centralizers over couplings on 5 joints below and 5 joints above stage tool. • Do not place tongs on ES cementer, this can cause damaged to the tool. • Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3300 psi. • ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2080 psi, and the tool to open at — 3000 psi. Reference ESIPC Procedure. 9-5/8" 409 L-80 TXP Make Up Torques: Casing OD Minimum Optimum Maximum 9-5/8" 18,860 ft -lbs 20,960 ft -lbs 23,060 ft -lbs Page 19 ff Hilcorp E—gy Company Milne Point Unit M-26 SB Producer Drilling Procedure TXPR'l-P-3 BTC ds� 1110812018 Outside Diameter 9.625 m. Min. Wall Thickness t"I Grade L80 Type 1 Wall Thickness 0.395 m. Connection 00 REGULAR Option CSI. UPLENG PIPE 96QY Eddy. Red 1steard::Red Grade L80 Type i• Cprift API Standard 1st Bard Brown 2na Band: 2nd ear= : - Brown Type Casing arc sand: - Bra nand: - 48v Band: - Nominal C* 9.625 in Nominal tVeight 40ILVil Drift 8:679 ir. Nominal IC 8.835 in. We, Thie%nass 0-3S5 �a Flair, End'Weight 38.97 :bs't oD Toga :.z API PERFORMANCE Body'raeal Strength 916 x1000 s tclema''Yf-a 5750 p=-.. SM'IS BOM psi Co-Iacse 3090 "Si GEOMETRY Cc nectcn o[I 10.625 in Cooping Le*.g.h 10.825 en. Connection IG 8:823 it Make-up Lass 4.891 in. Ts.2s:s per i^ 5 Conne0on vC Opiion REGULAR PERFORMANCE ersion Errciency 100-0 £int sr -ad Svzngth 9 16 .000 x1000 tntemal Pressure Capacity l'! 5750.000 psi lbs Compre=-sion Efficiency t00': C,-mpression Strerrgh 946:000 x1000 Max. Allowaec4 Bending 38 -100 ft lbs Er-emal =7zs5l7a Cas -;city 3090.000 ps WAKE-UP TORQUES I M.7;mur. 1686V'— optimum 20960 P4Ls hlaximurr 23HO f. -in OPERATION LIMIT TORQUES operatrg Twqua 3,60V1-:- .__ Yield Torque 45300 f -hs Notes This connection is fully interchangeable with. TXP@ BTC - 9.625 in. - 35143.5 i 47153.5155.4 lbs/ft [1] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C3 /ISO 1 0400 - 2007. Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load. which will be reduced. Please contact a local Tenaris technical sales representative. Page 20 Hilcorp Energy C—p-y Milne Point Unit M-26 SB Producer Drilling Procedure 12.8 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use BOL 2000 thread compound. Dope pin end only w/ paint brush. • Centralization: o 1 centralizer every 2 joints to base of conductor 12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.10 Slow in and out of slips. 12.11 P/U landing joint and M/U to casing string. Position the casing shoe +/- 10' from TD. Strap the landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference when getting the casing on depth. 12.12 Lower casing to setting depth. Confirm measurements. 12.13 Have slips staged in cellar, along with necessary equipment for the operation. 12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement job. Ensure adequate amounts of cold M/U water are available to achieve this. If possible reciprocate casing string while conditioning mud. Page 21 13.0 Cement 9-5/8" Surface Casing Milne Point Unit M-26 SB Producer Drilling Procedure 13.1 Hold a pre job safety meeting over the upcoming cement operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cementing unit at acceptable rates. • How to handle cement returns at surface. Ensure vac trucks are on standby and ready to assist. • Which pumps will be utilized for displacement, and how fluid will be fed to displacement PUMP. • Ensure adequate amounts of water for mix fluid is heated and available in the water tanks. • Positions and expectations of personnel involved with the cementing operation. i. Extra hands in the pits to strap during the cement job to identify any losses • Review test reports and ensure pump times are acceptable. • Conduct visual inspection of all hard lines and connections used to route slurry to rig floor. 13.2 Document efficiency of all possible displacement pumps prior to cement job. 13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will help ensure any debris left in the cement pump or treating iron will not be pumped downhole. 13.4 R/U cement line (if not already done so). Company Rep to witness loading of the top and bottom plugs to ensure done in correct order. 13.5 Fill surface cement lines with water and pressure test. 13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below calculations for the 1St stage, confirm actual cement volumes with cementer after TD is reached. 13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead & f J) tail, TOC brought to stage tool. �11 Estimated 11t Stage Total Cement Volume: Page 22 3T'" Section Calculation Vol (bbl) Vol (ft3) 12-1/4" OH x 9-5/8" (5,535'- 2500') x .0558 b pf x 1.3 = 220.2 1236.3 JCasing Total Lead 220.2 1236.3 12-1/4" OH x 9-5/8" (6,535'- 5,535') x .0558 b pf x 1.3 = 72.5 407 — Casing ~ 9-5/8" Shoe Track 120' x .0758 bpf = 9.1 51.09 Total Tail 1 81.6 458 Page 22 3T'" Milne Point Unit M-26 SB Producer Drilling Procedure Cement Slurry Design (1st Stage Cement Job): 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. • Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: VI/ s 6,415' x .0758 bpf = 486.3 bbls aLo ny 80 bbls of tuned spacer to be left b nd stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until Page 23 Lead Slurry Tail Slurry System ExtendaCEM TM System SwiftCEM TM System Density 11.7 Ib/gal 15.8 Ib/gal Yield 4.298 ft3/sk 1.16 ft3/sk Mixed Water 21.13 gal/sk 5.04 gal/sk 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue with the cement job. 13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of mud pits, spotting water across the HEC stage cementer. • Ensure volumes pumped and volumes returned are documented and constant communication between mud pits, HEC Rep and HES Cementers during the entire job. 13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very accurate using 0.0625 bps (5" liners) for the Quattro pump output. To operate the stage tool hydraulically, the plug must be bumped. 13.11 Displacement calculation: VI/ s 6,415' x .0758 bpf = 486.3 bbls aLo ny 80 bbls of tuned spacer to be left b nd stage tool 13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any point during the job. Be prepared to pump out fluid from cellar. Have black water available to contaminate any cement seen at surface. 13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over displace by no more than 50% of shoe track volume, ±4.5 bbls before consulting with Drilling Engineer. 13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening plug is available if needed. This is the back-up option to open the stage tool if the plugs are not bumped. 13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until Page 23 Milne Point Unit M-26 SB Producer Drilling Procedure cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened. 0rl--- e4 13.16 Increase pressure to 3300 psi to open circulating ports in stage collar. Slightly higher pressure may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation for the 2nd stage of the cement job. 13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker bypass line to the cuttings tank. Have black water available and vac trucks ready to assist. Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact with the cement. Page 24 Second Stage Surface Cement Job: 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre job safety meeting. • Past wells have seen pressure increase while circulating through stage tool after reduced rate 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Section Calculation Vol (bbl) Vol (ft3) SwiftCEM TM System (Hal Cem) Milne Point Unit (110') x.26 bpf x 1= 28.6 161 M-26 SB Producer 12-1/4" OH x 9-5/8" Casing Hilco "� Drilling Procedure Second Stage Surface Cement Job: 13.18 Prepare for the 2nd stage as necessary. Circulate until first stage reaches sufficient compressive strength. Try to maintain flow rate through stage tool until 2nd stage is ready. Hold pre job safety meeting. • Past wells have seen pressure increase while circulating through stage tool after reduced rate 13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing head. 13.20 Fill surface lines with water and pressure test. 13.21 Pump remaining 60 bbls 10.5 ppg tuned spacer. 13.22 Mix and pump cmt per below recipe for the 2nd stage. 13.23 Cement volume based on annular volume + open hole excess (200% for lead and 100% for tail). Job will consist of lead & tail, TOC brought to surface. However cement will continue to be pumped until clean spacer is observed at surface. Estimated 2nd Stage Total Cement Volume: Cement Slurry Design (2nd stage cement job): Section Calculation Vol (bbl) Vol (ft3) SwiftCEM TM System (Hal Cem) 20" Conductor x 9-5/8" Casing (110') x.26 bpf x 1= 28.6 161 J 12-1/4" OH x 9-5/8" Casing (2000' - 110') x .0558 bpf x 3 = 316.4 1776.3 Total Lead 345 1937 — ra 12-1/4" OH x 9-5/8" Casin g (2500'- 2000') x.0558 bpf x 2 = 55.8 314 ~ Total Tail 1 55.8 314 Cement Slurry Design (2nd stage cement job): Page 25 4� Lead Slurry Tail Slurry System Permafrost L SwiftCEM TM System (Hal Cem) Density 10.7 Ib/gal 15.8 Ib/gal Yield 4.3279 ft3/sk 1.16 ft3/sk Mixed Water 21.405 gal/sk 5.08 gal/sk Page 25 4� Hilcorp W C. -Pa, Milne Point Unit M-26 SB Producer Drilling Procedure 13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail. 13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out of mud pits. 13.26 Displacement calculation: / 2500' x .0758 bpf = 19(ll�hIs mud v ,- 13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out fluid from cellar. Have black water available to retard setting of cement. 13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should circulate approximately 100 - 150 bbls of cement slurry to surface. µI 13.29 Land closing plug on stage collar and pressure up to 1000 — 1500 psi to ensure stage tool closes. Follow instructions of Halliburton personnel. Bleed o pry ess e and check to ensure stage tool has closed. Slips will be set as per plan to allow full annulus for returns during surface cement job. Set slips 13.30 Make initial cut on 9-5/8" final joint. L/D cut joint. Make final cut on 9-5/8". Dress off stump. Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule. Ensure to report the following on wellez: • Pre flush type, volume (bbls) & weight (ppg) • Cement slurry type, lead or tail, volume & weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped & bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface & volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As -Run" casing tally & casing and cement report to ien eellghilcorp.com and cdin eerrghilcorp. com This will be included with the EOW documentation that goes to the AOGCC. Page 26 14.0 N/D Diverter, NX Wellhead, Run Killstring, RDMO 14.1 N/D the diverter T, knife gate, diverter line & N/U 11" x 13-5/8" 5M casing spool. 14.2 RIH w/ 3.5" Killstring to 2,500' TVD 14.3 Land tubing hanger. 14.4 RILDS and test hanger. LD landing joint. 14.5 Install BPV. 14.6 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. 14.7 Freeze protect well. 14.8 Set BPV dart. Test tree to 250 psi low / 5000 psi high. Pull BPV dart and BPV 14.9 RDMO Doyon 14 Page 27 1� Milne Point Unit M-26 SB Producer Hilco+rp E—gy Cumpeny Drilling Procedure 14.0 N/D Diverter, NX Wellhead, Run Killstring, RDMO 14.1 N/D the diverter T, knife gate, diverter line & N/U 11" x 13-5/8" 5M casing spool. 14.2 RIH w/ 3.5" Killstring to 2,500' TVD 14.3 Land tubing hanger. 14.4 RILDS and test hanger. LD landing joint. 14.5 Install BPV. 14.6 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. 14.7 Freeze protect well. 14.8 Set BPV dart. Test tree to 250 psi low / 5000 psi high. Pull BPV dart and BPV 14.9 RDMO Doyon 14 Page 27 1� Milne Point Unit M-26 SB Producer Drilling Procedure 15.0 MIRU Innovation, BOP NX and Test, Pull Killstring 15.1 MIRU Innovation Rig • NOTE DIFFERENCE IN RKB for surface casing equipment depths 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" x 5M single gate • Double gate ram should be dressed with 2-7/8" x 5" VBRs in top cavity, blind ram in bottom cavity. �� • Single ram can be dressed with 2-7/8" x 5" VBRs • N/U bell nipple, install flowline. �, 0 • Install (1) manual valve & 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 HRC outside of the manual valve 15.3 RU MPD RCD and related equipment 15.4 Run 5" BOP test plug 15.5 Test BOP to 250/3000 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Test 5" test joints • Confirm test pressures with PTD • Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure is trapped underneath test plug • Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech 15.6 R/D BOP test equipment 15.7 RAJ circ lines and circulate out diesel freeze protect 15.8 POOH, L/D killstrin g G 15.9 Mix 8.9 ppg FloPro fluid for production hole. ' 15.10 Set wearbushing in wellhead. 15.11 If needed, rack back as much 5" DP in derrick as possible to be used while drilling the hole section. 15.12 Ensure 5" liners in mud pumps. Page 28 16.0 Drill 8-1/2" Hole Section 16.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.220 PDM) 16.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 16.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 9 Vt; t. 0 `e- 16.4 RX and test casing to 2500 psi / 30 min. Ensure to record volume / pressure (every'/4 bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5750 / 2 = —2875 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 16.5 Drill out shoe track and 20' of new formation. 16.6 CBU and condition mud for FIT. I r 16.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 16.8 POOH & LD Cleanout BHA 16.9 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135 DS50 & NC50. • Run a ported float in the production hole section. 16.10 8-1/2" hole section mud program summary: • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. • 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 Page 29 Milne Point Unit M-26 SB Producer Hilcorp Ecegy Company Drilling Procedure 16.0 Drill 8-1/2" Hole Section 16.1 M/U 8.5" Cleanout BHA (Milltooth Bit & 1.220 PDM) 16.2 TIH w/ 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out stage tool. 16.3 TIH to TOC above the baffle adapter. Note depth TOC tagged on morning report. 9 Vt; t. 0 `e- 16.4 RX and test casing to 2500 psi / 30 min. Ensure to record volume / pressure (every'/4 bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5750 / 2 = —2875 psi, but max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as per AOGCC Industry Guidance Bulletin 17-001. 16.5 Drill out shoe track and 20' of new formation. 16.6 CBU and condition mud for FIT. I r 16.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT. Document incremental volume pumped (and subsequent pressure) and volume returned. 16.8 POOH & LD Cleanout BHA 16.9 P/U 8-1/2" directional BHA. • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure MWD is R/U and operational. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Drill string will be 5" 19.5# S-135 DS50 & NC50. • Run a ported float in the production hole section. 16.10 8-1/2" hole section mud program summary: • Density: Weighting material to be used for the hole section will be calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. • 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 Page 29 Milne Point Unit M-26 SB Producer Drilling Procedure running to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are running the finest screens possible. • Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests excessive viscosifier concentrations can decrease return permeability. Do not pump high vis sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8.5 (hole diameter sufficient hole cleaning • Run the centrifuge continuously while drilling the production hole, this will help with solids removal. • Dump and dilute as necessary to keep drilled solids to an absolute minimum. • MD Totco PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, & Toolpusher office. System Type: 8.9 — 9.5 ppg Baradrill N drilling fluid Properties: IntervalDens ty PV YP LSYP Total Solids MBT HPHT Hardness Production 8.9-9.5 -25 - ALAP 15-30 4-6 <10% <8 <1 1.0 <100 System FormiTFa on: Product Concentration Water 0.955 bbl KCL 11 ppb KOH 0.1 ppb N -VIS 1.0 — 1.5 ppb DEXTRID LT 5 ppb BARACARB 5 4 ppb BARACARB 25 4 ppb BARACARB 50 2 ppb BARACOR 700 1.0 ppb BARASCAV D 0.5 ppb X-CIDE 207 0.015 ppb 16.11 TIH with 8-1/2" directional assembly to bottom 16.12 Displace wellbore to 8.9 ppg Baradrill-N drilling fluid Page 30 16.13 Begin drilling 8.5" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 16.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm • RPM: 120+ • Milne Point Unit wet to maximize solids removal efficiency. Check for holes in screens on every connection. • M-26 SB Producer • Hilco+rp E—gy Campeny Drilling Procedure 16.13 Begin drilling 8.5" hole section, on -bottom staging technique: • Tag bottom and begin drilling with 100 - 120 rpms at bit. Allow WOB to stabilize at 5-8k. • Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations • If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to P/U off bottom and restart on bottom staging technique. If stick slip continues, consider adding .5% lubes 16.14 Drill 8-1/2" hole section to section TD per Geologist and Drilling Engineer. • Flow Rate: 350-550 gpm, target min. AV's 200 ft/min, 385 gpm • RPM: 120+ • Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly wet to maximize solids removal efficiency. Check for holes in screens on every connection. • Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low • Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex: concretion deflection • Monitor Torque and Drag with pumps on every 5 stands • Monitor ECD, pump pressure & hookload trends for hole cleaning indication • Surveys can be taken more frequently if deemed necessary. • Good drilling and tripping practices are vital for avoidance of differential sticking. Make every effort to keep the drill string moving whenever possible and avoid stopping with the BHA across the sand for any extended period of time. • Use ADR to stay in section. Reservoir plan is to undulate between Schrader OA1 & OA3 lobes in 1000-1500' MD increments, and keeping DLS <3° when moving between lobes • Limit maximum instantaneous ROP to < 250 fph. The sands will drill faster than this, but when concretions are hit when drilling this fast, cutter damage can occur. • Target ROP is as fast as we can clean the hole without having to backream connections .� • Schrader Bluff OA Concretions: 5-10% of lateral L-47: 6%, L-50 9.5% : F-106: 6.1%, F-107: 4.7%, F-018: 9.9%, F-109: 10%, F-110: 10.1% • Offset injection and abnormal pressure has been seen on M-10, -11, -12. MPD will be utilized to monitor pressure build up on connections. -" • 8.5" Lateral A/C: • There are no wells with a clearance factor < 1.0 16.15 Reference: Open hole sidetracking practice: • If a known fault is coming up, put a slight "kick-off ramp" in wellbore ahead of the fault so we have a nice place to low side. • Attempt to lowside in a fast drilling interval where the wellbore is headed up. • Orient TF to low side and dig a trough with high flowrates for the first 10 ft, working string back and forth. Trough for approx. 30 min. • Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the openhole sidetrack is achieved. Page 31 Milne Point Unit M-26 SB Producer Drilling Procedure 16.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ gpm) and rotation (120+ rpm). Pump tandem sweeps if needed • Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a consistent stream, circulate more if necessary • If seepage losses are seen while drilling, consider reducing MW at TD to 9.Oppg minimum 16.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter cake and calcium carbonate. Circulate the well clean. Losses during the cleanup of the wellbore are a good indication that the mud filter cake is being removed, including an increase in the loss rate. 16.18 Displace 1.5 OH + Liner volume with viscosified brine. • Proposed brine blend (same as used on M-16, aiming for an 8 on the 6rpm reading) - KCl: 7.1bbp for 2% NaCl: 60.9ppg for 9.4ppg Lotorq: 1.5% Lube 776: 1.5% Soda Ash: as needed for 9.5pH Busan 1060: 0.42ppb Flo -Vis Plus: 1.25ppb • Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further discussion needed prior to BROOH. 16.19 BROOH with the drilling assembly to the 9-5/8" casing shoe • Circulate at full drill rate (less if losses are seen, 350 gpm min). • Rotate at maximum rpm that can be sustained. • Pulling speed 5 — 10 min/std (slip to slip time, not including connections), adjust as dictated by hole conditions • If backreaming operations are commenced, continue backreaming to the shoe 16.20 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while 'f BROOH. 16.21 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps. Page 32 Milne Point Unit M-26 SB Producer Drilling Procedure 16.22 Monitor well for flow / monitor for pressure build up with MPD. Increase fluid weight if necessary • Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to determine if well is breathing, treat all flow as an influx until proven otherwise 16.23 POOH and LD BHA. 16.24 Continue to POH and stand back BHA if possible. Rabbit DP on TOH, ensure rabbit diameter is sufficient for future ball drops. Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any additional logging runs conducted. Page 33 Hilcorp E—Sy C—pauy 17.0 Run 6-5/8" Production Liner Milne Point Unit M-26 SB Producer Drilling Procedure 17.1 Well control preparedness: In the event of an influx of formation fluids while running the 6- 5/8" pre drilled liner, the following well control response procedure will be followed: • P/U & M/U the 5" safety joint (with 6-5/8" crossover installed on bottom, TIW valve in open position on top, 6-5/8" handling joint above TIW). This joint shall be fully M/U and available prior to running the first joint of 6-5/8" Predrilled liner. • Slack off and with 5" DP across the BOP, shut in ram or annular on 5" DP. Close TIW. • Proceed with well kill operations. 17.2 R/U 6-5/8" liner running equipment. • Ensure 6-5/8" 20# Hydril 563 x DS -50 crossover is on rig floor and M/U to FOSV. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total # of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/ vendor & model info. 17.3 Run 6-5/8" slotted production liner • Use API Modified or "Best O Life 2000 AG" thread compound. Dope pin end only w/ paint brush. Wipe off excess. • Utilize a collar clamp until weight is sufficient to keep slips set properly. • Run round nose float shoe on bottom. • 6-5/8" slotted liner will auto —fill • 6-5/8" Liner will be centralized with 1/joint free floating • If needed, install swell packers as 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 6-5/8" 20 # Hydri1563 Torque OD Minimum Optimum Maximum Yield Torque 6-5/8 5,900 ft -lbs 7,100 ft -lbs 10,300 ft -lbs 36,000 ft -lbs Page 34 H Hilcorp H -my C_p_y Milne Point Unit M-26 SB Producer Drilling Procedure Wedge 563(§-) 3.29.zflnmlztu -av t:f_"'p REGULAR PEWORMMCE Outairde Diameter 6.625m. Min, VWMI 439,IS3 , %,W Pr�jia Gapast, 6O1jC.Q1-Ax'_" WL Thickness Gra" LN 4wro Va, &W%;4f. =_urCrq 52.E Type I Wall Thickness 02m ¢r1 Com"bon OD REGULAR &A -UP TORQUES Option 7106 z" bi COUPLMG pff-E BOW 01MERATIOM LWIT TORQUES Rr�. Red 1!9 2mc Red Grade LNTypal* Drift AJDJ Standard fiat Brown 2nd Flami, fau"?"Jai Mavv".m ti 2rd Om-ia Brown Type Casing Std Banz 1-t Bard Wedge 5635 - 6-625 in. - 2.4126132 IWR Connections wish, Dopeless—IF, Te&mo' W are fuRy compatble v.aih the same cowection an its Standard version 3111 Cland GEOMETRY Nland'.x OC 6.6Z5 is Akm"'a! "'9m4fit 20.114 ftQ V 00 5.224 n Nurq,uN-) COO 4� 02U,ii 1151T.41 C 'liurc:. ARI PERFORAMNCE vc1d so,xn6024 453x 1 LCC It.; V�tjj Cw -V Y' i�l' -:Ajr.'a 3470 ps, GEONETW m4ti-Op Luys 4.056 �-c:)q 3.29.zflnmlztu -av t:f_"'p REGULAR PEWORMMCE 95.7 lo"I Y..111 sbcry^n 439,IS3 , %,W Pr�jia Gapast, 6O1jC.Q1-Ax'_" WL 1024 463-80G 010:13 Va, &W%;4f. =_urCrq 52.E Extu mz pmivva 34-70,00 ;m Ilewtl &A -UP TORQUES V plmam 5900 L" Optimum 7106 z" bi V.9014,111 10360 tw 01MERATIOM LWIT TORQUES Ow, aIr'Q Ta. 4.e 31M f-br, yleeTaqat 3600@';.f, BUCK -ON . ..... ...... fau"?"Jai Mavv".m ti Notes This conmcbon as ",mterdtiangeaNe with., Wedge 5635 - 6-625 in. - 2.4126132 IWR Connections wish, Dopeless—IF, Te&mo' W are fuRy compatble v.aih the same cowection an its Standard version Page 35 Milne Point Unit M-26 SB Producer Drilling Procedure 16.6. Ensure to run enough liner to provide for approx 150' overlap inside 9-5/8" casing. Ensure hanger/pkr will not be set in a 9-5/8" connection. AOGCC regulations require a minimum 100' overlap between the inner and outer strings as per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8" connection. 16.7. Before picking up Baker SLZXP liner hanger / packer assy, count the # of joints on the pipe deck to make sure it coincides with the pipe tally. 16.8. MX Baker SLZXP liner top packer to 6-5/8" liner. 16.9. Note PUW, SOW, ROT and torque of liner. Run liner in the hole one stand and pump through liner hanger to ensure a clear flow path exists. 16.10. RIH w/ liner on 5" HWDP no faster than 30 ft/min — this is to prevent buckling the liner and drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement carefully and avoid surging the hole or buckling the liner. Slow down running speed if necessary. • Ensure 5" HWDP has been drifted • There is no inner string planned to be run, as opposed to previous wells. The DP should auto fill. Monitor FL and if filling is required due to losses/surging. 16.11. 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. 16.12. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, & 20 rpm 16.13. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure shoe enters correct hole. 16.14. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in tension. 16.15. Rig up to pump down the work string with the rig pumps. 16.16. Break circulation. Begin circulating at —1 BPM and monitor pump pressures. Do not exceed 1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker. 16.17. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger. Page 36 jj Milne Point Unit M-26 SB Producer Drilling Procedure 16.18. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool and not at the WIV) down the workstring and pump slowly (1-2 bpm). Slow pump before the ball seats. Do not allow ball to slam into ball seat. 16.19. Continue pressuring ul) to 2700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes. Slack off 20K lbs on the ZXP liner hanger to ensure the HRDE setting tool is in compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4500 psi to release the HRDE running tool. 16.20. Bleed DP pressure to zero. Pick up to expose Rotating Dog Sub and set down 50k# without pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20 rpm and set down 50k# again, 16.21. PU to neutral weight, close BOP and test annulus to 1500 psi for 10 min and chart record same. 16.22. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If packer did not test, rotating dog sub can be used to set packer. If running tool cannot be hydraulically released, apply LH torque to mechanically release the setting tool. 16.23. P/U pulling running tool free of the packer and displace with at max rate to wash the liner top. Pump sweeps as needed. 16.24. POOH, L/D and inspect running tools. If setting of liner hanger/packer proceeded as planned, LDDP on the TOH. 16.25. M/U 3.5" wash tool & RIH w/ remaining DP out of derrick to liner top. 16.26. Wash through liner top at max rate & circulate hole clean. Pump sweeps around. Displace well to clean filtered brine after no solids are returned. c 16.27. POOH & L/D remaining 5" HWDP 16.28. Once running tool is L/D, swap to the completion AFE Page 37 M 18.1 Run 7" Tieback RIH w/ 3.5" washpipe on 5" dp to clean out liner top. POOH LDDP. Milne Point Unit M-26 SB Producer Drilling Procedure 18.2 RAJ 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" (250/3000 psi) solid body casing rams. 18.3 R/U 7" 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. 18.4 P/U tieback seal assembly and set in rotary table. Ensure 7" seal assembly has x4 1" holes above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7" annulus. 18.5 M/U first joint of 7" to seal assy. 18.6 Run 7" 26# TXP tieback to position seal assembly two joints above tieback sleeve. Record up & down weights. 7" 26# TXP MUT OD Minimum Optimum Maximum Yield Torque 7" 13,280 ft -lbs 14,750 ft -lbs 16,230 ft -lbs 23,400 ft -lbs Page 38 Energy Compevy Milne Point Unit M-26 SB Producer Drilling Procedure 87.5% TXP®R BTC 1 Z'D&201 B Outside Diameter TOM in- Min. Wall 87.5% Thickness Grade LBO elm 604.000 x1000 k4emalPressure Capacity 111 7240.000 psi Typo I Wall Thickness 0.362 in, Connection OD REGULAR lbs Option COUPLING PIPE OWY Body - Red I st Band: Red Grade LBO Type v Drift AN Standard 1st Ea., -J: Brown 2nd Band - 2nd Band. - Brown Type Casing 3rd Band - 3rd Band. - Atf, Sandi - PIPE BODY DATA GEJMEIW Normal 00 7-000 in NmiirA iiiivf'oo 26 lbyfl Drill 6.151 in. Norrinal ID 6,276 in Wall Trmoies.%i 0.362 in Plarr End'Wetght 25.69 tzeit OD Tcleram;s Apt PERFORMANCE So&j Yield SbmnM 604 0300 lbs Inlena Yie-j 7240 w SMYS 80000 psi Collapse 5410 Psi CONHEC�TION DATA GEOMETRY ceni —.1ion or) TOM in Cxrp4ing Lerld,- 10.200 In Connection ;D 6164 m, Mal;-amup Lms 4-579 in, TIrceadr ;*r in 5 Connection 00 Optm REGLFI-AR PERFORMANCE Tension Eftierey 100.0 % JanA Y4d Sbength 604.000 x1000 k4emalPressure Capacity 111 7240.000 psi bs Compression EFriercy 100's, C—Vesai- ,5-r-2tr, 6'O4,OQOx1,T,0 Max, Mcmable Sending 52'�I0QM lbs Eoiwiai Pressure Capactj 541 O.D00 psi MAKE-UP TORQUES Lfinit'-fum 132BO P -hs optmarl 14750 ft-ILs FiAa)'mxxr1 Ifim k OPERATION LIWTTORQUIES 0,erating T,:tqu= 20000 ft -t-- Yie,4 Tare 23400 ft -lbs Notes This connection is fully tnterchangeable With- TXF3V BTC - 7 in. - 23129 / 32135138 lbstft [1] Intenrial Pressure Capacitty related to structural resistance only. Internal pressure leak resistance as per section 10.3 API 5C3 I ISO 10400 - 2007, Page 39 18.7 M/U 7" to DP crossover. 18.8 M/U stand of DP to string, and M/U top drive. 18.9 Break circulation at 1 bpm and begin lowering string. Milne Point Unit M-26 SB Producer Drilling Procedure 18.10 Note seal assembly entering tieback sleeve with a pressure increase, Stop pumping and bleed off pressure, leave standpipe bleed off valve open. 18.11 Continue lowering string and land out on no-go. Set down 5 — l Ok lbs. Mark the pipe at this depth as "NO-GO DEPTH". 18.12 P/U string & remove unnecessary 7" joints. 18.13 P/U hanger assembly and space out. M/U (or L/D) necessary joints and pup joints to position seal assembly 1 ft above "NO-GO DEPTH" when tie -back hanger lands out in wellhead. 18.14 Ensure circulation is possible through 7" string.d �, d✓r c, y 18.15 RU and circulation corrosion inhibited brine in the 9-5/8" x 7" annulus. 18.16 With seals stabbed into SBE, Spot diesel freeze protection from 2500' to surface in 7" x 9-5/8" annulus by reverse circulating through the holes in the seal assembly. Ensure annular pressure are limited to prevent casing collapse of 7", verify collapse pressure of 7" tie back. 18.17 Slack off and land hanger. 18.18 Confirm hanger has seated properly in wellhead. Make note of actual weight on hanger on morning rpt. 18.19 Back out landing joint. M/U packoff running tool and install packoff on bottom of landing joint. Set tubing hanger pack off. RILDS. Test void to 3000 psi / 10 min. 18.20 R/D casing running tools. e� 18.21 Test 7" x 9-5/8" production annulus to 1000 psi / 30 min.'s 18.22 Set test plug and change top rams from 7" to 2-7/8" x 5-1/2" VBR. Test annular and lower rams to 2-7/8" test joint, 250 low / 3000 psi high. Page 40 19.0 Run Upper Completion Milne Point Unit M-26 SB Producer Drilling Procedure 19.1 Change upper pipe rams back to 2-7/8" x 5" VBR. Test same. Verify the Jet pump components. 19.2 Run the 4-1/2" Jet Pump Completion as per the following, verify with Operations Engineer: 4-1/2" Multi -drop Gauge Mandrel 5'u joint ''� 4-12p Sliding Sleeve S 5' pup joint 4-1/2" Gauge Mandrel 4' pup joint 10' pup joint 4-1/2" X Nipple (ID=3.813") 10' pup joint 10' pup joint 7"x4-1/2" Retrievable Packer 10' pup joint 10' pup joint 4-1/2" XN Nipple (ID=3.75") — set shallower than 70deg deviation 10' pup joint Preload RHC plug body. 4-1/2" full joints (# joints to be determined by on deviation survey) 4-1/2" WLEG Confirm depths with OE post drilling and final directional survey (reference updated schematic). 19.3 M/U Jet Pump assembly and RIH to setting depth. i. Ensure appropriate well control crossovers on rig floor and ready. ii. Monitor displacement from wellbore while RIH. 19.4 Record PU and SO weights before landing hanger. Note PU and SO weights on tally along with band/clamp summary. 19.5 MU tubing hanger and landing joint. Terminate control lines. 19.6 Land tubing hanger /19.7 Drop ball and rod, pressure up to 1,700 psi to start setting of PHL packer. `19.8 Continue to pressure up to 3,000 psi to set packer. 19.9 Pressure up to 3,500 psi to test tubing for 30 minutes and chart. X 19.10 Bleed tubing to 2,000 psi. 19.11 Pressure up annulus to 3,500 psi to test casing/packer for 30 minutes and chart. ` 19.12 Bleed tubing and IA down to 0 psi. 19.13 RILDS and test hanger. LD landing joint. 19.14 Install BPV. N/D BOP. Page 41 0 Hilcorp E-gy C-pmy Milne Point Unit M-26 SB Producer Drilling Procedure 19.15 N/U tree / adapter and tree. Test tubing hanger void to 500 psi low / 5000 psi high. Terminate the cap strings. 19.16 We won't be able to freeze protect the well with the rig. SL will be required to open the sliding sleeve to do this. Notify Wells Foreman of timing to ensure as close of coordination for SL from rig departure as possible. 19.17 Set BP{ plug. Test tree to 250 psi low / 5000 psi high. Pull BPV plug and BPV. 19.18 Prepare to hand over well to production. Ensure necessary forms filled out and well handed over with valve alignment as per operations personnel. 19.19 Notify AOGCC of SVS testing. Test SVS on horizontal run of tree within 5 days of the start of production. Set low pressure trip below 275 psi Moose Pad header & separator pressure. 19.20 RDMO Innovation Rig Page 42 H Hilcorp E -W C -p -y 20.0 Doyon 14 Diverter Schematic TIC Al R;ser- 21-1!412m— ONww'T' 21-114* 2#4 spocer spw 16-X4* 3M x 21 - f,A' W DSA Page 43 Milne Point Unit M-26 SB Producer Drilling Procedure -w, ra opNwv Km,* v*vo I ir ONerter Une 0 Hilcorp E -W Cmnp=y 21.0 Doyon 14 BOP Schematic Page 44 Milne Point Unit M-26 SB Producer Drilling Procedure 2-7/8" x 5" VBR Blind Rams xSMHCR 14 Gate VaNv 2-7/8" x 5" VB R HilctwEnergy Compmy 22"0 3-1/8" Kill Line Innovation BOP Schematic S-22 13-5/8" NOM 9-5/8" BTC Btm x 10.5" -4 SA Pin Top W/ Primary Seal Page 45 Milne Point Unit M-26 SB Producer Drilling Procedure 13-5/8" 5M Control Technology Annular BOP 13-5/8" 5M Control Technology Double Ram 3-1/8" Choke Line 1``-�---13-5/8" 5M Control Technology Single Ram 3-5/8" x 5M 1"x 5M 2-1/16" x 5M 13-5/8" x 5M `-2-1/16' x 5M 9-5/8" Casing 0 Hilcom Emrgy CmpRy 23.0 Wellhead Schematic "T, LI je -rd f{k 7-t 7-7 A - Milne Point Unit M-26 SB Producer Drilling Procedure Page 46 24.0 Days Vs Depth 0 2000 4000 N "i' C- 8000 a� Ln 10000 2 12000 14000 Page 47 Milne Point Unit M-26 SB Producer Drilling Procedure MPU M-26 SB OA Producer Days vs Depth 17 0 5 10 is 20 25 Days 25.0 Formation Tops & Information MPU M-26 Formations (wp06) MD (ft) TVDss (ft) ND (ft) Formation Pressure EMW (psi) (ppg) Base Permafrost Milne Point Unit -1797 1830 805.2 8.46 M-26 SB Producer 4483 HilCo}�•}��+ Energy Company Drilling Procedure 25.0 Formation Tops & Information MPU M-26 Formations (wp06) MD (ft) TVDss (ft) ND (ft) Formation Pressure EMW (psi) (ppg) Base Permafrost 2351 -1797 1830 805.2 8.46 LA3 4483 -2869 2902 1276.88 8.46 Schrader Bluff NA j 5818 j -3379 j 3412 1501.28 8.46 Schrader Bluff OA 1 6555 1 -3466 1 3499 1539.56 8.46 L -Pad Data Sheet Formation Description (Closest & Most Analogous MPU Pad to Moose Pad) GENERALIZED GEOLOGICAL FORECAST SS TVD FM LITH GEOLOGICAL DESCRIPTION COMMENTS arm • NOTE: Soo individual Wall Program for raow Gubik specific casing design, depths, sizes, •r +ae- 50 weights, grades and connections. ' Uncrxnofidatod coarse to modlum sand and small gravel A •• with minor slitstone. IF SIGNIFICANT AMOUNTS OF GRAVEL 1,000' a ARE ENCOUNTERED WHEN DRILLING THE -♦ SURFACE HOLE, THE VISCOSITY OF THE MUD SYSTEM SHOULD IMMEDIATELY BE RAISED TO 150 SEC TO ENSURE EFFECTIVE HOLE CLEANING. +750' Base permafrost Intorbods of sand, clays and siltstones with occasional 2,000' show of coal. Watch possible sidetracking while wasNnglresming. L-33 d L•15. Sagav rktok -oor No hydrates encountered on L -Pad wells drilled to date. Corrtlnuod Irderbodes of sand. clays and slitstones with occasional shows of coal. Traces of pyrifs at +1- 3100 it 3,000' artenvai at +f• 3400 it can be sticky and tight (L01). Clay Intorbeds between 3000 and 4500 ft C 347r• L A 3657• kends Y UGNU: Series of coarsening upward sand& which are (AMCD) made tg of: (from top to bottom) coarse sand fine sand, sifty shote. Bettor developed Intervening shales as you UGNU Progress into the L and M (dooper� Ugnu and Schrader Bluff. Possible hydrocarbons United to S W comor of Milne dowlopmont Northam area it 1-�b) downstnulurs and wet. •3739' st-sane (J18,C) 4000' ( N/+i Schrader Bluff Sands: Y 4,000 kSaros I.&O'ED, continued layering coarsening upward sands as above +41100 Schrader Bluff: Possible lost circuiation F.Fl except more condensed and with occasional coal. zoite while drilling long strings and running •4170• O -Sands Clay rich *hate Interval 4300 to 4600 it Ugnu and Schrader Blurt: Possiblo hydrocarbon s timited casing. Recommend deep setting surface (OA) to SW comer of Milne development L37 and L45 ars casing for Kuparuk long strings. Also, the D completed In the Schrader Stuff sand Northem area d Schrader Bluff sands are e potential Schrader L -Pad is dsownstnxture and wet, differential stuck pipe Interval if lett un -cased Bluff C Surface casing point M shale bolow for Kup uk long strings. Sand S:Schrader Bluff OB sand for longer reach wells. t Page 48 Hilcorp E—gy Company 26.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Milne Point Unit M-26 SB Producer Drilling Procedure Lost Circulation Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Gas Hydrates' Gas hyrates have not been seen on Moose pad. However, be prepared for them. Remember that hydrate gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates, but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching. Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized mud scale. The non -pressurized scale will reflect the actual mud cut weight. Add 1.0 — 2.0 ppb Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to remove hydrates from the system. Hole Cleaning: Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Anti -Collison: There are no known wells with a clearance factory <1.0. Take directional surveys every stand, take additional surveys if necessary. Continuously monitor proximity to offset wellbores and record any close approaches on AM report. Wellbore stability (Permafrost, running sands and gravel, conductor broaching): Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching. Maintain mud parameters and increase MW to combat running sands and gravel formations. H2S: Treat every hole section as though it has the potential for H2S. No H2S events have been documented on drill wells on this pad. Page 49 0 Hilcorp E -W Campany Milne Point Unit M-26 SB Producer Drilling Procedure The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 pptn during drilling operations. 2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements of 20 AAC 25.066. 3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a detailed mitigation procedure can be developed. Page 50 Hilcorp E—W Compy 8-1/2" Hole Section: Milne Point Unit M-26 SB Producer Drilling Procedure Hole Cleaning: Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of > 300 gpm Lost Circulation: Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of calcium carbonate. Faulting: 11 There is at least (1) fault that will be crossed while drilling the well. There could be others and the throw of these faults is not well understood at this point in time. When a known fault is coming up, ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed, we'll need to either drill up or down to get a look at the LWD log and determine the throw and then replan the wellbore. H2S: Treat every hole section as though it has the potential for 1-12S. No 1-12S events have been documented on drill wells on this pad. 1. The AOGCC will be notified within 24 hours if 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: Reservoir pressures are expected to be normal. Abnormal (offset injection) pressure has been seen on M - Pad. Utilize MPD to mitigate any abnormal pressure seen. Anti -Collision Take directional surveys every stand, take additional surveys if necessary. Continuously monitor drilling parameters for signs of magnetic interference with another well. Reference A/C report in directional plan. 1 Page 51 27.0 Dovon 14 Lavout C Page 52 e Milne Point Unit M-26 SB Producer Drilling Procedure ff Hilcorp E..w Company 28.0 Innovation Rig Layout Milne Point Unit M-26 SB Producer Drilling Procedure Page 53 29.0 FIT Procedure Formation Integrity Test (FIT) and Leak -Off Test (LOT) Procedures Procedure for FIT: Milne Point Unit M-26 SB Producer Drilling Procedure 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1 -minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental volume pumped and returned during test. Page 54 Hilcorp Energy Cumpa y 30.0 Doyon 14 Choke Manifold Schematic Milne Point Unit M-26 SB Producer Drilling Procedure Page 55 31.0 Innovation Choke Manifold Milne Point Unit M-26 SB Producer Drilling Procedure Page 56 ff Hilcorp Energy Compwy 32.0 Casing Design Calculation & Casing Design Factors Hole Size 12-1/4" Hole Size 8-1/2" Hole Size DATE: 11/11/2019 WELL: MPU M-26 DESIGN BY: Joe Engel n Criteria: Mud Density: 9.2 ppg Mud Density: 9.2 ppg Mud Density: Milne Point Unit M-26 SB Producer Drilling Procedure Drilling Mode MASP: 1199 psi (see attached MASP determination & calculation) MASP: Production Mode MASP: 1199 psi (see attached MASP determination & calculation Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress Page 57 jZ- Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 6-5/8" Top (MD) 0 6,535 Top (TVD) 0 3,524 Bottom (MD) 6,535 14,940 Bottom (TVD) 3,524 3,444 Length 6,535 8,405 Weight (ppf) 40 20 Grade L-80 L-80 Connection TXP H563 Weight w/o Bouyancy Factor (lbs) 261,400 168,100 Tension at Top of Section (lbs) 261,400 168,100 Min strength Tension (1000 lbs) 916 459 Worst Case Safety Factor (Tension) 3.50 2.73 Collapse Pressure at bottom (Psi) 1,741 1,701 Collapse Resistance w/o tension (Psi) 3,090 3,470 Worst Case Safety Factor (Collapse) 1.77V 2.04 MASP (psi) 1,199 1,199 Minimum Yield (psi) 5,750 6,090 Worst case safety factor (Burst) 4.80 e 5.08 - Page 57 jZ- ff Hilcorp Energy Company 33.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation xil1 8-1/2" Hole Section MPU M-26 Milne Point Unit MD TVD Planned Top: 6535 3524 Planned TD: 14940 3444 Milne Point Unit M-26 SB Producer Drilling Procedure Anticipated Formations and Pressures: Formation , TVD Est Pressure Oil/Gas/Wet PPG Grad Schrader Bluff OB Sand 3,524 1551 1 Oil 8.46 0.440 Offset Well Mud Densities Well MW ranee Top (TVD) Bottom (TVDI Date L-50 8.8-9.1 Surface 4125 2015 L-49 9.0-9.2 Surface 4196 2015 L-48 8.9-9.2 Surface 4147 2015 L-47 8.8-9.0 Surface 4158 2015 L-46 9.0-9.3 Surface 4177 2015 Assumptions: 1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW. 2. Maximum planned mud density 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: 3524 (ft) x 0.78(psi/ft)= 2749 2749(psi) - [0.1(psi/ft)*3524(ft)]= 2397 psi MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff OA sand) 3524 (ft) x 0.44(psi/ft)= 1551 psi �1551(psi)-0.1(psi/ft)*3524(ft) 1199 psi Summary: 1. MASP while drilling 8-1/2" production hole is governed by pore pressure and evacuation of entire wellbore togas at 0.1 psi/ft. Page 5 8 34.0 Spider Plot (NAD 27) (Governmental Sections) 37-03 r' rrt r I r f fr *, Sec. 22 s ! , 7 4 4 i y 1 t r a ` h , w* i s \ e Az ADL025320'-- %A Sec. 27 S&P D f. rurnra5a Page 59 ADL355023 Sec. 1! -LAC }1 } 1 Sec 12 o . - - .}_ Milne Point Unit M-26 SB Producer Hilcorp Ecegy c— Drilling Procedure 34.0 Spider Plot (NAD 27) (Governmental Sections) 37-03 r' rrt r I r f fr *, Sec. 22 s ! , 7 4 4 i y 1 t r a ` h , w* i s \ e Az ADL025320'-- %A Sec. 27 S&P D f. rurnra5a Page 59 ADL355023 Sec. 1! -LAC }1 } 1 Sec 12 o . - - .}_ t i 1 ! V( i t lyi:T 1 fi ! { ft POINT UNIT U013N008E r a + I 1 a + { o f rrr M I tf c f �.r 1 o { � } r r 4 ! Mr`U \1 -'ti TPM 9 Se :14 �� i '\ \Sec 13 L! :I 1 } 1 Q r Q + I 1 � t - L.�* I a } t i 1 ! V( i t lyi:T 1 fi ! { ft POINT UNIT U013N008E r a + I 1 a + { o f rrr M I tf c f �.r 1 o { � } r r 4 ! Legend • MPU M-26,SHL Other Surface Holes (SHL) MPU M-26_TPH Other Bottom Holes (BHL) L .a - - - Other Well Paths MPU M-26 BHr_ ,`• L,jep, # MPU M-26_BHL ICoastline (USGS 1:63k) .L3@LI' L.36L i w" 01 and Gas Unit Boundary Pad Foolpdnt ADL025519 Sec. 26 Milne Point Unit MPU M-26 Well wpO6a ENTPAL, Sec -25 Alaska State Plane Zane 4 NAD 1827 0 750 1,504 Feet L! :I 1 } 1 Q r Q + I 1 � t - L.�* I a } r: r t I I 1 r 4 y i l 1 e } O ! a f etc, 23 1 I I t 1 Sec. 244 O % Q l 1 1 hriLfK.i. { Q a } ez�si. } r [ 4 [... L Legend • MPU M-26,SHL Other Surface Holes (SHL) MPU M-26_TPH Other Bottom Holes (BHL) L .a - - - Other Well Paths MPU M-26 BHr_ ,`• L,jep, # MPU M-26_BHL ICoastline (USGS 1:63k) .L3@LI' L.36L i w" 01 and Gas Unit Boundary Pad Foolpdnt ADL025519 Sec. 26 Milne Point Unit MPU M-26 Well wpO6a ENTPAL, Sec -25 Alaska State Plane Zane 4 NAD 1827 0 750 1,504 Feet 35.0 Surface Plat (As Built) (NAD 27) Milne Point Unit M-26 SB Producer Drilling Procedure _-�11 TM PROJECr' i -PAD y SEC. 12 SEC 13 ¢ n _ _ —Set a 'I L 1f -FO ■ AI -11 ■ ■ M-13 ¢ N-12 ■ r M-14 ' q 19 M-20 ■ 23 ��`Y#. yj Y -S7 ■ ■ M-15 ` Y-21 ■ ■ M-16 VICINITY MAP Q-58 ■ Hrs M-22 ■ ■ M-17 M-23 ■ ■ M-18 (}F AC d M-25 ■ I Tm1D1h . Branham 10200 I MOOSE PAD GRAPHIC SCALE 0 100 200 400 SURVEYOR'S CERTIFICATE ....1 HEREBY CERMY THAT I AY W FET ) PCO PRAcn ANyNyI.,yG�jN+SED I rrttll .TDD T>. THE STATE OF ALASKA AND TMAT THIS AS -BOLT REPRESENTS A SURVEY MADE BY 41E OR UNDER W DIRECT SLMEW9014 AND 7KAT ALL DIMENSIONS AND OTHER DETAILS ARE COWRECT AS CF OCTOBER m =91. As -Batt QONDUCTOR L AIASKA STATE PLANE ODMIMATES ARE NADV, ZONE 4, 2 ZEQDE17C P09TIO4 ARE NAD27, ■ CASING CONDUCTOR 3. BASS OF NCRIZMTAL AND WOi M QONIIIX. IS SYJILCAP STAG NE. 4, AtV NOOE AYMAE PAD SCALE FACTOZ M 09995011 S DATE OF 9AR.E1`. MOSER 1s 2919. & RE:E'RENC£ FIDS BDOIL HCIG-D4 PG 25: LOCATED WITHIN PROTRACTED SEC. 14. T. 13 N., R. 9 E.. UMIAT MERIDIAN. ALASKA r Page 60 [Hflcorp Alaska MPU MOOSE PAD AS -BUILT CONDUCTORS WELLS M-25 & M-26 Carl WELL A.S.P. PLANT GEODETIC GEODETIC SECTIONPAD CELLAR NO. COORDINATES COORDINATES POSI'nON DMS POSITION O.DO OFFSETS ELEVATION 80X EL M-25 Y= 5,027.889.56 N= 1,291.92 70'29'14.014' 70.4872262' 5,039' F'SL 25,1' 25.2' X= 533,543,90 E= 1.545.06 149'4.3'32,988" 149.7258300' 621' FEL M-26 Y= 6,027,889.58 N= 1,291.95 70'29'14.020" 70.4872277' 5,039' FSB.' 25 2' 25.3 X= 533,423.92 E= 1,425.06 149'43'36.519" 149.7268107' 741' FEL' r Page 60 [Hflcorp Alaska MPU MOOSE PAD AS -BUILT CONDUCTORS WELLS M-25 & M-26 Carl Milne Point Unit M-26 SB Producer Drilling Procedure 36.0 Schrader Bluff OA Sand Offset MW vs TVD Chart 500 Schrader Bluff OA Sand Offset MW vs TVD mw, ppg os 8.7 8.9 9.1 9.3 9.5 97 99 10.110310.5 3000 3500 � Page 61 —MPU L-us<zol5> —MPU L-w(zo15) --MPuL-48(2015) --MPU L-49(20zs) --MPU L-sn(2015) —MPU F-106 (2017) —MPU F'1O7(20D) —MPU p-z08(2nl7) —MPU r'109(2ol/) ---MPU p'zoo(zol7) Hilcorp Alaska, LLC Milne Point M Pt Moose Pad Plan: MPU M-26 MPU M-26 Plan: MPU M-26 wp06a Standard Proposal Report 11 November, 2019 HALLIBURTON Sperry Drilling Services 3 M ami 3 c 0) (O (0 O NN Ca (9ELd �2EL215 N O ❑ ❑ >❑ ❑ ❑(NO ❑N❑M OR 0- 00 v �`�� ( 0 .2om N In Nim 2 Sl M-L�ot 2 2 M o M� o LoM M M O M 0 0 ❑(❑ari❑v ❑��o co �o2 tn2� 2NOO N W Mv(D� M m �N O O vOo ONO (+j ON O O 0 0 o M O m O N o r C2 �Z (000 04 NL CO M V .. .. .. d' .. V m o 0 000000 0000 C N N II NII N II N II II W in in winwcnwin w`6Lcu a 2 U U F 0 co O O 3 3 3 3 o M (0 M J N N N N F F 2 2 2 2 Lu ❑ V O O M l C) M M O 1 r M N M o m!0 M O Or N 0000001 V'N (n M 00r Z wOOMN MOOr 6 V 6C 6 N U >r-('7MrMNOpMm d) M �-(h M� �MNNMm M VTy) M 0 ' N r Lu 0100 000 V' 0000000 M M o;7 O � UOOOOOl00NON0 rsr Oro cuoo o0ln 6 o oro o 000 F N N M N r co m0000000000000000 al0000000000o00000 poo ri (7 v v 0 v 0 v o v v 0 v o �oo�ooDVMM(Du1cDlnNraoM 000(0 V x•-0100011(1 MM(0 V'(O w000D V'o 00 M(0 l0 V'N MM f -0M M + �vom vn000 rn ' r V'000D COm o0�� M ' NMM C? C? MM(MM M woo M10M (Do rMNww( ; 010 M 00 rN00000 o V NoI? .rte r Z 00 MNM Cor o MN V to N10 N + �M (2rCON ODM0)� M M MNN MCO M01 M'7(D ' N N N r 1� W ❑o O M000 mN00v 0O (O0010 ]r0 M M N10000OrO FMOd)D) V' NNM V'O40 V M010D V' MaO rV'N M 01 NM NN V N V'ol0 N r(pV 1D(O(nlqr N M M M M oM mM mM o M m M 'N 0000(0 rr 00(0 wMoo o(0 M 0 0 0 0 0 v o w r r M w w N N M M 0000r -, co, covv��rnoornrn MMN NNM W OD M.r--M M�� U O O O O N r r 0 0 4) (3) r 0 0 0 0 0 D C O O o r 0 0 eq 0 q 10 M r r M M o0(00D(n 01 W M 1000 0000 . 1(DM MMMM W MM W poo OOO OD (D rr � MM o (D r0 o o o w V Iq r lnODo M O O o o V' M w (n N N M O N O M N w o o c3 o w o 01 ,rO N O N v N V 10r c0 Q7 In M NNr rm MM(0 (p CO MM NNS (1,N M V In oD cDo o�Nm 4ow to m 03 N !a 0 E `o Z u o, cc rnU) (n U tp (p 122 d N N YCLL Fww 0 U + + o F i OMM MIMI MI N N N aaa C d (a N (0 O BO O aan 2 3 3 3 O M to N N N 22M aaa E Or O O 2 6 o 1(i 1L MON L M d ❑ Oco m bf O(v M N O C1 0 bb x 3 d N 6�8Sbf 14000 0-746 ,,,V•6g. 9110O� 22<,,L • 13500 LO J/ . •0, ' - - _ _ 13000 0 Lob// - 3 O BELS t12500 2000 1500 1000 0500 O O 0 0 0 0 0 0 0 0 N M (ui/ysn 0091) 4#da4 leoilian anjl 0 0 0 _ 0 O m -0 M c o U) o � 0 0 0 0 0 O o 0 00 0 O o U Q N o U) � U 0 v O 0 O o N O 0 0 0 0 .0 p� 10000 LyfL SO� ' � O 500 LOSL 8L Sf fX28' O Ji /L62bL8 pp`� 000 U p ,06Lo6 J/p�P1S 6500 o bOoe m > 000 cli 0 17- MN 0 L�2699' SfN. 6 FCbSfs'8 Ji 2 pLN,lb. �OLabJ/ pp`� 500 o N 299 N M ' 2 pl1/ S8L9 p'LP! 000 o 0 0 v `° . '969 Ji `S S6f pAU 0099- y . x in OCL ob n ❑ .. J /pL/Pfs 009 v N N w (n o. OpgS X O O O 00, S EOR In C, �t rn O O 0 0 0 0 0 0 0 0 N M (ui/ysn 0091) 4#da4 leoilian anjl 0 0 0 _ 0 O m -0 M c o U) o � 0 0 0 0 0 O o 0 00 0 O o U Q N o U) � U 0 v O 0 O o N O 0 0 0 0 .0 HALLtBURTON Project: Milne Point Name Site: M Pt Moose Pad 5p.—y orin1„9 3524.00 3465.00 6535.47 9-5/8 Well: Plan: MPU M-26 YM Wellbore: MPU M-26 Plan: MPU M-26 wp06a 3444.00 3385.00 14940.06 6-5/8 6 5/8" x 8 1/2" End Dir : 8223.18' MD, 3513.61' TVD CASING DETAILS F i WELL DETAILS: Plan: MPU M-26 25.30 +N/ -S +E/ -W Northing Easting Iatittude Longitude 0.00 0.00 6027889.58 533423.92 70° 29' 14.020 N 149° 43'36.519 W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan: MPU M-26, True North Vertical (TVD) Reference: MPU M-26 Planned SH RKB @ 59.00usft Measured Depth Reference: MPU M-26 Planned SH RKB @ 59.00usfl Calculation Method Minimum Curvature -2250— TVD TVDSS MD Size Name 1500 3524.00 3465.00 6535.47 9-5/8 9 5/8" x 12 1/4" -3000- 3000 - - - - 3444.00 3385.00 14940.06 6-5/8 6 5/8" x 8 1/2" End Dir : 8223.18' MD, 3513.61' TVD l 3750o-3750— 750- 50 ( V%- -4500 -4500— a. N N C n O N ^ OD O 0 0— -5250 2'r0 -6000 S Start Start Dir 3o/1 00': :280' MD, 280"LVD Start Dir 49/100' : 550' MD, 549.1'TVD -750 3500 . - _ End Dir :1884.88' MD, 1622.13' TVD M-26 wp06 Heel- , _ _ End Dir : 6185.47' MD, 3493.5' TVD -1500 9 5/8" x 12 1/4" - - StartDir 4°/100' : 6535.47' MD, End Dir 6692.71' MD, 3530.04' TVD -2250— Start Dir 4°/100' : 8142.91' MD, 3515.0l'TVD M-26 wp06 CPl - —_ -3000- 3000 - - - - - End Dir : 8223.18' MD, 3513.61' TVD 3750o-3750— CD V%- -4500 -4500— t: -5250 -6000 -6750 Start Dir 4°/100' : 12700.51' MD, 3459TVD M-26 wp06 CP2 End Dir : 12722.89' MD, 3458.79' TVD 6 5/8" x 8 1/2" -9750 - - - - - - - Total Depth : 14940.06' MD, 3444' TVD M-26 wp06 Toe MPU M-26 wp06a -10500- -11250 -6750 -6000 -5250 -4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 West( -)/East(+) (1500 usfdin) HALLIBUR'TON Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-26 Wellbore: MPU M-26 Design: MPU M-26 wp06a Halliburton Standard Proposal Report Local Co-ordinate Reference: Well Plan: MPU M-26 TVD Reference: MPU M-26 Planned SH RKB @ 59.00usft MD Reference: MPU M-26 Planned SH RKB @ 59.00usft North Reference: True Survey Calculation Method: Minimum Curvature 'roject Milne Point, ACT, MILNE POINT nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point nap Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt Moose Pad Site Position: From: Map Position Uncertainty: 0.00 usft Well Plan: MPU M-26, Slot 10 Well Position +Nl-S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Wellbore MPU M-26 Magnetics Model Name Northing: 6,027,877.65usft Latitude: Easting: 533,363.92 usft Longitude: Slot Radius: 13-3/16" Grid Convergence: Northing: 6,027,889.58 usfi Easting: 533,423.92 usfi Wellhead Elevation: usfi Sample Date Declination (°) BGGM2018 11/19/2019 Design MPU M-26 wp06a Build Turn Audit Notes: +E/ -W Rate Rate Rate Toot Face Version: (°/100usft) (°/100usft) Phase: PLAN Vertical Section: 0.00 0.00 Depth From (TVD) +N/ -S 0.00 0.00 0.00 (usft) -8.01 (usft) 3.00 0.00 310.00 26.30 3.00 0.00 Plan Sections 0.00 -49.48 4.00 3.81 -6.27 Measured -708.14 4.00 Vertical TVD -25.54 Depth Inclination Azimuth Depth System +N/ -S (usft) (°) (°) (usft) usft (usft) 33.70 0.00 0.00 33.70 -25.30 0.00 280.00 0.00 0.00 280.00 221.00 0.00 480.00 6.00 310.00 479.63 420.63 6.73 550.00 8.10 310.00 549.10 490.10 12.25 750.00 15.72 297.46 744.68 685.68 33.83 1,884.88 59.87 276.67 1,622.13 1,563.13 168.86 3,956.96 59.87 276.67 2,662.22 2,603.22 377.09 6,185.47 85.00 184.76 3,493.50 3,434.50 -881.97 6,535.47 85.00 184.76 3,524.00 3,465.00 -1,229.43 6,692.71 90.59 181.88 3,530.04 3,471.04 -1,386.22 8,142.91 90.59 181.88 3,515.01 3,456.01 -2,835.56 8,201.73 91.37 179.66 3,514.00 3,455.00 -2,894.35 8,223.18 90.70 180.20 3,513.61 3,454.61 -2,915.81 12,700.51 90.70 180.20 3,459.00 3,400.00 -7,392.78 12,722.89 90.38 179.36 3,458.79 3,399.79 -7,415.15 14,940.06 90.38 179.36 3,444.00 3,385.00 -9,632.13 16.36 Latitude: Longitude: Ground Level: Dip Angle 80.94 Tie On Depth: 33.70 +E/ -W Direction (usft) (°) 0.00 180.00 70° 29' 13.905 N 149° 43'38.286 W 0.26 ° 70° 29' 14.020 N 149° 43'36.519 W 25.30 usft Field Strength (nT) 57,407.19402629 11/112019 3:20:30PM Page 2 COMPASS 5000.15 Build 91 Dogleg Build Turn +E/ -W Rate Rate Rate Toot Face (usft) (°/100usft) (°/100usft) (°1100usft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -8.01 3.00 3.00 0.00 310.00 -14.60 3.00 3.00 0.00 0.00 -49.48 4.00 3.81 -6.27 -25.00 -708.14 4.00 3.89 -1.83 -25.54 -2,488.13 0.00 0.00 0.00 0.00 -3,816.93 4.00 1.13 -4.12 -95.28 -3,845.86 0.00 0.00 0.00 0.00 -3,854.95 4.00 3.56 -1.83 -27.28 -3,902.56 0.00 0.00 0.00 0.00 -3,903.35 4.00 1.32 -3.78 -70.73 -3,903.32 4.00 -3.13 2.49 141.43 -3,918.57 0.00 0.00 0.00 0.00 -3,918.48 4.00 -1.42 -3.74 -110.71 -3,893.63 0.00 0.00 0.00 0.00 11/112019 3:20:30PM Page 2 COMPASS 5000.15 Build 91 Halliburton HALLIBURTON Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU M-26 Company: Hilcorp Alaska, LLC ND Reference: MPU M-26 Planned SH RKB @ 59.00usft Project: Milne Point MD Reference: MPU M-26 Planned SH RKB @ 59.00usft Site: M Pt Moose Pad North Reference: True Well: Plan: MPU M-26 Survey Calculation Method: Minimum Curvature Wellbore: MPU M-26 Design: MPU M-26 wp06a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -25.30 33.70 0.00 0.00 33.70 -25.30 0.00 0.00 6,027,889.58 533,423.92 0.00 0.00 100.00 0.00 0.00 100.00 41.00 0.00 0.00 6,027,889.58 533,423.92 0.00 0.00 200.00 0.00 0.00 200.00 141.00 0.00 0.00 6,027,889.58 533,423.92 0.00 0.00 280.00 0.00 0.00 280.00 221.00 0.00 0.00 6,027,889.58 533,423.92 0.00 0.00 Start Dir 30/100' : 280' MD, 280'TVD 300.00 0.60 310.00 300.00 241.00 0.07 -0.08 6,027,889.65 533,423.84 3.00 -0.07 400.00 3.60 310.00 399.92 340.92 2.42 -2.89 6,027,891.99 533,421.02 3.00 -2.42 480.00 6.00 310.00 479.63 420.63 6.73 -8.01 6,027,896.27 533,415.88 3.00 -6.73 500.00 6.60 310.00 499.51 440.51 8.14 -9.70 6,027,897.67 533,414.19 3.00 -8.14 550.00 8.10 310.00 549.10 490.10 12.25 -14.60 6,027,901.76 533,409.27 3.00 -12.25 Start Dir 40/100' : 550' MD, 549.1'TVD 600.00 9.95 305.10 598.48 539.48 17.00 -20.83 6,027,906.48 533,403.02 4.00 -17.00 700.00 13.77 299.31 696.33 637.33 27.79 -38.28 6,027,917.20 533,385.52 4.00 -27.79 750.00 15.72 297.46 744.68 685.68 33.83 -49.48 6,027,923.18 533,374.29 4.00 -33.83 800.00 17.54 294.60 792.59 733.59 40.09 -62.34 6,027,929.38 533,361.40 4.00 -40.09 900.00 21.28 290.33 886.89 827.89 52.67 -93.08 6,027,941.83 533,330.62 4.00 -52.67 1,000.00 25.10 287.29 978.80 919.80 65.29 -130.36 6,027,954.27 533,293.28 4.00 -65.29 1,100.00 28.97 285.02 1,067.86 1,008.86 77.87 -174.02 6,027,966.66 533,249.57 4.00 -77.87 1,200.00 32.86 283.25 1,153.64 1,094.64 90.37 -223.84 6,027,978.94 533,199.70 4.00 -90.37 1,300.00 36.78 281.81 1,235.72 1,176.72 102.72 -279.57 6,027,991.03 533,143.92 4.00 -102.72 1,400.00 40.71 280.61 1,313.70 1,254.70 114.86 -340.95 6,028,002.89 533,082.49 4.00 -114.86 1,500.00 44.65 279.60 1,387.20 1,328.20 126.73 -407.67 6,028,014.46 533,015.72 4.00 -126.73 1,600.00 48.60 278.71 1,455.87 1,396.87 138.27 -479.42 6,028,025.68 532,943.93 4.00 -138.27 1,700.00 52.55 277.93 1,519.37 1,460.37 149.43 -555.83 6,028,036.49 532,867.47 4.00 -149.43 1,800.00 56.51 277.22 1,577.39 1,518.39 160.15 -636.55 6,028,046.85 532,786.72 4.00 -160.15 1,884.88 59.87 276.67 1,622.13 1,563.13 168.86 -708.14 6,028,055.24 532,715.10 4.00 -168.86 End Dir : 1884.88' MD, 1622.13' ND 1,900.00 59.87 276.67 1,629.72 1,570.72 170.38 -721.13 6,028,056.70 532,702.10 0.00 -170.38 2,000.00 59.87 276.67 1,679.91 1,620.91 180.43 -807.03 6,028,066.37 532,616.16 0.00 -180.43 2,100.00 59.87 276.67 1,730.11 1,671.11 190.48 -892.94 6,028,076.03 532,530.23 0.00 -190.48 2,200.00 59.87 276.67 1,780.30 1,721.30 200.53 -978.84 6,028,085.69 532,444.29 0.00 -200.53 2,300.00 59.87 276.67 1,830.50 1,771.50 210.58 -1,064.74 6,028,095.35 532,358.35 0.00 -210.58 2,400.00 59.87 276.67 1,880.69 1,821.69 220.63 -1,150.65 6,028,105.01 532,272.41 0.00 -220.63 2,500.00 59.87 276.67 1,930.89 1,871.89 230.68 -1,236.55 6,028,114.67 532,186.47 0.00 -230.68 2,600.00 59.87 276.67 1,981.09 1,922.09 240.73 -1,322.45 6,028,124.34 532,100.53 0.00 -240.73 2,700.00 59.87 276.67 2,031.28 1,972.28 250.77 -1,408.36 6,028,134.00 532,014.59 0.00 -250.77 2,800.00 59.87 276.67 2,081.48 2,022.48 260.82 -1,494.26 6,028,143.66 531,928.65 0.00 -260.82 2,900.00 59.87 276.67 2,131.67 2,072.67 270.87 -1,580.16 6,028,153.32 531,842.71 0.00 -270.87 3,000.00 59.87 276.67 2,181.87 2,122.87 280.92 -1,666.07 6,028,162.98 531,756.77 0.00 -280.92 3,100.00 59.87 276.67 2,232.06 2,173.06 290.97 -1,751.97 6,028,172.65 531,670.83 0.00 -290.97 3,200.00 59.87 276.67 2,282.26 2,223.26 301.02 -1,837.87 6,028,182.31 531,584.89 0.00 -301.02 3,300.00 59.87 276.67 2,332.46 2,273.46 311.07 -1,923.78 6,028,191.97 531,498.95 0.00 -311.07 3,400.00 59.87 276.67 2,382.65 2,323.65 321.12 -2,009.68 6,028,201.63 531,413.01 0.00 -321.12 3,500.00 59.87 276.67 2,432.85 2,373.85 331.17 -2,095.59 6,028,211.29 531,327.07 0.00 -331.17 3,600.00 59.87 276.67 2,483.04 2,424.04 341.21 -2,181.49 6,028,220.95 531,241.14 0.00 -341.21 11/11/2019 3:20:30PM Page 3 COMPASS 5000.15 Build 91 HALLIBUR'TON Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU M-26 Company: Hilcorp Alaska, LLC ND Reference: MPU M-26 Planned SH RKB @ 59.00usft Project: Milne Point MD Reference: MPU M-26 Planned SH RKB @ 59.00usft Site: M Pt Moose Pad North Reference: True Well: Plan: MPU M-26 Survey Calculation Method: Minimum Curvature Wellbore: MPU M-26 Design: MPU M-26 wp06a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 2,474.24 3,700.00 59.87 276.67 2,533.24 2,474.24 351.26 -2,267.39 6,028,230.62 531,155.20 0.00 -351.26 3,800.00 59.87 276.67 2,583.43 2,524.43 361.31 -2,353.30 6,028,240.28 531,069.26 0.00 -361.31 3,900.00 59.87 276.67 2,633.63 2,574.63 371.36 -2,439.20 6,028,249.94 530,983.32 0.00 -371.36 3,956.96 59.87 276.67 2,662.22 2,603.22 377.09 -2,488.13 6,028,255.44 530,934.37 0.00 -377.09 Start Dir 401100': 3956.96' MD, 2662.22'TVD 4,000.00 59.73 274.69 2,683.87 2,624.87 380.77 -2,525.14 6,028,258.96 530,897.34 4.00 -380.77 4,100.00 59.51 270.06 2,734.47 2,675.47 384.34 -2,611.30 6,028,262.14 530,811.18 4.00 -384.34 4,200.00 59.46 265.41 2,785.27 2,726.27 380.94 -2,697.35 6,028,258.35 530,725.16 4.00 -380.94 4,300.00 59.57 260.77 2,836.03 2,777.03 370.58 -2,782.86 6,028,247.61 530,639.70 4.00 -370.58 4,400.00 59.84 256.15 2,886.49 2,827.49 353.31 -2,867.42 6,028,229.97 530,555.22 4.00 -353.31 4,500.00 60.28 251.56 2,936.42 2,877.42 329.22 -2,950.62 6,028,205.50 530,472.14 4.00 -329.22 4,600.00 60.87 247.02 2,985.57 2,926.57 298.42 -3,032.06 6,028,174.34 530,390.85 4.00 -298.42 4,700.00 61.61 242.54 3,033.70 2,974.70 261.07 -3,111.33 6,028,136.64 530,311.75 4.00 -261.07 4,800.00 62.50 238.12 3,080.57 3,021.57 217.34 -3,188.06 6,028,092.57 530,235.23 4.00 -217.34 4,900.00 63.53 233.78 3,125.96 3,066.96 167.45 -3,261.86 6,028,042.36 530,161.66 4.00 -167.45 5,000.00 64.68 229.52 3,169.65 3,110.65 111.65 -3,332.38 6,027,986.24 530,091.40 4.00 -111.65 5,100.00 65.96 225.35 3,211.43 3,152.43 50.19 -3,399.27 6,027,924.49 530,024.79 4.00 -50.19 5,200.00 67.34 221.26 3,251.08 3,192.08 -16.60 -3,462.21 6,027,857.42 529,962.16 4.00 16.60 5,300.00 68.83 217.26 3,288.42 3,229.42 -88.42 -3,520.89 6,027,785.34 529,903.81 4.00 88.42 5,400.00 70.40 213.34 3,323.26 3,264.26 -164.92 -3,575.03 6,027,708.62 529,850.02 4.00 164.92 5,500.00 72.07 209.50 3,355.44 3,296.44 -245.71 -3,624.36 6,027,627.61 529,801.06 4.00 245.71 5,600.00 73.80 205.73 3,384.80 3,325.80 -330.40 -3,668.64 6,027,542.73 529,757.16 4.00 330.40 5,700.00 75.60 202.02 3,411.19 3,352.19 -418.59 -3,707.66 6,027,454.38 529,718.55 4.00 418.59 5,800.00 77.46 198.38 3,434.49 3,375.49 -509.84 -3,741.22 6,027,362.98 529,685.40 4.00 509.84 5,900.00 79.36 194.79 3,454.58 3,395.58 -603.71 -3,769.17 6,027,269.00 529,657.88 4.00 603.71 6,000.00 81.31 191.24 3,471.37 3,412.37 -699.74 -3,791.36 6,027,172.88 529,636.12 4.00 699.74 6,100.00 83.29 187.74 3,484.78 3,425.78 -797.46 -3,807.68 6,027,075.10 529,620.23 4.00 797.46 6,185.47 85.00 184.76 3,493.50 3,434.50 -881.97 -3,816.93 6,026,990.56 529,611.37 4.00 881.97 End Dir : 6185.47' MD, 3493.5' TVD 6,200.00 85.00 184.76 3,494.76 3,435.76 -896.39 -3,818.13 6,026,976.13 529,610.23 0.00 896.39 6,300.00 85.00 184.76 3,503.48 3,444.48 -995.67 -3,826.40 6,026,876.83 529,602.41 0.00 995.67 6,400.00 85.00 184.76 3,512.19 3,453.19 -1,094.94 -3,834.66 6,026,777.52 529,594.59 0.00 1,094.94 6,500.00 85.00 184.76 3,520.91 3,461.91 -1,194.22 -3,842.93 6,026,678.22 529,586.77 0.00 1,194.22 6,535.47 85.00 184.76 3,524.00 3,465.00 -1,229.43 -3,845.86 6,026,643.00 529,584.00 0.00 1,229.43 Start Dir 401100': 6535.47' MD, 3524'TVD - 9 5/8" x 12 1/4" 6,600.00 87.30 183.58 3,528.34 3,469.34 -1,293.64 -3,850.54 6,026,578.78 529,579.61 4.00 1,293.64 6,692.71 90.59 181.88 3,530.04 3,471.04 -1,386.21 -3,854.95 6,026,486.19 529,575.62 4.00 1,386.21 End Dir : 6692.71' MD, 3530.04' TVD 6,700.00 90.59 181.88 3,529.97 3,470.97 -1,393.50 -3,855.19 6,026,478.91 529,575.41 0.00 1,393.50 6,800.00 90.59 181.88 3,528.93 3,469.93 -1,493.44 -3,858.48 6,026,378.96 529,572.58 0.00 1,493.44 6,900.00 90.59 181.88 3,527.89 3,468.89 -1,593.38 -3,861.76 6,026,279.02 529,569.74 0.00 1,593.38 7,000.00 90.59 181.88 3,526.86 3,467.86 -1,693.32 -3,865.04 6,026,179.07 529,566.91 0.00 1,693.32 7,100.00 90.59 181.88 3,525.82 3,466.82 -1,793.26 -3,868.32 6,026,079.13 529,564.08 0.00 1,793.26 7,200.00 90.59 181.88 3,524.78 3,465.78 -1,893.20 -3,871.61 6,025,979.18 529,561.24 0.00 1,893.20 7,300.00 90.59 181.88 3,523.75 3,464.75 -1,993.14 -3,874.89 6,025,879.24 529,558.41 0.00 1,993.14 11/11/2019 3:20:30PM Page 4 COMPASS 5000.15 Build 91 I LM U IR tt off-=Ivi M Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU M-26 Company: Hilcorp Alaska, LLC TVD Reference: MPU M-26 Planned SH RKB @ 59.00usft Project: Milne Point MD Reference: MPU M-26 Planned SH RKB @ 59.00usft Site: M Pt Moose Pad North Reference: True Well: Plan: MPU M-26 Survey Calculation Method: Minimum Curvature Wellbore: MPU M-26 (usft) (°) Design: MPU M-26 wp06a usft (usft) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,463.71 7,400.00 90.59 181.88 3,522.71 3,463.71 -2,093.08 -3,878.17 6,025,779.30 529,555.58 0.00 2,093.08 7,500.00 90.59 181.88 3,521.67 3,462.67 -2,193.03 -3,881.45 6,025,679.35 529,552.74 0.00 2,193.03 7,600.00 90.59 181.88 3,520.64 3,461.64 -2,292.97 -3,884.74 6,025,579.41 529,549.91 0.00 2,292.97 7,700.00 90.59 181.88 3,519.60 3,460.60 -2,392.91 -3,888.02 6,025,479.46 529,547.08 0.00 2,392.91 7,800.00 90.59 181.88 3,518.56 3,459.56 -2,492.85 -3,891.30 6,025,379.52 529,544.24 0.00 2,492.85 7,900.00 90.59 181.88 3,517.53 3,458.53 -2,592.79 -3,894.59 6,025,279.57 529,541.41 0.00 2,592.79 8,000.00 90.59 181.88 3,516.49 3,457.49 -2,692.73 -3,897.87 6,025,179.63 529,538.58 0.00 2,692.73 8,100.00 90.59 181.88 3,515.45 3,456.45 -2,792.67 -3,901.15 6,025,079.68 529,535.74 0.00 2,792.67 8,142.91 90.59 181.88 3,515.01 3,456.01 -2,835.55 -3,902.56 6,025,036.80 529,534.53 0.00 2,835.55 Start Dir 401100': 8142.91' MD, 3515.017VD 8,201.73 91.37 179.66 3,514.00 3,455.00 -2,894.35 -3,903.35 6,024,978.00 529,534.00 4.00 2,894.35 8,223.18 90.70 180.19 3,513.61 3,454.61 -2,915.80 -3,903.32 6,024,956.55 529,534.12 4.00 2,915.80 End Dir : 8223.18' MD, 3513.61' ND 8,300.00 90.70 180.20 3,512.68 3,453.68 -2,992.62 -3,903.59 6,024,879.75 529,534.21 0.00 2,992.62 8,400.00 90.70 180.20 3,511.46 3,452.46 -3,092.61 -3,903.93 6,024,779.76 529,534.32 0.00 3,092.61 8,500.00 90.70 180.20 3,510.24 3,451.24 -3,192.60 -3,904.27 6,024,679.78 529,534.43 0.00 3,192.60 8,600.00 90.70 180.20 3,509.02 3,450.02 -3,292.59 -3,904.61 6,024,579.80 529,534.53 0.00 3,292.59 8,700.00 90.70 180.20 3,507.80 3,448.80 -3,392.58 -3,904.95 6,024,479.82 529,534.64 0.00 3,392.58 8,800.00 90.70 180.20 3,506.58 3,447.58 -3,492.58 -3,905.29 6,024,379.83 529,534.75 0.00 3,492.58 8,900.00 90.70 180.20 3,505.36 3,446.36 -3,592.57 -3,905.63 6,024,279.85 529,534.86 0.00 3,592.57 9,000.00 90.70 180.20 3,504.14 3,445.14 -3,692.56 -3,905.97 6,024,179.87 529,534.97 0.00 3,692.56 9,100.00 90.70 180.20 3,502.92 3,443.92 -3,792.55 -3,906.31 6,024,079.89 529,535.08 0.00 3,792.55 9,200.00 90.70 180.20 3,501.70 3,442.70 -3,892.54 -3,906.65 6,023,979.90 529,535.19 0.00 3,892.54 9,300.00 90.70 180.20 3,500.48 3,441.48 -3,992.54 -3,906.99 6,023,879.92 529,535.30 0.00 3,992.54 9,400.00 90.70 180.20 3,499.26 3,440.26 -4,092.53 -3,907.33 6,023,779.94 529,535.41 0.00 4,092.53 9,500.00 90.70 180.20 3,498.04 3,439.04 -4,192.52 -3,907.67 6,023,679.96 529,535.51 0.00 4,192.52 9,600.00 90.70 180.20 3,496.82 3,437.82 -4,292.51 -3,908.01 6,023,579.97 529,535.62 0.00 4,292.51 9,700.00 90.70 180.20 3,495.60 3,436.60 -4,392.50 -3,908.35 6,023,479.99 529,535.73 0.00 4,392.50 9,800.00 90.70 180.20 3,494.38 3,435.38 -4,492.50 -3,908.69 6,023,380.01 529,535.84 0.00 4,492.50 9,900.00 90.70 180.20 3,493.16 3,434.16 -4,592.49 -3,909.03 6,023,280.03 529,535.95 0.00 4,592.49 10,000.00 90.70 180.20 3,491.94 3,432.94 -4,692.48 -3,909.37 6,023,180.04 529,536.06 0.00 4,692.48 10,100.00 90.70 180.20 3,490.72 3,431.72 -4,792.47 -3,909.71 6,023,080.06 529,536.17 0.00 4,792.47 10,200.00 90.70 180.20 3,489.50 3,430.50 -4,892.46 -3,910.05 6,022,980.08 529,536.28 0.00 4,892.46 10,300.00 90.70 180.20 3,488.28 3,429.28 -4,992.46 -3,910.40 6,022,880.09 529,536.39 0.00 4,992.46 10,400.00 90.70 180.20 3,487.06 3,428.06 -5,092.45 -3,910.74 6,022,780.11 529,536.49 0.00 5,092.45 10,500.00 90.70 180.20 3,485.84 3,426.84 -5,192.44 -3,911.08 6,022,680.13 529,536.60 0.00 5,192.44 10,600.00 90.70 180.20 3,484.62 3,425.62 -5,292.43 -3,911.42 6,022,580.15 529,536.71 0.00 5,292.43 10,700.00 90.70 180.20 3,483.40 3,424.40 -5,392.42 -3,911.76 6,022,480.16 529,536.82 0.00 5,392.42 10,800.00 90.70 180.20 3,482.18 3,423.18 -5,492.42 -3,912.10 6,022,380.18 529,536.93 0.00 5,492.42 10,900.00 90.70 180.20 3,480.96 3,421.96 -5,592.41 -3,912.44 6,022,280.20 529,537.04 0.00 5,592.41 11,000.00 90.70 180.20 3,479.74 3,420.74 -5,692.40 -3,912.78 6,022,180.22 529,537.15 0.00 5,692.40 11,100.00 90.70 180.20 3,478.52 3,419.52 -5,792.39 -3,913.12 6,022,080.23 529,537.26 0.00 5,792.39 11,200.00 90.70 180.20 3,477.30 3,418.30 -5,892.38 -3,913.46 6,021,980.25 529,537.37 0.00 5,892.38 11,300.00 90.70 180.20 3,476.08 3,417.08 -5,992.38 -3,913.80 6,021,880.27 529,537.47 0.00 5,992.38 11,400.00 90.70 180.20 3,474.86 3,415.86 -6,092.37 -3,914.14 6,021,780.29 529,537.58 0.00 6,092.37 11/11/2019 3:20:30PM Page 5 COMPASS 5000.15 Build 91 Database: NORTH US + CANADA Company: Hilcorp Alaska, LLC Project: Milne Point Site: M Pt Moose Pad Well: Plan: MPU M-26 Wellbore: MPU M-26 Design: MPU M-26 wp06a Planned Survey Measured Vertical Depth Inclination Azimuth Depth (usft) (1) (°) (usft) 11,500.00 90.70 180.20 3,473.64 11,600.00 90.70 180.20 3,472.42 11,700.00 90.70 180.20 3,471.20 11,800.00 90.70 180.20 3,469.98 11,900.00 90.70 180.20 3,468.76 12,000.00 90.70 180.20 3,467.54 12,100.00 90.70 180.20 3,466.32 12,200.00 90.70 180.20 3,465.11 12,300.00 90.70 180.20 3,463.89 12,400.00 90.70 180.20 3,462.67 12,500.00 90.70 180.20 3,461.45 12,600.00 90.70 180.20 3,460.23 12,700.51 90.70 180.20 3,459.00 Start Dir 40/100' : 12700.51' MD, 3459'TVD 12,722.89 90.38 179.36 3,458.79 End Dir : 12722.89' MD, 3458.79' TVD 12,800.00 90.38 179.36 3,458.27 12,900.00 90.38 179.36 3,457.61 13,000.00 90.38 179.36 3,456.94 13,100.00 90.38 179.36 3,456.27 13,200.00 90.38 179.36 3,455.61 13,300.00 90.38 179.36 3,454.94 13,400.00 90.38 179.36 3,454.27 13,500.00 90.38 179.36 3,453.61 13,600.00 90.38 179.36 3,452.94 13,700.00 90.38 179.36 3,452.27 13,800.00 90.38 179.36 3,451.60 13,900.00 90.38 179.36 3,450.94 14,000.00 90.38 179.36 3,450.27 14,100.00 90.38 179.36 3,449.60 14,200.00 90.38 179.36 3,448.94 14,300.00 90.38 179.36 3,448.27 14,400.00 90.38 179.36 3,447.60 14,500.00 90.38 179.36 3,446.94 14,600.00 90.38 179.36 3,446.27 14,700.00 90.38 179.36 3,445.60 14,800.00 90.38 179.36 3,444.93 14,900.00 90.38 179.36 3,444.27 14,940.06 90.38 179.36 3,444.00 Total Depth: 14940.06' MD, 3444' TVD Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton Standard Proposal Report Well Plan: MPU M-26 MPU M-26 Planned SH RKB @ 59.O0usft MPU M-26 Planned SH RKB @ 59.00usft True Minimum Curvature 11/112019 3:20:30PM Page 6 COMPASS 5000.15 Build 91 Map Map TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section usft (usft) (usft) (usft) (usft) 3,414.64 3,414.64 -6,192.36 -3,914.48 6,021,680.30 529,537.69 0.00 6,192.36 3,413.42 -6,292.35 -3,914.82 6,021,580.32 529,537.80 0.00 6,292.35 3,412.20 -6,392.34 -3,915.16 6,021,480.34 529,537.91 0.00 6,392.34 3,410.98 -6,492.34 -3,915.50 6,021,380.36 529,538.02 0.00 6,492.34 3,409.76 -6,592.33 -3,915.84 6,021,280.37 529,538.13 0.00 6,592.33 3,408.54 -6,692.32 -3,916.18 6,021,180.39 529,538.24 0.00 6,692.32 3,407.32 -6,792.31 -3,916.52 6,021,080.41 529,538.35 0.00 6,792.31 3,406.11 -6,892.30 -3,916.86 6,020,980.42 529,538.45 0.00 6,892.30 3,404.89 -6,992.30 -3,917.20 6,020,880.44 529,538.56 0.00 6,992.30 3,403.67 -7,092.29 -3,917.55 6,020,780.46 529,538.67 0.00 7,092.29 3,402.45 -7,192.28 -3,917.89 6,020,680.48 529,538.78 0.00 7,192.28 3,401.23 -7,292.27 -3,918.23 6,020,580.49 529,538.89 0.00 7,292.27 3,400.00 -7,392.77 -3,918.57 6,020,480.00 529,539.00 0.00 7,392.77 3,399.79 -7,415.15 -3,918.48 6,020,457.63 529,539.19 4.00 7,415.15 3,399.27 -7,492.26 -3,917.62 6,020,380.53 529,540.40 0.00 7,492.26 3,398.61 -7,592.25 -3,916.50 6,020,280.56 529,541.97 0.00 7,592.25 3,397.94 -7,692.24 -3,915.37 6,020,180.58 529,543.54 0.00 7,692.24 3,397.27 -7,792.23 -3,914.25 6,020,080.61 529,545.11 0.00 7,792.23 3,396.61 -7,892.22 -3,913.13 6,019,980.63 529,546.68 0.00 7,892.22 3,395.94 -7,992.21 -3,912.01 6,019,880.66 529,548.25 0.00 7,992.21 3,395.27 -8,092.20 -3,910.89 6,019,780.68 529,549.82 0.00 8,092.20 3,394.61 -8,192.20 -3,909.77 6,019,680.71 529,551.39 0.00 8,192.20 3,393.94 -8,292.19 -3,908.65 6,019,580.73 529,552.96 0.00 8,292.19 3,393.27 -8,392.18 -3,907.53 6,019,480.75 529,554.53 0.00 8,392.18 3,392.60 -8,492.17 -3,906.41 6,019,380.78 529,556.10 0.00 8,492.17 3,391.94 -8,592.16 -3,905.29 6,019,280.80 529,557.67 0.00 8,592.16 3,391.27 -8,692.15 -3,904.17 6,019,180.83 529,559.24 0.00 8,692.15 3,390.60 -8,792.15 -3,903.05 6,019,080.85 529,560.81 0.00 8,792.15 3,389.94 -8,892.14 -3,901.92 6,018,980.88 529,562.38 0.00 8,892.14 3,389.27 -8,992.13 -3,900.80 6,018,880.90 529,563.95 0.00 8,992.13 3,388.60 -9,092.12 -3,899.68 6,018,780.93 529,565.52 0.00 9,092.12 3,387.94 -9,192.11 -3,898.56 6,018,680.95 529,567.09 0.00 9,192.11 3,387.27 -9,292.10 -3,897.44 6,018,580.97 529,568.66 0.00 9,292.10 3,386.60 -9,392.09 -3,896.32 6,018,481.00 529,570.23 0.00 9,392.09 3,385.93 -9,492.09 -3,895.20 6,018,381.02 529,571.80 0.00 9,492.09 3,385.27 -9,592.08 -3,894.08 6,018,281.05 529,573.37 0.00 9,592.08 3,385.00 -9,632.13 -3,893.63 6,018,241.00. 529,574.00 0.00 9,632.13 11/112019 3:20:30PM Page 6 COMPASS 5000.15 Build 91 HALLIBURTON Halliburton Standard Proposal Report Database: NORTH US + CANADA Local Co-ordinate Reference: Well Plan: MPU M-26 Company: Hilcorp Alaska, LLC TVD Reference: MPU M-26 Planned SH RKB @ 59.00usft Project: Milne Point MD Reference: MPU M-26 Planned SH RKB @ 59.00usft Site: M Pt Moose Pad North Reference: True Well: Plan: MPU M-26 Survey Calculation Method: Minimum Curvature Wellbore: MPU M-26 Design: MPU M-26 wp06a Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (°) (I (usft) (usft) (usft) (usft) (usft) M-26 wp06 Toe 0.00 0.00 3,444.00 -9,632.13 -3,893.63 6,018,241.00 529,574.00 plan hits target center Point M-26 wp06 Heel 0.00 0.00 3,524.00 -1,229.43 -3,845.86 6,026,643.00 529,584.00 plan hits target center Circle (radius 30.00) M-26 wp06 CP2 0.00 0.00 3,459.00 -7,392.78 -3,918.57 6,020,480.00 529,539.00 plan hits tarqet center Point M-26 wp06 CP1 0.00 0.00 3,514.00 -2,894.35 -3,903.35 6,024,978.00 529,534.00 plan hits tarqet center Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 6,535.47 3,524.00 9 5/8" x 12 1/4" 9-5/8 12-1/4 14,940.06 3,444.00 6 5/8" x 8 1/2" 6-5/8 8-1/2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 280.00 280.00 0.00 0.00 Start Dir 31/100' : 280' MD, 280'TVD 550.00 549.10 12.25 -14.60 Start Dir 40/100' : 550' MD, 549.1'TVD 1,884.88 1,622.13 168.86 -708.14 End Dir : 1884.88' MD, 1622.13' TVD 3,956.96 2,662.22 377.09 -2,488.13 Start Dir 40/100' : 3956.96' MD, 2662.22'TVD 6,185.47 3,493.50 -881.97 -3,816.93 End Dir : 6185.47' MD, 3493.5' TVD 6,535.47 3,524.00 -1,229.43 -3,845.86 Start Dir 40/100' : 6535.47' MD, 3524'TVD 6,692.71 3,530.04 -1,386.21 -3,854.95 End Dir : 6692.71' MD, 3530.04' TVD 8,142.91 3,515.01 -2,835.55 -3,902.56 Start Dir 41/100' : 8142.91' MD, 3515.017VD 8,223.18 3,513.61 -2,915.80 -3,903.32 End Dir : 8223.18' MD, 3513.61' TVD 12,700.51 3,459.00 -7,392.77 -3,918.57 Start Dir 4°/100' : 12700.51' MD, 3459'TVD 12,722.89 3,458.79 -7,415.15 -3,918.48 End Dir : 12722.89' MD, 3458.79' TVD 14,940.06 3,444.00 -9,632.13 -3,893.63 Total Depth : 14940.06' MD, 3444' TVD 11/112019 3:20:30PM Page 7 COMPASS 5000.15 Build 91 V J J N 7 O O u�u O O 'i YI N C QCO O 0 ii CLC'4 cl) CC� C L .0 Neto o oaf, dO � R c V °-2_2:A U M: O N �a — 3 04 in a=a ,m W 0 M 3 N Ca G v N 7 O O O O N C O 0 R fib N U dO � R c ■ U M: O N 3 04 in N CD N d M a O d '[f lx O v a N � � IC r ' O + r2 N r O O O N � a c � T c s O �tD N N r N G 'COD G .r_ ■i � � W � p � n _N 3 ■ig��`Umo ■i U cMy Y N Q ° arae= m c M uLL W cl) u i a N J 13 O fq a z m a c R «�. mat c n m Q V,T) 00 W O J ._ O O` N N Q L N a a N„ Q W S 3 J i o E a O o r c a� c CU m p o CU U O) � M= LL r J LO M (� N 'r V E R .. N(v � 0 ■� C. 1 r y N R 0 }J > Q DRi ` O °' c O co `o c. c. U Q R R N r U£ O - Q Z T- N w w C a •N U c C ° N d R V N y U U T" U U) cn CD > to z L0 I" Ix M� W J J Q I m CD (^ CL 3 CD N 51 G D a 1 CD N 1 D a L.4- ItO .y O v C Q r - N CD 7 O O CD Lq N 0 m m CD m 0 Q N m 3 w N A. C) a w U) m t � � fD N 'p o a E a 3 N G O a7 ` LL U U C H C m (a 0 a m C V U) a N 0 N n ami E 0 t U % 0 LO 0!(0 0 (L to a' o ° E M O •_ n C LAM O y M N Q 0, a v C a = m m N y C C C m m U w fn N Q: a o m 3 c 0 m CL V% N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N co m m m m N N N N N N m m m m m (o N N N N N N m m m m m m N N N N N N m <a m m m m N N N N N m m m m co aaaa a a a a a a a a a a a a a a a a a a a a a a a a c 0 •O C C C C C C `O `O C C `O C C N E O O '� O a) 'L O O O p O O O O m O p 0 0 O O `O O O m m m 0 m 0 c m 0 0 cO 0 () (a 0 0 m m c (0 m c m 0 0 m 0 0 m m E LL =a =° Q a s a m LL m a LL m a o R a m o a Q n Q Q n Q W Z` C 0 O N 0 O N Q) O N 0 O N 0 U N N O N a) a) N Q) O N N O- () m c) 0 ❑ U) C-5 (5 c) L) ❑ co 0 ❑ co 0 ❑ cn 0 ❑ U) c ❑ U) 0 ❑ co 0 ❑ cn E a) m a) m m m m m m m m a) m o m m m m N N Q C Q N N N C ') C Q N N N C Q, C Q. N N C -Q . C Q N N N C ) C Q _Q _Q N W U U W U U W U U W U U W U U W U U W U U W U U W U U W O CO (D r M (O m m O M O CO CO O M M O M M N 00 00 CO M (O M N W V` V co C) (D n (o m 0) co (O O co (O O M 'o r u7 N (O (O N V M 'o N co C O V M (O V r (O (` 10 N 10 N N (fl N N (0 N r M M M W O n m (D n r M 00 m (7) m �n O V O co (fl LO r O 0) (D 0) co V 0) co O 0) (D O 0) (D O (O n00 V N M r V (O (O V M0) M N n (D (O V (O V M a) U. r r r U 0 o 0' V m v c) C) (o o v o v o 000 o m V o m (n o O a) r (O o (M n _v r V 0 CD r (O r r U7 r V V V V r 0o V M V V L r M O (` (D (O N O N N O N N O N 00 CO V 00 Cl) V M Cl) 00 M CO N O a) N d N (O (O W U7 (O V V V V M co O (O V N N M (D m (O m (O N M (fl N M (D (O M O (O a0 N N r- N N (O (O co (O (O O N N (O N co N 7 M V (O (O (O (D (D (O O (O (O M (O (O M (O (O M (OM V N N m (CO (` V (O (O M CLC)) C (0 m (D (0 N N N O (0 (D r (D (D (` (D M r r O V O 00 N r O n a) O r n N N co 0) 0) V (O (O (O X) (O (D (O (O (D O O (D (O V N (O (O (D N S F Q a) N N N N N M a7 O n N N N r a0 r a0 N N N N N N r N N (O M M r M M W O �' d CO O -O co O M O O N O C) 0 C) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N a) M r- N I` r N r n N (` r N (` r N I- r- in lr l- it P- n r` r- n n r-� t V M r CO M t` CO oo CO CO M CO 00 CO 00 M CO M CO cl) CO CO M M M C. co (O (O co V co O m O c0 a) O M m o 00 (O c0 O (O 00 M (O co co u) o m N a) (O (D V V V V V V N M (D N M (D N co co N N (` N N (O N N u) N M a) 7 M (D r N (0 r V M O V N M V N CO V N M CO CO 0) O r n N CO M (O r EM t- CO co r' O r (O r W O (` N O r N O M ('M O N N m V V r M V =M (O (0 N N M n n n n n n N N .- r r (O r r o (` t - C , EY N M M N (V N t` M r r r r n N N N r r N N N N N N r N N N (O r r N r r r M M N M M r r r r r C N �o •O M O c0 O O N O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O CO I` N n n N r (` N r- r- N r- n N (` (` n n r r- I` n (` r (` n r V M CO M n CO CO S W CO 00 CO 00 c) oo co W M M M c0 co co c0 00 U)d M (O (O Co V co O W O W ;; O 00 m O W (O c0 O (O co co (O co 00 (O O m (D (D V V V V V V N co (O N co (O N M (D N N I-- N N (1) N N (O N M N ❑ � M 0 0 0 Y 1 1 U) U) U) Y Y Y !, T T L L L n r R O W W W O a) N CII N Q) 2 N N N N of 0� m m m m m Co 0 0 U) c/) U) c c c m a a a a a a0 CO CO 00 co co co _9 9 �_ Q Q Q N N N a) >� > m >� Y Y Y 0 0 0 d M co V V V (0 (O (D M 00 M > > > ❑ ❑ ❑ O 0 0 0 0 0 O O O r r r--- --- I� P- a g g g a a a a a a a- m m m U) CO U) m m m o 0 U) U) U) :D D:D D 7) D D D D D m m m m m 0) 3 a a a a a a a a a a a _o _o _o m m m a) �» Gc cG ___ N N N (!J (n (n "O O C) a a CV m m m m m m m N N 04 o o m O o 0 0 E Co M <r v v o o m w o a s aaaa m o 0 00 0o m a a a 0 O O m .a 0 0 0 0 0 0 0 o r r— r— r � � Y Y Y r r r ,, r Z ILf 222E2i2i ��22i 2i2i�� (n U) 4. > > > > > D D D > > D > > > > > > QQc- a) a) a) o 0 0 0 0 0 rn y aaaaa aaaaaa aaaaaa () a)(DU)U)U) ❑❑❑ U)U)U)t` n o N (n �G C N N N CO CO CO 2 Q) d y O CO co V V V (D (7 O N N CO 00 W M W M W U) U) (n U U (n U) (n U) 'Q E 00000 000r rr —r — — —r 0-QQQQQ ❑ 0 -fl -0 -aa m G 2i 2F 2i 2 2i 2i 2i 2i 2i 2i 2 Y Y Y Y Y Y Y Y Y 2 0 G. )»> � >> 7 DD DD» c c c c c c c c c Z » aaaaa aaaaaa aaaaaa m m m m m m m m m m m in U 2 2 2 2i :E 2i 7i �� 2i :2 2i 2 2 2i a a a E a a a s a a- a- �- m co O to N 1 D 5a G N 1 D a C CL I- 0 0 O O .N O C Q v N 7 O 0 0 N O =:) W a x R IC N d a E N t N CL o p p � 0. o () in C i V R a a � U a H '� 3 R y r y O ? U O Lo M U) a � � E O n CSI MM y M M d p (D U�� C m y c c c O a (n E CO E 2"E E� E 3 (n d U C `O cc M cc d LL U MY M E m = U E R y c w Dov C d p E R z 2 O m d E m z N N (n to (n (n N (n m In In (n (n (n (n N (n W (n (n U) N (n (n (n (n N (n N (n 0 to (n N N (n N (n (n N (n (n 0 (n N In (n (n (n (n (n (n (n (n m (n w 0 N (n m m m m m m m m m m m m m m m m m m m m m m m m m m m m m m mmmmmaa 0 -0 -0 -0 -aa_ aa_aan.n. aa_aaaa as aa- a c c 0 0 .0 0 0 .2 0 C C LL LL m m LL 4 N 0) a N 0 j5 Cn � ❑ Cn � (n U) C O C O U U w U U W U M M M (O W W M r O O W OO N V W O r O V (DLO O 1 r M Cl) O co LO rl-f� (O C) C) 0 M 0 0 O O -It V Cl) «7 (O r (O V O M of M U') r r (O CO f� (0 N N (O N N (O C C 0 0 o m .2 `o U m U U m U m nLL m LL En ❑ W ❑ (/j In m m o m U W U U W U M t` O M M co M W r r co (O r N N N W N 00 r (O O O 00 r M co co V C c m .° o m .2 o mCL LL M nLL ❑ � U Q � U CL C C N U N N U W CJ U W U c0 r- O co CO (O O r «7 m c0 0) (o (O r- 't r (O (O N V V N c � C mnLL CU ❑ (n U ❑ U)co co U U W U U W U co N (O 00 O O M (D (O (D 0) N 10 V' O W V' CO co N 00 (0 M r N N (O (O r c ` o O O O o U 6 UU U y a LL LL U U n U W U U U O O 0) W a0 co NM CO rl- (D O CO O M I- O O Cl) O O N 0 0 0 0 0C) 0 C) 0 0 C) O N V (D O V't (D V V N It V N (O (O M V V It V V O 7 (D O r M 00 CO W(D M M M C r CO (O CO M m W co O co co M O) (O COLO 7 (O r) (0 (O N O (O co O (O 00 O N O co (O Cl) N N C NN N (O N N N N co N N M N N m N N O) N M O (O Q) N r M V — CO (O O f� 00 M (O V cO M M (D M O (O N u) O O (O r- W (O r d' V N (O (D CO M r N r 0 (O v: M M r Nu? V OC) (O (O V V M r O) (O M r (O W N N W r r r- r r- r- (0 r r N M r r-- r- I --r f� n r N (O r (D O) 6) M tO (O r O O r r r O V r co M N (O (O (O r O N N r (O M r r r N r r r N N V r r O r r'T r r f m N IZ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O co rl- r r hr -w r r r r t` r r r r� r rl r r� r� I� r� r-: r� r-� r- t` r r r (q V m of m m of m m 00 Cl) co co cY) co ca Ce) C,) 00 Ce) c*i 00 Cl) Cl) m co co co co co tl- (n M (O W O O CO CO (O co to to 00 co (f) co M O 00 0) (O Co M u') Co O (O O O V M (D N N (D N N (O N N V N N (O N N (D N N rl- N N 00 N N O N Cl) 0) (O (() N r V CO r (D (O M M W V V O O MN N M W O) CO M M O D ol Cl) (O 00 O O) O (O O r O) OO (0 V V N M M O 0 0't O O CO O O 0) O O O Co O N O M (O O O M CO M (0 O) O) O (O M ao r O(O N N W (O M M to M CO O r- ""4- oO r r r r r r N N V' r r r r� r r r 0 N O o O o O O O M of M m M M M M (O M O (O M of (D N N (O N N LO r m m (0 O co co co co m n n n 3 3 3 3 3 3 m m m co a a a 2i 2i 2E C2>» O N N N 00 co 00 »> d a a (n N N N W d d a a a a a a a C C C C C C C a a a a m a m O O O O O O O O O O O O O O O O O O O O O co r r r r- r r- r r r r r f` r- r- r- r r rl- r- r r r (D V W M co 00 co Co co Cl) M c0 M M c0 Cl) M 00 M 00 co 00 M r- (O u7 00 (O U') co co (O 00 co (O N co (O M M (O 00 (f) (f) O O It Cl) CV (V A N N (O N N (O N N r N N M N N O N M O (f) (O r r N r M r CO C C C N N N O O O O O O 3 3 3 0 0 0 aa_a 333 N N N M co M N N N N N N N N N N cn m m m a a a coco N N N N N N:� 2i 2i D a a N NN :E 2i 2 CL W W N N N M M M N N N N N N 2 2E 2 2 2 7 D D D D D aa. n. an_a m Co m m m R a a a a a a M M C C C N N O O O cG (O(O (O c),333 L N N N a- d 2i M co D D N N 0- ❑ d O O N N N N N O O 2i 2i 2E D a D d d 2E 2i 2 M M t } } N N N N N �F :5 2i 2 2i D D D D D d a a a a- 0- 0- a_ 0- aaa_a d d d C C C N NN O O O cG O O O ��wCNNN (n N U N N N a a a D D D N N N a a a f) LO U') N N N a a a NN 2 2 2i N d d d V t ,t 0 (O 0 N N N N N N 2i�5 2i 2i 2i 2 D D D R D:D a a a a a a C C C C C C m m@ m m m aaaaaa- d a N N N N N N N N N N m m @ (n (n d a a a a U) (n (O O (D N N N N N N r r O O O O O O O 0 O Cl) co Cl) L5 LB co O N N N N N :E 2E :� :� :� D D D D D a.a- an.d C C C C C m m m m m a a a a a ZE 0 U E `m 0 Io CL cnN N N N N NN N N N N N N N N N N aaan.aa as c 0 .a c c c N E .o O o° 4° f6 7 U U Um U m U CO E m m LL m uL to li E m m m° N N N (D _a c a a U) U W U U W U W U O M (D O (D I: 2 � ID U �4 �2 (`(0 M N O V' 04 M c R c m (0 LO ui o 0 lC f6 Lo L L M N LL U -OO 0 0 CD (D I- O y V O V U M O O co co O V O Cl) V' N to 00 O (o I- 00 It 1� m C N N N (o N N LO r r- 00 00 Cl) (D V' 0) VO (D V V C0 r V' V' O0 d O O O to V V' (D V' LO In N$ (O N N � N W a� N � 3 CO p O 0 0 0 0 0 0 O O 00 Cl) Cl) 00 MCC) Cl) M In N M LO co O (O OD 3 O W N N N O N N (D t` t` d � •O N 0 f6 W 04 N 00 O) Il d p m = U co co V I- r O O O D c s 0) E m y CO T cO v 3 CO (o CL =Na C N O D d W 000000 C)o N m d t co 0') co N co 00 M co N t 0 a) (n 00 Cl) V) 00 0 (D 00 ' 2 tD d Q N N O N N co r r GGS N f0 a a. o>1 c Z N s N m m m a s 7 .� Q) U N Q Q m m O (D m m m d (Q c 3 0 (D LO (O (n Cl) U) m m a a a o d N LL n N L•V1 O _O O a a C ma 3m 3 in v7cn�� QQ Q N a d X O M U E (n (n (n (n U) (n U) (n LL O v)-0 m ❑LO❑ ❑ ❑ ❑ ❑ ❑ Z U-)LO(O CO CO CO 0) rn 0 0 0 0 0 0 0 0 Q D _ m M O . •N s c 3 > aaaan.a as O .y MN O O 2i 2 2E 2 2 2 2i G D .. to EN .. .. .. .. .. .. .. . . 0 a a)0 N m 0 0° N N 0 N 0 U Z O- O O O O O O O O c (e IC .d n n n n n n n n y y _ O O O O O o 0 O O En U)0 aaa`aa_a` a`a a O m (a U U) U) LO a 0 U Q Q m m V +� CO o O U U) U) 2i2E > + + 2 Y04 LL u' U) U>>+ >+ T> I I I co co co b O R c m N � a � T d 3 C co CD- 0 C) CD C) W CL n n 3 3 3 m o N N N N2 N 2E 2 � o E D D D Q N C cu c 3 o CL a) ro U O O co c 3 O O O9 N U j O LO O O M V' �_ 9 O U F N I- (O m O N C is O m o o @ N N T m N — a =o N m m °) o m c 0 c O O O N N N c — N N a O I- O O M o LD N O o U O L 3 ° c O N M O if @ 't- O N m LL M y a U (D N 2, m m U U Ill ° n N c a a) cu 3 rn U❑ N m N E N U m C II 76 m m o a N CL L O 3 o E p ° N a� a o U co m a� > O O O m C Q � _ @ m m� N W U (D U) ❑ U Q CD d _ eco cMo NO Q O y c ¢ O (O (O z WM C M C h X00 � Cn O LL LO U v� � 3 3 do $ zoInv LO- io / N / O N O N awry . � YKK 00 LL LL -U+❑Q � C C 12 YY www M Q M Q ai�E mmm O - » E j--- z 3M� v Fo o 70 o 'O comm �a Twww N Ln N W _ -- Oi�� aaaCD W y� ry W M�Lo Wp > V F-000 c w a? 2 GOA N n O N O p j Do N 0 > o2(666 n 0 � N � N '' l0 (n (0 N O y� 3 p O C N (o f0r- C6 o o_`m 'o a 4. (B _ N uo) N �1 _ - - N cu N a c N— O U) c .N O Lo N (D OfP') s Q 3 3 o fl O U O 0 W O c Qt 3 �, .n 3 v o ..... U Z ..... o 0 0 v a _ t j � 13 a O o o o.� o > o o co o 0 0 a o O N o 0 0 0 0 0 0 0 0 0 0 o 0 W N N O co (u j4sn uoileiedag aaluao Gr M o; aa}ua� N O V' P7 jo}oej N uoileiedag r O _ 0009) V J J N 7 O O O O Q N C c Cfl cc N d O N fi0 r- o 0 0 CD C4 , ♦ CL C C — ca as C 3 N d 0) ru 0 L m m m c ._L 0 a L L m Q m N 7 O O O O N C O N fi0 N O la C 3 N d d I[7 � d NO N M :i Q' M _a G> > W a. N f6 t r 7 oar E dd N N U U U E N m o O L ,a o LL a C M O V N C 13 O cnazdo ■� w ° c o `° N N C v d CO D � � O •� °tea '+ N a N r° v Q a , Q ? v.9 3 i cO6 O m =, i O 02 '� c 2 co 0, N 0! , O i0 O N O O V ■ °. O C L 6 N (0 O LO 4 rO N 0'U F 0 o S V Q z r N _ r d d f0 y, r_ e- U U� 5 ��m mmCD> - 0) ru 0 L m m m c ._L 0 a L L m Q m ii Z O Ix J J a i 0 CL 3 CN G Ca G 1 N 1 IL I- 0 0 ^0 N� .y <.i a R c 0 R a N N N N N N N N N N N N N N N N N N N N N a- aR a a- a aR aR a a 0- a c -O O co LO Lo Lo r W(O 0 y M r- rl r "pC `o `o c L N E O o O.o Q)R N R G. N 7 U U U (6 U c U U U @ U cm m E R LL LL R (CO (CO LL LL R M V CO M CO n n •F- p U U 0 p p U U p R R Q) U) U) E C C R 2 0 C C 2 (` R C c0 Cl) O M N 0 VO) N O U (n (n C O O CL C U U C ,n C U N N O. N U U lL C� C� C) W a a Y 0� Of O N r- M m N OCO CO r O F- (.L a U r (O N co Cl) CO CO N N N V CO CO CO CO N U++ C (O N V N R V O Cc') co M M N (A O O 7 6, LL U co, co, co o U w cn y O m m n O COO N n W c O 'D L_ U L O 9 a N c w E c 3 o O n 3 m U c O O u cn U N C o c 0 o m w O O m 7 O` O C O C N C - y N O O O (Up 3 (6 O R O R O N 7 v m R N C U N N U O O N C O Q' O R O N OU R C N N cu '� U U N N R C I I R E O LO O '-CO m O o .c m o O O O U C � R '@ U � O C �p Q U Q R R N @ O m a) - W U U7 U Q a 0 U -O O co LO Lo Lo r W(O y M r- rl r V N r (O L O 6) LO Cn LO N (O r- CO M N R G. N (D (D O O 6) Lq D) M (q M N N r- N -,t M r- N V' V y O 7 Q O�2 �2 �2 M M V CO M CO p� l:J C c0 Cl) O M N V' O Cl) N co o.2 N (O W M O M N D It V) M V 61 LO V' � V co co r O. N V' M (O V) U0 (o CO O O m w Qv r r N N 7 (O � r- r (O r r- U')p d V O V' V' V V' Cl V- V' N C O L (O O (O LO (O O O OV R O N Q y Cl) V' M co O i0 C W M CA M V M M to O (fl O O d R ) a (D V V V V (o W O O a) N pp R m N r- co O O LO M r O (O M N N V Ct r- t` O O R d O S U CO O r COCOr r-- (O u CL O. c 3 m C ,�' Em U) M O N V- co O co O (M co (ol�000 In d C N 7 r 0 O N N � Q R R co d _C. CO (o (O n Q n O= W f� CO r- n r co r- r (n 3 3 3 . n R L V' O . V' 'V' . O V' V' N CO co O L O G^, L O (O CO Cl) (O O O O V' co N N N cD N O N Lq� oc 60i a Gi (( O 2i 2 2 N a y Q a (O V co m m R d r2 a a a- :3 p E 2i22 p IL - a? s c fl Z (� O N C V d d c c c 0 0 0 m>> o o 3 N Q � C1N N R R R C) O O O O CO O O O y d O O O Or Q 3 3 3 0 0 0 ~ (o v CL N N N N R O 47 O O Co Fo CO ow N �G o LL LL a a» > in 0 C N d m 't V' a a a N N�� N N olc:::"0 r 0 0 R c0 C L M C2 M O O M O Lo L Q C) O Cl) >. N O R y LO i0 _O to O d O V N N N O O LL .% E (n (n (n U) U) U)CL O �� IL z a a a � D D D Q v E d N N a a i a a 0 0 0 M - C LO Co Oo N N N N N Co Oo L L M N N p (p .y (ON O 0 2i 2i 2E 2i :t 2i 2i� 2i 2i CL E N o �aa=n�a da ci G ? R m Q m m m N N N Q V C 'O C R R Z y E w+ CL C C C C C O O O c c n n D- U) U) R Q' IX r O R R R R R R R 0 0 0 (D c v�v a- o- aaa_a`n`_ o U w cn y O m m n O COO N n W c O 'D L_ U L O 9 a N c w E c 3 o O n 3 m U c O O u cn U N C o c 0 o m w O O m 7 O` O C O C N C - y N O O O (Up 3 (6 O R O R O N 7 v m R N C U N N U O O N C O Q' O R O N OU R C N N cu '� U U N N R C I I R E O LO O '-CO m O o .c m o O O O U C � R '@ U � O C �p Q U Q R R N @ O m a) - W U U7 U Q a 0 U o Cp Co N 0 O y� 3 O dco co n- O 0 camera 2a2� ii d= m c G7 '- p a` 2 O a- iL N O N N 0 co J 5 rn a n M C s� N N y u I z — p X k 5 7O v o O o h u O M O z O o �� .o O 3 I N IL N ap N w ~ o 2 o Q «� ar Q d a z �M �C'M u M� 0 N C F O O d �o Q m O O O 3p O O M > Fvv I o ti o zo o Cp Co N 0 O y� 3 O dco co n- O 0 camera 2a2� ii d= m c G7 '- p a` 2 O a- iL N O N N 0 co J 0 0 0 0 0 0 0 O O O o 0 0 0 0 0 0 0 0 0 0 T N N O co M (u.i4sn 00.09) uoi}ejedag ailuao of ai;ua3 O M C N I — 00 o O M O O 3 I N IL N m M 0 N O N O M I o N O v N i N D) N j O c a O v > Q U) N cn r Q 0 c O 42 O 0 d - o U U) O a - W 0 O Z N O C) '�. O Q O .0 Q 0 N � O Cl) cu rn m I o N 0 0 rn 0 o j o 0 0 N r N 0 0 0 0 0 0 0 0 O O O o 0 0 0 0 0 0 0 0 0 0 T N N O co M (u.i4sn 00.09) uoi}ejedag ailuao of ai;ua3 0 0 0 o O 0 0 o O o M N - O io;oezj uoijejedag O N 0 _ ? v 0 _ N r -O M -(0 N 0 N O C_ U) Z3 o C -N O r C) C) Q o N o � a N O � OC G 0 m 0 0 'o rn _0 co U) ID .0 r 0 N O C I o M O 3 N IL N I v N i D) j c a o a to v > Q U) N cn Q 0 c O O O 0 d - o U to O O a - W 0 O Z 0 0 0 o O 0 0 o O o M N - O io;oezj uoijejedag O N 0 _ ? v 0 _ N r -O M -(0 N 0 N O C_ U) Z3 o C -N O r C) C) Q o N o � a N O � OC G 0 m 0 0 'o rn _0 co U) ID .0 r 0 N TRANSMITTAL LETTER CHECKLIST WELL NAME: / A_L. PTD:Z-1')--1_S_7 Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional FIELD: POOL: _� /� I- d �=r1 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--- 50-- from 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 cauJ t and 10' sam le 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. (C, ompan Name) must contact the AOGCC to obtain advance approval of such water wellro am. ,.testing 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 da s after com letion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 _ Well Name: MILNE PT UNIT M-26 Program DEV Well bore seg El PTD#: 2191570 Company Hilcorp Alaska LLC Initial Class/Type DEV/PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate_ _ _ _ - - - - - - - - - - - - - - - - - -- - . Yes - - - - - - - Surface Location lies within ADL9025514, Portion of Well Passes Thru ADL0355Q23;- - - - - 3 Unique well name and number _ _ - - - - - - - - - _ _ _ - - - - - - Yes - - - - - - Top -Prod Int _& TD he within_ADL0025514_. 4 Well located ina- - - - - - - - - - - - - - - - - - - - - - ---- ---------- Yes - - - - - Milne Point Schrader Bluff_ Oil Pool (525140), governed by CO 477, amended by CO 477.05. 5 Well located proper distance from drilling unit_bounda y- - - - - - - - - - - - - - - - - - - - - - - - Yes -- - - - - - CO 477.05 specifies:_ "There are no restrictions as to well Spacing except that no pay shall - 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - be opened -in a well closer than 500 feet from the exterior boundary of the affected area." - - - - - - - - - - - - - - - 7 Sufficient acreage available in drilling unit - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - Yes - - - - - - - As planned, well conforms to spacing requirements, - - - _ _ - - - - - - - - - -------- 8 If deviated, is wellbore plat _included - - - - - - - - - - - - - - - - - - - -- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Operator only affected party - - - - - - - - - - - - - - - - Yes ------------- - -------- - 10 Operator has -appropriate bond in force - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit_can be issued without conservation order_ - - - - - - - - - - - - - - - - - - - - - Yes - - - . _ - - ------------------------------- - - - --- Appr Date 12 Permit_can be issued without administrative -approval - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ - . - - _ - - - - - - - - - - - - - - - - - - 13 Can permit be approved before 15 -day wait_ Yes SFD 11/13/2019 _ _ _ - - - - - - - - - - - - - - - - - - - _ - - - - _ _ _ - _ 14 Well located within area and strata authorized by_ Injection Order # (put 10# in_comments)_(For_ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - - - _ _ - - - - - - - - - - 15 All wells -within 1Amile-area-of review identified (For service well only) - - - - - - - - - - - - - - - NA_ - _ _ - _ - - - - - - - - - - - - _ - - _ _ _ - _ _ - _ - _ - - _ - - - - - - 16 Pre -produced injector: duration of pre production less than 3 months -(For service well only) - _ NA- - - - - - - - - - - - - - - - - - - - - --------------------------- 17 Nonconven. gas conforms to AS31.05.030([.1_.A),(j.2.A-D) - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ _ _ _ - - - - - - - - 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ _ _ _ 29° con_ductor_set_ - - - - - - - - - - - - - - _ _ - _ - - - _ - - - Engineering 19 Surface_casing_protects all known USDWs - - - - - - - _ _ _ - - - NA_ - - - - - - - - 20 CMT_vol_ adequate- to circulate -on conductor & surf_csg Yes - - - - - - - 9 5/8" casing will use ES at 2500 ft to-do 2 stage cement. - - - - - - - - - - 21 CMT_ vol_ adequate -to tie-in long string to surf csg- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ _ - - - - - - - - - . - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT_will cover all known productive horizons_ - - - - - - - - - - - - - - - - - Yes - _ _ _ Lateral will_utilize slotted_liner. 6 5/8" OD- - 23 Casing designs adequate for C,_T, B &_permafrost- - - - - - Yes - - - - - _ _ BTC ca are supplied._ - - - - - - - - - - - - - - - -- 24 Adequate tank -- - age -or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - Both rigs -have steel tanks, - _ - ----------------------- 25 -If-a- re -drill, has -a 10403 for abandonment been approved - _ - - . - - - - - - - - - - - - - - NA- _ _ - _ _ - - grassroots -well --- - _ _ _ _ - - - - - - - - - - - - - - 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - NO issuues with collision - - _ - - _ _ _ - - 27 If_diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - _ Doyon 14 haS_16inch diverter. Will verify- placement based on Innovation_ status. - - - - Appr Date 28 Drilling fluid program schematic -& equip listadectuabe_ - - _ - - - - - - - - - Yes - - - - - - _ max form pressure =_1540 psi (8.5 ppg EMW) WIiI drill with8.9-9.5ppg mud. MPD _also _ - - - - _ GLS 11/14/2019 29 BOPEs,-do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes . - _ _ - - - Innovation has 13 5/8"_BOPE_ 5000 psi WP_ - - - - - - - - - - - - - - - - - - - - - _ - - - - _ - - 30 ROPE_press rating appropriate; test to -(put psig in comments)- - - - - - - - - - Yes - - - - - - - MASP= 1199 psi _will test BOPS to 3000psi- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 31 Choke_ manifold compliesw/API_RP-53(May 84)- - - -- - -- - - - - - - - - - - - - - - - - - - - - Yes - - - -- - - - - - - - - --------------- 32 Work will occur without operation shutdown_ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ - - - - - - - Doyon 14 drilling surf .. -ace hole.In_nov_ation rig_drilling production- _ - - - - - - - - - - - - - - _ - - - - - - - - - - - 33 Is presence_ of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- Yes H2S on_ pad --- - - - - - - - 34 Me chanical_condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - NA_ - - - - - _ _ _ _ - - - - - - - - - - - - - - _ _ _ - - - - _ _ _ _ _ _ - - _ - - - - - _ - - - - - - - - - - - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - H2S not anticipated from drilling of offset wells; however, rig will have H2S sensors and alarms._ _ - - - - - - - - - - Geology 36 Data_presented onoverpressure zones p - _ potential over - - - - - - - - - - - - - - - - Yes - - - - - - - Gas hydrates not expected from drilling -of offset wells. However, mitigation -measures are discussed_in - - - - - - - Appr Date 37 Seismicanalysis shallow gas_zones- - - - - - - - - - - - - - - - - _ _ _ _ _ "Anticipated NA- _ - - - - - - Drilling Hazards" section. Abnormal pressure has been encountered in -M -Pad wells - _ - _ - - - - SFD 11/13/2019 38 Seabed condition survey -0f off --shore) - - - - - - - - - - - - - - - - - - NA_ - - - - due to nearby injection. Managed Pressure Drilling will be used to monitor and control pressure. - - - - - - - - - - - 39 Contact name/phone for weekly_ progress reports [exploratory only] - - - - - - - - - - - - - - - - - NA_ - - - - - - - Other_ potential drilling hazards discussed along with mitigation measures on pages 49-51._ Geologic Engineering Public To date,10 production and injection wells have been drilled successfully from MPU Moose Pad. Doyon 14 rig will be used to drill Date: Date Date Commissioner: Commissioner: Commi oner and case the surface hole. Hilcorp's Innovations rig will be used to drill and complete the production interval. SFD